UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM
(Mark One)
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For the fiscal year ended
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Date of event requiring this shell company report …………………………..
Commission file number:
(Exact name of Registrant as specified in its charter)
N/A
(Translation of Registrant’s name into English)
(Jurisdiction of incorporation or organization)
Tel. (57) 310 315 8600
(Address of principal executive )
Investor Relations
Tel. (
(Name, Telephone, E-Mail and/or Facsimile number and Address of Company Contact Person)
Securities registered or to be registered pursuant to Section 12(b) of the Act.
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8.625% Notes due 2029 |
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EC29 |
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New York Stock Exchange |
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6.875% Notes due 2030 |
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EC30 |
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4.625% Notes due 2031 |
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EC31 |
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New York Stock Exchange |
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7.750% Notes due 2032 |
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EC32 |
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8.875% Notes due 2033 |
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EC33 |
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New York Stock Exchange |
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8.375% Notes due 2036 |
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EC36 |
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New York Stock Exchange |
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7.375% Notes due 2043 |
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EC43 |
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New York Stock Exchange |
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5.875% Notes due 2045 |
EC45 |
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New York Stock Exchange |
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5.875% Bonds due 2051 |
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EC51 |
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New York Stock Exchange |
Securities registered or to be registered pursuant to Section 12(g) of the Act: None
Securities for which there is a reporting obligation pursuant to Section 15(d) of the Act: None
Indicate the number of outstanding shares of each of the issuer’s classes of capital or common stock as of the close of the period covered by the annual report.
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.
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If this report is an annual or transition report, indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934.
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Yes
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Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.
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Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).
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Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or an emerging growth company. See definition of “large accelerated filer,” “accelerated filer,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
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Accelerated filer ◻ |
Non-accelerated filer ◻ |
Emerging growth company
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If an emerging growth company that prepares its financial statements in accordance with U.S. GAAP, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards† provided pursuant to Section 13(a) of the Exchange Act. ◻
† The term “new or revised financial accounting standard” refers to any update issued by the Financial Accounting Standards Board to its Accounting Standards Codification after April 5, 2012.
Indicate by check mark whether the registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report.
If securities are registered pursuant to Section 12(b) of the Act, indicate by check mark whether the financial statements of the registrant included in the filing reflect the correction of an error to previously issued financial statements.
Indicate by check mark whether any of those error corrections are restatements that required a recovery analysis of incentive based compensation received by any of the registrant’s executive officers during the relevant recovery period pursuant to §240.10D-1(b). ☐
Indicate by check mark which basis of accounting the registrant has used to prepare the financial statements included in this filing:
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◻ U.S. GAAP |
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◻ Other |
If “Other” has been checked in response to the previous question, indicate by check mark which financial statement item the registrant has elected to follow:
◻ Item 17 ◻ Item 18
If this is an annual report, indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
Table of Contents
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3.5.2.1.1 Ecopetrol S.A.’s Production Activities in Colombia |
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3.5.2.1.2 Ecopetrol S.A.’s Affiliates and Subsidiaries’ Production Activities in Colombia |
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3.8.2.2 Electricity Transmission Activities Outside Colombia |
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ii
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5.3.1 Integrated Risk Management System and Internal Control System |
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F-1 |
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249 |
iv
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1. |
Introduction |
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1.1 |
About This Annual Report |
We file our Annual Report on Form 20-F and other information with the U.S. Securities and Exchange Commission.
We file reports, including annual reports on Form 20-F, and other information with the SEC pursuant to the rules and regulations of the SEC that apply to foreign private issuers. The materials included in this annual report on Form 20-F may be downloaded at the SEC’s website: http://www.sec.gov. Any filings we make are also available to the public over the Internet at the SEC’s website at www.sec.gov and at our website at www.ecopetrol.com.co. These URLs are intended to be inactive textual references only. They are not intended to be active hyperlinks to such websites. The information on our website, which might be accessible through a hyperlink resulting from such URL, is not and shall not be deemed to be incorporated into this annual report.
Unless the context otherwise requires, the terms “Ecopetrol”, “we”, “us”, “our”, “Ecopetrol Group”, “Group” or the “Company” are used in this annual report to refer to Ecopetrol S.A. and its subsidiaries on a consolidated basis.
For purposes of the section Business Overview—Exploration and Production , “we” refers to Ecopetrol S.A., its subsidiaries and the partnerships in which Ecopetrol has an interest.
References to the “Nation” or “Colombia” in this annual report relate to the Republic of Colombia, our controlling shareholder. References made to the Colombian Government or the “Government” correspond to the executive branch including the President of Colombia, the ministries, and other government agencies responsible for regulating our business.
Our consolidated financial statements for the years ended December 31, 2022, 2023, and 2024 were prepared in accordance with IFRS accounting standards as issued by IASB. References in this annual report to IFRS mean IFRS as issued by the IASB.
IFRS differs in certain significant aspects from the current reporting standards as in effect in Colombia (“Colombian IFRS”), which is the accounting standard we use for local reporting purposes. As a result, our financial information presented under IFRS is not directly comparable to our financial information presented under Colombian IFRS. For a description of the differences between Colombian IFRS and IFRS, see section Financial Review—Summary of Differences between Internal Reporting Policies (Colombian IFRS) and IFRS .
Our consolidated financial statements were consolidated line by line and all transactions and balances among subsidiaries have been eliminated. These financial statements include the financial results of all subsidiary companies controlled, directly or indirectly, by Ecopetrol S.A. See Exhibit 1 – Consolidated subsidiaries, associates, and joint ventures, to our consolidated financial statements included in this annual report .
In this annual report, references to “USD” or “U.S. dollars” are to United States dollars and references to “COP” “Colombian Peso” or “Colombian Pesos” are to Colombian Pesos, the Ecopetrol Group’s functional and presentation currency under which we prepare our consolidated financial statements. This annual report translates certain Colombian Peso amounts into U.S. dollars at specified rates solely for the convenience of the reader. Unless otherwise indicated, such Colombian Peso amounts have been translated at the rate of COP 4,073.75 per USD 1.00, which corresponds to the average Tasa Representativa del Mercado (TRM), or Representative Market Exchange Rate, for 2024. Such conversion should not be construed as a representation that the Colombian Peso amounts correspond to, or have been or could be converted into, U.S. dollars at that rate or any other rate. On March 31, 2025, the Representative Market Exchange Rate was COP 4,192.57 per USD 1.00. Certain figures shown in this annual report have been subject to rounding adjustments, and, accordingly, certain totals may therefore not precisely equal the sum of the numbers presented. In this annual report, a billion is equal to one with nine zeros.
In this annual report, we use unit measures like: “bpd” (barrels per day), “boepd” (barrels of oil equivalent per day), “mbd” (thousand barrels day), “mboed” (thousand barrels of oil equivalent day), “mboe” (thousand barrels of oil equivalent), “mmboe” (million barrels of oil equivalent), “mmbd” (million barrels per day) and “mmb” (million barrels).
1
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1.2 |
Forward-looking Statements |
This annual report on Form 20-F contains forward-looking statements within the meaning of the safe harbor provisions of the U.S. Private Securities Litigation Reform Act of 1995. These statements are not based on historical facts and reflect our expectations for future events and results. Most facts are uncertain because of their nature. Words such as “anticipate”, “believe”, “could”, “estimate”, “expect”, “should”, “plan”, “potential”, “predict”, “prognosticate”, “project”, “target”, “achieve” and “intend”, among other similar expressions, are understood as forward-looking statements. We have made forward-looking statements that address, among other things:
| ● | changes in international crude oil and natural gas prices; |
| ● | our exploration and production activities, including drilling; and import and export activities; |
| ● | our liquidity, cash flow, and sources of funding; |
| ● | the results of our electric power transmission and toll roads activities through our subsidiary, Interconexión Eléctrica S.A. (“ISA”); |
| ● | our projected and targeted capital expenditures and other cost commitments and revenues; and |
| ● | dates by which certain areas will be developed or will come on-stream. |
Our forward-looking statements and sensitivity analysis are not guarantees of future performance and are subject to assumptions that may prove incorrect and to risks and uncertainties that are difficult to predict. Actual results could differ materially from those expressed or forecasted in any forward-looking statements as a result of a variety of factors. These factors may include, but are not limited to, the following:
| ● | future growth and development of the energy industry and its transition into lower carbon sources of energy; |
| ● | general economic and business conditions, including increased and prolonged inflation in Colombia and worldwide, volatility in crude oil and other commodity prices, refining margins and prevailing exchange rates; |
| ● | competition; |
| ● | our ability to obtain financing; |
| ● | our ability to find, acquire or gain access to additional reserves and our ability to develop existing reserves; |
| ● | uncertainties inherent in making estimates of our reserves; |
| ● | the modification, adjustment or reduction of the tariffs, rates or fees charged by the electricity transmission and transport businesses in the countries where they operate; |
| ● | significant political, economic and social developments in Colombia and other countries where we do business; |
| ● | the impact of tariffs, trade barriers and other restrictions imposed on global trade; |
| ● | natural disasters, pandemics and other public health events; |
| ● | the continuing Russian invasion of Ukraine and Israel - Hamas conflict; |
| ● | other military operations, terrorist acts, wars or embargoes; |
| ● | regulatory developments, including regulations related to climate change and cybersecurity; |
2
| ● | receipt and maintenance of government approvals and licenses; |
| ● | technical difficulties; and |
| ● | other factors discussed in section Risk Review—Risk Factors of this document as “Risk Factors.” |
All forward-looking statements attributed to us are qualified in their entirety by this cautionary statement. We undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information or for any other reason. Accordingly, readers should not place undue reliance on forward-looking statements.
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1.3 |
Selected Operating Data |
The following table sets forth, for the periods and at the dates indicated, certain key operating data.
Table 1 – Selected Operating Data
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Operating Information |
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2024 |
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2023 |
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2022 |
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2021 |
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2020 |
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Oil and gas production (mboed) |
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745.8 |
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736.6 |
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709.5 |
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679.0 |
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697.0 |
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Proved oil and gas reserves (mmboe) (1) |
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1,893 |
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1,883 |
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2,011 |
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2,002 |
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1,770 |
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Exploratory wells (2)(3) |
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16 |
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26 |
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29 |
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16 |
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18 |
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Refinery throughput (bpd) (4) |
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416,879 |
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422,623 |
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360,451 |
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355,895 |
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322,038 |
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1P Reserves replacement ratio |
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104 |
% |
48 |
% |
104 |
% |
200 |
% |
48 |
% |
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Transmission Lines (km) |
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49,677 |
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49,426 |
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48,766 |
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48,330 |
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47,358 |
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(1) |
Include natural gas royalties and exclude crude oil royalties. |
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(2) |
Gross exploratory wells. |
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(3) |
The table does not include stratigraphic wells, although they are considered exploratory. These wells do not come into production, and are subsequently plugged and abandoned after the relevant study is completed. The table also includes wells drilled by partners at sole risk. |
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(4) |
Includes the Barrancabermeja, Cartagena, Apiay and Orito refineries. |
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2. |
Strategy and Market Overview |
Our consolidated financial results for 2024 reflect the cumulative impact of a crude oil price that exceeded our initial expectations. In our investment plan for 2024, we forecasted a Brent Crude oil price of USD 75 per barrel for the year, while the actual average price stood at USD 79.84 per barrel, a decrease of USD 2.33 per barrel compared to 2023. This higher-than-expected price was due to (i) a volatile global crude market, shaped by the steady growth in supply from non-OPEC+ countries and subdued demand, and (ii) to weaker-than-anticipated consumption in China and the influence of geopolitical factors. Despite the overall increase in 2024, Brent oil prices averaged lower than in 2023, reflecting a market shift towards supply-side dominance.
On the demand front, global oil consumption grew by one million barrels per day (“mmbd”) in 2024, below the trend rate of 1.2 mmbd over five years preceding the pandemic (2015-2019). Notably, while the U.S. economy exceeded expectations for a second consecutive year, with robust growth, China’s oil demand slowed significantly in 2024. Given that China accounted for nearly 50% of global oil demand growth over the past two decades, this slowdown weighed heavily on the worldwide demand balance. However, strong demand growth in emerging markets, particularly in Asia-Pacific, partially offset this weakness. Meanwhile, demand in OECD countries showed minimal growth, reflecting a manufacturing sector that remained in contraction throughout the year.
On the supply side, OPEC and its allies (OPEC+), including Russia, maintained their production quotas throughout the year, prioritizing price stability through disciplined output cuts. By year-end, OPEC+ supply was 0.7 mmbd lower than in 2023, reflecting improved compliance among member countries. These cuts helped counterbalance the increasing supply from non-OPEC+ countries (excluding Russia), which decreased by 1.4 mmbd over the year. As a result, global crude inventories remained essentially unchanged compared to the beginning of 2024. The expansion of non-OPEC+ supply was primarily driven by the U.S. production of 0.3 mmbd. However, non-OPEC+ supply growth fell short of market expectations made at the beginning of the year, highlighting a more constrained expansion than anticipated (1.4 mmbd versus the 2.5 mmbd forecast in January). Overall, the market achieved better balance by the end of 2024, driven by a combination of disciplined output reductions by OPEC+ and the moderated growth of non-OPEC+ supply. The graph below sets forth the oil demand and supply balance compared against the evolution of the Brent price as of the periods indicated.
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Graph 1 – Supply/Demand Balance vs ICE Brent Price Evolution
Source: SP Global Commodity Insights, Bloomberg
In the latter part of 2024, with the U.S. economy stabilizing, inflation moderating in developed markets, and major economies initiating interest rate cuts, signs of demand recovery emerged. Additionally, China’s economy rebounded, boosting market sentiment. These developments prompted the International Monetary Fund (IMF) to maintain the forecast global economic growth of 3.2% for 2024, with advanced economies growing at 1.8% and emerging market and developing economies at 4.2%.
Although international oil prices and global demand and supply dynamics are significant factors affecting our business and financial condition, Colombia’s local economic factors have also influenced, and will continue to affect our performance, given that we conduct most of our business in Colombia.
The Colombian economy, as measured by real GDP, grew at a rate of 1.7% in 2024, one of the lowest in the region, but exhibiting a much faster economy as compared to the 0.6% growth rate in 2023. In 2024, GDP growth rate was mainly driven by (i) a small increase in private consumption, which expanded at a rate of 1.6%, and (ii) a decrease in the unemployment rate to 9.1%, which was 0.89 percentage points lower compared to 2023 and positively impacted by a growth of investment into the country. Investment spending also contributed favorable to GDP, with an increase in gross capital formation in annual terms of 3.0% in 2024. In contrast, the external sector contributed negatively to GDP growth, with imports increasing by 4.2% and exports growing by 2.0%, resulting in an increase in the current account deficit.
Under current Colombian regulations, depending on the price of fuels in the international markets, participants in the Colombian fuel market either contribute to or receive payments from the Fuel Price Stabilization Fund (“FEPC” for its acronym in Spanish), a fund managed by the MHCP to attenuate, in the domestic market, the impact of fluctuations of fuel prices in international markets. Moreover, the decrease in the difference between gasoline and diesel parity prices with those of domestic prices due to factors such as Brent price, gasoline and diesel cracks and the exchange rate, has resulted in a decrease in the amounts owed by FEPC to Ecopetrol. See “ Regulation Concerning Production and Prices—Fuel Price Stabilization Fund (FEPC) ”. On March 22, 2024, the Annual Shareholders’ Meeting announced a dividend per share of COP 312. The dividend amount declared by the Company for the Government of Colombia (the “Government”) as majority shareholder was COP 11.35 trillion. This dividend was offset against the 2024 FEPC receivables from the Government. As of December 31, 2024, the cumulative balance of the FEPC account receivable was COP 7.6 trillion, accrued in 2024, to be paid in 2025.
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2.1 |
Our Corporate Strategy |
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2.1.1 |
2040 Strategy: Energy That Transforms |
On February 8, 2022, the Ecopetrol Group published its long-term strategy (the “2040 Strategy”), also referred to as “Energy That Transforms”, being the first company in the oil and gas industry in Latin America to disclose a roadmap for the next 20 years. The strategy aims to address comprehensively current environmental, social, and governance priorities, while maintaining our focus on generating sustainable value for all our stakeholders. The objective of this long-term strategy is to consolidate an agile and dynamic organization that promptly adapts to the changes faced by the energy industry.
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“Energy That Transforms” is designed to position the Ecopetrol Group as an integrated energy group, leader in Latin America in energy diversification, that participates in all segments of the hydrocarbon chain (upstream, midstream, downstream and commercialization) as well as energy infrastructure, with the ambition to diversify into low-emission businesses that allow us to continue reducing our carbon footprint and achieve a 55% reduction in methane emissions by 2030, a net-zero carbon emissions (scopes 1 and 2) and a 50% reduction in total emissions (scopes 1, 2 and 3) by 2050. This strategy comprises four strategic pillars: (i) Grow with the Energy Transition, (ii) Generate Value through Technology, Environmental, Social and Governance (“TESG”), (iii) Cutting-edge Knowledge, and (iv) Competitive Returns. The strategy is based on a short-term Brent price of USD 75/Bl and a long-term oil price of USD 55/Bl.
In addition, on September 11, 2023, Ecopetrol announced certain adjustments to its 2040 Strategy initially presented in February 2022. Such adjustments were approved by the Board of Directors of the Company and pertain to the following aspects of the strategy: (1) the new strategic focus of the Caribbean offshore lever is to maximize gas potential in the Colombian Caribbean; (2) unconventional hydrocarbon exploration activities will not be pursued in Colombia; and (3) the previously defined strategic objective of “energy efficiency” has been replaced by optimization of the internal consumption of energy by 25 petajoules (“PJ”) for the period 2018-2030.
The replacement of the strategic objective of “energy efficiency” has impacted the “Generate Value through TESG” and “Grow with the Energy Transition” pillars of the Company. All other elements of the 2040 Strategy which were announced to the market in February 2022 remain unchanged. The long-term strategy reaffirms our commitment to a just and equitable energy transition, emphasizing portfolio diversification while preserving the integrity and value of our traditional business. Additionally, our focus remains on strict capital discipline to ensure profitable and sustainable growth in our business lines and the creation of value for all our stakeholders.
Although the Company has not yet updated its operating and financial reporting model to the 2040 Strategy, some progress made in relation to the 2040 Strategy includes (i) changes in the management structure of the upstream subsegment, which belongs to the exploration and production segment (see Ecopetrol S.A.’s Production Activities in Colombia ), (ii) statutory reforms to include guiding principles of the 2040 Strategy, (iii) new business line committees and a strategic committee aligned to the 2040 Strategy (see – Section 7 – Corporate Governance ).
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2.1.1.1 |
Grow with the Energy Transition |
The first pillar seeks to maximize the life and value of the hydrocarbon portfolio, while advancing in the decarbonization and diversification strategy of low-emission businesses. This pillar aims to maintain Ecopetrol Group’s competitiveness in the integrated hydrocarbon value chain and increasing gas supply, offshore exploration, and enhanced recovery, thereby strengthening our traditional businesses with the latest technology and innovations to have more sustainable processes and maximize the value of reserves and future barrels.
On average, we expect to invest between COP 20 and COP 30 trillion annually by 2040. In production, investment is expected to be focused on enhanced recovery technologies, Caribbean offshore gas developments, and protecting the base production curve by improving the natural decline of production fields. In line with international best practices, the valuation for these projects includes greenhouse gas emissions cost under the CO2 shadow price methodology, with a price curve that begins at 40 USD/tCO 2 e today and reaches 50 USD/tCO 2 e by 2030.
In the upstream segment, we expect to maintain our production between 700 and 750 thousand barrels of oil equivalent per day (“mboed”) through 2040. For gas, production is expected to increase, along with new commercialization options, with the long-term expectation of business to grow its stake in relative EBITDA generation.
In the midstream segment, the long-term objectives include capturing over 90% share of the Colombian hydrocarbon transport market, among others.
The downstream segment seeks to: (i) increase the margin of existing refineries’ assets; (ii) maximize the polypropylene margin, and (iii) assess options for diversifying into petrochemicals and on green fuels.
Additionally, the value of the various products is expected to be strengthened through commercial strategies which seek to diversify heavy crude destinations, leverage the advantage in quality and reliability of supply and integrate customer-based logistics and recipes.
5
The diversification towards low-emission businesses in the long term contemplates a gradual incursion into emerging businesses that seek to mitigate the effects of climate change, such as the production of low-carbon hydrogen as an energy carrier, Carbon Capture, Utilization, and Storage (“CCUS”), and Natural Climate Solutions (NCS). The value proposition includes diversifying into low-emission businesses, for which more than USD 183 million are expected to be invested over the next three years, in green hydrogen projects, CCUS and in renewables incorporation.
ISA, a leader in the electric power transmission business, responds competitively to the challenges of decarbonization and diversification, meeting new demands in the context of the energy transition.
In the electric power transmission and road concessions segment, the aim is to continue the growth trajectory in both new and existing geographies, leveraging ISA’s strategic leadership position in the power transmission business in Latin America.
On March 13, 2025, ISA launched its 2040 Strategy “Energy that brings life to the transition” intending to establish itself as a leading energy transmission company on the continent, with investments in new electric energy businesses. In this new strategic cycle, the goal is to maintain the relevance of the transmission business and seize opportunities in new businesses derived from the energy transition, complementing the core business.
For this new strategic cycle, the focus will be on: consolidating the core business, and accelerating new energy businesses (i.e. energy solutions, and storage). Additionally, the strategy includes expanding into new locations, making a positive contribution to communities and nature, and growing selectively and strategically in the roads business. By 2040, ISA intends to have invested between USD 28 billion and USD 33 billion across the continent, focusing on: (i) consolidating electric energy transmission in Latin America (67%), (ii) deploying/accelerating new electric energy businesses (23%), (iii) growing selectively/strategically in the toll roads business (10%), (iv) expanding into new geographies, (v) doubling 2024 EBITDA COP 0.7 trillion, (vi) actively managing its portfolio of toll roads and concessions transmission lines, and (vii) positively contributing to the development of talent, communities, and nature.
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2.1.1.2 |
Generate Value through TESG |
This pillar seeks to strengthen transparent and ethical relations with our stakeholders, applying high standards of corporate governance to achieve environmentally responsible, safe, and efficient operations in which innovation and technology act as catalysts to accelerate solutions for future challenges. To achieve this, the Ecopetrol Group has identified five strategic lines: (i) build and generate value through an efficient, clean and safe production, (ii) accelerate and prioritize decarbonization and energy efficiency, (iii) ensure circular water management, (iv) support local development in the places where we operate, and (v) generate trust in the social context through proactive dialogue and by improving the quality of life of people looking for mutual benefits, with a focus on inclusion, and on reactivating and diversifying local economies.
Environmentally, the long-term TESG targets include the achievement of: (i) 45% and 55% reduction in methane emissions by 2025 and 2030 in the upstream business, respectively (however, Ecopetrol intends to reach zero methane emissions under the Oil and Gas Climate Initiative (OGCI), (ii) net-zero emissions of CO2 equivalent by 2050 (scopes 1 and 2) in all our operations, (iii) zero routine gas flaring by 2030 in the upstream business, (iv) zero treated produced and wastewater discharges by 2045 along with an expected reduction of 58% to 66% in the intake of fresh water for operations, (v) the addition of a portfolio of Natural Climate Solutions (NCS) that help reduce 2-4 metric tons of carbon dioxide equivalent (MtCO 2 e) by 2030.
The Company has set specific targets towards achieving its energy matrix decarbonization and enabling the incorporation of low-emission businesses within its portfolio. Additionally, by 2025, the Company aims to accelerate the incorporation of approximately 900 MW of non-conventional renewable energy into its generation. The Company maintains its long-term target of incorporating more than 1,000 MW of non-conventional renewable energy by 2030.
On the social front, the long-term TESG targets focus on promoting the generation of approximately 230 thousand new non-oil related jobs by 2040 and contributing to the education of two million young Colombians.
|
2.1.1.3 |
Cutting-edge Knowledge |
This pillar seeks to develop the required skills and capacities to face the challenges towards growth and TESG, through a comprehensive science, technology, and innovation strategy, as well as improving the competitiveness and resilience of current assets, contributing to diversification, increasing clean energy, decarbonizing operations and strengthening of talent through transformative practices by means of training programs to optimize performance (upskilling) or fill new positions (reskilling).
6
Thus, the expected long-term goals are, among others: (i) having approximately 70% of workers complete reskilling programs by 2030, and (ii) achieving automation of 100% of human talent processes by 2030.
|
2.1.1.4 |
Competitive Returns |
The fourth pillar ensures continuity of our strict capital discipline, the efficient use of resources, and the protection of cash, all of which have been leveraging the Ecopetrol Group’s strategy since 2015. The long-term aspiration includes, among others, maintaining the ordinary dividend policy at between 40% and 60%, in line with operating results. The long-term strategy will allow transfers to the Nation between COP 13-20 trillion annually on average, through royalties, taxes, and dividends and is expected to enable a sustainable capital structure with a gross debt to EBITDA ratio below 2.5 times.
|
2.1.2 |
2025 Investment Plan |
On November 29, 2024, we announced that the Board of Directors approved the 2025 investment plan (the “2025 Investment Plan”) which contemplates a budget of between COP 24 trillion pesos (USD 5.9 billion) and COP 28 trillion pesos (USD 6.9 billion). The 2025 Investment Plan is aligned with the group’s commitment to energy security and the country’s energy transition. The 2025 Investment Plan assumes, among others, a USD 73 /Bl Brent price, an exchange rate of COP 4,100 per USD 1.00 and assumes the collection of the accounts receivable from the FEPC for 2024. The 2025 Investment Plan increases investment levels compared to 2024, under capital discipline criteria and is expected to have the following implications:
The upstream business is expected to invest approximately COP 17.2 trillion pesos (approximately USD 4.0 billion) (equivalent to 52% of the 2025 Investment Plan for crude oil-related investments and 12% for gas-related investments). The upper range of the target is adjusted to 740,000 and 750,000 barrels of oil equivalent per day for 2025 (78% crude, 17% gas, and 5% white products), seeking to implement recovery technologies that optimize the use of available resources and maintain production levels. Crude oil production in Colombia is expected to grow, compensating the natural decline of gas fields. In 2025, the Company plans to drill between 455 and 465 development wells, of which 79% are expected to be executed in Colombia and the remaining 21% in the United States. In terms of exploration, the Company expects to drill 10 wells mainly in the Llanos area and Caribbean offshore of Colombia. Gas investments are estimated between COP 3.1 and COP 3.3 trillion pesos (approximately 750 and 800 million dollars), mainly in the Piedemonte Llanero and Offshore, to develop the gas of the Caribbean offshore, contributing to a production of approximately 123,000 barrels of oil equivalent per day (which represents approximately 700 million cubic feet of natural gas), of which 85% are forecasted to be part of the gas supply for the country.
Investments in the transportation segment are expected to reach approximately COP 1.5 trillion pesos (approximately USD 350 million), corresponding to 5% of the 2025 Investment Plan, mainly focused on integrity and reliability projects concerning the infrastructure developed by Cenit Transporte y Logística de Hidrocarburos S.A.S., Oleoducto Central S.A., Oleoducto de Colombia S.A., and Oleoducto de los Llanos S.A. Transported volumes are expected to reach between 1,130,000 and 1,170,000 barrels per day, in line with the country’s production expectations and refined products demand. Investments in the refining segment are expected to reach approximately COP 1.6 trillion pesos (approximately USD 400 million), corresponding to 6% of the total investment budget for 2025, and are expected to be focused on ensuring the reliability, availability, and sustainability of the operation of the Barrancabermeja and Cartagena refineries, as well as developing programs that would reduce product imports, improve quality of fuels, and advancing sustainable fuel (SAF) projects. The joint load of both refineries is expected to be between 415,000 and 420,000 barrels per day.
Interconexión Eléctrica S.A E.S.P. (ISA), a subsidiary of Ecopetrol S.A., is expected to invest between COP 5.7 and COP 6.5 trillion pesos (approximately 1.4 and 1.6 billion dollars) in 2025 (equivalent to approximately 21% of the 2025 Investment Plan), of which approximately 90% is expected to be allocated to the electric transmission business. These investments seek to increase the electric power grid to achieve approximately 50,400 km in operation by 2025, maintaining the Company as the energy transmission leader in the region.
In order to advance in the energy transition goals while simultaneously decarbonizing the hydrocarbon operations, the 2025 Investment Plan intends to allocate an amount between COP 9.4 trillion pesos (approximately USD 2.3 billion) and COP 11.4 trillion pesos (approximately USD 2.8 billion), which include investments in electric power transmission and roads, gas investments, and renewable energy projects, among others. We continue to review growth opportunities in all business lines and depending on the results of this process, the Company may allocate additional investment resources towards energy transition in 2025.
7
Moreover, in 2025, the Company expects to achieve an additional energy optimization of 2.6 Peta Joules (PJ) reaching an accumulated energy saving of around 21 PJ between 2018 and 2025, accelerating the completion of the goal of 25 PJ optimization by 2030. Additionally, the goal of 900 MW by 2025 is projected to be accomplished in line with the corporate strategy. As part of the Company’s energy transition efforts, the 2025 Investment Plan forecasts an additional reduction of about 300,000 tons of CO2 equivalent emissions by 2025, contributing to the achievement of the total emissions reduction target by 2030.
In line with our goal of generating value through TESG, the 2025 Investment Plan allocates COP 2.3 trillion pesos (USD 555 million) towards this objective. The financial plan for 2025 aims to ensure competitive returns in a scenario of Brent prices averaging USD 73/barrel, generating an EBITDA margin at levels close to 39%.
The plan incorporates efficiency targets for 2025, exceeding 4 trillion pesos, aiming to capture savings in operational management and investment projects, to achieve improvements on indicators such as lifting cost, total refining cost, and cost per barrel transported. We expect our Return on Average Capital Employed (ROACE) to remain at competitive levels. Considering the above, the financing of the 2025 Investment Plan for Ecopetrol S.A. is expected to be carried out with operational resources and forecasts transfers to the Nation (including dividends, royalties, and taxes) of approximately 35 trillion pesos (approximately USD 8.4 billion). The table below sets forth the details of the investment plan per business segment:
Table 2 – 2025 Investment Plan
|
Business Segment |
|
% Percentage (1) |
|
|
Exploration |
|
6 |
% |
|
Production |
|
59 |
% |
|
Downstream |
|
6 |
% |
|
Midstream |
|
5 |
% |
|
Electric Power Transmission and Toll Roads |
|
21 |
% |
|
Other |
|
3 |
% |
|
TOTAL |
|
100 |
% |
|
(1) |
Percentage over the upper range. |
|
3. |
Business Overview |
|
3.1 |
Our History |
We were formed in 1951 by the Colombian Government as Empresa Colombiana de Petróleos and began operating the crude oil fields at La Cira-Infantas, the first oil field in Colombia, where production started in 1918, and the pipeline that connected that field with the Barrancabermeja refinery and the port of Cartagena. In 1961, we assumed the direct operation of the Barrancabermeja refinery and continued its transformation into an industrial complex. In 1974, we acquired the Cartagena Refinery (as defined below), which had been in operation since 1957. Pursuant to Decree 0062 of 1970, we were transformed into a governmental, industrial, and commercial company.
In 2003, pursuant to Decree Law 1760, the National Hydrocarbons Agency ( Agencia Nacional de Hidrocarburos or “ANH” for its acronym in Spanish) was created and Ecopetrol’s public role as administrator and regulator of the national hydrocarbons resources was transferred to the ANH. Ecopetrol modified its organic structure and became Ecopetrol S.A., a publicly held corporation, one hundred percent state-owned, and continued the development of exploration and production activities on a competitive basis with autonomy over business decisions. Since 2006, according to Law 1118, we evolved from a wholly state-owned entity to a mixed-economy company with private capital. This process has resulted in a substantial change in the legal framework to which we are subject, and in the nature of our relationship with the Nation, as our controlling shareholder.
We carried out our initial public offering in August 2007, when our common shares were listed on the Colombian Stock Exchange. Our American Depositary Shares (ADSs) were listed on the New York Stock Exchange in September 2008. We carried out a follow-on public offering in Colombia in August 2011.
In June 2012, Cenit was incorporated as a subsidiary specialized in logistics and transportation of hydrocarbons in Colombia, whose main objective was to enhance the strategic and logistical framework of the Colombian oil industry, given the boost in hydrocarbon production and looking to increase sales of crude oil and refined products in Colombia and in the international markets.
8
In 2016, 34 units of the Cartagena Refinery came into operation and upgrades were made to the Barrancabermeja refinery.
In 2017, we entered for the first time into the Mexican market, where we were awarded (together with Petronas and Pemex) two blocks to explore and produce hydrocarbons in shallow waters in the southeastern basin.
In 2018, we made progress in the internationalization of offshore exploration by entering the Brazilian pre-salt oil region, one of the areas with the greatest potential for oil reserves in the world, working together with top-tier companies such as British Petroleum, China National Petroleum, China National Offshore Oil Corporation (“CNOOC”), Shell and Chevron. Additionally, we reached a milestone in our plan to transition into renewable energies with the award of a contract for the construction of the first solar farm in Meta, with an installed capacity of more than 20 MW to supply part of the energy demanded by the Castilla field.
In 2019, we began operations in the Permian Basin through a strategic alliance with Occidental Petroleum. We believe this project contributed to strengthen our position in knowledge and technology in unconventional reservoirs.
On July 1, 2021, we incorporated Ecopetrol Singapore Pte Ltd., a wholly owned subsidiary which owns 100% of the capital stock of Ecopetrol Trading Asia Pte Ltd. The latter’s main purpose is the international commercialization of crude oil and refined products of the Ecopetrol Group and of third parties throughout Asia.
On August 20, 2021, we acquired 51.4% of the outstanding shares of ISA from the Ministry of the Treasury and Public Credit ( Ministerio de Hacienda y Crédito Público or “MHCP” for its acronym in Spanish), through which we expect to reposition ourselves along the energy value chain by offering services such as electricity transmission and aligning ourselves with the market trends towards decarbonization and electrification.
On November 16, 2022, we incorporated Ecopetrol US Trading LLC, a wholly owned indirect subsidiary of the Company owned through its subsidiary Ecopetrol USA Inc. Ecopetrol US Trading LLC’s main purpose is the international marketing of refined, petrochemical and industrial products as well as crude oil and natural gas from the Ecopetrol Group and third parties.
On March 17, 2023, we incorporated Econova Technology Innovation, S.L.U. (“Econova”), a wholly owned subsidiary in Spain. Econova’s main purpose is the development of technology, innovation and science activities.
On October 1, 2024, the Company concluded the liquidation process of Ecopetrol Energía S.A.S. E.S.P.
|
3.2 |
Our Corporate Structure |
We are currently organized into three corporate business lines: (A) hydrocarbons, which includes four operational divisions: (i) exploration and production, (ii) transportation and logistics, (iii) refining, petrochemicals and biofuels, and (iv) sales and marketing; (B) energies for the transition; and (C) energy transmission and toll roads. This organization seeks to maintain the competitiveness of the Hydrocarbons business, the development and scaling of the businesses in the Energies for the Transition portfolio, and the growth of the Transmission and Toll Roads line. However, as discussed above in Our Corporate Strategy—2025 Investment Plan , given the transformation of our Company with the ISA acquisition and in line with our 2040 Strategy, in 2022, we started a process to align our current segments more closely to the vision of the 2040 Strategy for the Ecopetrol Group and such process is expected to continue throughout 2025.
For purposes of this annual report, the financial information included in this annual report is organized by the following segments: (i) exploration and production, (ii) transportation and logistics, (iii) refining and petrochemicals, and (iv) energy transmission and roads, which is consistent with previous Company annual reports. The Company’s management is currently reviewing different options to update the operating and financial reporting model of the Company to be better aligned with the 2040 Strategy.
Our subsidiaries, Refinería de Cartagena S.A.S. (“Reficar” or “Cartagena Refinery”), Cenit, ISA, Ecopetrol Trading Asia Pte Ltd. (“Ecopetrol Trading Asia”), Ecopetrol US Trading LLC, Esenttia S.A., Ecopetrol Permian LLC (“Permian”), and Ocensa are significant subsidiaries, as such term is defined under SEC Regulation S-X.
We have several directly and indirectly held subsidiaries both in Colombia and abroad. As of December 31, 2024, we have 12 directly owned and 76 indirectly owned subsidiaries.
9
In 2024, the Ecopetrol Group’s corporate structure changed as follows:
| ● | The Shareholders’ Meeting of Ecopetrol Energia S.A.S E.S.P., with the favorable and affirmative vote of 100% of its subscribed shares, authorized its liquidator, Mr. Christian Schneider Jaramillo, to carry out all the necessary steps for the due liquidation of this company whose purpose was the commercialization of energy, which culminated with the cancellation of its commercial registration the first days of October 2024. The liquidation of this entity was because Ecopetrol S.A. is currently the parent company of an electric power transmission company, and current regulations restrict the same group from simultaneously carrying out commercialization and transmission activities. |
| ● | On July 22, 2024, a share purchase agreement was executed among Oleoducto Central S.A. (“Ocensa”), as purchaser, and Talisman Colombia Holdco Limited, as seller, by means of which Ocensa acquired 100% of the shares of C.I. Repsol Ductos Colombia S.A.S., which is now known as Ocensa Ductos S.A.S. (“Ocensa Ductos”). Ocensa Ductos holds a 7.14% equity interest in Oleoducto de Colombia S.A. (“ODC”), a subsidiary of Ecopetrol. Following the closing of the transaction, Ocensa Ductos became a fully-owned subsidiary of Ocensa. |
| ● | On December 16, 2024, the respective General Shareholders’ Meetings of both Ocensa and Ocensa Ductos approved the merger of Ocensa Ductos S.A.S. and Ocensa, with Ocensa resulting the surviving entity. The completion of this merger is subject to the authorization of the Superintendence of Companies ( Superintendencia de Sociedades ). Once the merger is completed, Ocensa will become a direct shareholder of ODC, holding a 7.14% equity interest in the company. |
The table below sets forth our corporate structure as of December 31, 2024:
Graph 2 – Ecopetrol’s Corporate Structure
The stock ownership percentage listed next to each entity refers to Ecopetrol S.A.’s direct and indirect participation therein as of December 31, 2024. Such data presents a summary of Ecopetrol S.A.’s corporate structure and does not include information about every entity directly or indirectly owned by the Company, and participation information has been rounded to the nearest integer; as such, it should not be relied upon and should be used solely for information purposes.
Exhibit 8.1 to this annual report identifies our principal operating subsidiaries, their respective countries of incorporation, and our percentage ownership in each (both directly and indirectly through other subsidiaries).
10
|
3.3 |
Recent Developments |
Refineria of Cartagena
On January 16, 2025, Refinería de Cartagena S.A.S. was notified of the decision issued by the Court of the Southern District of New York, by which it denied the request presented by Chicago Bridge Iron Company N.V., CBI UK Limited to vacate the arbitration award dated June 2, 2023 in relation to the EPC Contract (Engineering, Procurement, and Construction Contract) executed between Reficar and CBI for the expansion and modernization of the refinery located in the city of Cartagena, accordingly resolving the disputes between Reficar and Chicago Bridge Iron Company N.V., CBI UK Limited and CBI Colombiana S.A. (collectively “CBI”). Consequently, the arbitration award in question was confirmed in its entirety. For more information, see section Risk Review—Legal Proceedings and Related Matters—Reficar Investigations.
Management
On January 15, 2025, we announced the following senior management changes:
|
1. |
Walter Fabián Canova, who had served as Vice President of Refining and Industrial Processes, performed his duties until January 15, 2025 and terminated his employment contract by mutual agreement after working at the Company for more than seven years. |
|
2. |
Felipe Trujillo López, current Vice President of Commercial and Marketing, serves as Vice President of Refining and Industrial Processes until a permanent appointment is made. |
|
3. |
Julio César Herrera serves as Vice President of Commercial and Marketing in charge and until a permanent appointment is made. |
On January 31, 2025, we announced the following senior management changes:
|
1. |
María Cristina Toro Restrepo was confirmed as Corporate Legal Vice President and General Secretary. This Vice Presidency reports directly to the President. |
|
2. |
Rafael Ernesto Guzmán Ayala was appointed Executive Vice President of Hydrocarbons. He will continue to report directly to the President. |
On April 23, 2025, we announced the following senior management changes:
|
1. |
Diana Marcela Jimenez Rodriguez was confirmed as Director of Institutional Relations and Communication. |
|
2. |
Julian Fernando Lemos Valero was confirmed as Corporate Vice President of Strategy and Business Development. |
|
3. |
Julio Herrera was confirmed as Vice President of Commercial and Marketing. |
See Corporate Governance – Management .
Temporal reduction in the conversion cost of Ecopetrol´s ADR
On January 15, 2025, Ecopetrol reached an agreement with JPMorgan Chase Bank N.A., the depositary bank of its American Depositary Receipts (ADR) program, to reduce 50% of the conversion cost for the purchase and sale of ADRs in the United States. The measure is temporary and is expected to be effective until July 10, 2025.
Ecopetrol Occidental Petroleum Corp. Joint Venture extension agreement
On February 3, 2025, Ecopetrol Permian LLC and Occidental Petroleum Corp (“Oxy”) reached an agreement to extend the development plan of Rodeo Midland Basin LLC, located in the Permian Basin in Texas, under the joint-venture established in July 2019.
11
Ecopetrol Repsol transaction completion to acquire 45% of its participation in Block CPO-09
Ecopetrol S.A. successfully completed the transaction with Repsol Colombia Oil Gas Limited to acquire the remaining 45% of its participation in the CPO-09 Block, making it the holder of 100% of the participation interest in the block, a strategic asset in the Piedemonte Llanero.
Agreement for Launching the Market Maker program for its Shares on the Colombian Stock Exchange
On March 3, 2025, Ecopetrol S.A. announced it implemented a market maker program for Ecopetrol’s shares listed on the Colombian Stock Exchange, for a 12-month period with Valores Bancolombia S.A. Comisionista de Bolsa and Andes Investment Group Inc., a subsidiary of the Chilean group Larraín Vial and an affiliate of the local Larraín Vial broker-dealer, each entity operating under applicable regulation and in compliance with Colombian markets’ regulation. On March 14, 2025, Ecopetrol S.A. announced it had completed the necessary procedures for the implementation of market maker program for its common stock, with Andes Investment Group Inc., and Valores Bancolombia S.A. Comisionista de Bolsa. The market maker program began on March 3, 2025, through Andes Investment Group Inc., while through Valores Bancolombia S.A. Comisionista de Bolsa, the program began on Friday, March 14, with the authorization from the Colombian Stock Exchange.
Election of the statutory auditor for the 2025–2029 period
On March 28, 2025, Ecopetrol S.A. shareholders approved to appoint the firm Deloitte Touche S.A.S., as the statutory auditor of Ecopetrol S.A. for fiscal years 2025-2028. The agreement with Deloitte Touche S.A.S. was executed in April 2025, while the statutory audit and external audit agreement executed with the firm ERNST YOUNG AUDIT S.A.S., ending on May 27, 2025.
Ecopetrol signed an agreement to build the Jemeiwaa Ka’I wind cluster in La Guajira
On April 14, 2025, Ecopetrol S.A. signed an investment framework agreement with AES Colombia CIA SCA E.S.P. to build 49% of the Jemeiwaa Ka’I wind cluster located in La Guajira, subject to the fulfillment of condition precedents and other legal requirements. Jemeiwaa Ka’I comprises a portfolio of wind projects located in the upper and middle Guajira, in the municipality of Uribia, with an approximate capacity of 1,087 MW, along with a 35 km transmission line.
|
3.4 |
Our Business |
We are the largest company in Colombia and one of the main integrated energy companies in the American continent. We are responsible for more than 60% of the hydrocarbon production, of most transportation, logistics, and hydrocarbon refining systems, and hold leading positions in the petrochemicals and gas distribution segments. With the acquisition of 51.4% of ISA’s shares, the Company participates in energy transmission, the management of real-time systems (XM), and the Barranquilla - Cartagena coastal highway concession. At the international level, Ecopetrol has a stake in strategic basins in the American continent, with drilling and exploration operations in the United States (Permian basin and the Gulf of Mexico (aka Gulf of America)), Brazil, and Mexico, and, through ISA and its subsidiaries, Ecopetrol holds leading positions in the power transmission business in Brazil, Chile, Peru, and Bolivia, road concessions in Chile, and the telecommunications sector. The Nation currently owns 88.49% of our voting capital stock. We are among the world’s largest public companies, ranking 316 on the Forbes 2024 Global 2000 Ranking, and the largest Colombian company in this ranking.
3.5 Exploration and Production
Our exploration and production business segment includes exploration, development, and production activities in Colombia and abroad. We began local exploration in 1955 and international exploration in 2006. Exploration and production activities are conducted directly by Ecopetrol S.A., and through some of our subsidiaries, as well as through joint ventures with third parties. As of December 31, 2024, we were the largest operator and producer of crude oil and natural gas in Colombia, maintaining the largest exploration acreage position in Colombia.
Unless otherwise stated, all figures are given before deducting royalties.
12
|
3.5.1 |
Exploration Activities |
In 2024, our exploration strategy was focused on three working fronts: Colombian onshore, Colombian Caribbean offshore, and overseas. By year-end, the Ecopetrol Group was a party to 86 contracts for exploratory activities, with 49 of those contracts being for Colombia, and 37 of those contracts for outside of Colombia, distributed as follows:
| ● | Exploratory Activities in Colombia: |
| o | Ecopetrol is a party to (i) 22 EP contracts in exploratory stage, (ii) three EP Agreement in exploratory stage, (iii) three technical evaluation agreements (TEAs), (iv) one risk sharing agreement, (v) two association contracts. |
| o | Hocol S.A. (“Hocol”), is a party to (i) 16 EP contracts in exploratory stage, and (ii) two EP Agreements in exploratory stage. |
| ● | Exploratory Activities outside of Colombia: |
| o | One production sharing contract (PSC) in Mexico; |
| o | 24 royalty tax agreements for Ecopetrol America LLC, and |
| o | One production sharing (PSC) and 11 concessions (four in 2024 (S-M-1717, S-M-1707, S-M-1719, and S-M-1715) for Ecopetrol Óleo e Gás do Brasil Ltda. |
Our Business Plan aims at incorporating resources in high reward projects concentrated in: (i) onshore basins in Colombia (both foothills and foreland in Llanos basin, Middle and Upper Magdalena Valley, Putumayo and gas in Guajira, Sinú-San Jacinto and Lower Magdalena Valley), (ii) offshore Colombia (appraise and evaluate existing gas discoveries as well as identify new hydrocarbons accumulations), and (iii) international areas such as Gulf of Mexico (aka Gulf of America) and offshore Brazil in pre-salt and post-salt Santos and Campos basins.
Graph 3 – Sedimentary Basins where Ecopetrol Executes Exploration Activities
13
|
3.5.1.1 |
Exploration Activities in Colombia |
In 2024, Ecopetrol S.A. and its subsidiaries drilled 15 exploration and appraisal wells in Colombia, out of which ten were exploratory (A3/A2) and five were appraisal (A1) wells. As of December 31, 2024, six wells were successful, six were dry, and three remained under technical evaluation. This drilling activity was concentrated in basins of interest around Colombia, including the Caribbean offshore, Llanos, the Lower, Middle and Upper Magdalena Valley.
The six successful wells drilled by Ecopetrol S.A. and its partners in Colombia during 2024 were located in the following regions: Toritos Norte-1,Toritos-2, Toritos Sur-1, Bisbita Este-1 and Guamal Profundo-1 in Llanos basin, and Sirius-2 in the Caribe Offshore.
In 2024, Ecopetrol and other partners executed the following agreements for exploration activities:
| ● | In April, a business collaboration agreement (BCA) was signed with Parex Resources (Colombia) AG (“Parex”) with the objective to develop exploratory activities in the Siriri region of the Piedemonte basin. |
| ● | In June, Ecopetrol and Parex signed an amendment to LLA-121, LLA 16-1 and LLA 4-1 EP agreements to make exploratory gas activities in Piedemonte, with a 50% participation by Ecopetrol and 50% participation by Parex in each agreement. |
| ● | In July, Río Magdalena EP agreement for an exploratory stage in Medium Magdalena Valley basin was executed. Ecopetrol holds 100% of the participation in this agreement. |
| ● | In September, the Magangué EP agreement for an exploratory stage in the Lower Magdalena Valley basin was assigned from Ecopetrol to Hocol. |
| ● | In November, an agreement with Parex was executed to develop exploratory activities in the Farallones region of the Llano’s basin, which is in process of formalization with the ANH. |
On February 5, 2025, Ecopetrol S.A. successfully completed the transaction with Repsol Colombia Oil Gas Limited to acquire the remaining 45% of its participation in the CPO-09 Block, making it the holder of 100% of the participation interest in the block, a strategic asset in the Piedemonte Llanero.
The following table sets forth, for the periods indicated, the number of gross and net productive, dry, and under evaluation exploratory wells drilled by Ecopetrol S.A., Hocol and by our joint venture partners, and the exploratory wells drilled by third parties pursuant to sole risk contracts with us.
14
Table 3 – Exploratory Drilling in Colombia
|
|
|
For the year ended December 31, |
||||
|
|
|
2024 |
|
2023 |
|
2022 |
|
|
|
(Number of wells) |
||||
|
COLOMBIA |
|
|
|
|
|
|
|
Ecopetrol S.A. |
|
|
|
|
|
|
|
Gross exploratory wells |
|
|
|
|
|
|
|
Owned and operated by Ecopetrol |
|
|
|
|
|
|
|
Productive |
|
— |
|
— |
|
1.00 |
|
Dry (1) |
|
— |
|
3.00 |
|
1.00 |
|
Under Evaluation (2) |
|
— |
|
2.00 |
|
1.00 |
|
Total |
|
— |
|
5.00 |
|
3.00 |
|
Operated by a partner in Joint Venture |
|
|
|
|
|
|
|
Productive |
|
1.00 |
|
1.00 |
|
3.00 |
|
Dry (1) |
|
2.00 |
|
— |
|
2.00 |
|
Under Evaluation (2)(4) |
|
1.00 |
|
2.00 |
|
1.00 |
|
Total |
|
4.00 |
|
3.00 |
|
6.00 |
|
Operated by Ecopetrol in Joint Venture |
|
|
|
|
|
|
|
Productive |
|
1.00 |
|
2.00 |
|
1.00 |
|
Dry (1) |
|
1.00 |
|
1.00 |
|
— |
|
Under Evaluation (2) |
|
— |
|
1.00 |
|
1.00 |
|
Total |
|
2.00 |
|
4.00 |
|
2.00 |
|
Net Exploratory Wells (3) |
|
|
|
|
|
|
|
Productive |
|
1.11 |
|
1.60 |
|
3.10 |
|
Dry (1) |
|
1.21 |
|
3.48 |
|
2.00 |
|
Under Evaluation (2)(4) |
|
0.65 |
|
3.55 |
|
1.75 |
|
Total |
|
2.97 |
|
8.63 |
|
6.85 |
|
Sole Risk |
|
|
|
|
|
|
|
Productive |
|
— |
|
— |
|
1.00 |
|
Dry (1) |
|
— |
|
2.00 |
|
3.00 |
|
Under Evaluation (2) |
|
— |
|
1.00 |
|
2.00 |
|
Total |
|
— |
|
3.00 |
|
6.00 |
|
Hocol |
|
|
|
|
|
|
|
Gross Exploratory Wells |
|
|
|
|
|
|
|
Productive |
|
4.00 |
|
5.00 |
|
2.00 |
|
Dry (1) |
|
3.00 |
|
3.00 |
|
6.00 |
|
Under Evaluation (2) |
|
2.00 |
|
3.00 |
|
3.00 |
|
Total |
|
9.00 |
|
11.00 |
|
11.00 |
|
Net Exploratory Wells (3) |
|
|
|
|
|
|
|
Productive |
|
2.00 |
|
2.50 |
|
2.00 |
|
Dry (1) |
|
2.50 |
|
1.50 |
|
5.50 |
|
Under Evaluation (2) |
|
1.00 |
|
2.00 |
|
2.50 |
|
Total |
|
5.50 |
|
6.00 |
|
10.00 |
|
(1) |
A dry well or hole is an exploratory well found to be incapable of producing either crude oil or natural gas in sufficient quantities to justify completion as a crude oil or natural gas well. |
|
(2) |
An “under evaluation” well is an exploratory well where there is not yet enough information to determine its result as successful or dry. This classification is maintained until additional well-testing operations are carried out to determine the hydrocarbon production capacity or some petrophysical parameter of the rocks or fluids in the reservoir. |
|
(3) |
Net exploratory wells were calculated according to our percentage of ownership in these wells. |
|
(4) |
Caripeto-1 well was classified as “under evaluation”. However, as of January 2025, it has been declared successful well drilling, confirming hydrocarbon presence. |
15
Seismic
In Colombia, during 2024, Ecopetrol acquired 193.4 km 2 of seismic information through the Yacopí 3D program, and the completion of 2.7 km2 through the Cesar 3D program, while Hocol acquired 352.9 km 2 3D of seismic information in Llanos 86, 281 km 2 in Llanos 104, and 84,53 km 2 in COR 9. Additionally, Ecopetrol purchased 108.65 km of 2D seismic and 333.99 km2 of 3D seismic of the Middle Magdalena Valley; while Hocol purchased 98.9 km of 2D seismic of the Lower and Upper Magdalena Valley.
Moreover, 23,969 km 2 of 3D seismic and 3,858 km of 2D seismic were reprocessed by Ecopetrol in the Middle (VMM) and Lower (VIM) Magdalena Valley, Putumayo Llanos, Piedemonte and in the Colombian Caribbean. In non-seismic methods, 18,413 km of aerogradiometry (iFTG) data were acquired and reprocessed and seismic characterization has been done through quantitative interpretation – IQ of 7,256 km 2 of 3D projects and 83 km in 2D in the Middle (VMM) and Lower (VIM) Magdalena Valley, Llanos and in the Colombian Caribbean.
|
3.5.1.2 |
Exploration Activities Outside Colombia |
Our international exploration strategy is focused on basins with high materiality, aiming at mitigating our risk exposure and ultimately increasing our reserves. This strategy is supported by an efficient, business-oriented portfolio management, which involves the participation in competitive bidding rounds to secure high-potential exploration blocks in the focus areas. Within this context, a key element is the formation of strong joint-ventures with international and regional oil companies which can contribute with operational expertise and leading-edge technology.
In the Santos Basin, the partnership among BP plc (“BP”), CNOOC, Ecopetrol Óleo e Gás do Brasil Ltda., in which the aforementioned partners have, respectively, a 50%, 30% and 20% ownership stake, pursued the exploration and drilling of the Pau Brasil-1 well. The Pau Brasil-1 well resulted dry with hydrocarbon shows.
Regarding the Gato do Mato project in Brazil, operated by Shell and associated with Total Energies, the project has made steady progress. In 2025 Ecopetrol Óleo e Gás do Brasil Ltda, a subsidiary of the Ecopetrol Group S.A., has already approved the Final Investment Decision (FID). The project completed the basic engineering “Front End Engineering Design” (FEED) for the subsea and floating production facilities, with the expectation of incorporating the first volumes of 1P reserves during 2025.
16
The following table sets forth information on our international exploratory drilling for the periods indicated.
Table 4 – Exploratory Drilling Outside Colombia
|
|
|
For the year ended December 31, |
||||
|
|
|
2024 |
|
2023 |
|
2022 |
|
|
|
(Number of wells) |
||||
|
UNITED STATES |
|
|
|
|
|
|
|
Ecopetrol America LLC |
|
|
|
|
|
|
|
Gross Exploratory Wells |
|
|
|
|
|
|
|
Productive |
|
— |
|
— |
|
— |
|
Dry (1) |
|
— |
|
— |
|
1.00 |
|
Under Evaluation (2) |
|
— |
|
— |
|
— |
|
Total |
|
— |
|
— |
|
1.00 |
|
Net Exploratory Wells (3) |
|
|
|
|
|
|
|
Productive |
|
— |
|
— |
|
— |
|
Dry (1) |
|
— |
|
— |
|
0.25 |
|
Under Evaluation (2) |
|
— |
|
— |
|
— |
|
Total |
|
— |
|
— |
|
0.25 |
|
BRAZIL |
|
|
|
|
|
|
|
Ecopetrol Óleo e Gás do Brasil Ltda. |
|
|
|
|
|
|
|
Gross Exploratory Wells |
|
|
|
|
|
|
|
Productive (5) |
|
— |
|
— |
|
— |
|
Dry (1) |
|
1.00 |
|
— |
|
— |
|
Under Evaluation (2) |
|
— |
|
— |
|
— |
|
Total |
|
1.00 |
|
— |
|
— |
|
Net Exploratory Wells (3)(4) |
|
|
|
|
|
|
|
Productive |
|
— |
|
— |
|
— |
|
Dry (1) |
|
0.20 |
|
— |
|
— |
|
Under Evaluation (2) |
|
— |
|
— |
|
— |
|
Total |
|
0.20 |
|
— |
|
— |
|
(1) |
A dry well or hole is an exploratory well found to be incapable of producing either crude oil or natural gas in sufficient quantities to justify completion as a crude oil or natural gas well. |
|
(2) |
An “under evaluation well” is an exploratory well where there is not yet enough information to determine its result as successful or dry. This classification is maintained until additional well testing operations are carried out to determine the hydrocarbon production capacity or some petrophysical parameter of the rocks or fluids in the reservoir. |
|
(3) |
Net exploratory wells were calculated according to our percentage of ownership in these wells. |
|
(4) |
None of our international wells were drilled pursuant to a sole risk contract. |
Seismic
During 2024, Ecopetrol Óleo e Gás do Brasil Ltda, aligned with its commitment to the National Petroleum Agency (ANP, for its acronym in Portuguese), completed the high-quality multi-client 3D seismic campaign, acquiring 2,173 km 2 of 3D seismic data this year, for a total of 10,816 km 2 of 3D seismic data located in the southern Santos basin. This dataset will be used to evaluate the exploratory potential of the area and mature existing opportunities within the portfolio.
|
3.5.2 |
Production Activities |
In 2024, our consolidated average production was 745.8 thousand barrels of oil equivalent per day (“mboed”), showing an increase of 9.2 mboed as compared to 2023, primarily due to the following factors: (i) incremental production from Permian, (ii) an increase in production of 7.6 thousand barrels of oil per day (“mboed”) as compared to 2023 due to a better performance in production and increased capacity in water facilities in Caño Sur Field; and (iii) better performance in basic production in fields located in Llanos and Central regions. The above was partially offset by: (i) environmental impacts mainly of the fields located in Llanos, Putumayo and Arauca (6.4 mboed decrease in 2024 compared to 6.7 mboed decrease in 2023); (ii) Hurricane season in Gulf of Mexico (aka Gulf of America) that affected Ecopetrol America LLC, and (iii) a decrease in gas sales.
17
The following table summarizes the results of our oil and gas production activities for the periods indicated:
Table 5 – Ecopetrol Group’s Oil and Gas Production
|
|
|
For the year ended December 31, |
||||||||||||||||
|
|
|
2024 |
|
2023 |
|
2022 |
||||||||||||
|
|
|
Oil |
|
Gas (1) |
|
Total |
|
Oil |
|
Gas (1) |
|
Total |
|
Oil |
|
Gas (1) |
|
Total |
|
|
|
(mboed) |
||||||||||||||||
|
Total gross production in Colombia (2)(5) |
|
509.4 |
|
135.1 |
|
644.5 |
|
515.7 |
|
147.6 |
|
663.3 |
|
509.9 |
|
152.5 |
|
662.4 |
|
Total international gross production (3) |
|
60.4 |
|
40.9 |
|
101.3 |
|
44.5 |
|
28.8 |
|
73.3 |
|
31.9 |
|
15.2 |
|
47.1 |
|
Total gross production of Ecopetrol Group |
|
569.8 |
|
176.0 |
|
745.8 |
|
560.2 |
|
176.4 |
|
736.6 |
|
541.8 |
|
167.7 |
|
709.5 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total production of Ecopetrol Group for presentation of reserves (4) |
|
531.6 |
|
152.6 |
|
684.2 |
|
521.1 |
|
156.9 |
|
678.0 |
|
502.1 |
|
155.2 |
|
657.3 |
|
(1) |
Conversion between million cubic feet per day (mcfpd) and boepd is performed at 5,700 mcfpd to 1 boepd. Includes natural gas and natural gas liquids. |
|
(2) |
Total production in Colombia corresponds to Ecopetrol S.A. and Hocol. Includes royalties. |
|
(3) |
Total International production corresponds to Ecopetrol Permian LLC and Ecopetrol America LLC. Includes royalties. |
|
(4) |
For the Company’s presentation of reserves, the Company deducts from its total gross production the 100% of crude royalties from Ecopetrol Group companies and gas royalties from non-Colombian Ecopetrol Group companies, Ecopetrol Permian LLC (United States) and Ecopetrol America LLC (United States). Gas royalties derived from Colombian production are not deducted because according to local regulation the Company is entitled to such gas royalties. Also includes self-consumption, which is only comprised of natural gas self-consumption and is immaterial. Oil production include natural gas liquids (“NGL”) and oil self-consumption, which is immaterial. |
|
(5) |
The total gross production in Colombia, includes the production of 50% of Arauca field (0.5 mboed). In December 2024, Ecopetrol S.A. and Parex filed a request to transfer Ecopetrol’s 50% stake in the agreement for the Arauca field to Parex, as a result of the business collaboration agreement (BCA) executed between Ecopetrol S.A. and Parex . |
|
3.5.2.1 |
Production Activities in Colombia |
|
3.5.2.1.1 |
Ecopetrol S.A.’s Production Activities in Colombia |
For the year ended December 31, 2024, Ecopetrol S.A. was the largest participant in the Colombian hydrocarbons industry, accounting for approximately 63.6% of crude oil production and 59.9% of natural gas production (calculations based on information from the Ministry of Mines and Energy ( Ministerio de Minas y Energía or “MME” for its acronym in Spanish ). In 2024, Ecopetrol S.A. drilled and completed 326 development wells, mainly in the Andina Oriente region and some through associated operation with partners (209 through direct operations and 117 through associated companies).
Up until February 16, 2025, Ecopetrol S.A. managed its production operations taking into account the regional location of the operation and whether the operation was carried out in association with partners (“associated operations”). Such organization comprised a total of 158 oil and gas fields with active production in 2024 divided into four regions: (i) Central Region, (ii) Orinoquía Region, (iii) Andina Oriente Region, and (iv) Piedemonte Region. Additionally, we operate 69 fields with active production through associated operations with different partners.
On February 16, 2025, the upstream segment changed its management structure from one defined by regions to one defined by defined by products or asset groups (i.e. oil and gas). This change seeks to strategically redirect the segment to comply with the 2040 Strategy. The map below shows the locations of Ecopetrol S.A.’s operations by region until February 16, 2025.
18
Graph 4 – Ecopetrol S.A. Operations in Colombia
Note: Associated operations are conducted through a countrywide vice-presidency of subsidiaries and assets with partners.
The map below shows the locations of Ecopetrol S.A.’s operations by product, adopted on February 16, 2025.
Graph 5 – Ecopetrol S.A. Operations in Colombia
Note: Associated operation is conducted through a countrywide management of assets with partners.
19
Crude Oil Production
The average daily production of crude oil in Colombia by Ecopetrol S.A. (excluding its subsidiaries), was 491.4 mbd in 2024, 7.3 mbd lower than in 2023, which represents a year-to-year decrease of 1.5%.
The following chart summarizes Ecopetrol S.A.’s average daily crude oil production in Colombia by region, prior to deducting royalties, for the periods indicated.
Table 6 – Ecopetrol S.A.’s Average Daily Crude Oil Production in Colombia by Region
|
|
|
For the year ended December 31, |
||||
|
|
|
2024 |
|
2023 |
|
2022 |
|
|
|
(Thousand bpd) |
||||
|
Central Region |
|
|
|
|
|
|
|
La Cira – Infantas |
|
15.10 |
|
16.35 |
|
17.31 |
|
Casabe |
|
11.62 |
|
12.47 |
|
12.67 |
|
Yarigui |
|
14.28 |
|
15.53 |
|
16.81 |
|
Nare |
|
14.45 |
|
14.79 |
|
15.66 |
|
Other |
|
15.35 |
|
15.98 |
|
16.35 |
|
Total Central Region |
|
70.80 |
|
75.12 |
|
78.80 |
|
Orinoquía Region |
|
|
|
|
|
|
|
Castilla |
|
98.64 |
|
100.69 |
|
102.77 |
|
Chichimene |
|
57.72 |
|
59.03 |
|
62.62 |
|
CPO-09 |
|
12.68 |
|
11.46 |
|
8.95 |
|
Apiay |
|
6.07 |
|
5.04 |
|
4.70 |
|
Other |
|
6.00 |
|
6.63 |
|
7.07 |
|
Total Orinoquía Region |
|
181.11 |
|
182.85 |
|
186.11 |
|
Piedemonte Region |
|
|
|
|
|
|
|
Floreña |
|
16.53 |
|
16.45 |
|
20.02 |
|
Cupiagua |
|
3.75 |
|
3.73 |
|
5.05 |
|
Cusiana |
|
0.70 |
|
0.86 |
|
1.10 |
|
Recetor |
|
1.54 |
|
2.09 |
|
2.37 |
|
Gibraltar (1) |
|
0.59 |
|
0.63 |
|
0.74 |
|
Total Piedemonte Region |
|
23.11 |
|
23.76 |
|
29.28 |
|
Andina Oriente Region |
|
|
|
|
|
|
|
Rubiales |
|
97.98 |
|
103.29 |
|
101.58 |
|
Caño Sur |
|
39.54 |
|
31.91 |
|
7.66 |
|
San Francisco |
|
3.12 |
|
3.43 |
|
3.54 |
|
Huila Area |
|
4.03 |
|
4.19 |
|
4.09 |
|
Tello |
|
3.93 |
|
4.28 |
|
4.38 |
|
Other |
|
8.94 |
|
8.60 |
|
8.52 |
|
Total Andina Oriente Region |
|
157.54 |
|
155.70 |
|
129.77 |
|
Associated Operations |
|
|
|
|
|
|
|
Quifa |
|
12.47 |
|
13.38 |
|
13.97 |
|
Caño Limon |
|
22.44 |
|
23.90 |
|
26.10 |
|
Other |
|
23.91 |
|
24.00 |
|
28.76 |
|
Total Associated Operations |
|
58.82 |
|
61.28 |
|
68.83 |
|
Total average daily crude oil production Ecopetrol S.A. (Colombia) |
|
491.38 |
|
498.71 |
|
492.79 |
|
(1) |
Since 2022, Gibraltar field is included in Table 6 pursuant to the ANH’s request to consider condensate as crude oil production and not as natural gas liquids in this field. |
20
Table 7 – Ecopetrol S.A. Production per Type of Crude
|
|
|
2024 |
|
Year-on-Year |
|
2023 |
|
Year-on-Year |
|
2022 |
|
|
|
(Mbd) |
|
∆ (%) |
|
(Mbd) |
|
∆ (%) |
|
(Mbd) |
|
Light |
|
23.9 |
|
(1.0) |
% |
24.1 |
|
(19.5) |
% |
29.9 |
|
Medium |
|
115.4 |
|
(5.2) |
% |
121.8 |
|
(8.1) |
% |
132.6 |
|
Heavy |
|
352.1 |
|
(0.2) |
% |
352.8 |
|
6.8 |
% |
330.3 |
|
Total |
|
491.4 |
|
(1.5) |
% |
498.7 |
|
1.2 |
% |
492.8 |
Ecopetrol S.A.’s crude oil production in Colombia during 2024 was approximately 72% heavy crudes and 28% light and medium crudes. In 2023, approximately 71% of the crude oil production consisted of heavy crudes, and 29% of the crude oil production consisted of light and medium crudes. In 2022, approximately 67% of the crude oil production consisted of heavy crudes and 33% consisted of light and medium crudes.
Natural Gas Production
In 2024, the average daily production of natural gas by Ecopetrol S.A. (excluding its subsidiaries) reached 118.26 mboed, including natural gas liquids (NGLs), corresponding to a 3.6% decrease compared to 2023 production. This production was supplied from the following fields: Floreña (36.0%), Cupiagua (31.9%), Cusiana (14.4%), Guajira (7.2%), and the remaining 10.5% from other fields.
By the end of December 31, 2024, the Liquefied Petroleum Gas (“LPG”) plant of the Cupiagua field produced 9,455 LPG barrels per day. The plant produces LPG and other products such as natural gas liquids (NGL), and penthane (C5).
21
Table 8 – Ecopetrol S.A.’s Average Daily Natural Gas Production in Colombia
|
|
|
For the year ended December 31, |
||||||||||
|
|
|
2024 |
|
2023 |
|
2022 |
||||||
|
|
|
Thousand |
|
|
|
Thousand |
|
|
|
Thousand |
|
|
|
|
|
bpd |
|
mmcfpd |
|
bpd |
|
mmcfpd |
|
bpd |
|
mmcfpd |
|
Central Region |
|
|
|
|
|
|
|
|
|
|
|
|
|
La Cira – Infantas |
|
0.46 |
|
2.11 |
|
0.43 |
|
1.99 |
|
0.29 |
|
1.51 |
|
Provincia |
|
1.17 |
|
3.67 |
|
1.00 |
|
2.73 |
|
1.00 |
|
2.29 |
|
Yarigui |
|
0.24 |
|
1.39 |
|
0.37 |
|
2.13 |
|
0.29 |
|
1.70 |
|
Other |
|
1.84 |
|
9.55 |
|
1.72 |
|
8.9 |
|
1.68 |
|
8.98 |
|
Total Central Region |
|
3.71 |
|
16.72 |
|
3.52 |
|
15.75 |
|
3.26 |
|
14.48 |
|
Orinoquía Region |
|
|
|
|
|
|
|
|
|
|
|
|
|
Apiay |
|
0.12 |
|
— |
|
0.14 |
|
— |
|
0.12 |
|
— |
|
Other |
|
0.29 |
|
— |
|
0.40 |
|
— |
|
0.41 |
|
— |
|
Total Orinoquía Region |
|
0.41 |
|
— |
|
0.54 |
|
— |
|
0.53 |
|
— |
|
Piedemonte Region |
|
|
|
|
|
|
|
|
|
|
|
|
|
Floreña |
|
42.58 |
|
215.49 |
|
42.10 |
|
212.04 |
|
39.53 |
|
197.18 |
|
Cupiagua |
|
37.71 |
|
169.23 |
|
41.16 |
|
183.87 |
|
45.19 |
|
205.29 |
|
Cusiana |
|
16.99 |
|
81.61 |
|
23.84 |
|
113.63 |
|
23.02 |
|
106.47 |
|
Gibraltar |
|
5.70 |
|
32.48 |
|
5.68 |
|
32.41 |
|
6.46 |
|
36.81 |
|
Total Piedemonte Region |
|
102.98 |
|
498.81 |
|
112.78 |
|
541.95 |
|
114.20 |
|
545.75 |
|
Andina Oriente Region |
|
|
|
|
|
|
|
|
|
|
|
|
|
Huila Area |
|
0.17 |
|
0.33 |
|
0.28 |
|
0.9 |
|
0.29 |
|
0.94 |
|
Tello |
|
0.06 |
|
0.32 |
|
0.07 |
|
0.4 |
|
0.07 |
|
0.32 |
|
Other |
|
0.28 |
|
1.24 |
|
0.30 |
|
1.35 |
|
0.38 |
|
1.88 |
|
Total Andina Oriente Region |
|
0.51 |
|
1.89 |
|
0.65 |
|
2.65 |
|
0.74 |
|
3.14 |
|
Associated Operations |
|
|
|
|
|
|
|
|
|
|
|
|
|
Guajira |
|
8.57 |
|
48.86 |
|
9.93 |
|
56.62 |
|
12.23 |
|
69.70 |
|
Other |
|
2.08 |
|
8.16 |
|
1.75 |
|
7.24 |
|
1.73 |
|
7.22 |
|
Total Associated Operations |
|
10.65 |
|
57.02 |
|
11.68 |
|
63.86 |
|
13.96 |
|
76.92 |
|
Total Natural Gas Production (Colombia) |
|
118.26 |
|
574.44 |
|
129.17 |
|
624.21 |
|
132.69 |
|
640.29 |
Note: Conversion between mcfpd and boepd is performed at 5,700 mcfpd to 1 boepd. Conversion was done only in respect of natural gas since natural gas liquids cannot be converted into mcfpd. Therefore, when the Company’s natural gas production is measured in boepd, it is higher as that includes natural gas and natural gas liquids. Ecopetrol S.A.’s sales of natural gas liquids represented less than 2.9 % of the Ecopetrol S.A.’s consolidated production for the periods presented in this annual report.
Projects to Increase Recovery Factor
In 2024, Ecopetrol continued to implement recovery programs to enhance the recovery factor of the fields. By year-end 2024, the fields with secondary and tertiary recovery programs contributed 41% of the Ecopetrol Group’s production.
The recovery programs increased proven reserves by 97 mmboe with an investment of approximately USD 662 million distributed among 36 recovery projects, 32 of which correspond to secondary recovery and four to tertiary recovery.
22
Development Wells
The following table sets forth the number of gross and net development wells drilled and completed or plugged and abandoned in Colombia, both solely by Ecopetrol S.A. and with its associates, that reached total depth for the years ended December 31, 2024, 2023 and 2022.
Table 9 – Ecopetrol S.A.’s Gross and Net Development Wells in Colombia (1)
|
|
|
For the year ended December 31, |
||||||||||
|
|
|
2024 |
|
2023 |
|
2022 |
||||||
|
|
|
Productive |
|
Dry |
|
Productive |
|
Dry |
|
Productive |
|
Dry |
|
|
|
Wells |
|
Wells |
|
Wells |
|
Wells |
|
Wells |
|
Wells |
|
Central Region |
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross development wells owned and operated by Ecopetrol |
|
— |
|
1.0 |
|
1.0 |
|
1.0 |
|
43.0 |
|
— |
|
Orinoquía Region |
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross development wells owned and operated by Ecopetrol |
|
21.0 |
|
— |
|
21.0 |
|
1.0 |
|
12.0 |
|
— |
|
Andina Oriente Region |
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross development wells owned and operated by Ecopetrol |
|
176.0 |
|
— |
|
181.0 |
|
4.0 |
|
185.0 |
|
— |
|
Piedemonte Region |
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross development wells owned and operated by Ecopetrol |
|
1.0 |
|
— |
|
2.0 |
|
- |
|
1.0 |
|
— |
|
Total gross development wells owned and operated in Colombia |
|
198.0 |
|
1.0 |
|
205.0 |
|
6.0 |
|
241.0 |
|
— |
|
Associated Operations |
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross development wells in joint ventures |
|
128.0 |
|
2.0 |
|
131.0 |
|
— |
|
171.0 |
|
1.0 |
|
Net development wells |
|
67.18 |
|
0.5 |
|
79.8 |
|
— |
|
103.96 |
|
0.55 |
|
Total gross development wells in joint ventures Ecopetrol S.A. in Colombia |
|
128.0 |
|
2.0 |
|
131.0 |
|
— |
|
171 |
|
1.0 |
|
Total net development wells in joint ventures Ecopetrol S.A. in Colombia (2) |
|
67.18 |
|
0.5 |
|
79.8 |
|
— |
|
103.96 |
|
0.55 |
|
Total gross development wells Ecopetrol S.A. in Colombia |
|
326 |
|
3 |
|
336.0 |
|
6.0 |
|
412 |
|
1.0 |
|
Total net development wells Ecopetrol S.A. in Colombia (2) |
|
265.18 |
|
1.5 |
|
284.8 |
|
6.0 |
|
344.96 |
|
0.55 |
|
(1) |
Includes only wells that were drilled and completed or plugged and abandoned. |
|
(2) |
Net wells correspond to the sum of wells owned and operated by us plus the net wells in our associated operations. Net wells in the associated operations are the result of our working interest in wells owned in joint ventures with our partners, as defined in the contract obligations. |
23
The following tables set forth activities by geographical area, including the number of gross and net wells in the process of being drilled, completed, or waiting on completion for the year ended December 31, 2024.
Table 10 – Ecopetrol S.A.’s Gross and Net In Process Wells
|
|
|
For the year ended December 31, 2024 |
||||||
|
|
|
Drilled |
|
|
|
|
|
|
|
|
|
but not |
|
|
|
Being |
|
Being |
|
|
|
completed |
|
Mobilization |
|
drilled |
|
completed |
|
|
|
(Number of wells) |
||||||
|
COLOMBIA |
|
|
|
|
|
|
|
|
|
Central Region |
|
|
|
|
|
|
|
|
|
Gross in process wells owned and operated by Ecopetrol |
|
— |
|
— |
|
— |
|
— |
|
Orinoquía Region |
|
|
|
|
|
|
|
|
|
Gross in process wells owned and operated by Ecopetrol |
|
2.0 |
|
1.0 |
|
1.0 |
|
— |
|
Andina Oriente Region |
|
|
|
|
|
|
|
|
|
Gross in process wells owned and operated by Ecopetrol |
|
— |
|
2.0 |
|
4.0 |
|
— |
|
Piedemonte Region |
|
|
|
|
|
|
|
|
|
Gross in process wells owned and operated by Ecopetrol |
|
— |
|
— |
|
1.0 |
|
— |
|
Total gross in process wells owned and operated in Colombia |
|
2.0 |
|
3.0 |
|
6.0 |
|
0.0 |
|
Associated Operations |
|
|
|
|
|
|
|
|
|
Gross in process wells in joint ventures |
|
6.0 |
|
— |
|
— |
|
2.0 |
|
Net in process wells (1) |
|
3.4 |
|
— |
|
— |
|
1.1 |
|
Total gross in process wells in joint ventures Ecopetrol S.A. |
|
6.0 |
|
— |
|
— |
|
2.0 |
|
Total net in process wells in joint ventures Ecopetrol S.A. (1) |
|
3.4 |
|
— |
|
— |
|
1.1 |
|
Total gross in process wells Ecopetrol S.A. in Colombia |
|
8.0 |
|
3.0 |
|
6.0 |
|
2.0 |
|
Total net in process wells Ecopetrol S.A. in Colombia (1) |
|
5.4 |
|
3.0 |
|
6.0 |
|
1.1 |
|
(1) |
Net wells correspond to the sum of wells owned and operated by Ecopetrol plus the net wells in our associated operations. Net wells in the associated operations are the result of our working interest in wells owned in joint ventures with our partners, as defined in the contract obligations. |
Production Acreage
The following table sets forth Ecopetrol S.A.’s developed and undeveloped gross and net acreage of crude oil and natural gas production in Colombia for the year ended December 31, 2024.
Table 11 – Ecopetrol SA.’s Developed and Undeveloped Gross and Net Acreage of Crude Oil and Natural Gas Production in Colombia
|
|
|
For the year ended December 31, 2024 |
||||||
|
|
|
Developed |
|
Undeveloped |
||||
|
|
|
Gross |
|
Net (Acres) |
|
Gross |
|
Net (Acres) |
|
|
|
|
||||||
|
Ecopetrol S.A. |
|
429,536 |
|
371,616 |
|
3,945,532 |
|
2,993,850 |
24
Gross and Net Productive Wells
The following table sets forth Ecopetrol S.A.’s total gross and net productive wells by region for the year ended December 31, 2024.
Table 12 – Ecopetrol S.A.’s Gross and Net Productive Wells by Region (1)(2)
|
|
|
For the year ended December 31, 2024 |
||||||
|
|
|
Crude Oil (3) |
|
Natural Gas (4) |
||||
|
|
|
Gross |
|
Net (5) |
|
Gross |
|
Net (5) |
|
|
|
(Number of wells) |
||||||
|
COLOMBIA |
|
|
|
|
|
|
|
|
|
Central Region |
|
3,404 |
|
2,877 |
|
18 |
|
17 |
|
Orinoquía Region |
|
987 |
|
963 |
|
— |
|
— |
|
Andina Oriente Region |
|
1,627 |
|
1,615 |
|
1 |
|
1 |
|
Piedemonte Region |
|
60 |
|
60 |
|
7 |
|
7 |
|
Associated Operations |
|
1,537 |
|
886 |
|
28 |
|
17 |
|
Total |
|
7,615 |
|
6,401 |
|
54 |
|
42 |
|
(1) |
The table reflects the productive wells that directly contribute to hydrocarbon production and therefore excludes wells used for injection, disposal, water abstraction, or other similar activities. |
|
(2) |
Includes only wells that were drilled and completed. |
|
(3) |
We consider crude oil wells to be those in which the main operation is oil production, although many of these wells produce gas associated with oil production that, in some cases, have a commercial purpose. |
|
(4) |
Natural gas wells are those in which operations are directed only toward the production of commercial gas. |
|
(5) |
Net productive wells are calculated by multiplying gross productive wells by our ownership percentage. |
|
3.5.2.1.2 |
Ecopetrol S.A.’s Affiliates and Subsidiaries’ Production Activities in Colombia |
In 2024, the subsidiaries’ production in Colombia came from Hocol, with a production of 34.9 mboed, which represents 4.7% of the Ecopetrol Group’s total production.
Crude Oil Production
The following table sets forth our average daily crude oil production from Hocol, prior to deducting royalties, for the periods indicated.
Table 13 – Ecopetrol S.A.’s Subsidiaries in Colombia Average Daily Crude Oil Production
|
|
|
For the year ended December 31, |
||||
|
|
|
2024 |
|
2023 |
|
2022 |
|
|
|
(Thousand bpd) |
||||
|
COLOMBIA |
|
|
|
|
|
|
|
Hocol |
|
|
|
|
|
|
|
Joint venture operation |
|
3.49 |
|
1.77 |
|
1.35 |
|
Direct operation |
|
14.53 |
|
15.25 |
|
15.75 |
|
Total Hocol |
|
18.02 |
|
17.02 |
|
17.10 |
|
Total Average Daily Crude Oil Production (Subsidiaries in Colombia) |
|
18.02 |
|
17.02 |
|
17.10 |
25
Natural Gas Production
The following table sets forth our subsidiaries’ average daily natural gas production, prior to deducting royalties, for the periods indicated.
Table 14 – Ecopetrol S.A.’s Subsidiaries in Colombia Average Daily Natural Gas Production
|
|
|
For the year ended December 31, |
||||||||||
|
|
|
2024 |
|
2023 |
|
2022 |
||||||
|
|
|
Thousand |
|
|
|
Thousand |
|
|
|
Thousand |
|
|
|
|
|
bpd |
|
mmcfpd |
|
bpd |
|
mmcfpd |
|
bpd |
|
mmcfpd |
|
COLOMBIA |
|
|
|
|
|
|
|
|
|
|
|
|
|
Hocol |
|
|
|
|
|
|
|
|
|
|
|
|
|
Joint venture operation |
|
2.62 |
|
14.95 |
|
3.12 |
|
17.80 |
|
2.71 |
|
15.45 |
|
Direct operation |
|
14.26 |
|
81.29 |
|
15.31 |
|
87.26 |
|
17.06 |
|
97.24 |
|
Total Hocol |
|
16.88 |
|
96.24 |
|
18.43 |
|
105.06 |
|
19.77 |
|
112.69 |
|
Production Tests |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
Total Average Daily Gas Production (Subsidiaries in Colombia) |
|
16.88 |
|
96.24 |
|
18.43 |
|
105.06 |
|
19.77 |
|
112.69 |
Note: Conversion between mcfpd and boepd is performed at 5,700 mcfpd to 1 boepd.
Development Wells
The following table sets forth the number of gross and net development wells drilled and completed exclusively by our subsidiaries and in their joint ventures in Colombia for the periods indicated.
Table 15 – Ecopetrol S.A.’s Subsidiaries in Colombia Gross and Net Development Wells (1)
|
|
|
For the year ended December 31, |
||||||||||
|
|
|
2024 |
|
2023 |
|
2022 |
||||||
|
|
|
Productive |
|
Dry |
|
Productive |
|
Dry |
|
Productive |
|
Dry |
|
|
|
Wells |
|
Wells |
|
Wells |
|
Wells |
|
Wells |
|
Wells |
|
|
|
(Number of wells) |
||||||||||
|
Hocol |
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross development wells owned and operated by Hocol |
|
3.0 |
|
— |
|
14.0 |
|
1.0 |
|
18.0 |
|
1.0 |
|
Gross development wells in joint ventures |
|
— |
|
— |
|
2.0 |
|
— |
|
2.0 |
|
— |
|
Net development wells (2) |
|
3.0 |
|
— |
|
15.0 |
|
1.0 |
|
19.0 |
|
1.0 |
|
Total gross development wells owned and operated in Colombia |
|
3.0 |
|
— |
|
14.0 |
|
1.0 |
|
18.0 |
|
1.0 |
|
Total gross development wells in joint ventures in Colombia |
|
— |
|
— |
|
2.0 |
|
— |
|
2.0 |
|
— |
|
Total net development wells (Subsidiaries in Colombia) (2) |
|
3.0 |
|
— |
|
15.0 |
|
1.0 |
|
19.0 |
|
1.0 |
|
(1) |
Includes only wells that were drilled and completed. |
|
(2) |
Net wells correspond to the sum of wells owned and operated by us plus the net wells in our associated operations. Net wells in the associated operations are the result of our working interest in wells owned in joint ventures with our partners, as defined in the contract obligations. |
There were no gross and net in process wells drilled and completed exclusively by our subsidiaries and in their joint ventures in Colombia for the year ended December 31, 2024.
26
Production Acreage
The following table sets forth our subsidiaries developed and undeveloped gross and net acreage of crude oil and natural gas production in Colombia for the year ended December 31, 2024.
Table 16 – Ecopetrol S.A.’s Subsidiaries in Colombia Developed and Undeveloped Gross and Net Acreage of Crude Oil and Natural Gas Production
|
|
|
For the year ended December 31, 2024 |
||||||
|
|
|
Developed |
|
Undeveloped |
||||
|
|
|
Gross |
|
Net |
|
Gross |
|
Net |
|
|
|
(Acres) |
||||||
|
Hocol |
|
63,888 |
|
39,758 |
|
855 |
|
696 |
|
Total |
|
63,888 |
|
39,758 |
|
855 |
|
696 |
The following table sets for the expiration dates of material concentrations of the Company’s consolidated undeveloped acreage by geographic area as of December 31, 2024.
Table 17 – Undeveloped Production Acreage as of December 31, 2024 by Expiration Year
|
|
|
For the year ended December 31, |
||||||||||||||||||
|
|
|
2025 |
|
2026 |
|
2027 |
|
2028 |
|
2029 and beyond |
||||||||||
|
|
|
Gross |
|
Net |
|
Gross |
|
Net |
|
Gross |
|
Net |
|
Gross |
|
Net |
|
Gross |
|
Net |
|
|
|
(Acres) |
||||||||||||||||||
|
COLOMBIA |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Ecopetrol S.A. (1) |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
509,920 |
|
509,920 |
|
Hocol |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
Total Colombia |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
509,920 |
|
509,920 |
|
UNITED STATES OF AMERICA |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Ecopetrol America LLC |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
Ecopetrol Permian LLC (2) |
|
39 |
|
39 |
|
5,233 |
|
5,233 |
|
10 |
|
10 |
|
— |
|
— |
|
— |
|
— |
|
Total United States of America |
|
39 |
|
39 |
|
5,233 |
|
5,233 |
|
10 |
|
10 |
|
— |
|
— |
|
— |
|
— |
|
(1) |
Inclusive of potentially material areas with an expiration date. Areas which represent more than 5% of the total net undeveloped areas are considered material. Areas that can be developed until their resources are exhausted or until they need to be reverted to their owners, are not included. |
|
(2) |
Net acres correspond to our share and includes only acreage under direct operation by Occidental Petroleum. Non-operated acreage is not included because they are not considered material. |
Gross and Net Productive Wells
The following table sets forth our subsidiaries’ total gross and net productive wells in Colombia for the year ended December 31, 2024.
Table 18 – Ecopetrol S.A.’s Subsidiaries in Colombia Gross and Net Productive Wells (1)(2)
|
|
|
For the year ended December 31, 2024 |
||||||
|
|
|
Crude Oil (3) |
|
Natural Gas (4) |
||||
|
|
|
Gross |
|
Net (5) |
|
Gross |
|
Net (5) |
|
|
|
(Number of wells) |
||||||
|
Hocol |
|
404 |
|
367.7 |
|
47 |
|
27.9 |
|
Total (Subsidiaries in Colombia) |
|
404 |
|
367.7 |
|
47 |
|
27.9 |
|
(1) |
The table reflects productive wells that directly contribute to hydrocarbons production and therefore excludes wells used for injection, disposal, water abstraction or other similar activities. |
|
(2) |
Includes only wells that were drilled and completed. |
|
(3) |
We consider crude oil wells to be those in which the main operation is oil production, although many of these wells produce gas associated with oil production that, in some cases, have a commercial purpose. |
|
(4) |
Natural gas wells are those in which operations are directed only towards the production of commercial gas. |
|
(5) |
Net wells correspond to the sum of wells entirely owned by us or our subsidiaries and our ownership percentage of wells owned in joint ventures with our partners. |
27
|
3.5.2.2 |
Production Activities Outside Colombia |
In 2024, the subsidiaries’ production outside Colombia came mainly from Ecopetrol America LLC and Ecopetrol Permian LLC. In 2024, the production obtained from these two companies was 101.27 mboed, which represents 13.6% of the Ecopetrol Group’s total production.
Crude Oil Production
The following table sets forth our average daily crude oil production outside Colombia, prior to deducting royalties, for the periods indicated.
Table 19 – Ecopetrol S.A.’s Subsidiaries Outside Colombia Average Daily Crude Oil Production
|
|
|
For the year ended December 31, |
||||
|
|
|
2024 |
|
2023 |
|
2022 |
|
|
|
(Thousand bpd) |
||||
|
UNITED STATES OF AMERICA |
|
|
|
|
|
|
|
Ecopetrol America LLC |
|
6.68 |
|
5.86 |
|
8.10 |
|
Ecopetrol Permian LLC |
|
53.69 |
|
38.61 |
|
23.84 |
|
Total average daily crude oil production (International) |
|
60.37 |
|
44.47 |
|
31.94 |
Natural Gas Production
The following table sets forth our average daily natural gas production outside Colombia, prior to deducting royalties, for the periods indicated.
Table 20 – Ecopetrol S.A.’s Subsidiaries Outside Colombia Average Daily Natural Gas Production
|
|
|
For the year ended December 31, |
||||||||||
|
|
|
2024 |
|
2023 |
|
2022 |
||||||
|
|
|
Thousand |
|
|
|
Thousand |
|
|
|
Thousand |
|
|
|
|
|
bpd |
|
mmcfpd |
|
bpd |
|
mmcfpd |
|
bpd |
|
mmcfpd |
|
UNITED STATES OF AMERICA |
|
|
|
|
|
|
|
|
|
|
|
|
|
Ecopetrol America LLC |
|
0.83 |
|
4.73 |
|
0.95 |
|
5.41 |
|
1.21 |
|
6.89 |
|
Ecopetrol Permian LLC |
|
40.06 |
|
102.34 |
|
27.82 |
|
70.11 |
|
13.95 |
|
35.77 |
|
Total average daily natural gas production (International) |
|
40.89 |
|
107.07 |
|
28.77 |
|
75.52 |
|
15.16 |
|
42.66 |
Note: Conversion between mcfpd and boepd is performed at 5,700 mcfpd to 1 boepd. Conversion was done only in respect of natural gas since natural gas liquids cannot be converted into mcfpd. Therefore, when the Company’s natural gas production is measured in boepd, it is higher as that includes natural gas and natural gas liquids. The sales of natural gas liquids by Ecopetrol S.A.’s subsidiaries outside Colombia represented less than 21.8% of the consolidated production by Ecopetrol S.A.’s subsidiaries outside Colombia for the periods presented in this annual report.
28
Development Wells
The following table sets forth the number of gross and net development wells outside Colombia, drilled and completed exclusively by us and in joint ventures for the periods indicated.
Table 21 – Ecopetrol S.A.’s Subsidiaries Outside Colombia Gross and Net Development Wells (1)
|
|
|
2024 |
|
2023 |
|
2022 |
||||||
|
|
|
Productive |
|
Dry |
|
Productive |
|
Dry |
|
Productive |
|
Dry |
|
Number of wells |
|
Wells |
|
Wells |
|
Wells |
|
Wells |
|
Wells |
|
Wells |
|
UNITED STATES OF AMERICA |
|
|
|
|
|
|
|
|
|
|
|
|
|
Ecopetrol America LLC |
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross development wells |
|
1 |
|
— |
|
2.0 |
|
— |
|
— |
|
— |
|
Net development wells (2) |
|
0.2 |
|
— |
|
0.6 |
|
— |
|
— |
|
— |
|
Ecopetrol Permian LLC |
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross development wells |
|
105.0 |
|
2.0 |
|
111.0 |
|
— |
|
102.0 |
|
1.0 |
|
Net development wells (2) |
|
61.0 |
|
1.1 |
|
67.5 |
|
— |
|
50.0 |
|
0.5 |
|
Total gross wells (International) |
|
106.0 |
|
2.0 |
|
113.0 |
|
— |
|
102.0 |
|
1.0 |
|
Total net wells (International) (2) |
|
61.2 |
|
1.1 |
|
68.1 |
|
— |
|
50.0 |
|
0.5 |
|
(1) |
Includes only wells that were drilled and completed. |
|
(2) |
Net wells correspond to the sum of wells entirely owned by us or our subsidiaries and our ownership percentage of wells owned in joint ventures with our partners. |
Table 22 – Ecopetrol S.A.’s Subsidiaries Outside Colombia Gross and Net In Process Wells
|
|
|
For the year ended December 31, 2024 |
||||||
|
|
|
Drilled |
|
|
|
|
|
|
|
|
|
but not |
|
|
|
Being |
|
Being |
|
|
|
completed |
|
Mobilization |
|
drilled |
|
completed |
|
|
|
(Number of wells) |
||||||
|
UNITED STATES OF AMERICA |
|
|
|
|
|
|
|
|
|
Ecopetrol America LLC |
|
|
|
|
|
|
|
|
|
Gross in process wells |
|
— |
|
— |
|
— |
|
— |
|
Net in process wells (1) |
|
— |
|
— |
|
— |
|
— |
|
Ecopetrol Permian LLC (2) |
|
|
|
|
|
|
|
|
|
Gross in process wells |
|
22.0 |
|
— |
|
9.0 |
|
10.0 |
|
Net in process wells (1) |
|
14.6 |
|
— |
|
5.2 |
|
3.5 |
|
Total gross in process wells (International) |
|
22.0 |
|
— |
|
9.0 |
|
10.0 |
|
Total net in process wells (International) (1) |
|
14.6 |
|
— |
|
5.2 |
|
3.5 |
|
(1) |
Net wells correspond to the sum of wells owned and operated by us plus the net wells in our associated operations. Net wells in the associated operations are the result of our working interest in wells owned in joint ventures with our partners, as defined in the contract obligations. |
|
(2) |
Includes only wells under direct operation by Occidental Petroleum. Non -operated wells are not included because they are not material. |
29
Production Acreage
The following table sets forth our developed and undeveloped gross and net acreage of crude oil and natural gas production outside Colombia for the year ended December 31, 2024.
Table 23 – Ecopetrol S.A.’s Subsidiaries Outside Colombia Developed and Undeveloped Gross and Net Acreage of Crude Oil and Natural Gas Production
|
|
|
For the year ended December 31, 2024 |
||||||
|
|
|
Developed |
|
Undeveloped |
||||
|
|
|
Gross |
|
Net |
|
Gross |
|
Net |
|
|
|
(Acres) |
||||||
|
UNITED STATES OF AMERICA |
|
|
|
|
|
|
|
|
|
Ecopetrol America LLC |
|
56,420 |
|
14,773 |
|
— |
|
— |
|
Ecopetrol Permian LLC (1) |
|
54,366 |
|
41,595 |
|
5,283 |
|
5,283 |
|
Total (International) |
|
110,786 |
|
56,368 |
|
5,283 |
|
5,283 |
|
(1) |
Inclusive of acreage held by production. |
Gross and Net Productive Wells
The following table sets forth our total gross and net productive wells outside Colombia for the year ended December 31, 2024.
Table 24 – Ecopetrol S.A.’s Subsidiaries Outside Colombia Gross and Net Productive Wells (1)
|
|
|
For the year ended |
||
|
|
|
December 31, 2024 |
||
|
|
|
Crude Oil |
||
|
|
|
Gross |
|
Net |
|
|
|
(Number of wells) |
||
|
UNITED STATES OF AMERICA |
|
|
|
|
|
Ecopetrol America LLC |
|
20 |
|
5 |
|
Ecopetrol Permian LLC (4) |
|
420 |
|
240.18 |
|
Total (International) |
|
440 |
|
245.18 |
| (1) | The table reflects productive wells that directly contribute to hydrocarbons production and therefore excludes wells used for injection, disposal, water abstraction or other similar activities. |
|
3.5.2.3 |
Unconventional Hydrocarbons |
On February 28, 2020, the Colombian Government, issued the Decree 328, providing the general guidelines for developing Integral Research Pilot Projects (PPIIs), followed by the issuance of corresponding environmental technical and social regulation by other Ministries to allow PPIIs to be performed. Furthermore, on December 24, 2020, Ecopetrol S.A. signed a Special Contract for Research Projects (Contrato Especial de Proyectos de Investigación, or “CEPI” for its acronym in Spanish) with the ANH regarding the development of a PPII, entitled Kalé. On June 4, 2021, Exxon Mobil Colombia signed a contract for the development of a PPII located near Ecopetrol S.A.’s PPII area, named Platero. On June 17, 2021, Exxon Mobil and Ecopetrol S.A. signed a consortium to jointly develop both PPIIs, in which Ecopetrol S.A. is the consortium operator.
The Government of Colombia (Ministry of Mines and Energy and Ministry of Environment and Sustainable Development) has announced a change in the energy policy of the country, according to which it seeks to prohibit activities related to the application of the technique known as “fracking”, including the prohibition of the Integral Research Pilot Projects PPII which were being executed through the referred CEPIs. In connection to said new policy, on September 9, 2022, Ecopetrol S.A and ExxonMobil requested to the ANH the suspension of the CEPIs.
30
On September 23, 2022, Ecopetrol S.A. filed a request for the suspension of the environmental obligations of Resolutions 00648 of March 25, 2022, and 01283 of June 10, 2022 before the National Authority of Environmental Licenses (“ANLA” for its acronym in Spanish), relating to the environmental license for the PPII Kalé. On September 29, 2022, the ANLA accepted Ecopetrol’s request and suspended such environmental obligations relating to the environmental license for PPII Kalé.
On November 4, 2022, in response to the request for suspension of the CEPIs filed on September 9, 2022, the ANH published Agreement 009, through which it was authorized to amend Clause 55 of the CEPIs, to allow for the suspension by mutual agreement of such contracts.
On December 28, 2022, the CEPI Kalé was formally amended to allow for its suspension by mutual agreement, as authorized by Agreement 009 of November 4, 2022, and was extended by Suspension Agreement No. 2 on October 4, 2023.
After a failed attempt with a bill proposed in 2022, a new bill to prohibit fracking was proposed to the legislative branch in 2024. Ecopetrol is currently awaiting the outcome of the legislative process in the Colombian Congress regarding such bill.
For more information see Applicable Laws and Regulations and Risk Factors – Risks Related to Our Operations .
In addition, in connection with Ecopetrol’s unconventional resources strategy outside Colombia, in 2019 we formed a joint venture (JV) with Occidental Petroleum Corp. (“Occidental Petroleum”) for the development of approximately 97,000 acres in the Midland Basin, within the Permian Basin, Texas, by which we acquired 49% of Rodeo Midland Basin LLC (“Rodeo JV”).
See section Business Overview—Exploration and Production—Production Activities—Production Activities Outside Colombia .
As of January 1, 2022, the Rodeo JV agreement with the Company and Occidental Petroleum was amended to provide Ecopetrol access to a larger production stake (75%) and adjust the carry obligation in the Midland area of the Permian Basin. On June 17, 2022, Ecopetrol Permian LLC (a subsidiary of Ecopetrol) signed a Joint Development Agreement (JDA) with certain Occidental Petroleum subsidiaries to carry out drilling and production programs from 2022 to 2027, in an area of approximately 21,000 acres located in Permian Basin. The agreement allowed Ecopetrol to expand its presence in the Permian with an approximately 49% interest stake of drilling and production programs in this area.
On September 11, 2023, Ecopetrol announced certain adjustments to its 2040 Strategy, including that unconventional hydrocarbon exploration activities will not be pursued in Colombia, among other updates. See section 2040 Strategy: Energy That Transforms.
On February 3, 2025, Ecopetrol and Oxy announced they reached an agreement to extend the Midland development plan, in the Permian Basin, until June 2026, under the joint-venture established in July 2019. The agreement maintains the possibility of signing a new extension of the development plan in the future, subject to the macroeconomic environment, industry situation, and partners’ interests. Ecopetrol and Oxy expect to keep an independent contract for the development of the Delaware subbasin active, which is expected to remain in force until 2027. Ecopetrol Permian’s 2025 Plan for Midland and Delaware sub-basins intends to include the drilling of approximately 91 development wells, with an estimated investment of USD 885 million and an average annual production of approximately 90 thousand barrels of oil equivalent per day (net to Ecopetrol Permian).
For more information, see section Business Overview—Applicable Laws and Regulations and section Risk Review—Risk Factors—Risks Related to Our Business .
|
3.5.2.4 |
Marketing of Crude Oil and Natural Gas |
In 2024, we sold 1,011.6 mboed, out of which 466.8 mboed represented sales of fuels and petrochemicals (46%), 445.9 mboed represented sales of crude oil (44%), and 99.0 mboed sales of natural gas (10%).
Crude Oil Export Sales
In 2024, crude oil export sales totaled 445.9 mboed and increased by 15.9 mboed compared to 2023, mainly due to higher production (10 mboed). Our crude oil export sales are traded both in the spot and contract markets, primarily to refiners in Asia and the United States.
31
The Castilla blend is the main type of crude oil for export sales, with 270.9 mboed sold during 2024 (a 61% share of the crude oil basket) followed by the Apiay blend with 61.5 mboed (a 14% share of the crude oil basket), the Mares blend with 32.0 mboed (a 7% share of the crude oil basket) and the domestic crudes from Ecopetrol Permian LLC with 40.6 mboed (a 9% share of the crude oil basket).
We place our exports in markets that provide the best value for its crudes. In 2024, Asia was the main destination, representing 50% of crude oil exports, followed by the United States with 44%. Crude oil flows from Colombia to Asia were supported by the refining capacity’s growth, mainly in China, as well as the increase in crude oil demand from India. At the same time, the United States kept a strong position as a result of its economic activity.
Moreover, volatility in the production of regional competitors has given refiners in the United States, India, and other markets an incentive to diversify their supply sources, which in turn has opened opportunities for Colombian producers. Our crude basket realization price decreased by USD 0.1/Bl year over year, due to market conditions.
Crude Oil Purchase Contracts
We have signed several crude oil purchase contracts with third parties and business partners. We also purchased the country’s crude oil royalties from the ANH. These crudes are processed in our refineries or exported. The purchase price is referenced to export parity based on international market prices, plus a commercial fee. See section Business Overview—Related Party and Intercompany Transactions .
The table below sets forth the volumes of crude oil purchased from our business partners and third parties and volumes of crude oil purchased from the ANH from royalties for the years ended on December 31, 2024, 2023 and 2022.
Table 25 – Ecopetrol Consolidated Crude Oil Purchases
|
|
|
For the year ended December 31, |
||||
|
|
|
2024 |
|
2023 |
|
2022 |
|
|
|
(Million barrels) |
||||
|
Crude oil purchased from ANH royalties |
|
35.5 |
|
32.1 |
|
27.2 |
|
Crude oil purchased from third parties |
|
42.7 |
|
42.7 |
|
42.2 |
|
Crude oil imported from third parties |
|
16.8 |
|
23.0 |
|
12.1 |
During 2024, part of our crude strategy was centered on increasing the purchase and subsequent commercialization of crude oil from third parties, which enables further optimization of the supply chain and margin capture.
Import of Diluents
In 2024, we increased the imports of diluent by 15% (3.7 mboed) compared to 2023, due to higher crude sales. Diluent is used to transport heavy crudes through the pipeline system.
Natural Gas Sales
We sell natural gas to distribution companies through firm, interruptible and conditional contracts. These distributors supply natural gas to the residential market, as compressed natural gas for vehicles market and to large industrials in Colombia. We also market and sell natural gas directly to the industrial sector and to gas-fired power plants.
Our natural gas sales and self-consumption in 2024 decreased by 3.34% (-0.0047 mboed) compared to 2023, mainly due to the decrease in production from large fields and external events that affected production (-0.0104 mboed), which was partially offset by the increase in production in the Permian (+0.0057 mboed).
32
Natural Gas Delivery Commitments
The table below sets forth the commitments we have in Colombia under firm contracts with local natural gas distribution companies, local industries, gas-fired power generators and internal agreements with our refineries and fields.
Table 26 – Ecopetrol Consolidated Natural Gas Delivery Commitments
|
|
|
For the year ended December 31, |
||||||
|
|
|
2025 |
|
2026 |
|
2027 |
|
2028 |
|
|
|
(GBtud) |
||||||
|
Volume for sales third parties |
|
362.60 |
|
160.70 |
|
140.6 |
|
44.90 |
|
Volume for self-consumption |
|
119.40 |
|
154.10 |
|
154.70 |
|
154.61 |
|
Volume for intercompany sales |
|
53.20 |
|
54.10 |
|
51.60 |
|
42.20 |
|
Total Commitments |
|
535.20 |
|
368.90 |
|
346.90 |
|
241.71 |
The table above is based on current contracts of Ecopetrol S.A. and the official report made to the Ministry of Mines and Energy in 2024. Self-consumption volumes decreased over time as a result of more efficient operations in our refineries. Third party volumes do not include potential production coming from exploratory projects. According to current regulations, these volumes will be committed and commercialized after declaring exploratory success.
|
3.5.3 |
Reserves |
The reserves reporting process was conducted in accordance with SEC definitions and rules set forth in Rule 4-10(a) of Regulation S-X and the disclosure guidelines contained in the SEC’s Modernization of oil and gas reporting final rule dated December 31, 2008, and effective as of January 1, 2010.
The estimated reserve amounts presented in this annual report, as of December 31, 2024, are based on the average price during the 12-month period prior to the ending date of the period covered in this annual report, determined as the unweighted arithmetic averages of the prices in effect on the first day of the month for each month within such period, unless prices were defined by contractual arrangements, as required by the SEC regulations. For 2024, the average ICE Brent price was USD 79.7/Bl.
Our crude oil and natural gas net proved reserves include reserves from our subsidiaries located in the United States, and from Hocol’s assets in Colombia.
33
Estimated Net Proved Reserves
The following table sets forth our estimated net proved developed reserves of crude oil and gas by region for the years ended December 31, 2024, 2023 and 2022.
Table 27 – Net Proved Developed Reserves
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
North |
|
|
|
|
|
Colombia |
|
America |
|
Total |
|
Net Proved Developed oil reserves in million barrels oil equivalent |
|
|
|
|
|
|
|
As of December 31, 2024 |
|
971.9 |
|
56.5 |
|
1,028.9 |
|
As of December 31, 2023 |
|
969.2 |
|
56.8 |
|
1,026.0 |
|
As of December 31, 2022 |
|
893.3 |
|
44.6 |
|
937.9 |
|
Net Proved Developed NGL reserves in million barrels oil equivalent |
|
|
|
|
|
|
|
As of December 31, 2024 |
|
33.4 |
|
25.4 |
|
58.8 |
|
As of December 31, 2023 |
|
37.3 |
|
19.4 |
|
56.7 |
|
As of December 31, 2022 |
|
44.0 |
|
12.9 |
|
56.9 |
|
Net Proved Developed gas reserves in billion standard cubic feet |
|
|
|
|
|
|
|
As of December 31, 2024 |
|
1,622.4 |
|
127.6 |
|
1,750 |
|
As of December 31, 2023 |
|
1,906.4 |
|
100.9 |
|
2,007.3 |
|
As of December 31, 2022 |
|
2,101.9 |
|
72.1 |
|
2,174.0 |
|
Net Proved Developed oil, NGL and gas reserves in million barrels oil equivalent |
|
|
|
|
|
|
|
As of December 31, 2024 |
|
1,289.9 |
|
104.3 |
|
1,394.2 |
|
As of December 31, 2023 |
|
1,341.0 |
|
93.9 |
|
1,434.9 |
|
As of December 31, 2022 |
|
1,306.0 |
|
70.1 |
|
1,376.1 |
Note: Totals may not exactly equal the sum of the individual entries due to rounding. The conversion rate used is 5,700 standard cubic feet = 1 barrel of oil equivalent.
We are required, as are all oil companies undertaking exploratory and production activities in Colombia, to pay a percentage of our production to the Government as royalties. However, the ANH’s Resolution 877 of 2013, Resolution 351 of 2014 and Resolution 640 of 2014 require natural gas royalties to be paid in cash, which has the effect of determining the amount to be paid in royalties, based on property rights to the total volume of natural gas produced, without deductions on account of royalties. The main producing gas fields are Cupiagua, Pauto, Cusiana, Chuchupa and Cupiagua Sur.
Ecopetrol S.A. owns 100% of Cenit, a subsidiary that operates in Colombia and is dedicated to the storage and transportation of hydrocarbons through pipelines and of refined products through multipurpose pipelines. Cenit provides transportation services for the entire Ecopetrol Group, and Cenit is fully consolidated into our consolidated results of operations. Therefore, the difference between the tariffs set by the Ministry of Mines and Energy and the real transportation costs (fixed and variable operating expenses) does not affect our consolidated income statement. Thus, in presenting our reserves information in the 2022, 2023 and 2024 annual reports, we have used our real transportation costs, rather than the regular tariffs set by the Ministry of Mines and Energy.
The following table summarizes our proved oil, NGL and natural gas reserves, which includes 19.96 million barrels of fuel oil, 235.5 billion standard cubic feet of fuel gas within our natural gas results and 276.8 billion cubic feet of royalties, as of December 31, 2024. Of the total of 104.3 mmboe of proved developed reserves within North America, 94.1 mmboe corresponds to unconventional reservoirs within the Permian Basin, and 10.2 mmboe correspond to Gulf of Mexico (aka Gulf of America) fields. Moreover, of the total of 100 mmboe of proved undeveloped reserves within North America, 95 mmboe corresponds to unconventional reservoirs within the Permian Basin, and 5 mmboe corresponds to Gulf of Mexico (aka Gulf of America) fields.
34
Table 28 – Proved Oil, NGL and Natural Gas Reserves for 2024
|
|
|
|
|
|
|
Natural |
|
Total Oil |
|
|
|
|
|
NGL |
|
Gas |
|
and Gas |
|
|
|
Oil (mmb) |
|
(mmb) |
|
(bcf) |
|
(mmboe) |
|
PROVED DEVELOPED RESERVES |
|
|
|
|
|
|
|
|
|
Colombia |
|
971.9 |
|
33.4 |
|
1,622.4 |
|
1,289.9 |
|
International |
|
|
|
|
|
|
|
|
|
North America |
|
56.5 |
|
25.4 |
|
127.6 |
|
104.3 |
|
TOTAL PROVED DEVELOPED RESERVES |
|
1,028.4 |
|
58.8 |
|
1,750.0 |
|
1,394.2 |
|
PROVED UNDEVELOPED RESERVES |
|
|
|
|
|
|
|
|
|
Colombia |
|
353.6 |
|
4.7 |
|
231.5 |
|
398.9 |
|
International |
|
|
|
|
|
|
|
|
|
North America |
|
46.8 |
|
29.3 |
|
134.0 |
|
99.6 |
|
TOTAL PROVED UNDEVELOPED RESERVES |
|
400.4 |
|
34.0 |
|
365.5 |
|
498.5 |
|
TOTAL PROVED RESERVES |
|
1,428.8 |
|
92.8 |
|
2,115.5 |
|
1,892.7 |
Note: Totals may not exactly equal the sum of the individual entries due to rounding. The conversion rate used is 5,700 standard cubic feet = 1 barrel of oil equivalent.
The following table summarizes our proved oil, NGL and natural gas reserves, which includes 17.9 million barrels of fuel oil, 281.5 billion standard cubic feet of fuel gas within our natural gas results and 304.9 billion cubic feet of royalties, as of December 31, 2023.
Table 29 – Proved Oil, NGL and Natural Gas Reserves for 2023
|
|
|
|
|
NGL |
|
Natural Gas |
|
Total Oil and |
|
|
|
Oil (mmb) |
|
(mmb) |
|
(bcf) |
|
Gas (mmboe) |
|
PROVED DEVELOPED RESERVES |
|
|
|
|
|
|
|
|
|
Colombia |
|
969.2 |
|
37.3 |
|
1,906.4 |
|
1,341.0 |
|
International |
|
|
|
|
|
|
|
|
|
North America |
|
56.8 |
|
19.4 |
|
100.9 |
|
93.9 |
|
TOTAL PROVED DEVELOPED RESERVES |
|
1,026.0 |
|
56.7 |
|
2,007.3 |
|
1,434.9 |
|
PROVED UNDEVELOPED RESERVES |
|
|
|
|
|
|
|
|
|
Colombia |
|
282.7 |
|
6.4 |
|
221.7 |
|
328.0 |
|
International |
|
|
|
|
|
|
|
|
|
North America |
|
75.4 |
|
24.0 |
|
116.8 |
|
119.9 |
|
TOTAL PROVED UNDEVELOPED RESERVES |
|
358.1 |
|
30.4 |
|
338.6 |
|
447.9 |
|
TOTAL PROVED RESERVES |
|
1,384.2 |
|
87.1 |
|
2,345.9 |
|
1,882.8 |
Note: Totals may not exactly equal the sum of the individual entries due to rounding. The conversion rate used is 5,700 standard cubic feet = 1 barrel of oil equivalent.
35
The following table summarizes our proved oil, NGL and natural gas reserves, which includes 17.5 million barrels of fuel oil, 368.9 billion standard cubic feet of fuel gas within our natural gas results and 375.7 billion cubic feet of royalties, as of December 31, 2022.
Table 30 – Proved Oil, NGL and Natural Gas Reserves for 2022
|
|
|
|
|
|
|
|
|
Total Oil |
|
|
|
|
|
NGL |
|
Natural Gas |
|
and Gas |
|
|
|
Oil (mmb) |
|
(mmb) |
|
(bcf) |
|
(mmboe) |
|
PROVED DEVELOPED RESERVES |
|
|
|
|
|
|
|
|
|
Colombia |
|
893.3 |
|
44.0 |
|
2,101.9 |
|
1,306.0 |
|
International |
|
|
|
|
|
|
|
|
|
North America |
|
44.6 |
|
12.9 |
|
72.1 |
|
70.1 |
|
TOTAL PROVED DEVELOPED RESERVES |
|
937.9 |
|
56.9 |
|
2,174.0 |
|
1,376.1 |
|
PROVED UNDEVELOPED RESERVES |
|
|
|
|
|
|
|
|
|
Colombia |
|
375.0 |
|
14.1 |
|
503.4 |
|
477.5 |
|
International |
|
|
|
|
|
|
|
|
|
North America |
|
101.1 |
|
29.8 |
|
151.1 |
|
157.4 |
|
TOTAL PROVED UNDEVELOPED RESERVES |
|
476.2 |
|
43.9 |
|
654.4 |
|
634.9 |
|
TOTAL PROVED RESERVES |
|
1,414.0 |
|
100.8 |
|
2,828.5 |
|
2,011.0 |
Note: Totals may not exactly equal the sum of the individual entries due to rounding. The conversion rate used is 5,700 standard cubic feet = 1 barrel of oil equivalent.
Changes in Proved Reserves
Table 31 – Changes in Proved Reserves
|
|
|
For the year ended December 31, |
||||
|
|
|
2024 |
|
2023 |
|
2022 |
|
|
|
(Mmboe) |
||||
|
Revisions of previous estimates |
|
84.4 |
|
8.9 |
|
63.0 |
|
Improved Recovery |
|
97.0 |
|
93.1 |
|
80.9 |
|
Extensions and discoveries |
|
49.2 |
|
17.2 |
|
57.5 |
|
Purchases |
|
35.4 |
|
— |
|
47.7 |
|
Sales |
|
(6.3) |
|
— |
|
— |
|
Total reserves additions |
|
259.6 |
|
119.3 |
|
249.0 |
|
Production |
|
(249.7) |
|
(247.5) |
|
(239.9) |
|
Net change in proved reserves |
|
10.0 |
|
(128.2) |
|
9.0 |
Note: Totals may not exactly equal the sum of the individual entries due to rounding.
Reserves Replacement
The reserves replacement ratio is defined as the sum of additions and revisions of proved reserves divided by produced volumes in any given period. The following table presents the changes in reserves in each category relating to the reserve replacement ratio for the years 2024, 2023 and 2022.
The reserves replacement ratio for 2024 was 104% compared to 48% in 2023 and 104% in 2022.
The average replacement ratio for the last three years was 85%.
36
Table 32 – Reserves Replacement Ratio (Including Purchases and Sales)
|
|
|
For the year ended December 31, |
|
||||
|
|
|
2024 |
|
2023 |
|
2022 |
|
|
Annual |
|
104 |
% |
48 |
% |
104 |
% |
|
Three-year average |
|
85 |
% |
117 |
% |
117 |
% |
Revisions of Previous Estimates
In 2024, revisions increased reserves by 84.4 mmboe, mainly as a result of:
|
(i) |
An increase of 51.5 mmboe in reserves due to better performance in development activities in existing fields, including the Caño Sur, Chichimene, Castilla, Pauto, La Cira- Infantas, Apiay-Suria, Caño Limon, Palagua and Nare Area fields, among others,. |
|
(ii) |
A decrease of 36 mmboe in reserves due to depletion of gas fields including Ballena, Chuchupa, Cupiagua and Gibraltar among others. |
|
(iii) |
An increase of 15.7 mmboe in reserves due to new projects mainly in the Palogrande and Cupiagua fields. |
|
(iv) |
An increase 14.4 mmboe as a result of the agreement executed by and amount ANH and Ecopetrol in 2024, by means of which it was agreed that the payments related to the EP Contract CPO-9 for the oil and gas produced from the Akacias field are to be paid in cash, and therefore, included in reserves pursuant to applicable legislation. |
|
(v) |
An increase of 30.9 mmboe in reserves due to better performance in North American fields. |
|
(vi) |
7.9 mmboe, increase in reserves was due to varying increases due to development activities and good well performance in others fields. |
In 2023, revisions increased reserves by 9 mmboe, mainly as a result of:
|
(i) |
An increase of 67 mmboe in reserves due to new projects and better performance in development activities in different fields; mainly in the Rubiales, Castilla Asset and Caño Sur fields. |
|
(ii) |
A decrease of 58 mmboe, due to economic factors, primarily the decrease in oil prices, and the ICE Brent crude price decreasing by 15.5% in 2023 as compared to 2022, which resulted in the lowering of economic limits in some of our fields and an increase of operating costs. |
In 2022, revisions increased reserves by 63 mmboe, mainly as a result of:
|
(i) |
An increase of 54 mmboe in reserves due to new areas included in the approved development plan for the North American fields. |
|
(ii) |
An increase of 40 mmboe in reserves due to new projects mainly in the Caño Sur, Palogrande and Recetor fields. |
|
(iii) |
An increase of 70 mmboe in reserves due to better performance in development activities in existing fields, including, among others, the Rubiales and Caño Sur fields. |
This increase was partially offset by a decrease of 101 mmboe in reserves due to changes in the development plan in some of the North American fields where Ecopetrol holds working interest, as well as a reduction in Ecopetrol’s working interest in some fields in Colombia.
37
Improved Recovery
In 2024, improved recovery activities increased reserves by 97 mmboe. This increase was mainly associated with new proved areas under water flooding in the Chichimene, Akacias, Castilla, Suria, Yarigui, Casabe and La Cira- Infantas fields among others, and optimization of the gas injection of the Pauto and Floreña fields.
In 2023, improved recovery activities increased reserves by 93 mmboe, mainly due to new proved areas under water flooding in the Chichimene Asset, Castilla Asset and Akacias fields.
In 2022, improved recovery activities increased reserves by 81 mmboe, mainly due to new proved areas under water flooding in the Chicheme, Castilla, Akacias, Dina Terciario and Rio Ceibas fields.
Extensions and Discoveries
The following table sets forth the change in the Company’s proved reserves attributed to extensions and discoveries in millions of barrels of oil equivalent for the periods indicated.
Table 33 – Changes in Proved Reserves Attributed to Extensions and Discoveries
|
|
|
For the year ended December 31, |
||||
|
|
|
2024 |
|
2023 |
|
2022 |
|
|
|
(Mmboe) |
||||
|
Extensions and discoveries |
|
|
|
|
|
|
|
Total change |
|
49.2 |
|
17.2 |
|
57.5 |
|
Proved Undeveloped Reserves Change |
|
39.7 |
|
10.4 |
|
51.7 |
|
Change from unproved to proved developed reserves |
|
9.4 |
|
6.8 |
|
5.8 |
Note: Totals may not exactly equal the sum of the individual entries due to rounding.
The difference between the change of developed proved reserves and undeveloped proved reserves is related to the drilling of new wells in unproved acreage that led to new proved producing reserves.
The Company’s extensions and discoveries during 2024 amounted to 49.2 mmboe, primarily due to extensions of proved acreage, which in turn were mainly from activities in new proved areas in the Rubiales and Caño Sur fields, among others, which accounted for 34.8 mmboe of the increase. The remaining 14.4 mmboe corresponds to 6.1 million in small changes in different fields and 8.3 million in newly discovered fields Arrecife, Saltador and Toritos fields.
The Company’s extensions and discoveries during 2023 amounted to 17.2 mmboe, primarily due to extensions of proved acreage, which in turn were mainly from activities in new proved areas in the Caño Sur y Cohembi fields, among others, which accounted for 13.5 mmboe of the increase. The remaining 3 mmboe corresponds to 1.8 million in small changes in four fields and 1.9 million in newly discovered fields and reservoirs in the Alqamari, Flamencos and Ibamaca fields.
The Company’s extensions and discoveries during 2022 amounted to 57 mmboe, primarily due to extensions of proved acreage, which in turn were mainly from activities in new proved areas in the Rubiales and Quifa fields, among others, which accounted for 47 mmboe of the increase. The remaining 10 mmboe corresponds to newly discovered fields and reservoirs in the Recetor West, Ibamaca, El Niño and Capachos fields.
Purchases
On February 5, 2025, Ecopetrol acquired the remaining 45% of its participation in the CPO-09 Block of Repsol Colombia Oil Gas Limited (“Repsol”), for an amount of USD 452 million, making it the holder of 100% of the participation interest in the block, a strategic asset in the Piedemonte Llanero. This transaction is the result of the exercise of the right of first refusal by Ecopetrol, within the framework of the Joint Operation Agreement (JOA). This purchase increased Ecopetrol’s proved reserves by 31.7 mmboe.
38
Additionally, Ecopetrol S.A., through its wholly owned subsidiary, Ecopetrol Permian LLC, and acting within the joint venture with Occidental Midland Basin LLC, purchased additional acreage of 5,840 acres net to the joint venture that extended the South Curtis Ranch Field area in the Midland Basin. This purchase increased Ecopetrol’s proved reserves by 3.7 mmboe.
In 2023, there were no purchases or acquisitions of reserves.
In 2022, Ecopetrol S.A., through its wholly owned subsidiary, Ecopetrol Permian LLC, entered into a joint development agreement with affiliates of Occidental Petroleum and acquired participation rights in certain future drilling locations in the Delaware Basin, including access to up to 21,000 net acres in Lea County, New Mexico and Loving County, Texas. Also, Ecopetrol Permian LLC, through its joint venture with Occidental Midland Basin LLC, acquired additional acreage extending the South Curtis Ranch Field in the Midland Basin. These purchases increased proved reserves as of December 31, 2022 by 48 mmboe.
Sales
In 2024, Ecopetrol S.A., through its wholly owned subsidiary, Ecopetrol Permian LLC, and acting within the joint venture with Occidental Midland Basin LLC, sold all acreage of 4,967 acres net to the joint venture that comprised the Saint Andrews field area. The result of the sale reduced Ecopetrol’s proved reserves by 6.3 mmboe.
In 2023 and 2022, there were no sales of reserves.
Development of Reserves
As of December 31, 2024, our total proved undeveloped oil and gas reserves amounted to 498.5 mmboe, 80% of which is related to development activities at the Rubiales, Caño Sur Este, Akacias, Castilla Asset, Chichimene Asset, Pauto, Palogrande, Quifa, Floreña and Suria in Colombia, among others, and 20% of which is related to development activities in North American fields; which is broken down as follows: 95% corresponding to unconventional reservoirs within Permian and Delaware basins and the other 5% corresponding to Gulf of Mexico (aka Gulf of America) fields.
The proved undeveloped reserves estimated for the As of January 1, 2022, the Rodeo JV agreement with the Company and Occidental Petroleum was amended to provide Ecopetrol access to a larger production stake (75%) and adjust the carry obligation in the Midland area of the Permian Basin, with an effective date of January 1, 2022. Rubiales, and Caño Sur Este fields included locations with production start dates that extend beyond the five-year initial disclosure period and were associated with the water-handling capacities in these fields.
Similarly, the development plan of La Cira and Infantas fields includes investments for next seven years because the current waterflooding project considers the drilling of new injectors wells and starting the water injection before the drilling of producers in the same pattern. These exemptions were reviewed and approved by an external certification agent.
As of December 31, 2023, our total proved undeveloped oil and gas reserves amounted to 448 mmboe, 73% of which was related to development activities at the Rubiales, Castilla Asset, Chichimene Asset, Caño Sur Este, Pauto, Cupiagua, Recetor, Akacias, Quifa and La Cira fields in Colombia, among others, and 27% of which was related to development activities in North American fields; which is broken down as follows: 25% corresponding to unconventional reservoirs within Permian and Delaware basins and the other 2% corresponding to Gulf of Mexico (aka Gulf of America) fields. The proved undeveloped reserves estimated for the Rubiales, and Caño Sur Este fields included locations with production start dates that extend beyond the five-year initial disclosure period and were associated with the water-handling capacities in these fields. Similarly, the development plan of La Cira and Infantas fields includes investments beyond the next five years, because the current waterflooding project requires the drilling of new injector wells and beginning the water injection before drilling of producers in the same pattern. These exemptions were reviewed and approved by an external certification agent.
39
As of December 31, 2022, our total proved undeveloped oil and gas reserves amounted to 635 mmboe, 75% of which is related to development activities at the Rubiales, Castilla, Chichimene, Caño Sur, Pauto, Cupiagua, Akacias, Quifa and Casabe fields in Colombia, among others, and 25% of which is related to development activities in North American fields. The proved undeveloped reserves estimated for the Cajúa and Caño Sur Este fields include locations with production start dates that extend beyond the five-year initial disclosure period and are associated with the current water-handling capacities in these fields. The development plan in the Rubiales field includes investments beyond the next five years due to the limitations in water-handling capacities in the field, which require the scheduling of the entry of new wells based on spare capacity of the plant. These exemptions were reviewed and approved by an external certification agent.
The following table reflects the developed and undeveloped proved reserves estimates through the past three fiscal years.
Table 34 – Developed and Undeveloped Proved Reserves
|
|
|
|
|
|
|
|
|
Total Oil |
|
|
|
Oil |
|
NGL |
|
Natural Gas |
|
and Gas |
|
|
|
(mmb) |
|
(mmb) |
|
(bcf) |
|
(mmboe) |
|
2024 Proved Reserves |
|
|
|
|
|
|
|
|
|
Developed |
|
1,028 |
|
59 |
|
1,750 |
|
1,394 |
|
Undeveloped |
|
400 |
|
34 |
|
366 |
|
499 |
|
2023 Proved Reserves |
|
|
|
|
|
|
|
|
|
Developed |
|
1,026 |
|
57 |
|
2,007 |
|
1,435 |
|
Undeveloped |
|
358 |
|
30 |
|
339 |
|
448 |
|
2022 Proved Reserves |
|
|
|
|
|
|
|
|
|
Developed |
|
938 |
|
57 |
|
2,174 |
|
1,376 |
|
Undeveloped |
|
476 |
|
44 |
|
654 |
|
635 |
Changes in Undeveloped Proved Reserves
The following table reflects the main changes in undeveloped proved reserves as of December 31, 2024, 2023, and 2022.
Table 35 – Changes in Undeveloped Proved Reserves
|
|
|
For the year ended December 31, |
||||
|
|
|
2024 |
|
2023 |
|
2022 |
|
|
|
(Mmboe) |
||||
|
Consolidated companies |
|
|
|
|
|
|
|
Revisions of previous estimates |
|
41.3 |
|
(91.1) |
|
(2.5) |
|
Improved Recovery |
|
75.9 |
|
22.8 |
|
26.6 |
|
Extensions and discoveries |
|
39.7 |
|
10.4 |
|
51.7 |
|
Purchases |
|
16.5 |
|
— |
|
46.4 |
|
Sales |
|
(6.3) |
|
|
|
|
|
Proved undeveloped converted to proved developed |
|
(116.6) |
|
(129.0) |
|
(119.1) |
|
Net change in unproved reserves |
|
50.5 |
|
(186.9) |
|
(3.1) |
Note: The conversion rate used is 5,700 standard cubic feet = 1 barrel of oil equivalent. Totals may not exactly equal the sum of the individual entries due to rounding.
Of the total amount of proved undeveloped reserves that we had at the end of 2023 (448 mmboe), we converted approximately 116.6 mmboe, or 26%, to proven developed reserves during 2024. Approximately 73% of the total conversion is mainly associated with the development of crude oil and gas projects in Caño Sur, Rubiales, Castilla, Chichimene Cupiagua and Pauto , among others, and 27% is associated with development execution in fields in the United States, 100% of the total volume within United States corresponds to unconventional fields within the Permian and Delaware basins. Investments made during 2024 to convert proved undeveloped reserves to proved developed reserves totaled USD 1,145 million in cash.
40
Of the total amount of proved undeveloped reserves that we had at the end of 2022 (635 mmboe), we converted approximately 129 mmboe, or 20%, to proven developed reserves during 2023. Approximately 73.6% of the total conversion is mainly associated with the development of crude oil and gas projects in Castilla Asset, Chichimene Asset, Rubiales, Caño Sur Este and Pauto fields, among others, and 26.4% is associated with development execution in fields in the United States, which in turn is broken down as follows: 25.9% of the total volume within United States corresponds to unconventional fields within the Permian and Delaware basins and 0.5% corresponds to Gulf of Mexico (aka Gulf of America) fields. Investments made during 2023 to convert proved undeveloped reserves to proved developed reserves totaled USD 1,498 million in cash.
Of the total amount of proved undeveloped reserves that we had at the end of 2021 (632 mmboe), we converted approximately 119 mmboe, or 19%, to proven developed reserves during 2022. Approximately 80% of the total conversion is mainly associated with the development of crude oil and gas projects in the Castilla, Rubiales, Caño Sur, Cupiagua and Cusiana fields, among others, and 20% is associated with development execution in fields in the United States. Investments made during 2022 to convert proved undeveloped reserves to proved developed reserves totaled USD 1,066 million in cash.
All the explanations that were included in the section on Changes in Proved Reserves apply to this section.
Reserves Process
The Ecopetrol Group follows international standards for estimating, classifying, and reporting reserves, as defined in SEC regulation. Our reserves process is coordinated by Fidel Antonio Delgado Loría, the Resources and Reserves Manager. Mr. Delgado Loría is a Petroleum Engineer with over 20 years of experience in the upstream sector of production business in the Ecopetrol Group and other companies in the oil and gas industry in Colombia and Venezuela. He received his engineering degree from Universidad Central de Venezuela and a financial management specialist degree from Pontificia Universidad Javeriana. He reports to the Hydrocarbon Chief Financial Officer. In addition, our reserves team is comprised of reserves coordinators who are geologists and petroleum engineers, each of them with more than fifteen years of experience in reservoir characterization, field development, estimation, and reporting of reserves by SEC guidelines. This team supports and interacts with the specialists involved in the estimation and reporting process, following an established procedure with its corresponding internal controls. As in previous years, reserves are estimated and certified by recognized external independent engineers, this year consisting of DeGolyer and MacNaughton, GaffneyCline, and Ryder Scott Company, in compliance with the definitions of the Society of Petroleum Engineers and the applicable SEC rules. According to our corporate policy, we report the values of the reserves obtained from the external engineers, even if they are lower than our expected reserves.
The reserves estimation process ends when the Resources and Reserves Manager consolidates the results and together, and the Upstream Vice-President, presents the outcome to the Resources and Reserves Committee, which comprises the Ecopetrol Group’s CEO, CFO, COO and the Upstream Vice-President, among others. Results are later presented to the Audit and Risk Committee of the Board of Directors and finally reviewed and approved by the Board of Directors.
The Resources and Reserves unit, and the Vice-Presidency of Upstream presented the reserves balance to the Board of Directors, who approved it in February 2025.
The aforementioned external independent engineering consultants have estimated and certified our proved reserves as of December 31, 2024. These external engineers estimated 99% of our estimated net proved reserves for the year ended December 31, 2024, 2023 and 2022. In accordance with these certifications, our reserves report complies with Rule 4-10 of Regulation S-X issued by the SEC. The reserves’ reports of the external engineers are included as exhibits to this annual report.
Our reserves process uses deterministic methods which are commonly used internationally to estimate reserves. These methods whilst reliable, have some inherent uncertainty, and thus, estimates should not be interpreted as exact amounts. Most of the producing proved reserves were estimated by applying appropriate decline curves or other performance relationships. In analyzing decline curves, reserves were estimated by calculating economic limits that are based on current economic conditions. In certain cases where the methods previously employed could not be used, reserves were estimated by analogy with similar reserves for which more complete data was available.
Estimates of reserves were prepared by geological and engineering standard methods commonly used in the oil and gas industry. The method or combination of methods used in the analysis of each reserve was adopted from experience analogy reserves, including information on the stage of development, quality and completeness of basic data and production history.
41
The following table reflects the estimated proved reserves of oil and gas as of December 31, 2022 until 2024, and the changes therein.
Table 36 – Estimated Proved Reserves of Oil and Gas
|
|
|
|
|
|
|
|
|
|
|
|
|
North |
|
|
|
|
|
Colombia |
|
America |
|
Total |
|
|
|
Net proved oil, NGL and gas reserves in mmboe |
||||
|
At December 31, 2022 |
|
1,783.0 |
|
228.0 |
|
2,011.0 |
|
Revisions |
|
2.2 |
|
6.7 |
|
8.9 |
|
Improved Recovery |
|
93.1 |
|
— |
|
93.1 |
|
Extensions and Discoveries |
|
17.2 |
|
— |
|
17.2 |
|
Purchases |
|
0 |
|
— |
|
— |
|
Sales |
|
0 |
|
— |
|
— |
|
Production |
|
(227.1) |
|
(20.4) |
|
(247.5) |
|
At December 31, 2023 |
|
1,668.7 |
|
213.9 |
|
1,882.8 |
|
Revisions |
|
63.3 |
|
21.1 |
|
84.4 |
|
Improved Recovery |
|
97.0 |
|
— |
|
97.0 |
|
Extensions and Discoveries |
|
49.2 |
|
— |
|
49.2 |
|
Purchases |
|
31.7 |
|
3.7 |
|
35.4 |
|
Sales |
|
0 |
|
(6.3) |
|
(6.3) |
|
Production |
|
(221.5) |
|
(28.3) |
|
(249.7) |
|
At December 31, 2024 |
|
1,688.4 |
|
204.0 |
|
1,892.7 |
Note: Totals may not exactly equal the sum of the individual entries due to rounding.
|
3.5.4 |
Joint Venture and Other Contractual Arrangements |
We conduct our exploration and production business through a variety of contractual arrangements with the Colombian Government or with third parties. Below is a general description of the main types of contractual arrangements to which we were a party as of December 31, 2024.
Association Contracts
Association contracts were introduced by Decree 2310 of 1974 and were entered into between private companies and Ecopetrol between 1975 and 2003. Through an association contract, Ecopetrol partnered with a petroleum company or a consortium to explore and, upon successful discovery, exploit the found oil and gas resources. An operator is defined among them or hired as a third party.
Under association contracts, the exploratory risk is entirely assumed by Ecopetrol S.A.’s contractual partner, the associate. If there is a discovery and Ecopetrol S.A. agrees that the relevant field is commercially viable, Ecopetrol S.A. intends to participate in the field’s development. A joint account is expected to be created, and Ecopetrol S.A. and the partner plan to participate in the expenses and investments in the proportions established in the corresponding contract. Ecopetrol S.A. intends to reimburse the direct exploratory expenses incurred by the contractual partner in the proportions established by the contract.
If Ecopetrol S.A. does not believe that the relevant field is commercially viable, the partner has the right to execute on its own all activities considered necessary for the field’s exploitation as a “sole risk operation”, and to be reimbursed for a defined percentage of all investments for such sole risk operation in accordance with the corresponding contract.
Every association contract provides for an executive committee that makes all technical, financial, and operational decisions if Ecopetrol S.A. has agreed that a field is commercially viable. All major decisions of this committee must be made unanimously.
The maximum term of an association contract is 28 years. The first six years of the contract are for the exploratory phase, which may be extended for one or two additional years at the partner’s request. The remaining time is for the exploitation phase. This type of contract, together with EP contracts and special contracts (La Cira-Infantas and Teca-Cocorná fields), both of which are described below, are the most significant in terms of our production and proved reserves.
42
Incremental Production Contracts
We enter into incremental production contracts to obtain additional hydrocarbon production beyond a base production curve that is established based on the proven reserves of a specific field or well, originating from contracts entered into by Ecopetrol with third parties or from projects undertaken by Ecopetrol. This incremental production results from new investments to increase the recovery factor of reservoirs or to add new reserves. Therefore, under this type of arrangement, Ecopetrol S.A. owns 100% of the hydrocarbons defined by the base production curve. The incremental production (i.e., the hydrocarbon volume obtained beyond the basic production as a result of investment activities), is expected to be owned by the contract parties in the proportions established by such contract.
The initial phase of an incremental production contract has a term of up to three years, in which the contractual partner executes an initial work program approved by Ecopetrol S.A. in order to gain the right (but not the obligation) to continue with the second phase. If our partner decides to continue with the project for the second phase (the complementary phase), it must inform Ecopetrol S.A. in writing no later than 90 days prior to the termination date of the initial phase and deliver a proposed development plan for each covered field. The second phase is the production phase and has a maximum term of 22 years minus the length of the initial phase.
Incremental production contracts provide for an executive committee that is responsible for making all decisions in order to approve, control and supervise all operations that take place during the duration of the contract. These contracts also provide for a steering committee, which is responsible for the supervision of the execution of the work programs, the 2025 Investment Plan, and other items.
Special Contracts
We are party to a joint venture for exploration and exploitation of “La Cira-Infantas” Area and of “Teca-Cocorná” Area.
These contracts between Ecopetrol S.A. and SierraCol Energy, formerly known as Occidental Andina LLC, which were executed on September 6, 2005, and June 24, 2014, respectively, have as their purpose, a joint collaboration between the parties with the goal of increasing the economic value of the La Cira-Infantas and the Teca-Corcorná fields, by means of hydrocarbon exploration and production activities, including, among others, an incremental production project to improve the recovery factor, process optimization, and exploratory activities.
Ecopetrol S.A. partially assigned its exploratory and production rights in the contracted areas to SierraCol Energy. Additionally, pursuant to these contracts, Ecopetrol S.A. provides financial resources and the preferential rights of use for the existing infrastructure in that zone and SierraCol Energy provides financial resources and the technical and operative experience in mature fields redevelopment projects and enhanced recovery technologies.
Ecopetrol S.A. is the operator under both joint ventures, and, on behalf of the parties, is responsible for the conduction, execution, and control, directly or via contractors, of the operational activities.
The La Cira-Infantas joint venture is divided into three phases. The first phase lasts 180 days, the second lasts 730 days, and the third phase lasts up to the date in which the field reaches its commercial viability.
The incremental production, after deduction of the royalties, is owned 52% by Ecopetrol S.A. and 48% by SierraCol Energy. These same percentages apply to the participation in the operational and direct expenses. Adjustments to the participations for the benefit of Ecopetrol S.A. are expected to occur if there are high production levels or high prices.
The Teca-Cocorná joint venture is divided into two phases. The first phase lasts three years and may be extended for up to an additional year; the second term is 20 years and could be reduced by the term of any extensions of the first phase.
The basic production is 100% owned by Ecopetrol S.A. The incremental production, after deduction of the royalties, is owned 60% by Ecopetrol S.A. and 40% by SierraCol Energy. These same percentages apply to the participation in the operational and direct expenses. Adjustments to the participations for the benefit of Ecopetrol S.A. is expected to occur if there are high production levels and high prices.
43
The National Hydrocarbons Agency (ANH) and its Contracts
The ANH was created by Decree Law 1760 of 2003 and was given the authority to administer all national hydrocarbon reserves under contracts executed since January 1, 2004. Pursuant to Decree Law 1760 of 2003, Empresa Colombiana de Petróleos, Ecopetrol, was split, and its organic structure was modified, to create two new entities: the Agencia Nacional de Hidrocarburos and the Sociedad Promotora de Energía de Colombia S.A. Prior to January 1, 2004, Ecopetrol S.A. had the authority to contract with third parties for the exploration and production of new areas.
However, the creation of the ANH did not modify our rights or obligations or the rights or obligations of other parties with respect to contracts in existence before January 1, 2004, when the ANH was created. Therefore, we have retained the authority to execute agreements with respect to all areas held by us prior to such date.
Below, we include a brief description of each type of contract that we have entered into with the ANH:
Technical Evaluation Agreements
This type of contract grants the contractor the exclusive right to develop technical evaluation operations with operational autonomy at its own cost and risk, seeking to appraise the hydrocarbon potential of an area under specific conditions, with the purpose of identifying the zones of prospective interest in the area by means of the execution of an exploratory program. The contractor has the option to request the conversion of a technical evaluation agreement (“TEA”) into one or more EP contracts that cover the area of the TEA (or a portion thereof). The contractor will be subject to payment of rights for the use of the subsoil, other applicable economic compensations.
The contractor can conduct evaluation activities for terms that vary between 18, 24, and 36 months, depending on the terms of reference of the ANH’s bidding round.
EP Contracts
The ANH enters into concession contracts pursuant to which the Nation grants exploration and production rights and receives royalties and taxes. In turn, the contractor provides 100% of the investment and expenses resources and receives 100% of the production after royalties and taxes. The ANH has named this contract an “Exploration and Production Contract” or an “EP contract”.
The ANH only receives a percentage of oil revenues in two cases:
|
(i) |
when the international oil prices rise beyond a specified price (high price fee), above which the ANH has a right to participate in a share of the increased revenues generated, or |
|
(ii) |
in the case of recognition of production rights in an extended contractual phase (additional production share). |
Since the 2008 bidding round held by the ANH, the ANH receives a percentage of the production share from EP contracts, from the commencement of the production phase (instead of solely from the extension phase of the contract (additional production share) as mentioned in the previous paragraph). In addition, the ANH acquires economic rights when the price of oil exceeds a reference price set in the contract (high price fee) as well as when the surface fee based on the hectares of the assigned area of the contract (both with and without production) exceeds the reference number set in the contract.
44
EP contracts have three phases: (i) an exploration period of up to six years counted from the effective date, which may be extended for two additional years, (ii) an evaluation period of two years, assuming reserves are discovered, to determine the commercial potential of the discovered reserves, and (iii) a production period, with respect to each production field, which may last for up to 24 years plus extensions, counted from the date in which the commercial viability of the corresponding field is declared. The abovementioned terms were modified during ANH’s 2014 bidding round for unconventional and offshore reservoirs, resulting in an exploration period of nine years and a production period of 30 years. On June 29, 2018, a new model EP contract was published by the ANH. In accordance with the new model for EP contracts, offshore contracts entered into in or after 2019 will have evaluation periods of three, five, or seven years, depending on the depth of the water where the discovered reserves are located. In 2021, for the fourth round of its Permanent Area Assignment Process ( Proceso Permanente para la Asignación de Acreaje or “PPAA” for its acronym in Spanish), the ANH introduced to the model of the EP contract, the concept of an “economic value for the exclusivity” of exploration and production of a specific area. Such value must be expressed in dollar amounts and must be offered by each bidder to the ANH, as remuneration for receiving the exclusive exploration and production rights and acts as a guarantee for the obligations of the contractor during the exploration phase of the executed EP contract.
ANH and Ecopetrol Agreements (Convenios)
Decree-Law 1760 of 2003 established that the rights over the production area and over the personal and real property assets of (i) all fields that were directly operated by Ecopetrol S.A. as of December 31, 2003, and (ii) all fields in which there was an association contract before said date would continue to belong to Ecopetrol S.A.
Pursuant to Article 2 of Decree 2288 of 2004, which regulates Decree Law 1760 of 2003, Ecopetrol S.A. must execute an agreement with the ANH to regulate the exploration and exploitation terms and conditions of the relevant area, which was previously subject to an association contract.
Decree 2288 of 2004 also established that Ecopetrol S.A. would have to execute agreements with the ANH, covering fields directly operated by Ecopetrol S.A. Under these agreements, the ANH recognizes the exclusive right of Ecopetrol S.A. to explore and exploit the hydrocarbons which are property of the Nation and might be obtained in the areas covered by the corresponding agreements. Ecopetrol S.A.’s rights shall last until resources are depleted or Ecopetrol S.A. returns such areas to the Nation through the ANH.
These agreements also provide the conditions under which Ecopetrol S.A. may, either partially or completely, assign to third parties its rights and obligations thereunder.
CrownRock Negotiations
During 2024, Ecopetrol engaged in conversations with Occidental Petroleum Corp. (“OXY”) for the potential acquisition of a certain percentage of assets owned by CrownRock, L.P., a company located in the United States. On July 31, 2024, the Company’s board of directors decided not to acquire any assets of CrownRock, L.P. owned by OXY.
|
3.6 |
Transportation and Logistics |
|
3.6.1 |
Transportation Activities |
The transportation and logistics segment includes the transportation of crude oil, motor fuels, fuel oil, and other refined products including diesel, jet, and biofuels. We conduct most of these activities through our wholly owned subsidiary Cenit and its subsidiaries.
The map below shows the locations of the main transportation networks owned by our business partners and us.
45
The table below sets forth the volumes of crude oil and refined products transported through the crude oil pipelines and multi-purpose pipelines owned by us.
Table 37 – Volumes of Crude Oil and Refined Products Transported
|
|
|
For the year ended December 31, |
||||
|
|
|
2024 |
|
2023 |
|
2022 |
|
|
|
(Thousand bpd) |
||||
|
Crude oil transport (1) |
|
815.2 |
|
807.0 |
|
772.6 |
|
Refined products transport (2) |
|
303.5 |
|
305.9 |
|
298.1 |
|
Total |
|
1,118.7 |
|
1,112.9 |
|
1,070.7 |
|
(1) |
The crude oil transported volumes correspond to the following systems: Ocensa Segment 3, ODC, Vasconia-Galan, Ayacucho-Galan, Ayacucho-Coveñas and Trasandino Pipeline. |
|
(2) |
The pipelines transporting refined products include the following: Galan-Sebastopol, Galan-Salgar, Galan-Bucaramanga, Buenaventura-Yumbo, Cartagena-Baranoa and Sebastopol. |
The volume of crude oil transported by Cenit’s main systems and those of its subsidiaries increased by 1% in 2024, compared to the previous year, as a result of higher deliveries of Castilla Norte crude from the Barrancabermeja refinery, increased third-party production, and the capture of barrels outside the main network. Of the total volume of crude transported by oil pipelines, approximately 91.7% belonged to the Ecopetrol Group.
The volume of refined products transported by Cenit decreased by 0.8% in 2024 compared to the previous year, mainly due to lower domestic gasoline demand and a higher ethanol blending ratio, partially offset by increased transportation of naphtha and JET-A1 fuel to meet regional demand. Of the total volume of refined products transported by multi-purpose pipelines in 2024, 30.1% belonged to the Ecopetrol Group.
Transportation Capacity
Our main crude oil pipeline systems’ operating capacity was 1,484 thousand barrels per day in 2024. Our main multi-purpose pipeline transportation capacity increased from 549 thousand barrels per day in 2023 to 588 thousand barrels per day in 2024.
References to our crude oil transportation capacity in this annual report refer to the capacity of the pipelines that belong to Cenit and its subsidiaries to transport crude oil volumes either to the refineries or to our export facilities. In addition, we have other feeder systems that transport oil volumes from producing facilities or other pumping stations to these main pipelines. References to our refined products transportation capacity refer to the capacity of pipelines that begin in the Galan station (Barrancabermeja refinery) and Cartagena station (Cartagena Refinery).
|
3.6.1.1 |
Pipelines |
As of December 31, 2024, we, directly or indirectly with private partners, own, operate and maintain an extensive network of crude oil and multi-purpose pipelines. These pipelines connect our own and third-party production centers, import facilities and terminals to refineries, major distribution points, and export facilities in Colombia.
Cenit directly owns 45% of the total crude oil pipeline shipping capacity in Colombia. When aggregated with the crude oil pipelines in which Cenit owns an interest, Cenit owns 86% of the oil pipeline shipping capacity in Colombia. By December 31, 2024, our network of crude oil and multi-purpose pipelines was approximately 9,043 kilometers in length. The transportation network consists of approximately 5,337 kilometers of main crude terminals and oil pipeline networks connecting various fields to the Barrancabermeja refinery and Cartagena Refinery, as well as to our export facilities.
We also own 3,706 kilometers of multi-purpose pipelines for transportation of refined products from the Barrancabermeja and Cartagena refineries to major distribution points. Out of the approximately 5,337 kilometers of crude oil pipelines, owned by us, 3,355 kilometers of crude oil pipeline are wholly owned, and 1,982 kilometers of crude oil pipeline are owned through non-wholly owned subsidiaries.
48
The following table sets forth our main pipelines in which we own an indirect interest as of December 31, 2024.
Table 38 – Our Main Pipelines
|
|
|
|
|
|
|
|
|
|
|
|
|
Indirect |
|
|
|
|
|
|
Capacity |
|
Product |
|
|
|
|
|
Ownership |
|
|
Pipeline |
|
Kilometers |
|
(mbd) |
|
Transported |
|
Origin |
|
Destination |
|
Percentage |
|
|
Caño Limón-Coveñas |
|
773 |
|
250 |
|
Crude Oil |
|
Caño Limón |
|
Coveñas |
|
100.00 |
% |
|
Oleoducto de Alto Magdalena (OAM) |
|
391 |
|
102 |
|
Crude Oil |
|
Tenay |
|
Vasconia |
|
93.62 |
% |
|
Oleoducto de Colombia (ODC) |
|
483 |
|
231 |
|
Crude Oil |
|
Vasconia |
|
Coveñas |
|
78.19 |
% |
|
Oleoducto Central – Ocensa |
|
848 |
|
745 |
(1) |
Crude Oil |
|
Cupiagua |
|
Coveñas |
|
72.65 |
% |
|
Oleoducto de los Llanos (ODL) |
|
260 |
|
297 |
(2) |
Crude Oil |
|
East fields |
|
Monterrey Cusiana |
|
65.00 |
% |
|
Oleoducto Bicentenario de Colombia |
|
229 |
|
143 |
(3) |
Crude Oil |
|
Araguaney |
|
Banadia |
|
100.00 |
% |
|
(1) |
Ocensa has four segments with different capacities. 745 mbd refers to the capacity of segment two (El Porvenir-Vasconia). The capacity of the other segments are as follows: |
|
a. |
Cupiagua-Cusiana (segment zero): 198 mbd |
|
b. |
Cusiana-El Porvenir (segment one): 745 mbd |
|
c. |
Vasconia-Coveñas (segment three): 550 mbd |
|
(2) |
Transportation capacity for this pipeline is measured by using crude oil viscosity of 1.350 cStk (30° C). |
As of December 31, 2024, we owned 75 stations, 42 located in crude oil pipelines, 29 in refined products pipelines, two in crude oil ports and two in refined product ports.
As of December 31, 2024, we had a nominal storage capacity associated with the transportation network of 16.4 million barrels of crude oil and 5.9 million barrels of refined products. We do not own any tankers.
Pipeline Projects
Pozos Colorados Fuel Loading Dock
Seeking fuel supply flexibility in the area, the Fuel Loading Dock Project was developed in Pozos Colorados Terminal. As such, the scope of the project consists of enabling the facilities to deliver gasoline and load fuel trucks inside the station. The project was completed in December 2022 and is ready to use based on fuels demand in the area.
Vasconia Energy Recovery (RECVA)
In connection with Ecopetrol Group’s focus on energy efficiency, we developed the Vasconia Energy Recovery (“RECVA”) project, which seeks to capture energy dissipated in the transportation process. Such energy is captured and converted from hydraulic principles into electrical energy to be used in the operation of the station, which reduces the consumption of energy supplied by the Regional Transmission Systems ( Sistema de Transmisión Regional or “STR” for its acronym in Spanish).
Given that the Vasconia station operates 24 hours a day, an opportunity was identified to recover energy from the system, converting hydraulic energy (flow and pressure) into electrical energy through the installation of a hydraulic power recovery turbine (“HPRT”). In 2019, the HPRT was purchased, manufacturing was completed, and the engineering development was concluded.
In 2021, once the inconveniences derived from the pandemic were overcome, (i) the execution phase continued; (ii) the construction contract was awarded; and (iii) the civil, mechanical, electrical, and instrumentation works began. During that same year, pre-commissioning activities, including the selection of vendors for the commissioning stage, took place. In April 2022, the construction phase and commissioning stage were completed, and, in July 2022, HPRT operating tests and stabilization process, along with the environmental program (energy recovery and the reduction of CO2 emissions) were commenced. Corrective maintenance in certain components and implementation of improvements to ensure a long and stable operation to meet the expected recovery efficiency were required once the operating tests were concluded and the HPRT started operations.
49
Operational Storage Program The operational storage program’s objectives and scope includes ensuring a storage of more than one million barrels of refined products in five different stations. The program foresees the construction of more than 10 tanks distributed through four projects divided in this way: (i) one tank of 260,000 barrels for Nafta and one tank of 323,000 barrels (under construction) for Biodiesel Extra (B2E) or Gasoline (GM) in Pozos Colorados Terminal, (ii) two tanks of 100,000 barrels each in Sebastopol station and one tank of 62,000 barrels in Yumbo station (all this storage is for Biodiesel Extra (B2E) and Gasoline (GM)). We are currently evaluating the construction of: (i) two tanks of 70,000 barrels each, to storage B2E and GM in Cartago Station and (ii) four new tanks in Medellín that in total has 254,000 barrels of capacity to storage Jet (JA1), Gasoline Extra (GE) and B2E. The construction phase began in 2020 in Pozos Terminal and Sebastopol station and in 2021 in Yumbo station. According to the construction, startup phase and commissioning, the systems in Pozos Terminal, was completed in August 2022. Startup of the new tank at Yumbo took place in the first quarter of 2023, and the startup of the additional tank in Pozos Colorados Terminal is expected to take place in 2025.
Andina Reliability Project
The aim of the Andina project is to recover reliability of delivering of refined hydrocarbons to Bogotá and the center of Colombia, included Dorado Airport, by means of the reposition of twelve main updated pumping units in capacity, efficiency and technology for each of the pumping stations (Puerto Salgar, Guaduero, Villeta and Albán). The construction of the new facilities started in August 2022 and the system is currently operating with nine new pumping units for the stations of Puerto Salgar, Guaduero and Villeta. We expect to begin operations with the three pumping units for the Albán station by the end of the second quarter of 2025.
Replacement of the “La Valeria” Single Point Mooring in Pozos Colorados Terminal.
The “La Valeria” Single Point Mooring (SPM) operating in the Pozos Colorados Maritime Terminal had to be replaced in 2024, as the operational term specified in its safety certificate had come to an end, and at which point the asset reached its 30-year lifespan.
During the third quarter of 2024, the new Valeria SPM (Single Point Mooring) was put into operation. This unmanned unit plays a critical role in transferring refined hydrocarbons, such as gasoline, naphtha, and diesel, from ships to the Pozos Colorados Maritime Terminal in Santa Marta through an underwater pipeline.
The replacement required, among other things, (i) procuring the design and construction of the SPM, (ii) transportation and delivery of materials, (iii) obtaining permits, registrations, and authorizations for the new unit and decommissioning of the current one, (iv) dismantling and final disposal of the current SPM; (v) assembly, commissioning, and operational start-up of the new SPM; and (vi) stabilization of operations. The project represented an approximate investment of USD 27 million and involved 270 professionals for over more than two years.
Caño Sur Pipeline
The objective of this project is to enable the transportation of 100% of the production projection of the Caño Sur field owned by Ecopetrol, through a pipeline of approximately 20 kilometers long, between Caño Sur and the kilometer 30 of the Oleoducto de los Llanos Orientales - ODL transportation system. The producer could have benefits from an efficient transportation system, with a greater oil evacuation capacity updated to 47,840 bpd and with lower risks compared to the current transportation conditions. In 2024, the project completed the following milestones: (i) construction began on July 15, 2024, (ii) progress of Centauros station works, which consisted of location and excavation of the firefighting system pipeline, CCM construction and correspondent equipment placement, and installation of booster pumps, and (iii) pipeline progress, consisting of the completion of pipe welding, pending closure of ties, progress in river tunnel drilling, and progress in trenching, pipe lowering and covering activities. We expect the new pipeline segment to become operational in the first half of 2025.
Electric Interconnection of the Estación el Porvenir (ENERGEPO)
Ocensa established a strategic framework to reduce emissions by 51% by 2030. In connection with such goal, Ocensa’s analyses indicate that the El Porvenir station is one of the plants with highest number of emissions, contributing 30% of the total tons of CO 2 e from Ocensa.
The station’s energy source is natural gas, which feeds a system of electricity generation turbines. An alternative for reducing CO 2 e is the electrical connection to the National Interconnected System ( Sistema Interconectado Nacional or “SIN” for its acronym in Spanish), which emission factor is lower than that of gas.
50
Based on this strategic plan, Ocensa is developing projects that aim to guarantee safe, reliable, and eco-efficient operations such as the 115 kilo Volts (“KV”) electrical connection between the El Porvenir station and the SIN, which project started during the first quarter of 2022.
Currently, the ENERGEPO project is subject to the completion of the Alcaraván expansion project, which consists of expanding the 230 KV and 115 KV electrical networks between San Antonio in Nobsa Boyacá and the new Alcaraván electrical substation in Yopal, by the Mining and Energy Planning Unit ( Unidad de Planeación Minero-Energética or “UPME” for its acronym in Spanish).
During 2022, the project achieved the following milestones: (i) a collaboration agreement was signed with Cenit to update the connection study with new information uploaded by UPME that allows the analysis of different scenarios regarding synergies with the Alcaraván project, (ii) companies and entities such as ISA, Grupo Energía Bogotá, Genersa S.A.S E.S.P, UPME, Empresa de Energía de Casanare S.A. E.S.P, Empresa de Energía de Boyacá S.A E.S.P, among others, were approached to analyze a connection alternative that does not depend on Alcaraván, and (iii) the preliminary analyses of additional alternatives, such as solar farms, wind energy, and carbon capture.
In 2023, we updated and defined the connection study and analysis regarding the importance of repowering the existing system with the execution of the Alcaraván project. In October 2023, OCENSA submitted a new request for connection to the STR. This request was based on analyzed connection and a pre-feasibility studies, considering a technical variant that removes the need for the Alcaraván project. Considering the time required to establish a reliable connection to the STR, efforts have been coordinated with subsidiary companies to identify efficient and beneficial solutions for the business group. Among the alternatives considered is the potential installation of solar farms. In November 2023, UPME officially awarded this project (Alcaraván) to Alupar Colombia SAS.
In 2024, we moved forward with the ENERGEPO project as we (i) held meetings with regional energy companies to validate their interest in building connection assets and explore third-party financing alternatives, (ii) conducted field sessions with different companies in the midstream sector to understand their energy needs and connections to the STR, (iii) concluded that the connection to the STR is essential, and (iv) explored options for electricity supply from solar farms and energy storage systems. The project is currently in its second phase of development: conceptualization.
Solar Energy Farms
The Ecopetrol Group aims to develop projects that help to achieve the energy transition to non-conventional renewable energies and that contribute to Colombia’s decarbonization strategic goals. For this reason, within the framework of the investment program in the energy category, Ocensa is developing two initiatives focused on the construction of solar farms at the Coveñas and Vasconia stations, which leverages current resources to achieve safe, reliable, eco-efficient and sustainable operations.
These solar farms are currently in the execution stage. The Miraflores solar farm (0.4 MW) came online in 2023. In 2024, the following goals were achieved: (i) Vasconia Solar farm (7 MW) completed 100% of its pre-operational stage, including the execution of a power purchase agreement, and (ii) Coveñas Solar farm (5 MW) started operations and completed its testing and stabilization phases.
We believe these projects have potential to create renewable energy sources to contribute to our 2030 decarbonization strategy, as we aim to include a 51% reduction in emissions compared to the baseline, the installation of 12 MW of renewable sources, optimization of the cost associated with the station’s energy consumption due to a reduction in the average kWh rate, and opportunity for synergies within the Ecopetrol Group through surplus energy.
Caucasia Main Units Replacement Project
With the objective of ensuring the reliability of the system and transport capacity while reducing CO 2 direct emissions, the Ecopetrol Group started the Caucasia Main Units Replacement Project, which consists of replacing the three internal combustion engines at the ODC Caucasia station with three new electric motors. The total investment estimated for the project is USD 19.2 million.
The project is divided into several stages. In 2021, investments were made in long-term procurement and project management. In 2022, construction began with detailed engineering, soil studies and equipment procurement. In 2023, construction was completed, with the project currently being fully operational.
51
As for the energization phases, temporary thermal generation with natural gas supply has been used since 2023 and is expected to be used until synchronization with the STR in 2025. In October 2024, Caucasia solar farm came into operation, with an installed capacity of 6.7 Megawatt peak (MWP). Due to a massive illegal occupation in Caucasia that includes some of the areas required for the construction of the transmission line, the energization phase in the synchronization stage with the STR is currently on hold. ODC is working on an alternative solution to guarantee the energy demand of the Caucasia station.
Installation of units in Salgar Gualanday
The scope of this project is to improve the reliability and availability of the Puerto Salgar – Gualanday – Neiva 10” oil pipeline to address the volumetric demand for refined products in the south of the country projected to 2040, through the replacement of five main pumping units in two stations (Puerto Salgar and Gualanday). Each new pumping package includes an electric motor, pump and variable speed drive, control and communications panels and shelter.
In 2024, the procurement and manufacturing of the packaged units for both Salgar and Gualanday were completed, along with the development of detailed engineering, enabling the contracting of installation works for 2025–2026.
Emissions Reduction at Monterrey Station
This project is part of our strategic pillar of Operational Efficiencies, aimed at improving the safety, reliability, and environmental performance of the Monterrey Station. The initiative involves replacing natural gas internal combustion engines with modern electric motors and optimizing operations to match pumping needs. These changes are expected to significantly reduce CO2 emissions and noise levels, improve coexistence with neighboring communities, and minimize operational risks associated with the use of combustion engines.
In 2024, the project achieved significant milestones, including the completion of the 34.5 KV electric line, installation of a 10 megavolt-amperes (MVA) transformer, and placement of critical equipment like switchgear and motor shelters. Maintenance on one of the main units was finalized, and construction of the primary electrical paths continues. The project remains on schedule, with the final commissioning planned for 2026, marking a significant step toward safer and more sustainable operations.
Replacement of units Galán Chimitá
The project to upgrade the Galán - Chimitá system aims to increase its transportation capacity to 42 thousand barrels per day (mbd) improving operational efficiency and reliability while reducing risks. Key achievements in 2024 included advancing the installation of new equipment, strengthening infrastructure, and ensuring the readiness of critical components to support the system’s expansion. These upgrades also ensure smoother operations and reliable deliveries to key locations, including the Lizama station and Río Sogamoso. We expect to commission the new units in 2025.
|
3.6.1.2 |
Export and Import Facilities |
We currently have concessions granted by the Colombian Government for four export/import docks for crude oil and refined products: Coveñas, Tumaco, Pozos Colorados, and Cartagena. Our export capacity reached 2.35 million barrels per day for crude oil. Our import capacity of refined products and crude oil reached 0.18 million barrels per day and 0.34 million barrels per day, respectively. Our crude oil loading facilities can load tankers of up to 350 thousand deadweight tonnage (DWT). Adjacent to these loading facilities we also have storage facilities with 9.98 million barrels of capacity. Our docks, used for import and export refined products, can load tankers of 55 thousand DWT. Additionally, these facilities have a storage capacity of up to 1.5 million barrels.
|
3.6.2 |
Other Transportation Facilities |
We have entered into transportation agreements with tanker trucks and barge companies to transport crude oil from locations that do not have pipeline connections to refineries and export facilities. The volume of refined products that cannot be transported by pipelines or tanker trucks due to capacity limitation, is transported by barges. During 2024, 47.9 million barrels of crude oil and refined products were transported by tanker trucks, and 8.5 million barrels of refined products were transported by barges, particularly using the Magdalena River, connecting Barrancabermeja with Barranquilla and Cartagena.
52
|
3.6.3 |
Marketing of Transportation Services |
Cenit and its subsidiaries main line of business is the crude oil pipeline transport (76 % of revenues), followed by the refined products pipeline transport (16% of revenues) and ports and related services (8% of revenues). Both crude and refined product pipeline transport are regulated activities; crude oil pipeline transport services are regulated by the Ministry of Mines and Energy, while refined product pipeline transport services are regulated by the Energy and Gas Regulatory Commission (Comisión de Regulación de Energía y Gas or “CREG” by its acronym in Spanish).
Transportation contracts of crude oil may take several forms: ship or pay (payment for the availability of a fixed capacity in the system), ship and pay (payment for volumes actually transported), or spot contracts. The main users for the crude oil transportation business are Ecopetrol S.A., Frontera Energy, Trafigura, Parex, Hocol, and Vitol, who collectively represented 76% of this business segment’s revenues in 2024. Transportation services for crude oil provided to Ecopetrol S.A. represented 91% of this business segment’s crude oil transport revenues in 2024.
Cenit also transports refined products, and its main client is Ecopetrol S.A., which accounted for 39% of refined products pipeline transport revenues in 2024, mainly due to the transport of naphtha, diesel, and gasoline. Cenit also has 31 other fuel wholesalers’ customers for whom it transports refined products. The most significant among them are Organización Terpel, Primax Colombia, Chevron Petroleum Company, Biocombustibles S.A.S., Terpel Exportaciones and Petrobras Colombia.
Deregulated businesses, such as ports and crude-loading facilities, represent a smaller portion of Cenit and its subsidiaries revenue 8% in 2024. Clients for these businesses include some of the same parties for which Cenit provides crude oil and refined products transportation services.
|
3.7 |
Refining and Petrochemicals |
|
3.7.1 |
Refining |
Our main refineries are the Barrancabermeja refinery, which Ecopetrol S.A. directly owns and operates, and a refinery in the Free Trade Zone in Cartagena owned by Refinería de Cartagena S.A.S., a wholly owned subsidiary of Ecopetrol S.A., who operates this refinery and two other minor refineries -Orito and Apiay-, but these are considered part of the upstream segment since most of the production is for self-consumption.
Our refineries produce a full range of refined products, including gasoline, diesel, jet fuel, LPG and heavy fuel oils, among others.
The following table sets forth our average daily installed and actual refinery capacity for each of the last three years:
Table 39 – Average Daily Installed and Actual Refinery Capacity
|
|
|
For the year ended December 31, |
|
||||||||||||||||
|
|
|
2024 |
|
2023 |
|
2022 |
|
||||||||||||
|
|
|
Capacity |
|
Throughput |
|
Use |
|
Capacity |
|
Throughput |
|
Use |
|
Capacity |
|
Throughput |
|
Use |
|
|
|
|
(bpd) |
|
(bpd) |
|
(%) |
|
(bpd) |
|
(bpd) |
|
(%) |
|
(bpd) |
|
(bpd) |
|
(%) |
|
|
Barrancabermeja |
|
250,000 |
|
221,609 |
|
89 |
|
250,000 |
|
221,810 |
|
89 |
|
250,000 |
|
217,720 |
|
87 |
|
|
Cartagena (1) |
|
210,000 |
|
192,205 |
|
92 |
|
210,000 |
|
197,824 |
|
94 |
|
210,000 |
|
140,005 |
|
67 |
|
|
Apiay |
|
2,500 |
|
1,658 |
|
66 |
|
2,500 |
|
1,290 |
|
52 |
|
2,500 |
|
1,253 |
|
50 |
|
|
Orito |
|
2,200 |
|
1,407 |
|
64 |
|
2,300 |
|
1,699 |
|
74 |
|
2,300 |
|
1,372 |
|
60 |
|
|
Total |
|
464,700 |
|
416,879 |
|
90 |
|
464,800 |
|
422,623 |
|
91 |
|
464,800 |
|
360,350 |
|
78 |
|
|
(1) |
Includes crudes and recirculated products. |
53
|
3.7.1.1 |
Barrancabermeja Refinery |
The Barrancabermeja refinery produced approximately 39.8% of the fuels consumed in Colombia in 2024, according to internal calculations made by us and Colombia’s fuel consumption as reported by the Ministry of Mines and Energy.
The following table sets forth the production of refined products of the Barrancabermeja refinery for the periods indicated.
Table 40 – Production of Refined Products from the Barrancabermeja Refinery
|
|
|
For the year ended December 31, |
||||
|
|
|
2024 |
|
2023 |
|
2022 |
|
|
|
(bpd) |
||||
|
LPG, Propylene and Butane |
|
11,446 |
|
11,252 |
|
10,695 |
|
Gasoline Fuels and Naphtha |
|
57,385 |
|
60,034 |
|
59,421 |
|
Diesel |
|
57,931 |
|
58,143 |
|
55,272 |
|
Jet Fuel and Kerosene |
|
23,526 |
|
25,548 |
|
24,413 |
|
Fuel Oil |
|
23,260 |
|
26,490 |
|
28,454 |
|
Lube Base Oils and Waxes |
|
1,087 |
|
883 |
|
782 |
|
Aromatics and Solvents |
|
2,517 |
|
2,298 |
|
2,337 |
|
Asphalts and Aromatic Tar |
|
44,958 |
|
40,645 |
|
36,396 |
|
Polyethylene, Sulphur and Sulphuric Acid |
|
1,351 |
|
1,376 |
|
1,282 |
|
Total |
|
223,461 |
|
226,669 |
|
219,052 |
|
Difference between Inventory of Intermediate Product |
|
1,511 |
|
(1,286) |
|
1,720 |
|
Total Production |
|
224,972 |
|
225,383 |
|
220,772 |
In 2024, total production from the Barrancabermeja refinery decreased by 0.2% compared to 2023, mainly due to a lower delivery of Caño Limon crude oil to the refinery, which implied a reduction in gasoline, diesel and jet yields and an increase in the production of heavy intermediate products. Moreover, the production of bases and waxes and aromatics increased to serve the national and international market.
We own and operate four petrochemical plants and one paraffin and lube plant located within the Barrancabermeja refinery. In 2024, we produced 44,237 tons of low-density polyethylene, an increase of 2.1% compared to the production of 43,320 tons in 2023. This increase was primarily due to the operational availability of the units associated with the polyethylene chain. We produced 655 mboe of aromatics (benzene, toluene, xylene, orthoxylene, heavy aromatics, and cyclohexane), a 9.4% of increase as compared to the production of 598 mboe of aromatics in 2023, mainly due to an increase in exports to the international market and greater operational availability of the unit.
The gross refining margin decreased from USD 15.7/Bl in 2023 to USD 10.3/Bl in 2024, primarily due to a price decrease of refined products compared to crude, mainly in petrochemical and industrial prices and a generalized drop in international refining cracks. In addition, due to lower delivery of Caño Limon crude oil, which resulted in lower yields of valuable products. The average conversion index for the Barrancabermeja refinery was 91% in 2024 and 89.7% in 2023. This increase was primarily due to an increase in exports of asphalt and other industrial products to international market accompanied by greater operational availability of the unit.
54
|
3.7.1.2 |
Cartagena Refinery |
The following table sets forth the production of refined products from the Cartagena Refinery for the periods indicated.
Table 41 – Production of Refined Products from the Cartagena Refinery
|
|
|
For the year ended December 31, |
||||
|
|
|
2024 |
|
2023 |
|
2022 |
|
|
|
(bpd) |
||||
|
LPG, Propylene and Butane |
|
3,430 |
|
3,962 |
|
3,011 |
|
Gasoline Fuels and Naphtha |
|
54,511 |
|
61,861 |
|
46,914 |
|
Diesel |
|
80,438 |
|
93,575 |
|
61,732 |
|
Jet Fuel and Kerosene |
|
11,798 |
|
12,312 |
|
7,870 |
|
Fuel Oil |
|
16,124 |
|
18,920 |
|
15,871 |
|
Sulphur |
|
441 |
|
550 |
|
361 |
|
Total |
|
166,742 |
|
191,180 |
|
135,759 |
|
Difference between Inventory of Intermediate Product |
|
17,071 |
|
1,339 |
|
74 |
|
Total Production (1) |
|
183,813 |
|
192,519 |
|
135,833 |
|
Petcoke (Metric Tons) |
|
1,036,703 |
|
1,023,556 |
|
710,867 |
|
(1) |
Does not include petcoke. |
The following tables set forth the imports and sales of refined products from the Cartagena Refinery for the periods indicated.
Table 42 – Imports and Sales of Refined Products from the Cartagena Refinery
|
|
|
For the year ended December 31, |
||||
|
|
|
2024 |
|
2023 |
|
2022 |
|
|
|
(bpd) |
||||
|
Imports |
|
|
|
|
|
|
|
Motor Fuels |
|
— |
|
— |
|
1,633 |
|
Jet Fuel and Kerosene |
|
— |
|
— |
|
616 |
|
LPG and Butane |
|
1,524 |
|
1,538 |
|
2,204 |
|
Total Imports |
|
1,524 |
|
1,538 |
|
4,452 |
|
|
|
For the year ended December 31, |
||||
|
|
|
2024 |
|
2023 |
|
2022 |
|
|
|
(bpd) |
||||
|
Sales |
|
|
|
|
|
|
|
Motor Fuels |
|
33,208 |
|
35,626 |
|
36,747 |
|
Diesel |
|
80,653 |
|
94,004 |
|
61,864 |
|
Jet Fuel and Kerosene |
|
11,738 |
|
12,329 |
|
8,628 |
|
Fuel Oil |
|
15,638 |
|
15,365 |
|
12,521 |
|
Other Products |
|
58,224 |
|
52,143 |
|
30,666 |
|
Total Sales |
|
199,461 |
|
209,467 |
|
150,427 |
During 2024, the Cartagena Refinery imported butane in order to achieve the planned feed of the Butamer Unit and to increase the production of alkylate.
Total sales decreased from USD 7,051 million in 2023 to USD 6,031 million in 2024. A total of 70 million barrels of crude were processed in 2024 compared to 72 million barrels of crude processed in 2023. Exports to international markets represented 21% of total sales (USD 1,265 million).
The gross refining margin decreased to USD 9.4/Bl in 2024 from USD 19.7/Bl in 2023, mainly due to weakening of refined products prices.
55
|
3.7.1.3 |
Esenttia S.A. |
In 2024, Esenttia’s production totaled 322.8 thousand tons of petrochemical products, a 25% decrease compared to the 441 thousand tons produced in 2023, primarily driven by the company’s focus on addressing the increased oversupply of Asian products in the region by prioritizing sectors with higher value.
Table 43 – Operating Capacity of Esenttia
|
|
|
For the year ended December 31, |
|
||||
|
|
|
2024 |
|
2023 |
|
2022 |
|
|
|
|
(Metric Tons) |
|
||||
|
Average capacity |
|
570,000 |
|
505,940 |
|
494,695 |
|
|
Throughput |
|
332,862 |
|
440,783 |
|
467,765 |
|
|
% Use |
|
58 |
% |
87 |
% |
95 |
% |
|
3.7.1.4 |
Invercolsa |
During 2024, Inversiones de Gases de Colombia S.A. (“Invercolsa”), registered 1.51 million users of natural gas, an increase of 4.5% compared to the 1.45 million users of natural gas in 2023. Additionally, non-controlled companies registered 2.59 million users of natural gas in 2024, an increase of 3.5% compared to the 2.50 million users of natural gas in 2023. Throughout 2022, Invercolsa completed the integration of its operations into the Ecopetrol Group, in connection with the increase in stake completed by Ecopetrol in November 2019. In May 2022, Ecopetrol reported that it had initiated the divestment of its participation in Invercolsa. As of the date of this annual report, this process is ongoing.
|
3.7.1.5 |
Biofuels |
As of the date of this annual report, we have investments in the biofuel company Ecodiesel Colombia S.A., in which we own 50% of the shares, currently in operation with a capacity of 150 thousand tons of biodiesel per year.
In 2024, we faced certain challenges and reduced our production from 145 thousand tons in 2023 to 140 thousand tons in 2024. This represents a year-to-year decline of 3.46% and was due mainly to shortage of crude palm oil and a maintenance shutdown, which was partially offset by an increase in throughput, from 17.34 tons/hour in 2023 to 17.39 tons/hour in 2024.
|
3.7.2 |
Marketing and Supply of Refined Products |
We are the main producer and supplier of refined products in Colombia. We market a full range of refined and feedstock products, including regular and high-octane gasoline, diesel fuel, jet fuel, LPG and petrochemical products, among others.
Domestic sales of refined products totaled 352.0 mboed and decreased by 7.9 mboed in 2024, 2% lower as compared to 2023. This decrease is primarily the result of the combined effects of a decrease in the demand for gasoline, partially offset by an increase in the demand of diesel fuel.
In 2024, 14.2 million barrels of diesel and 2.2 million barrels of gasoline produced by the Cartagena Refinery were allocated to complement the supply from the Barrancabermeja refinery and fulfill Colombia’s demand, avoiding larger imports and allowing us to maintain the share of the national market. In the same way, 7.9 million barrels of diluent produced by the Cartagena Refinery were used to transport crude reducing diluent imports. In addition, we imported petrochemicals to complement the national supply, generating additional sales of lubricating bases, polyethylene, hexanes, and others.
Exports of products increased by 2% (2.3 mboed) in 2024 compared to 2023, explained by an increase of 13.6 mboed in exports of vacuum gas oil and 5.0 mboed in exports of propane that partially offset a decrease of 15.9 mboed in exports of middle distillates.
|
3.8 |
Electric Power Transmission and Toll Roads Concessions |
Our electric power transmission and toll roads concessions segment includes the offering of services such as electricity transmission and the designing, building, operating, and maintaining toll road infrastructure in various countries in Latin America. We conduct these activities through ISA and its subsidiaries.
56
|
3.8.1 |
ISA |
ISA was founded as a joint stock company in Bogotá, Colombia, in 1967. Since then, it has grown into a multi-Latin corporate group operating in Colombia, Brazil, Peru, Chile, Bolivia, Argentina, and Central America. ISA and its 50 subsidiaries operate and maintain electricity transmission networks, with the broadest presence of any Latin American electricity transmission company in terms of the number of countries where ISA operates. ISA is also involved in toll-road concessions, telecommunications, and information and communications technology (ICT) businesses.
ISA is organized as a Colombian stock corporation and as a mixed public services company. As of December 31, 2024, we owned 51.41% of ISA’s capital stock and other shareholders (including Colombian pension funds, international and local institutional investors, and retail shareholders) owned the remaining 48.59% of ISA’s capital stock.
The majority of ISA’s consolidated revenues are derived from (i) contracts with customers, (ii) the regulated payments that ISA and its consolidated subsidiaries operating in the electricity transmission segment receive from making their electricity transmission assets available to the national interconnected systems of the countries where they operate, (iii) revenues related to interconnection charges, the dispatch and coordination of the National Dispatch Center (Centro Nacional de Despacho or “CND” for its acronym in Spanish) in Colombia and administration services of the Wholesale Energy Market (Mercado de Energía Mayorista or “MEM” for its acronym in Spanish) in Colombia, (iv) revenues recognized by reference to the stage of completion of contract activity in the electricity transmission business and in toll roads and (v) as concessionaire, with the right to retain most of the toll revenues derived from operation of the toll road for the term of the concession.
|
3.8.2 |
Electricity Transmission Activities |
ISA is one of the largest international energy transmission companies in Latin America in terms of kilometers of electricity lines in operation, according to ISA’s internal calculation of the total kilometers of high-voltage network circuits of the energy transmission segment in each country in which ISA operates. The energy transmission companies of ISA operate and maintain a high-voltage transmission network in Colombia, Brazil, Bolivia, Peru, and Chile, as well as some international interconnections that operate between Colombia–Ecuador and Ecuador–Peru. In Central America, the company holds a stake in Empresa Propietaria de la Red (EPR), a company incorporated under the laws of Panama and headquartered in San José, Costa Rica, which operates the Energy Interconnection System for the Countries of Central America ( Sistema de Interconexión Eléctrica de los Países de América Central or “SIEPAC” for its acronym in Spanish).
The revenues associated with the provision of energy transmission services are regulated and are not affected by the supply or demand of electricity. Additionally, revenues are indexed to macroeconomic variables such as the Colombian peso to U.S. dollar exchange rate, the Producer Price Index (PPI), the Consumer Price Index (“CPI”), or the corresponding indexes in the different countries.
ISA owns 49,677 kilometers of high-voltage grid circuits, which support the supply of energy in Latin America. As of December 31, 2024, ISA is in the process of constructing an additional 8,200 kilometers of high-voltage grid circuits, which are expected to begin operations in the short term.
In Colombia, ISA’s subsidiary, XM Compañía Expertos en Mercados S.A. E.S.P. (“XM”), exclusively operates, plans and coordinates the resources of the National Interconnected System (Sistema Interconectado Nacional or “SIN” for its acronym in Spanish), and also manages the Commercial Settlement System (Sistema de Intercambios Comerciales or “SIC” for its acronym in Spanish) in the MEM, the International Electricity Transactions (Transacciones Internacionales de Electricidad or “TIE” for its acronym in Spanish) with Ecuador, and carries out the settling and clearing of charges for use of the SIN’s grids. XM also develops solutions and provides energy and information services. As the sole operator of the Colombian SIN, XM guarantees the balance between production and consumption of energy in the country. Also, based on energy demand estimates, XM carries out the coordinated real-time operation of the generation plants and the grid to ensure that power plants’ generation continuously responds to consumers’ demand in a cost-effective, reliable, and safe manner with quality standards.
The following table sets forth certain metrics related to ISA’s energy transmission operations for the periods indicated:
57
Table 44 – Key Electricity Transmission Metrics
|
|
|
For the year ended December 31, |
|
||||
|
|
|
2024 |
|
2023 |
|
2022 |
|
|
In Operation |
|
|
|
|
|
|
|
|
Km of Circuit |
|
49,677 |
|
49,426 |
|
48,766 |
|
|
MVA Installed Capacity |
|
113,365 |
|
109,258 |
|
104,438 |
|
|
In Construction |
|
|
|
|
|
|
|
|
Km of Circuit |
|
8,200 |
|
6,897 |
|
4,928 |
|
|
MVA Capacity |
|
15,306 |
|
16,321 |
|
16,451 |
|
|
Operational Results |
|
|
|
|
|
|
|
|
Reliability |
|
99.99 |
% |
99.99 |
% |
99.99 |
% |
|
Availability |
|
99.83 |
% |
99.72 |
% |
99.82 |
% |
|
3.8.2.1 |
Electricity Transmission Activities in Colombia |
In 2024, ISA’s subsidiaries electricity transmission activities in Colombia included 13,694 km of transmission lines. As of December 31, 2024, ISA owned and operated an aggregate transformation capacity of 23,471 MVA (Megavolt-Amperes), transforming high voltage electricity into low voltage electricity, and vice versa.
The following table sets forth ISA’s transmission lines and transformation capacity relating to electricity transmission activities in Colombia, for the periods indicated.
Table 45 - Transmission Infrastructure in Colombia
|
|
|
For the year ended December 31, |
||||||||||
|
|
|
2024 |
|
2023 |
|
2022 |
||||||
|
|
|
Transmission |
|
Transformation |
|
Transmission |
|
Transformation |
|
Transmission |
|
Transformation |
|
|
|
Lines |
|
Capacity |
|
Lines |
|
Capacity |
|
Lines |
|
Capacity |
|
|
|
(Km) |
|
(MVA) |
|
(Km) |
|
(MVA) |
|
(Km) |
|
(MVA) |
|
Colombia |
|
13,694 |
|
23,471 |
|
13,635 |
|
23,371 |
|
13,569 |
|
22,721 |
|
3.8.2.2 |
Electricity Transmission Activities Outside Colombia |
In 2024, ISA’s subsidiaries electricity transmission activities outside Colombia included 35,983 km of controlled transmission lines, where Brazil represents 43% of the total transmission infrastructure.
The following table sets forth ISA’s electricity transmission activities outside Colombia, for the periods indicated.
Table 46 - Transmission Infrastructure Outside Colombia
|
|
|
For the year ended December 31, |
||||||||||
|
|
|
2024 |
|
2023 |
|
2022 |
||||||
|
|
|
Transmission |
|
Transformation |
|
Transmission |
|
Transformation |
|
Transmission |
|
Transformation |
|
|
|
Lines |
|
Capacity |
|
Lines |
|
Capacity |
|
Lines |
|
Capacity |
|
|
|
(Km) |
|
(MVA) |
|
(Km) |
|
(MVA) |
|
(Km) |
|
(MVA) |
|
Brazil |
|
21,293 |
|
67,403 |
|
21,065 |
|
64,307 |
|
20,828 |
|
62,157 |
|
Peru |
|
12,155 |
|
16,172 |
|
12,191 |
|
15,260 |
|
11,836 |
|
13,240 |
|
Chile |
|
1,948 |
|
5,850 |
|
1,948 |
|
5,850 |
|
1,948 |
|
5,850 |
|
Bolivia |
|
587 |
|
470 |
|
587 |
|
470 |
|
587 |
|
470 |
|
Total |
|
35,983 |
|
89,895 |
|
35,791 |
|
85,887 |
|
35,199 |
|
81,717 |
58
|
3.8.3 |
Toll Roads Concessions Activities |
ISA designs, builds, operates, and maintains toll road infrastructure that connects millions of people in Chile, Colombia and Panamá. As of December 31, 2024, ISA was one of the largest intercity road operator and operated four concessions in Chile (Ruta del Maipo, Ruta de la Araucanía, Ruta de los Ríos and Ruta del Loa - A Sector), while in Colombia, it operated the Ruta Costera Concession. In total, it operated five toll roads concessions, which covered a total of 811 kilometers in these two countries and had 296 kilometers of new road infrastructure under construction in Ruta del Este in Panamá and Ruta Orbital Sur and Ruta del Loa - B Sector, in Chile. In the year ended December 31, 2024, 139 million vehicles traveled on roads operated by ISA.
The following tables set forth certain metrics related to ISA’s toll road concession operations in Colombia and Chile for the periods indicated:
Table 47 - Total Traffic (Vehicles)
|
|
|
For the year ended December 31, |
||||||
|
|
|
Road Length |
|
|
|
|
|
|
|
|
|
(Km) (1) |
|
2024 |
|
2023 |
|
2022 |
|
COLOMBIA |
|
|
|
|
|
|
|
|
|
Ruta Costera |
|
146 |
|
8,685,033 |
|
9,032,156 |
|
7,453,152 |
|
CHILE |
|
|
|
|
|
|
|
|
|
Ruta del Maipo |
|
237 |
|
95,877,049 |
|
95,492,117 |
|
100,780,722 |
|
Ruta del Bosque (2) |
|
— |
|
— |
|
— |
|
21,874,196 |
|
Ruta de la Araucania |
|
144 |
|
23,476,965 |
|
23,740,110 |
|
25,883,823 |
|
Ruta de los Ríos |
|
172 |
|
10,079,544 |
|
10,471,290 |
|
11,255,310 |
|
Ruta del Loa |
|
112 |
|
743,345 |
|
— |
|
— |
|
Total |
|
811 |
|
138,861,936 |
|
138,735,673 |
|
167,247,203 |
(1) Road length for the year ended December 31, 2024.
(2) Expired in February, 2023.
In 2024, ISA subsidiaries in Panama and Chile were awarded road concession contracts. Both contracts are currently in the design phase. Also, 25 kilometers corresponding to the B Sector of Ruta del Loa remain under construction.
|
|
|
Road Length
|
|
CHILE |
|
|
|
Proyecto Orbital Sur Santiago – Ruta Orbital Sur |
|
25 |
|
|
|
|
|
PANAMÁ |
|
|
|
Carretera Panamericana Este – Ruta del Este |
|
246 |
|
|
|
|
|
Total |
|
271 |
|
3.8.4 |
Telecommunications and ICT |
Within the telecommunications segment, InterNexa provides connectivity solutions, especially in urban and interurban fiber optics, in a wholesale model, to provide network and data center infrastructure in Colombia and Peru, and with commercial presence in the United States. As of December 2024, InterNexa had over 30,000 kilometers of optical fiber and operated data centers in Medellín and Bogotá. Its strategy focuses on strengthening their position as a wholesale operator of fiber optic connectivity services and data center integration, while increasing its scale with attributes of reliability, proximity and agility to maximize efficiency and productivity, and on accompanying the evolution and growth of its clients.
In 2024, ISA sold Internexa Argentina, Internexa Brasil and Internexa Chile. These transactions are expected to allow Internexa to focus on the telecommunications business in locations where it has greater relevance.
59
Additionally, InterNexa is developing infrastructure businesses under the “InfraCo” model, focused on acquiring or building networks to lease them under long-term partnerships, enhancing its capacity to deliver high-value solutions to its clients.
In Colombia, InterNexa is working with the Ministry of Information and Communication Technologies (MinTIC) in the “ ConectiVIDAd para Cambiar Vidas ” project, which aims to bring connectivity to remote areas of the country and contribute to closing the digital gap.
3.9 Research and Development; Intellectual Property
As a key lever of our TESG strategy, technology and innovation are essential to our efforts to add value to our business segments. Value generation is achieved through the development of proprietary technologies and competitive advantages and the adaptation of third-party technologies to our processes.
Our main innovation and technology development center is the Colombian Petroleum and Energies of the Transition Institute ( Instituto Colombiano del Petróleo or “ICPET” for its acronym in Spanish), established in 1985 and located in Piedecuesta, Santander. The scope of the ICPET activities covers our entire value chain: exploration, production refining, transportation, trading, and marketing including asset integrity and environmental sustainability and energy transition technologies.
Ecopetrol has focused its research, technology development and innovation efforts in four main clusters and areas:
(i) Hydrocarbons cluster . The main goal of this pillar is to support the results of the traditional business of Ecopetrol reaching differential goals in their exploration, production and refining activities with technology. It includes seismic processing technologies, geological modeling, enhance oil recovery methods, new additives for improving production/transport of oil and advance technologies and modeling of refining processes.
(ii) Energy transition cluster. We support decarbonization and energy transition corporate plans through studies related to energy efficiency, and to the implementation of CCUS, sustainable fuels, renewables energies and the hydrogen value chain. We are incorporating multi-scale technological approaches to identify, quantify, characterize, and abate methane emissions to reduce our impact on climate. Furthermore, we are conducting studies to establish carbon stocks and fluxes associated to strategic ecosystems, to promote transparent carbon compensation projects related to nature-based solutions, and to reduce the risk of biodiversity loss in Colombia and we also work modeling and developing tools to optimize the energy value chain.
(iii) Circular Economy and Sustainability cluster. In these clusters we are exploring opportunities to increase circularity in our operations, considering not only recycling and the safe disposal of residues, but also initiatives for reuse, remanufacturing, and repurposing. Since water represents a critical resource, this area includes a technology–enabled water management program that encompasses the conservation, recycling, reuse, and valuation of production water streams. The production and upscaling of high-performance materials from petroleum molecules, that could be the base for advanced, sustainable, reusable, non-combustion products, are also part of our research, development, and innovation efforts, aimed at reducing our scope 3 CO2 emissions. We are working mainly in mechanical and chemical plastic recycling and biopolymer
(iv) Technology Services Management : We lead the various strategies to ensure the delivery of laboratory work-based solutions as part of the technology support provided by ICPET to the corporate business plan covering both hydrocarbons and energy transition projects. Additionally, management aims to continuously improve the research and development facilities at ICPET’s location in Piedecuesta, Colombia. This includes specialized maintenance, updates, automation, robotization and the implementation of digital transformation solutions to ensure the sustainable and more efficient operation of our technology assets.
Each year we bring to the Colombian National Council for Tax Benefits ( Consejo Nacional de Beneficios Tributarios , or “CNBT” for its acronym in Spanish) our research, technology development projects and innovation initiatives, to obtain certifications for its science and technology investments. The CNBT certifies eligible science and technology investments, which are deductible from income tax upon execution.
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Our intangible assets are preserved through a technology valuation process and an intellectual property protection process, which include the consolidation of trade secrets, patents, copyrights, trademarks, industrial designs, publications in peer reviewed journals and presentations in prime level technical events. Ecopetrol has filed 330 patent applications in the last 19 years, that include innovative technologies such as (i) acrylic electrospun membranes doped with sulfonated petcoke and it application in cations removal in water, (ii) optimization of the cyclic steam stimulation process in heavy oil reservoirs through the use of metallic nanoparticles in solvents, (iii) procedure for the formulation of linseed oil in water emulsions stabilized with manganese oxide (MnO2) to enhance the ignition in in-situ combustion processes y (iv) mist equipment for subsoil steam generation by means of mist injection for crude oil recovery.
As of December 31, 2024, we held 138 patents. In Colombia, we have been also granted new patents related to the following technologies, (i) acceleration nozzle system for generating preformed foam at the wellhead for self-selectivity of steam injection comprising two opposing nozzles, (ii) a diluent injection monitoring and control system for dehydration of heavy and extra-heavy crude oil, (iii) staged polymeric fluid injection control system and improved valve for positioning in mandrels and pipes, (iv) electrolytic reactor for polishing oilfield production water comprising a pressurized vessel with a geared agitator and deflectors, (v) device for coalescing oil droplets dispersed in industrial wastewater by magnetic fields, (vi) device for pressure and flow control in selective injection of polymeric solutions used in enhanced oil recovery, and (vii) industrial wastewater polishing process for removal of total oil hydrocarbons by means of a filtration train. We currently hold patents in Colombia, the United States, Mexico, Argentina, Peru, Venezuela, Brazil, Russia, Nigeria, Indonesia, India, and Malaysia.
As of December 31, 2024, 30 technologies have been commercialized, with different business and technology transfers models to Colombian and multinational companies, thus achieving their monetization and generating additional income for the Company for USD 1.58 million.
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3.10 |
Applicable Laws and Regulations |
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3.10.1 |
Regulation of Exploration and Production Activities |
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3.10.1.1 |
Business Regulation |
Pursuant to the Colombian Constitution, the State is the exclusive owner of minerals and non-renewable resources located in the subsoil and has full authority to determine the rights to be held and royalties or compensation to be paid by investors for the exploration and production of any hydrocarbon resources. The hydrocarbon industry is under governmental supervision and control. The MME and the ANH are the authorities responsible for regulating all activities related to the exploration and production of hydrocarbons in Colombia.
Decree Law 1056 of 1953 (the Petroleum Code, or Código de Petróleos ) declares that the hydrocarbon industry and its activities of exploration, exploitation, refining, transportation, and distribution are of public interest, which means that, in the interest of the hydrocarbon industry, the Colombian Government may order, for example, necessary expropriations in order to develop such industry. The hydrocarbon industry is under governmental supervision and control, regulated mainly by the Ministry of Mines and Energy and the ANH.
Ministry of Mines and Energy Resolution 180742 of 2012, partially repealed by Resolution 90341 of 2014 and 40303 of 2022, includes a series of technical regulations for unconventional hydrocarbon resources, including the procedures for advancing the exploration and exploitation of unconventional reserves. It also establishes the types of wells and their classification, as well as the fulfillment of those minimum (drilling and abandoning) conditions necessary to initiate or perform EP activities. Furthermore, it contemplates the applicable procedure to resolve disputes between the mining sector and the oil and gas sector, regarding the coexistence of their rights in some specific projects.
Decree 3004 of 2013, issued by the MME and compiled by the Regulatory Decree 1073 of 2015, sets forth guidelines regarding future regulation related to the exploration and exploitation of unconventional hydrocarbon resources in Colombia. Under Decree 3004, an unconventional field is defined as a rock formation with low primary permeability that requires stimulation in order to improve the conditions of mobility and recovery of hydrocarbons. This regulation contains a series of guidelines regarding the regulation for unconventional hydrocarbon resources, including a definition of unconventional reservoirs and the term in which the MME has to issue the specific technical regulation regarding the exploration and exploitation of unconventional hydrocarbons and the proceedings that interested actors have to follow in order to seek the exploration and exploitation of unconventional hydrocarbons in Colombia. Resolution 90341 was issued on March 27, 2014, by the MME in development of the mandate of Decree 3004 setting the technical conditions, requirements and procedures for the exploration and exploitation of unconventional fields.
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On May 26, 2015, Decree 1073 compiled the majority of Colombian decrees in force regarding the administrative sector of mines and energy.
Decree Law 4137 of 2011, which modified the legal nature of the ANH regulates what corresponds to the integral administration of the hydrocarbon reserves and resources owned by the nation of Colombia.
In accordance with the aforementioned Decree Law, it is the responsibility of the Board of Directors of the ANH to define the criteria for administration and allocation of the areas; approve model contracts for their exploration and exploitation, while establishing the rules and criteria for their management and monitoring the contribution to the economic and social development of the country through the promotion and sustainable use of reserves and resources.
The contracts for the exploration and exploitation of hydrocarbons signed with the ANH are regulated through “Agreements” ( Acuerdos in Spanish) issued by the ANH. Notwithstanding the ongoing modifications to the area allocation regime established by the ANH, the rules and agreements under which the aforementioned contracts were originally executed or subsequently modified shall govern these contracts until their termination.
Agreement 004 of 2012, as issued by the ANH, repealed Agreement 008 of 2004 and sets forth the rules governing the award of exploration and production areas and the execution of contracts. As set forth below, Agreement 002 of 2017 replaces this Acuerdo and was amended by Agreement 009 of 2021 and Agreement 003 of 2022 (amended by Agreement 002 of 2023). Each agreement entered into with ANH is ruled by the Acuerdo that was in effect on the date of execution of the relevant agreement.
Agreement 003 of 2014, as issued by the ANH and modified by Agreement 005 of 2015, complements Agreement 004 of 2012 (which was replaced by Agreement 002 of 2017) by setting forth the contractual framework for the carrying out of activities in unconventional reservoirs, the procurement regulations for the exploration and exploitation of unconventional fields and the procurement process for the awarding of hydrocarbon exploration and exploitation areas.
Agreement 002 of 2015, as issued by the ANH, partially amends Agreement 004 of 2012 and sets forth the initial rules and measures the Government can take to mitigate the adverse effects of the decline of international oil prices.
Agreement 003 of 2015, as issued by the ANH, modifies and also partially amends Agreement 004 of 2012, and provides certain rules and measures the Government can take to mitigate the adverse effects of the decline of international oil prices. This agreement permits performance guarantees required under EP contracts to be reduced in the same amount as the works actually performed during the term of the respective phase.
Agreement 004 of 2015, as issued by the ANH, also partially amends Agreement 004 of 2012, and provides certain rules and measures for the Government to mitigate the adverse effects of the decline of international oil prices. This agreement allows contractors to attribute additional activities carried out under a TEA to commitments under the first phase of an EP contract.
Agreement 002 of 2017, modified by Annex I of Agreement 03 of 2022, replaces Agreement 004 of 2012, Agreement 003 of 2014, and Agreements 002, 003, 004 and 005 of 2015. It establishes the general structure of the New Regulation for Administration and Assignment of Areas and the general guidelines regarding future hydrocarbon contracts in Colombia. Seeking the interests of the Nation, the market conditions, the national hydrocarbon sector strategy, the competitive context of producer countries and the Nation’s social and environmental evolution.
Agreement 002 of 2017 adapts the existing regulations for the selection of contractors, and the applicable rules for the award, execution, termination, liquidation, monitoring, control and surveillance of the contracts signed with the ANH. Regarding unconventional reservoirs, this agreement also establishes the need to sign additional contracts and additional arrangements for the industry to exploit unconventional reservoirs in Colombia.
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On November 8, 2018, the High Court for Administrative Matters ( Consejo de Estado ) analyzed the potential annulment of Decree 3004 of 2013 and Resolution 90341 of 2014 and issued an interim order to suspend their effects as of such date. However, the aforementioned Court established that, “… if the Colombian Government is interested in investigation, clarifying and exploring the feasibility of the hydraulic fracturing procedure for the exploration and exploitation of hydrocarbons in unconventional reservoirs, it could advance in the PPII to identify the risks of unconventional activity.” On July 7, 2022, the High Court for Administrative Matters resolved the claim against the aforementioned regulations, denying the requested annulment claims. With this decision, the suspension of Decree 3004 of 2013 and Resolution 90341 of 2014 was lifted.
On February 4, 2019, the ANH published the new model contract for offshore exploration and production. The purpose of this new model contract is to foster and stimulate investments in exploration and the exploitation of offshore hydrocarbons, enhancing Colombia’s competitiveness to attract and retain investments from large and experienced OG operators.
On February 5, 2019, the ANH by implementing the Acuerdo No. 002 (Agreement No. 002 of 2017) opened a PPAA, which aims to select, among previously qualified proponents on equal terms, the most favorable offers to allocate the areas previously determined, marked and classified by the ANH. Several addendums have modified the terms of references of the PPAA, but, as to date, the applicable terms of reference of such bidding process are included in Addendum No. 25 of November 23, 2021.
On February 18, 2019, the ANH issued the Agreement 003 to clarify the moment in which contractors may withdraw from the contracts signed with the ANH and also presents another alternative for those interested in the PPAA when they belong to business groups, other than the issuance of a parent company guarantee.
Resolution 078 of 2019, as issued by the ANH, approved the final terms of reference and the model of the onshore and offshore contract for the PPAA. Pursuant to this procedure, the ANH will select areas over which proposals may be received at any time, without the need of launching specific bidding procedures for their allocation.
As a result, in 2019, the ANH issued terms of references for the PPAA and carried out two cycles both of which were divided into the following four stages: (i) submission of the proposals and selection of the initial proponent, (ii) submission of counterproposals and selection of the most favorable counterproposal, (iii) the exercise by the initial proponent of the option to improve the initial proposal, and (iv) allocation of areas, contract awards and execution of contracts. In 2020, a third cycle was carried out by the ANH.
As result of the first cycle of the PPAA, the ANH awarded 11 onshore areas and one offshore area. As part of the second cycle, the ANH allocated 14 onshore blocks. Finally, as a result of the third cycle, the ANH awarded four onshore areas.
Agreement 001 of March 27, 2020 of the ANH regulates the transfer of activities or investments between legal instruments signed with the ANH to promote exploratory investment in the country and to seek the incorporation of new reserves, repealing specific articles of Agreement 002 of 2017.
Agreement 006 of September 11, 2020 of the ANH, amended by Agreement 004 of 2021, added certain rules from Agreement 18 of 2004, Agreement 04 of 2005, Agreement 21 of 2006, and Agreement 02 of 2017 to the Contracting Regulations for the Exploration and Exploitation of Hydrocarbons, to allow entities to carry out PPII on hydrocarbons in unconventional reservoirs with the use of the Multistage Hydraulic Fracturing with Horizontal Drilling ( Fracturamiento Hidráulico Multietapa con Perforación Horizontal or “FHPH” for its acronym in Spanish) technique. These terms and conditions were modified by Agreements 007, 008 and 009 of 2020 establishing the final terms and conditions for the selection of contractors by the ANH to perform the aforementioned hydrocarbons activities, as well as the final terms of the CEPI to be executed.
Through Resolution 0613 of September 14, 2020, the ANH opened a competitive process for the development of research projects in unconventional reservoirs using the FHPH technique.
Agreement 001 of February 5, 2021, issued by the ANH, established the requirements for the request of extension by mutual agreement to carry out additional exploratory activities in the exploration period, subsequent exploration program, and appraisal programs, as each of these phases are defined in the law. Furthermore, it regulated the requests and granting of term extensions to comply with contractual obligations.
Agreement 003 of February 11, 2021, issued by the ANH, approved the model agreement for the exploration and production of hydrocarbons.
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Agreement 004 of February 26, 2021, issued by the ANH, amended Agreement 006 of 2020 regarding the accreditation of commitments and counteroffer requirements applicable to the PPAA.
Considering the remaining impact caused by the COVID-19 pandemic, the ANH issued Agreement 005 of July 14, 2021, and established additional temporary measures to aid hydrocarbon companies in Colombia, including: (i) approving the transfer of activities or investments allowed under Agreement 001 of 2020 to areas included in the fourth cycle of the PPAA process undertaken in 2021; and (ii) extensions to comply with contractual obligations with the ANH.
Agreement 006 of July 14, 2021, issued by the ANH, established general PPAA guidelines, in addition to those listed in the ANH Agreement 002 of 2019.
Agreement 009 of October 12, 2021, issued by the ANH, amended Agreement 002 of 2017 and established the annex 1 with the compiled and updated rules to allocate and entitle areas to develop exploration and production of hydrocarbons in Colombia and the procedures to perform the contractual obligations agreed according to these rules.
Resolution 728 of October 14, 2021, issued by the ANH, provided the terms and conditions to carry out “Benefit Programs for the Communities” established in the geographic areas covered by EP agreements. In accordance with this resolution, EP contracts oblige operators to develop programs for the benefit of the communities where the EP activities take place.
The ANH also issued Agreement 10 of November 12, 2021 and established the possibility to comply with exploratory obligations in EP and TEA agreements, as well as in any Convenios by drilling A3 or A2 wells in any area of the Colombian territory that is included in the land map provided by the ANH. This possibility would apply for wells that were drilled in 2021 and 2022. If any company wants to use this possibility, its legal representative shall previously notify the ANH. Regarding CEPI contracts ruled by Agreement 06 of 2021, this Agreement, established specific procedures and alternatives that the contractor has for certification of compliance obligations under this type of special agreement including: effective investment performance criteria, obligation to deliver technical information to the Petroleum Information Bank of the Colombian Geological Service and allocation of the investment performed by the contractor. This Agreement was regulated by Resolution 10882 of 2021, issued by the ANH as well.
On December 1, 2021, the hearing for the presentation and opening of bids for the fourth round of the PPAA was held, according to the schedule of the terms of reference, in which Ecopetrol S.A. submitted four proposals corresponding to three areas offered at the initiative of the Company and one area offered at the initiative of the ANH.
Per the terms of reference and the declaration of initial bidder for the fourth round of the PPAA by the ANH, dated December 14, 2021, concerning the areas labeled “LLA 141,” “VMM 4-1,” “VMM 14-1,” and “VMM 65,” the ANH, through Resolution 20919 of December 20, 2021, awarded the four areas to Ecopetrol S.A.
As a result of the award, on January 18, 2022, the ANH and ECOPETROL S.A. signed the TEA contracts VMM 65, VMM 141 and VMM 41, and the EP Llanos 141.
In 2022, several agreements were issued by ANH related to the modification of concessions awarding conditions and contractual terms as follows:
Agreement 001 of June 29, 2022, issued by the ANH, regulates the termination by mutual consent, of contracts and agreements for the evaluation, exploration, exploitation and production of hydrocarbons.
Agreement 003 of July 25, 2022, issued by the ANH and amended by Agreement 003 of 2024, by which the regulations for the selection of contractors and allocation of areas for exploration and exploitation of hydrocarbons are adopted and partially superseded Agreement 002 of 2017.
Agreement 004 of July 25, 2022, issued by the ANH, establishes the conditions for the nomination of areas returned to the ANH in the frame of PPAA process. This Agreement was repealed by Agreement 008 of 2024.
Agreement 005 of July 25, 2022, issued by the ANH, establishes new criteria for the administration of contracts and agreements for hydrocarbon exploration and production and extended the term provided by Agreement 10 of 2021 for drilling of A2 and A3 wells until the ANH’s council determines otherwise.
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Agreement 006 of August 5, 2022, issued by the ANH, by which the model minute for “shared production” was approved for areas which are under production and are being returned to the nation. This Agreement was repealed by Agreement 008 of 2024.
Agreement 007 of August 5, 2022, by which the ANH approved the definitive terms of reference for the Open Process for the Nomination of Areas ( Proceso Abierto de Nominación de Áreas or “PANA” for its acronym in Spanish) and included the commitment to carbon management as a primary factor in the evaluation and qualification of bids for the award of EP contracts.
Agreement 009 of November 4, 2022, that authorizes the ANH to enter into amendments to the CEPI with the contractors.
Agreement 002 of January 11, 2023, issued by the ANH, eliminated a phrase of Articles 17 and 18 of Agreement 003 of 2022, both related to the process of “Direct Allocation with Counteroffer”. Such process which requires the prior establishment of rules, capacity requirements, and conditions and terms required of the proponent, that have not yet been established by the ANH. In this regard, these amendments were made to avoid confusion among proponents, and to prevent the ANH from becoming involved in the initiation of “Direct Allocation with Counteroffer” procedures which rules and conditions have not been established.
Agreement 003 of July 19, 2023, issued by the ANH, allows the use of a three-month term SOFR (Secured Overnight Financing Rate) plus a spread equivalent to 4%, as a measure to mitigate the adverse effects caused by the change in the international reference interest rate for obligations denominated in U.S. dollars within contracts and other legal transactions administered by the ANH.
Agreement 006 of September 28, 2023, issued by the ANH, seeks to promote exploratory investment in hydrocarbons in the country to favor and ensure the maintenance and increase of oil and gas reserves, as well as to drive the national government’s policy of a “Just Energy Transition”. The agreement establishes the following four criteria, with the following application requirements:
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1) |
Extension of deadlines for exploration periods or subsequent exploratory programs phases for additional exploratory activity. |
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Reduction of guarantees for additional exploratory activity. |
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3) |
Conversion of unconventional reservoir contracts. |
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4) |
Allocation of up to fifty percent (50%) of the remaining investment for power generation through sources of unconventional energy ( fuentes no convencionales de energía or “FNCE” for its acronym in Spanish). |
This Agreement is limited to existing hydrocarbon contracts and agreements, except for those signed under the fourth cycle of PPAAs, as they do not align with the timelines of the Agreement.
Resolution 40622 of October 17, 2023, issued by the Ministry of Mines and Energy establishes the technical requirements for the temporary suspension, and the temporary and definitive abandonment of hydrocarbon exploration and production activities, and partially modified Resolution 181495 of 2009. This resolution clarified the possibility of temporarily abandoning offshore wells and is expected to have a positive impact on the development of deepwater projects in Colombia.
Agreement 002 of April 30, 2024, issued by the ANH, established that, in all cases involving EP contracts and additional contracts for unconventional reservoirs, where an exploratory program with unconventional techniques was agreed, contractors may voluntarily adhere to the Agreement and choose one of the following alternatives: (i) modification of the Exploratory Program to restrict it to conventional techniques; (ii) suspension by mutual agreement of all obligations assumed by the contractor, including economic and financial obligations; or (iii) termination by mutual agreement. As of the ANH approves the contractor’s request to adhere to the Agreement, all obligations related to the contracts, including economic rights, will cease and will only resume when the exploratory program is modified, under the terms agreed in the respective amendment of the contracts.
Additionally, this Agreement sets forth the conditions under which contractors of unconventional reservoirs contracts or additional contract for unconventional reservoirs may request the modification of the agreed exploratory program to modify its execution toward the exploration and production of hydrocarbons using conventional techniques. In such cases, the obligations derived from the exploratory program for unconventional reservoirs will be terminated.
Finally, regarding the performance guarantees for the contracts under this Agreement, contractors may request a reduction to a minimum amount of USD 100,000 for the period during which the activities remain suspended or until the selected alternative becomes effective.
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Agreement 003 of April 30, 2024, issued by the ANH, amended Agreement 003 of 2022 and established that the ANH may contract the operation and management of areas with productive assets that become property of the Nation due to termination of the production period, reversion of productive assets, or any other situation where the management of productive assets of the Nation is necessary. This Agreement was regulated through Agreement 008 of 2024 as explained below.
Agreement 004 of September 27, 2024, issued by the ANH, amended Agreement 002 of 2017, Agreement 009 of 2021, and Agreement 003 of 2022 and established guidelines (definition, scope, mechanisms, and methods of compliance) related to the obligations of contributions for training, institutional strengthening, and technology transfer under the contracts and agreements entered with the ANH.
Agreement 008 of December 2, 2024, issued by the ANH, repealed Agreement 004 of 2022 and Agreement 006 of 2022 and established the terms and conditions for contracting the operation and management of areas with productive assets owned by the Nation, due to events such as the end of the production period, reversion of productive assets, or, in general, when the management of the Nation’s productive assets is necessary for production in discovered reservoirs.
Agreement 009 of December 2, 2024, issued by the ANH, approved the final terms of reference for the “Permanent Process for Selecting Contractors for the Operation and Management of Areas with Productive Assets” and the draft of the “Contract for the Operation and Management of Areas with Productive Assets”. Additionally, it authorized the President of the ANH to direct and manage the “Permanent Process for Selecting Contractors for the Operation and Management of Areas with Productive Assets” until its conclusion and to issue the contract drafts necessary to incorporate new areas with productive assets.
Resolution 40537 of December 11, 2024, issued by the Ministry of Mines and Energy, repealed Resolution 181495 of 2009 and established new technical measures for the development of activities related to exploration and production of hydrocarbons in the national territory. Some measures established by the Resolution are: (i) the unification and updating of applicable technical and environmental regulations: (ii) the authorization of an initial production period under certain conditions while the definitive environmental license is being processed; (iii) the definition of criteria for classifying wells and procedures for drilling and exploitation; (iv) goals and measures regarding carbon neutrality and climate resilience are highlighted, encouraging the oil industry’s plans and strategies for decarbonization and energy efficiency, among others.
Temporary regulation for the Comprehensive Research Pilot Projects (PPII)
We have actively participated in the formulation of specific regulation for the implementation of the PPII. The regulatory framework includes:
| ● | Resolution 40185 of 2020, modified by Resolution 40011 of 2021, of the Ministry of Mines and Energy. Technical regulations for the development of PPII. |
| ● | Resolution 0904 of 2020 of the Ministry of Interior and the Ministry of Mines and Energy. Social Guidelines for the development of PPII. |
| ● | Resolution 304 of 2020 of the Colombian Geological Service. Guidelines for the monitoring of seismicity and the inclusion of a seismic traffic light for the PPII. |
| ● | Agreement 006 of 2020 of the ANH, modified by Agreements 007, 008 and 009 of 2020 and Agreement 004 of 2021. Regulations for the selection of contractors for CEPIs. |
| ● | Decree 328 of 2020 issued by the Ministry of Mines and Energy providing the general guidelines for developing PPII on unconventional reservoirs. |
| ● | In January 2021, the Colombian Geological Service office issued the third version of the technical guidelines for the laboratory sampling and analysis procedure of radioactive materials produced by the PPII. |
| ● | Resolution 1541 of 2021 of the Ministry of Health guidelines for the development of PPII. |
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3.10.1.1.1 |
Environmental Licensing and Prior Consultation |
The ANLA, created by means of Decree 3573 of 2011 (modified by means of the Decree 376 of 2020), is the authority responsible for evaluating the applications and issuing the environmental licenses for OG-related activities, as well as surveilling and overseeing all hydrocarbon projects and monitoring the environmental compliance of such activity.
If the projects or activities could have a direct impact over the territories or the interests of indigenous, Afro-Colombian or Raizal communities, the Colombian Constitution provides that the companies developing such projects or activities must conduct a consultation process with those communities before initiating such projects or activities. This consultation process is a prerequisite for obtaining the required environmental licenses.
Any person or company that intends to conduct projects, works and/or activities is required to file a request before the National Authority of Prior Consultation. The National Authority of Prior Consultation will consider the following factors in its decision: (i) the presence of ethnically differentiated communities within or nearby the area of the project, work and/or activity; (ii) the positive or negative impact over the social, economic, environmental or cultural conditions of said communities, and that could be derived from the project, work or activity. Presidential Directive 10 of 2013 (which was subsequently amended by Presidential Directive 8 of 2020), Decree 1066 of 2015, and the Constitutional Court case law have established the phases applicable to the prior consultation process. In August of 2023, the Constitutional Court declared the invalidity of certain provisions applicable to the prior consultation process.
In addition, the Colombian Constitution and laws establish that, as part of the public participation mechanisms, Colombian citizens may request information regarding the activities of the project and their potential impacts. They may also request to undertake an environmental hearing to obtain information of the project subject to environmental licensing.
On May 26, 2015, the Ministry of Environment and Sustainable Development ( Ministerio de Ambiente y Desarrollo Sostenible or “MADS” for its acronym in Spanish) issued Decree 1076 of 2015, which compiles most of Colombian regulations in force regarding environment and sustainable development, including those applicable to environmental licenses.
The environmental license encompasses all the necessary permits, authorizations, concessions and other control instruments necessary under Colombian environmental law to undertake a project or activity that may result in the serious deterioration of renewable natural resources, or that has the capacity of materially modifying the physical environment. The license defines specific conditions under which the license holder shall undertake such project or activity. The procedure to obtain an environmental license begins when the company files an EIA related to the project before the ANLA. The licensing process includes an application for the use of natural renewable resources (water, soil, and air). When the project or activity requires permits for the use of forestry banned species, these should be included in the environmental license process, according to Decree 2106 of 2019. The EIA must be filed as well as a plan to prevent, mitigate, correct, and compensate for any activity that may harm the environment, known as the Environmental Management Plan ( Plan de Manejo Ambiental or “PMA” for its acronym in Spanish).
The environmental licensing procedure in Colombia is included in Decree 1076 of 2015. According to the regulation currently in effect, the procedure to obtain an environmental license shall not take more than 90 business days. But, depending on the complexity of the information requested by the ANLA and administrative delays, including an oral hearing to request additional information for the EIA assessment, the procedure may take between 165 and 265 business days, depending on whether the applicant is required to file additional information.
The environmental licensing process for the PPII is established in Decree 1076 of 2015. However, the Ministry of Environment and Sustainable Development issued Resolution 0821 of September 24, 2020, which established the terms of reference for the preparation of the Environmental Impact Study of the PPII.
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The MADS is also responsible for issuing regulation and establishing climate change policies for different sectors in Colombia. The Ecopetrol Group complies with all applicable regulations. MADS is responsible for issuing regulation regarding Law 1931 of 2018 (amended by Law 2294 of 2023) (also known as the “Climate Change Law”), which outlines provisions for the establishment of a National Program of Greenhouse Gas (“GHG”) Tradable Emission Quotas ( Programa Nacional de Cupos Transables de Emisión de Gases de Efecto Invernadero or “PNCTE” for its acronym in Spanish). The PNCTE must be fully implemented by 2030. The MADS is also responsible for the National Emission Reductions Registry ( Registro Nacional de Reducción de Emisiones de Gases de Efecto Invernadero or “RENARE” for its acronym in Spanish), in which companies must register verified GHG emission reductions (Article 175 of Law 1753 of 2015, modified by article 230 of Law 2294 of 2023, and partially regulated by Resolution 418 of 2024, issued by MADS) RENARE started operating in 2021. As part of our continuous monitoring of climate change requirements, we also participated in a regulatory process related to the issuance of Resolution 40066 of 2022 regarding the reduction of fugitive emissions and routine flaring, led by the Ministry of Mines and Energy. A company that does not comply with the applicable environmental laws and regulations, does not execute the corresponding PMAs approved by the environmental authority or ignores the requirements imposed by an environmental license may be subject to an administrative sanction proceeding initiated either by the ANLA or the regional environmental authorities established by Law 1333 of 2009, modified by Law 2387 of 2024, without disregard to the criminal actions that may take place in accordance with law 2111 of 2021. The proceeding may result in oral or written warnings, monetary penalties, fines, license revocation or the temporary or permanent suspension of the activity being undertaken. Besides administrative sanctions, the Colombian judiciary or other law enforcement authorities may also impose civil and even criminal sanctions if environmental damages are verified as a consequence of having breached the environmental laws and regulations applicable to the project.
The Escazú Agreement, which emerged from the 2012 United Nations Conference on Sustainable Development (Rio+20), was negotiated and approved in Escazú, Costa Rica in 2018. Civil society as well as human rights and environmental experts participated in this process and played an essential role in the adoption of this agreement.
This agreement provides for access to information, public participation and justice in environmental matters in Latin America and the Caribbean as well as regional environmental human rights to set forth a framework for environmental democracy, international cooperation and multilateralism in connection with efforts to build back better using a human rights-based approach.
Colombia is one of the 14 countries to approve the Escazú Agreement. Said agreement was adopted by means of Law 2273 of 2022. On August 28, 2024, the Colombian Constitutional Court confirmed the constitutionality of this law. In this sense, no significant changes are expected in its content that could affect the meaning or main objective of the Escazú Agreement, which is in line with Article 23 of the Escazú Agreement, which expressly establishes that deviations are not admitted. For more information see section Risk Review—Risk Factors—Risks Related to Our Business—Our operations, including our activities in areas classified as indigenous reserves and Afro-Colombian lands, could be subject to opposition from members of various communities .
New environmental regulations
Law No. 2327 dated September 13, 2023 (the “Environmental Liabilities Law”), issued by MADS. It contains provisions related to the definition of environmental liability, guidelines for its management, and, in general, provides for a general legal framework for environmental liabilities arising out of the development of projects and works, particularly concerning those environmental liabilities for which a responsible party cannot be easily determined. The law is particularly relevant in the context of hydrocarbon projects, which carry environmental contingencies that may result in environmental liabilities.
The National Government had one year as of the enactment date of the Environmental Liabilities Law to draft and release the environmental liability management public policy guidelines. MADS, in coordination with the Ministry of Finance and Public Credit, would establish the system and method for the financing and allocation of resources for environmental liabilities management. MADS had a term of six months as of the enactment date of Law No. 2327 to issue new regulations to structure the application of the Environmental Liabilities Law. As of the date of this annual report, the issuance of guidelines for the formulation, implementation and evaluation of public policy on the management of environmental liabilities by the National Government and the MADS is pending. Moreover, the Environmental Liabilities Information System was established in accordance with these new legal provisions, which must also include an Environmental Liabilities Registry (REPA, for its acronym in Spanish) as the information management tool.
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Decree 0582 of July 5, 2024, MADS modified Decree 1076 of 2015 regarding environmental licenses grants for projects of exploration and use of virtually polluting alternative energy sources in Colombia. This new rule extends the definition of virtually polluting alternative energy sources to Non-Conventional Renewable Energy Sources (FNCER) defined in Decree 1715 of 2014. ANLA is the competent environmental authority to issue environmental licenses for exploitation projects of virtually polluting alternative energy sources with installed capacity equal to or greater than 50 MW. Prior to the issuance of this Decree, ANLA’s competence covered projects with installed capacity equal to or higher than 100 MW. The Regional Authorities are granted competence to issue environmental licenses for projects of exploitation of virtually polluting alternative energy sources with installed capacity greater than 10 MW and less than 50 MW. Prior to the issuance of this Decree, CAR’s competence covered projects with installed capacity higher than 10 MW and less than or equal to 100 MW. This Decree only applies to projects that file a license application after October 5, 2024.
On July 11, 2024, by means of ruling C-280 of 2024, the Constitutional Court of Colombia declared the conditional constitutionality of the second paragraph of Article 57 of Law 99 of 1993, under the understanding that there is a constitutional protection deficit and establishes the obligation to include an evaluation of climate change impacts in the Environmental Impact Assessments (EIA). This requirement is expected to be enforceable for environmental license applications or renewals submitted on or after August 1, 2025. However, to this date there is no update on the reference terms for environmental licensing to include the evaluation of climate change impacts in the EIA submission. As of the date hereof, the MADS has submitted a draft Resolution to set forth generic terms of reference for the preparation of environmental impact studies in relation to the evaluation of climate change impacts that may be produced by works or activities whose execution requires an environmental license.
Law 2387 dated July 25, 2024, issued by MADS, which modifies the environmental administrative sanctioning regime. The most relevant aspects of this regulation include the following: (i) the increase of the liability and the amount of pecuniary fines (the new law establishes that the fines will be of up to 100,000 minimum legal monthly salaries); (ii) the inclusion of stage of closing arguments in the environmental administrative investigation process, as established in Article 48 of Law 1437 of 2011 (this stage was previously granted by certain regional environmental authorities, but it was not standardized as a stage of the procedure at the national level); (iii) the possibility of suspension and early termination of the environmental administrative investigation process (this provision allows the environmental administrative investigation process to be suspended and eventually terminated if the infringer proposes and conducts corrective measures and/or compensation for the environmental damage caused); (vi) the definition of Environmental Damage, understood as the partial or total deterioration, alteration or destruction of the environment, and; (v) the event of liquidation, reorganization, or insolvency of a legal entity, according to which the legal counsel or liquidator must inform the environmental authority immediately and provide guarantees to ensure the payment of the obligations arising from the environmental administrative investigation. This new regulation is in force as of its enactment, repealing all contrary provisions. These modifications have direct effects on the ongoing environmental administrative investigations.
On August 28, 2024, the Colombian Constitutional Court issued its decision regarding the constitutionality of Law 2273 of 2022, which approves the Regional Agreement on Access to Information, Public Participation, and Access to Justice in Environmental Matters in Latin America and the Caribbean, commonly known as the Escazú Agreement. The primary objectives of Law 2273 of 2022 are to: (i) ensure access to environmental information, (ii) promote public participation in environmental decision-making processes, (iii) guarantee access to justice in environmental matters, and (iv) protect human rights defenders in environmental issues.
The Ministry of the Internal Affairs issued Decree 1094 dated August 28, 2024, which recognizes the mandate of the Territorial Economic and Environmental Authority (ATEA) as an instrument of law of the traditional authorities of the indigenous peoples of the Regional Indigenous Council of Cauca-CRIC. The aforementioned Decree establishes the powers of the ATEA, the operation and coordination mechanisms with the public authorities for its exercise in the territories that comprise it within the framework of autonomy and self-determination.
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On October 15 of 2024, MADS issued Decree 1275, which established the measures required for the operation of the indigenous territories in environmental matters and the development of the environmental powers assigned to the indigenous authorities and their effective coordination with other administrative authorities and/or entities. The traditional indigenous authorities, the authorities of the indigenous territories, the indigenous cabildos and other similar self-government structures in their indigenous reserves, among others, will become part of the National Environmental System (“SINA” for its acronym in Spanish) and will perform its powers related to territorial environmental planning, determination of regulation, management and governance mechanisms for the preservation, conservation, restoration, protection, care, use and management of natural resources in accordance with Article 15 of OIT Convention 169. Said Decree 1275 does not indicate who will have the authority to authorize or deny procedures, permits and/or authorizations for projects whose area of influence includes Indigenous Territories, nor does it mention the implications on projects, works or activities with instruments in force, which are being executed in areas of Indigenous Territories. It is also important to note that according to the scope of application of said Decree, established in Article 4, Afro-descendant people were not included as part of the recognition as environmental authorities.
By means of Resolution 418 of 2024, MADS partially regulated article 175 of Law 1753 of 2015 (modified by article 230 of Law 2294 of 2023) regarding the definition of the administration of the National Greenhouse Gas Emissions Reduction and Removal Registry – RENARE.
3.10.1.1.2 Royalties
In Colombia, the State is the owner of minerals and non-renewable resources located in the subsurface, including hydrocarbons. Thus, companies engaged in exploration and production of hydrocarbons, such as us, must pay to the ANH, as representative of the Government of Colombia, a royalty on the production volume of each production field, as determined by the ANH.
Royalties may be paid in kind or in cash. Each production contract has its applicable royalty arrangement in accordance with applicable law. In 1999, a modification to the royalty regime established a sliding scale for royalty payments for crude oil and natural gas production fields discovered after July 29, 1999 and depending on the quality of the crude oil produced. Since 2002, as a result of the enactment of Law 756 of 2002, the royalty rate was fixed as a sliding scale depending on the produced volume from 8% for fields producing up to 5 mbd to 25% for fields producing in excess of 600 mbd. Notwithstanding the royalties for Incremental Production Contracts, Contracts for Undeveloped and Inactive Fields, and Incremental Production Projects defined in paragraph 3 of Article 16 of Law 756 of 2002, and Article 29 of Law 1753 of 2015, the changes in the royalty regime only apply to new discoveries and do not apply to fields already in the production stage as of July 29, 1999. Producing fields pay royalties in accordance with the royalty law in force at the time of the discovery.
With the issuance of Law 2056 of 2020 (“Through which the organization and operation of the general system of royalties is regulated”), the royalties’ regime applicable to the hydrocarbon fields on which there have been made additional investments aimed at increasing the recovery factor of existing deposits was established. Article 18 of this law established that all the volumes produced in these fields will be considered incremental.
For crude oil, the ANH issued Resolution 164 of 2015, modified by Resolutions 907 of 2016 and 855 of 2020 to determine the procedures and terms for liquidation of the royalties caused for crude oil production in Colombian territory.
Regarding natural gas, in accordance with Resolution 877 of 2013, as amended by Resolution 640 of 2014, and Resolution 351 of 2014, starting on January 1, 2014, the ANH has received royalties in cash rather than in kind. Thus, the producer may dispose of its gas production volumes corresponding to royalties paid in cash. Through Resolution 165 of 2015 modified by Resolution 436 of 2021, the ANH established the procedure to liquidate royalties of natural gas.
On September 23, 2021, the Ministry of the Interior issued Decree 1142 “Whereby Decree 1821 of 2020, Sole Regulatory Decree of the General Royalties System, is added and modified.” Article 3.1.1.2.1 of this Decree established that the total volume of hydrocarbons produced that is additional to that stipulated in the basic production curve of incremental production projects or incremental production contracts will enjoy the benefits provided in paragraph 3 of Article 16 of Law 756 of 2002.
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Law 2294 of May 19, 2023 amended Article 50 of Law 2056 of 2020 to, among other matters, allow the distribution of royalty resources for the financing of projects related to the creation and updating of roadmaps for the management of environmentally protected areas.
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3.10.2 |
Regulation of Transportation Activities |
Hydrocarbon transportation activity is a public interest activity in Colombia and a public service. As such, it is under governmental supervision and control, regulated mainly by the Ministry of Mines and Energy and the Energy and Gas Regulatory Commission.
Transportation and distribution of crude oil, liquefied petroleum gas and refined products must comply with the Petroleum Code, the Code of Commerce and all governmental decrees and resolutions. However, liquefied petroleum gas-related activities are regulated by CREG. According to Law 681 of 2001, multi-purpose pipelines owned by Cenit (a company wholly owned by Ecopetrol S.A.) must be open to third-party use on the basis of equal access to all.
Moreover, the Ministry of Mines and Energy issued Resolution 40745 of 2023, which regulates (i) multiphase pipeline transportation, which consists of the transportation of a combination of hydrocarbons known as multiphase fluids, (ii) the conditions and requirements for requesting the reclassification of a common crude pipeline to a multiphase pipeline, (iii) the applicable guidelines to access multiphase pipelines, (iv) the transportation contracts and permitted tariffs for multiphase pipelines, and (v) defining the obligations of both, the shipper and the transporter; for this subject matter.
Notwithstanding the general rules for hydrocarbon transportation in Colombia, Law 142 of 1994 defines the regulatory framework for the provision of public utility services, including the provision of natural gas and liquefied petroleum gas. Moreover, natural gas transportation is subject to regulations specific to the natural gas industry as issued by CREG, due to the categorization of natural gas distribution as utility, and therefore, a public interest activity under Colombian laws.
According to Resolution CREG 057 of 1996, natural gas producers, such as us, are not allowed to have significant economic interests in gas transportation companies. Accordingly, we currently do not perform any natural gas transportation activities. On the other hand, and by virtue of the publication of Decree 1467 of 2024, where the Ministry of Mines and Energy incorporates the definition of Infrastructure Conversion and the possibility of using existing infrastructure from hydrocarbon transportation activities for natural gas transportation, analyses are currently being carried out to assess the technical adaptation of crude oil transportation infrastructure for natural gas transportation, as well as other regulatory adjustments that allow for its proper remuneration. In such cases, the Decree establishes that the transportation service provided through converted infrastructure must be provided by a Natural Gas Transporter agent.
Transportation systems, classified as crude oil pipelines and multi-purpose pipelines, may be owned by private parties. Pipeline construction, operation and maintenance must comply with environmental, social, technical, and economic requirements under national guidelines and international standards for the oil and gas industry.
Construction of transportation systems requires endorsements, licenses and local permits awarded by MME, ANLA and regional environmental authorities, respectively.
Crude oil transportation
Crude Oil Pipelines
According to Resolution 72145 of 2014, the regulatory framework relating to crude oil transportation accounts for both private use and public use pipelines. Private use pipelines are those built by the operating or refining entity for its own exclusive right and that of its affiliates. Public use pipelines are defined as pipelines built and operated by a public or private legal entity, for the purpose of publicly providing crude oil transportation services. The Colombian Government, through the ANH, has a preferential right to use up to 20% of the total capacity of any public or private access pipeline to transportation its crude oil royalties, as provided by Resolution 72145 of 2014. However, for both private and public access pipelines, the ANH must pay the tariff for the pipeline use to transportation its percentage of production.
The Ministry of Mines and Energy is responsible for reviewing and approving the design of and tracks for crude oil pipelines and establishing transportation rates based on information provided by the service providers. It also oversees the calculation and payment of hydrocarbon transport-related taxes and manages the information system for the oil product distribution chain.
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In 2014, MME updated the transportation regulation and the rate calculation method for this line of business. It introduced a framework for the secondary market and incentives for new pipeline construction and current pipeline capacity expansions. According to the Petroleum Code, rates must be revised every four years.
During the scheduled revision of 2019, MME, by means of Resolutions 31123 and 31132 of 2019, modified Resolution 72146 of 2014 and established the applicable rules for transportation and oil production companies to negotiate tariffs for the next four years. Once the negotiation period was over, MME issued a series of resolutions to set the applicable tariffs for transportation of crude oil through pipelines. Such resolutions were in line with the tariff methodology that has been in place since 2014, providing more regulatory stability to midstream companies until June 2023.
In August 2022, MME started a consultation process to review, adjust, and update the methodology for setting crude oil tariffs. The scope of the study required contractors to prepare a document proposing changes to the current methodology determined by Resolution No. 72146 of 2014. The main results of such study were published and analyzed, and the various stakeholders presented their comments to MME.
On March 30, 2023, MME published Resolution No. 279 of 2023, which determined that the tariffs set for the period of July 2019 to June 2023 would remain in force until new tariffs were set for the period of July 2023 to June 2027, according to a new methodology yet to be defined. Any tariff or methodology revision must always be developed under the premise of an adequate compensation for investments and incentives for access and proper provision of the service for all agents, for which the Ministry must publish the proposed resolution for comments from the agents before its final issuance.
On May 16, 2024, MME published a draft resolution to update the Pipeline Tariff Methodology but maintaining the essence of the current regulation, introducing modifications concerning contingency management and procedures that shippers must follow to certify the crude oils entering the system for transportation, and rules for volumetric compensation applicable to determine the tariff for this activity. The proposed tariff methodology promotes direct agreements between transporters and shippers. Additionally, compared to the current methodology established in Resolution MME 72146 of 2014, various adjustments were proposed, analyzed and commented on by Cenit and its subsidiary companies within the stipulated time frame.
On August 26, 2024, MME issued Resolution No. 895 of 2024 to (i) lift the suspension indicated in Resolution No. 279 of 2023 and allow transporters to carry out the annual update of pipeline tariffs starting on September 1, 2024; and (ii) maintain the suspension of negotiation period regulations established in articles 5A, 5B, 5C, and 5D of Resolution No. 72146 of 2014.
Hydrocarbon Ports
The Port Superintendence is the authority that oversees the port business for crude oil and refined products. Although this business is not highly regulated, market participants are required to report certain information to the Port Superintendence.
With the purpose of regulating the administrative management of the ports, Law 1 of 1991 was issued, which defines the Port Concession Contract. This document allows a port company to temporarily occupy and use the beach, low tide and accessory areas in exchange for a consideration paid to the nation.
As a result of the enactment of Decree 119 of 2015, operators of private use hydrocarbon ports are currently able to provide hydrocarbon transportation services to third parties pursuant to a mechanism established under that decree.
Decree 119 of 2015 was incorporated into Decree 1079 of 2015 issued by the Ministry of Transport, which compiles the majority of Colombian decrees and regulations in force regarding the administrative sector of transportation.
Refined products and liquefied petroleum gas transportation
In 2014, CREG assumed responsibility for regulating product pipeline transportation from the Ministry of Mines and Energy, in addition to its pre-existing regulatory responsibility for liquefied petroleum gas, natural gas, and electric energy transportation.
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In February 2021, CREG issued Resolution 004 of 2021, partially modified by Resolutions 073 of 2021 and 105 003A of 2022 by which CREG defined the Weighted Average Cost of Capital (WACC) methodology applicable to the different activities that CREG regulates. The activities regulated by CREG include energy distribution and transmission, gas distribution and transportation and refined products transportation. The discount rate for transportation of refined products is calculated in accordance with the inputs defined by the resolution and will be applicable once the tariff methodology for this activity is updated and published.
In December 2021, CREG issued Resolution 208 of 2021, partially amended by Resolution 104 002 of 2022, which established the regulations for transportation by multi-purpose pipelines, including transportation of LPG. The main objectives of the regulation are: (i) to ensure access to the transportation system without discrimination; and (ii) to offer optimal conditions in the operation and provision of the public transportation service.
Also in December 2021, the MME published Resolution 40408 of 2021, which established the refined products pipelines expansion plan.
With draft Resolution CREG 705 002 of 2022, the Energy and Gas Regulatory Commission (CREG), proposed a tariff methodology for the remuneration of the transportation of liquid fuels and liquefied petroleum gas (LPG) through pipelines. This regulatory proposal aims to guarantee a fair and efficient tariff structure, promoting investment in infrastructure and improving service quality. Among the most relevant elements of the resolution are the integration of remuneration for liquid fuels and LPG, the consideration of the technical conditions of the transported products, and the inclusion of mechanisms for the remuneration of infrastructure defined by the central planner. The issuance process of the new methodology is expected to be completed during the first half of 2025.
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3.10.3 |
Regulation of Refining and Petrochemical Activities |
Article 58 of the Petroleum Code establishes that oil refining activities can be developed throughout the Colombian territory and are not reserved to the Nation. However, Article 4 establishes that such activities are considered of public interest subject to governmental regulation, and the development of those activities must comply with technical requirements established by regulation.
Law 1205 of 2008, further developed by Resolution 180689 of 2010, issued by the Ministry of Mines and Energy, has the main purpose of contributing to a cleaner environment. It established the minimum quality specifications for liquid fuels in Colombia. Since August 2010, we have been producing and selling diesel and gasoline that comply with the requirements of the aforementioned law.
Since 1995, under Resolution 898 of August 23, 1995, the Ministries of Environment and Sustainable Development and of Mines and Energy, have regulated the environmental criteria for liquid and solid fuels used in commercial and industrial furnaces and boilers, as well as automobile internal combustion engines. Resolution 898 has been subject to numerous modifications through the years, the most recent by Resolution 40444 of June 30, 2023, which states diesel quality requirements to protect the environment, health, and quality of liquid fuels in general.
Article 2.2.1.1.2.2.1.1. and following, Decree 1073 of 2015 establishes the general regulation related to buying and selling fuels in Colombia. With respect to refining activity, the aforementioned Decree provides the requirements and authorization procedures to develop this activity in Colombia. We are duly registered as a refining agent and therefore is authorized to sell fuels in Colombian territory to specific agents and use and acquire fuels as a large consumer, as well in specific oil plants as is published in the information system of liquid fuels of the Ministry of Mines and Energy.
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3.10.3.1 |
Regulation of Liquefied Petroleum Gas (LPG) and Liquid Fuels |
Wholesale marketing, transportation, distribution and retail marketing of LPG are mainly regulated by CREG Resolution 74 of 1996, and subsequent resolutions. LPG in Colombia is primarily obtained through our refineries, field production and imports. The LPG must meet minimum quality standards to be marketed. Our marketing activities are regulated by CREG Resolution 53 of 2011 (as amended by CREG Resolutions 108 of 2011, 154 of 2014, 19 of 2015, 18, 63, 64 of 2016, 171 of 2017 and 103 00-2 of 2022). The LPG price is regulated by CREG Resolutions 66 of 2007 (as amended by CREG Resolutions 59 of 2008, 002 of 2009, 123 of 2010, 95 of 2011, and 65 and 129 of 2016) as well as by CREG Resolution 80 of 2017 which sets forth that the price of LPG imported by us, which is meant to be marketed for the provision of public utilities, shall be the result of competitive procedures. In Resolution 108 of 2021, issued by CREG, was established the “ opción tarifaria ” mechanism or “rate option”, which was a temporary mechanism that defered on time the impact of the international rate hikes on the selling price of LPG to the final user.
According to Article 4 and 212 of the Petroleum Code and Law 39 of 1987 (added by Law 26 of 1989 and as amended by Law 812 of 2003), the distribution of crude oil and its derivatives has a public purpose ( utilidad pública ), and the distribution of fuel oil and crude oil by-products is considered a public utility activity. Consequently, individuals or entities engaged in these activities are subject to regulations issued by the Colombian Government. The Government has the power to determine quality standards, measurement, and control of liquid fuels, and establish penalties that may apply to dealers who do not operate in compliance therewith.
The Ministry of Mines and Energy is the entity that controls and exercises technical supervision over the distribution of liquid fuels derived from petroleum, including the refining, import, storage, transportation, and distribution in the country. Article 61 of Law 812 of 2003 (whose validity was extended by Law 1955 of 2019 and Law 2294 of 2023) identified the agents of the supply chain of petroleum-based liquid fuels.
The distribution of liquid fuels, except LPG, is governed by Decree 1073 of 2015 (as amended), which establishes the requirements, obligations, and penalties applicable to supply agents in the distribution, refining, import, storage, wholesale, transportation, retail sale and consumption of liquid fuels.
Decree 1073 of 2015 establishes the minimum technical requirements for the construction of storage plants and service stations. This Decree also regulates the distribution of liquid fuels, except LPG establishing the minimum requirements for distributors and the activities and types of agreements permitted for these agents. The Ministry of Mines and Energy also regulates the types of liquid fuels that can be sold and purchased and the penalties for noncompliance with governmental regulations. Decree 1310 of 2024 amended Decree 1073 of 2015, including some rules regarding the strategic storage of GLP and liquid fuels in the border areas.
Pursuant to Law 1430 of 2010, modified by Article 220 of Law 1819 of 2016, the distribution of fuels in areas near Colombian borders is the responsibility of the Ministry of Mines and Energy and is subject to specific regulations that impose strong control procedures and requirements. The Ministry of Mines and Energy establishes the safety standards for LPG, storage equipment, maintenance, and distribution of LPG.
Pursuant to Law 2294 of 2023, National Congress approved article 245 to assign the volume of fuels with tax and economic benefits to the final consumers of the municipalities. During the fourth quarter of 2025, the National Government is expected to define the methodology for applying tax benefits and mechanisms to control market saturation in the wholesale and retail distribution segment of liquid petroleum fuels in border areas.
The Superintendence of Public Domestic Utilities also oversees the liquefied petroleum gas transportation business.
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3.10.3.2 |
Regulation Concerning Production and Prices |
According to the Decree - Law 4130 of 2011 and Decree 1260 of 2013, CREG is responsible for setting the prices of petroleum by-products throughout the entire chain of production and distribution, except for gasoline, diesel and biofuels. On the other hand, by Decree 381 of 2012, as amended by Decree 1617 of 2013, and Decree 2881 of 2013, the Ministry of Mines and Energy is in charge of setting the methodology to determine the reference price of gasoline, diesel, biofuels and mixtures thereof.
Since May 2012, CREG sets the prices for most crude oil by-products, except for gasoline, diesel, and biofuels. CREG determines the methodology to calculate their price while the Ministry of Mines and Energy sets the relevant prices in accordance with said methodology. The ANH does not intervene in the definition of prices of gasoline and diesel fuel. In addition, under Resolution 007 of 2017, CREG determined the basis for the methodology of compensation of terrestrial transportation of liquid fuel-oil, including gasoline, diesel and biofuels between the storage plant and the fuel service station.
The methodology for calculating jet fuel prices is set out in Law 1450 of 2011, and jet fuel prices are set by the CREG according to Resolution 40193 of 2021, issued by MME and the Ministry of Finance and Public Credit.
The ANH determines the formula that is used to calculate royalty payments corresponding to the production of crude oil.
Decree 381 of 2012 and 1617 of 2013, as amended by Decree 2881 of 2013, as compiled in Decree 1073 of 2015, restructured the Ministry of Mines and Energy and gave it the responsibility to study industry problems and implement short and long-term refining planning policies. The Ministry is also responsible for establishing the governmental policies and goals to ensure the reliability, stability, and continuity for the production of liquid fuels, biofuels and others.
Pursuant to Article 58 of the Petroleum Code, if there is a fuel shortage, any refining company operating in Colombia must offer to sell a portion or, if needed, the total of its production to supply local demand prior to exporting any production.
Fuel Price Stabilization Fund (FEPC)
The Fuel Price Stabilization Fund was created by Law 1151 of 2007. It is a fund assigned and administered by the Ministry of Finance and Public Credit. Its function is to attenuate, in the domestic market, the impact of fluctuations on fuel prices in international markets.
Article 35 of the National Development Plan 2018-2022 (Law 1955 of 2019) established that the Ministry of Finance and Public Credit and the Ministry of Mines and Energy would define the methodology for calculating the producer’s income value of liquid fuels and biofuels, as well as the rates and margins associated with the remuneration of the entire chain of transportation, logistics, marketing, and distribution of such fuels that are part of the regulated market.
Article 244 of the National Development Plan 2022-2026 (Law 2294 of 2023) amended the aforementioned Article 35, adding that the Ministry of Finance and Public Credit and the Ministry of Mines and Energy may determine differential stabilization mechanisms for the structure of reference prices for the public sale of regulated fuels, considering the principles of efficiency and progressiveness.
According to Article 2.3.4.1.3 of Decree 1068 of 2015, amended by Decree 1451 of 2018, the resources for the functioning of the FEPC come from the following sources: (a) financial returns of resources of the Fund; (b) extraordinary credit resources received from the National Treasury; (c) funds allocated to the FEPC in the national general budget; (d) fuel taxes and; (e) bonds or other public debt securities issued by the Nation in favor of the FEPC, in order to cover the obligations of the Fund.
The operation of the FEPC is governed by Decree 1068 of 2015, amended by Decree 1451 of 2018, Chapter 1, and Title 4 (compilation decree regarding treasury public sector). First, refiners and/or importers of regular gasoline and diesel must report to the Ministry of Mines and Energy the volume of regular gasoline and diesel sold in the previous month and such reports must be made within the next 35 calendar days of each month.
The report must also contain, among other matters: information corresponding to each fuel disaggregated daily; the discrimination of the volumes sold, and the origin national or imported of the gasoline and diesel sold. If regular gasoline or diesel is of national origin, the refiner/importer must inform from which refinery they come. Secondly, the Ministry of Mines and Energy calculates and liquidates, by resolution, the net position of each refiner/importer and each fuel to be stabilized by the FEPC.
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Decree 1068 of 2015, amended by Decree 1451 of 2018, provides that the FEPC will pay in Colombian pesos the value corresponding to the calculation and settlement of the Net Position of each refiner and/or importer within the term defined by the Ministry of Mines and Energy and based on availability of FEPC resources.
Law 1819 of 2016 as amended created a tax, related contribution to finance the FEPC. This contribution is caused when the sum of the Differentials of Participation (difference between the Producer Revenue and the International Parity Price, when the first is greater than the second on the date of issuance of the sales invoice, multiplied by the volume of fuel sold) is greater than the sum of the Differentials of Compensation (the difference presented between the Producer Revenue and the International Parity Price, when the second is greater than the first on the date of issuance of the sales invoice, multiplied by the volume of fuel sold).
The event that generates the contribution is the sale in Colombia of gasoline or diesel by the refiners and/or importers to the wholesale distributor of fuels, according to the price set by the Ministry of Mines and Energy, however, if the importer is at the same time a wholesale distributor, the triggering event shall be the withdrawal of the product to be sold. The taxpayer responsible for the contribution is the refiner and/or importer and the active subject is the Nation. The tax base corresponds to the positive difference between the sum of the Differentials of Participation and the sum of the Differentials of Compensation.
The Ministry of Mines and Energy calculates the contribution through the liquidation of the Net Position of each refiner or importer with respect to the FEPC based on the report that the refiners and/or importers submit. If the sum of the Differentials of Participation is greater than the sum of the Differentials of Compensation and the contribution is caused, the Ministry of Mines and Energy will order the refiner or the importer to pay the contribution to the National Treasury within the 30 days following the execution of the liquidation resolution.
Subsequently, Law 1837 of 2017 (Article 16) provided that the remaining resources that were in our accounts as of December 2014, as a result of the collection of the Differential Contribution from the FEPC, would be transferred to the General Direction of Public Credit and Treasury of the Ministry of Finance and Public Credit (DGCPTN for its acronym in Spanish). In addition, Law 1955 of 2019 (Article 33) authorizes the Ministry of Finance and Public Credit to enter into hedging agreements and establishes the conditions thereof, for purposes of guaranteeing the sustainability and the functioning of the FEPC. Law 1955 of 2019 authorizes the Ministry of Finance and Public Credit, as administrator of the FEPC, among others, to carry out, directly or indirectly, the design, management, acquisition and/or execution of hedges on the Ministry of Finance’s direct exposure to (i) crude oil and liquid fuel oils prices in the international market or (ii) the exchange rate of the Colombian Peso. This law also authorizes the Ministry of Finance to set stabilization mechanisms of the reference recommended retail prices of regulated fuel oil, as well as the subsidies to such regulated fuel oils to be executed through the FEPC. Law 2342 of 2023, which sets forth the 2024 national general budget, gave the MHCP the ability to utilize different budgetary tools to address the debts relating to the FEPC, and to even to set-off these debts against dividends that it would be entitled to receive from Ecopetrol as its major shareholder.
On May 31, 2022, we reached an agreement with the MHCP for the payment and compensation of the COP 14.2 trillion account receivable due to us from the FEPC as of the first quarter of 2022. The accrued FEPC subsidy for the second quarter of 2022 due to us amounts to COP 10.6 trillion, which, by virtue of the provisions of the Government’s Medium-Term Fiscal Framework, are expected to be partially paid from fiscal surpluses during 2022 or with resources approved by Congress as part of the 2023 Budget for such purpose.
Resolution 1071 of 2022 establishes the amount due by FEPC to Ecopetrol S.A for the first quarter of 2022, which has been determined to be equal to COP 11,428,163,784,638.38 pesos. Resolution 00608 of 2023 establishes the amount due by FEPC to Ecopetrol S.A for the second quarter of 2022, which has been determined to be equal to COP 8,368,631,424,061.11. Resolution 01029 of 2023 establishes the amount due by FEPC to Ecopetrol S.A for the third quarter of 2022, which has been determined to be equal to an COP 8,047,275,278,508.68. Resolution 01585 of 2023 establishes the amount due to by FEPC to Ecopetrol S.A for the fourth quarter of 2022, which has been determined to be equal to COP 8,036,420,988,549.93.
As of December 31, 2023, Ecopetrol S.A. recorded COP 16.4 trillion in accounts receivable due from FEPC and Cartagena Refinery recorded COP 4.1 trillion in accounts receivable due from FEPC.
On April 1, 2024, the Ministry of Mines and Energy settled its net position corresponding to the first quarter of 2023 in favor of (i) Ecopetrol S.A., for an amount of COP 6,305,038,090,159.81, by means of Resolution 00297, and (ii) Refinería de Cartagena S.A.S., for an amount of COP 1,534,914,852,627.40, by means of Resolution 00296. See section Financial Review—Factors Affecting Our Operating Results—Fuel Price Stabilization Fund (FEPC) .
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On June 8, 2024, the Ministry of Mines and Energy settled its net position corresponding to the second quarter of 2023 in favor of (i) Ecopetrol S.A., for an amount of COP 4,109,054,714,024.82, by means of Resolution 0540, and (ii) Refinería de Cartagena S.A.S., for an amount of COP 1,008,291,095,755.84, by means of Resolution 00541.
On September 10, 2024, the Ministry of Mines and Energy settled its net position corresponding to the third quarter of 2023 in favor of (i) Ecopetrol S.A., for an amount of COP 3,749,512,065,086.77, by means of Resolution 01012, and (ii) Refinería de Cartagena S.A.S., for an amount of COP 965,950,525,099.75, by means of Resolution 01011.
On November 15, 2024, the Ministry of Mines and Energy settled its net position corresponding to the fourth quarter of 2023 in favor of (i) Ecopetrol S.A., for an amount of COP 2,286,216,138,799.36, by means of Resolution 01507, and (ii) Refinería de Cartagena S.A.S., for an amount of COP 555,059,027,840.35, by means of Resolution 01508.
On June 18, 2024, the MHCP issued Decree 0763, establishing that the income for fossil fuel producers of regular motor gasoline and ACPM-Diesel acquired by (i) agents authorized as large consumers; or (ii) those final consumers with an average annual consumption exceeding 20,000 gallons per month, regardless of their consumption per facility or delivery point, must be at least the international parity price. This means that the fuel acquired by these entities will not be stabilized or subsidized by the FEPC.
Resolution 40304 of August 2, 2024, established the procedure for determining the international parity price to be used as producer income within the price stabilization differential mechanism. It is the obligation of the refining or importing agent to calculate the producer income, publish it on their official website, and communicate it to their wholesale distributor clients and maritime service stations. Subsequently, wholesale distributors must communicate the resulting prices to retail distributors acting as industrial marketers, who, in turn, must communicate them to their large consumer and final consumer clients subject to the differential mechanism.
Resolution 40305 of August 2, 2024, established that, twice a year, the MME will publish on the SICOM platform and its website a list of large consumers and final consumers to whom the price stabilization differential mechanism applies. To determine inclusion on this list, the MME will use data on the volume of liquid fuels dispatched by refining agents, importers, wholesale distributors, and retail distributors acting as industrial marketers or maritime service stations over the last twelve (12) months as of each cutoff date.
On March 28, 2025, the Ministry of Mines and Energy settled its net position corresponding to the first quarter of 2024 in favor of (i) Ecopetrol S.A., for an amount of COP 1,727,183,344,199.28 by means of Resolution 299, and (ii) Refinería de Cartagena S.A.S., for an amount of COP 501,867,931,397.22 by means of Resolution 300.
Payments received from FEPC in 2024 and 2025 are made in cash or through Colombian Government treasury securities, which remain in Ecopetrol’s treasury until they are sold.
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3.10.3.3 |
Regulation of Biofuels, Biogas and Related Activities |
The sale and distribution of biofuels and biogas is regulated by the Ministry of Mines and Energy. Regulations establish the quality and pricing standards for biofuels and impose minimum requirements for mixing ethanol with gasoline and biodiesel with diesel. Resolution 40447 of October 31, 2022, amended by Resolution 40391 of 2023 and 40431 of 2024, orders retail distributors, such as fuel service stations, and wholesale or large distributors of fuel, to only commercialize blended fuels with a specific percentage of biofuel or fuel alcohol per gallon, depending on the month and year of the commercialization.
The sale and distribution of biogas is provided under CREG Resolution 240 of 2016, which particularly regulates: a) the sorts of market that will be served with biogas and biomethane; b) the quality and safety conditions; and c) the tariff regime. Pursuant to Article 4 of the foregoing Resolution, biogas supply through isolated networks to serve non-regulated users and natural gas vehicles (GNV as per its acronym in Spanish), shall be incorporated as a public utility company. Furthermore, Article 5 provides that biomethane supply through isolated networks or interconnected networks to the National Transportation System shall also be incorporated as a public utility company. Finally, Article 12 states that biogas suppliers may develop the production, transportation, distribution, and commercialization activities through integrated structures, provided that they keep separate accounts for each activity and grant free access to the networks to both regulated and non-regulated users. To the same extent, production, distribution, and commercialization of biomethane through interconnected networks to the National Transportation System may be developed through integrated structures, as long as the supplier keeps separate accounts for each activity and grants free access to the networks to both regulated and non-regulated users.
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In May 2023, the National Congress approved National Development Plan 2022-2026 through Law 2294 of 2023. In connection with biofuels, biogas and related activities provides that the Ministry of Agriculture and Rural Development, the MADS and the MME regulate the proportion of biofuels present in the mix of liquid fuels, due to the relationship between biofuels and the agricultural sector. It also established the framework to intervene in the FEPC regulation prices methodology as well as regulation related to strategic storage of fuels, biofuels, LPG and others.
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3.10.4 |
Regulation of the Natural Gas Market |
Decree 1073 of 2015, Part 2, Title 2, Chapter 2, modified by Decree 1467 of 2024, established that all producers have to issue a production statement that includes the volumes of natural gas available for sale for a period of ten years. This decree established the regime for the selling and marketing of natural gas in Colombia, including specific procedures that regulate the Colombian market in order to manage the remaining natural gas reserves owned by the Nation, and to protect domestic consumers, especially residential consumers, by prioritizing delivery of gas to residential consumers, regulating the export of natural gas and setting forth the export restrictions applicable during an internal shortage of natural gas.
Currently in Colombia the price of natural gas is determined freely by the market. CREG issued Resolutions 185 (for transportation) and 186 (for supply) of 2020, which jointly replaced Resolution 114 of 2017 and its amendments (Resolutions 102 009 and 102 013 of 2024 with some temporary measures), related to commercial aspects of the wholesale natural gas market in Colombia.
Resolution 102009 of 2024 issued by the CREG, introduces key modifications to Resolution CREG 186 of 2020. Among others, it (i) established the possibility for parties to agree specific firm supply contract conditions for natural gas produced in fields that have not reached commercial viability; (ii) included specific default grounds for imported natural gas firm supply contracts for special protection demand (public utility demand); (iii) included new regulations for C1 and C2 contracts, defining fixed and variable percentages and execution conditions; (iv) added new obligatory grounds for exemption from liability in firm supply contracts (national supply and importation); and (v) update the publication and transparency obligations of the market agents regarding the declared and available natural gas offer quantities,
Pursuant to Decree 1073 of 2015 and article 19 Resolution CREG 186 of 2020, the commercialization procedures do not apply to the following activities: a) natural gas exports; b) natural gas as raw material in petrochemical production; c) natural gas commercialization from minor fields (production capacity under 30 million SCFD); d) natural gas commercialization from hydrocarbon fields under testing phase or which have not yet been declared commercially viable; e) natural gas commercialization from unconventional reservoirs; and f) internal consumption from natural gas producers. In 2024, Colombia faced a potential natural gas deficit due to several factors, including the El Niño phenomenon (which significantly increased demand for natural gas for thermal energy production), a decline in natural gas reserves, and a reduction in exploration contracts. These circumstances culminated in the issuance of MME Resolution 40444 of 2024, declaring a scheduled natural gas rationing. In response, the Energy and Gas Regulatory Commission (CREG) issued Resolutions 102 007 and 102 009 of 2024, aimed at adjusting natural gas commercialization rules to enhance efficiency in the allocation and distribution of natural gas. CREG Resolution 102 007 of 2024 introduced temporary measures, while CREG Resolution 102 009 of 2024 established more permanent regulations. Notably, CREG Resolution 102 009 of 2024: (i) introduces greater flexibility for negotiations in the primary market to maximize the contracting and utilization of natural gas volumes produced at maximum levels in national fields at the most efficient price, (ii) improves primary market contracting conditions to reduce purchasing surpluses, (iii) establishes mechanisms to prioritize the satisfaction of essential demand by primary market sellers, (iv) aligns commercialization regulations with the provisions of Presidential Decree 484 of 2024 (regarding exceptions to the commercialization mechanisms established by CREG), and (v) facilitates the negotiation of gas volumes that may require importation.
CREG determines which agents can participate in the primary and secondary markets. We are authorized to participate as a seller in the primary market as a natural gas producer and as a buyer to acquire natural gas for our operation. We can also participate in the secondary market when we require natural gas from other producers for our own needs. CREG regulations provide that a natural gas producer cannot participate as a merchant of natural gas in the secondary market, except for the purchase of gas to meet its existing contractual obligations. We are also able to resell available natural gas transportation capacity into the secondary market as a non-regulated consumer.
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On February 16, 2023, President Gustavo Petro issued Presidential Decree 227 of 2023 by means of which he “reassumed” (as stated in such Presidential Decree) the powers to regulate the natural gas market that were delegated to the CREG, in accordance with article 68 of Law 142 of 1994. Nonetheless, Presidential Decree 227 of 2023 was suspended by the High Court for Administrative Matters ( Consejo de Estado ) via writ 00045 of 2023, in response to an annulment action filed before said organism. On July 7, 2023, the High Court for Administrative Matters ( Consejo de Estado ) confirmed the initial decision to suspend the aforementioned Presidential Decree after the appeal presented by the National Government. As of the date of this annual report, Presidential Decree 227 of 2023 is suspended until the High Court for Administrative Matters ( Consejo de Estado ) issues a final decision on the annulment action.
Decree 1467 of December 10, 2024 amended Decree 1073 of 2015 to adopt public policy measures aimed at enabling offshore natural gas sources and natural gas imports. Among these measures Decree 1467: (i) regulated the priority in the supply of natural gas; (ii) established that producers must declare their disaggregated production on a monthly and long-term basis, and import gas marketers must declare the quantities available for sale during the year; (iii) set forth certain exceptions to commercialization mechanisms; and (iv) regulated commercialization mechanisms for firm contracts subject to certain conditions.
Priority for the Supply of Natural Gas
The export of natural gas, in contrast, is not considered a public utility activity under Colombian law and therefore is not subject to Law 142 of 1994. Nevertheless, the domestic supply of natural gas is a priority for the Colombian Government and therefore, extends such priority and commitment to all agents working within the natural gas market (producers, producers-retailors, retailors, transporting and exporting agents - article 2.2.2.2.15 of Decree 1073 of 2015) and is considered a public utility complementary activity, and therefore public utility regulations apply to the internal supply of natural gas.
Decree 1073 of 2015 (amended by Decree 2345 of 2015) provides that in the event the supply of natural gas is reduced or halted as a result of a shortage, the Colombian Government has the right to suspend the supply of natural gas for export. If such export contracts are suspended by the Colombian Government, the export agents are entitled to receive compensation in accordance with Article 2.2.2.2.15 and 2.2.2.2.38 of Decree 1073, 2015. Notwithstanding the foregoing, Decree 1073 of 2015 establishes freedom to export natural gas under normal gas-reserve conditions. Producers of natural gas may enter into natural gas export contracts if the ratio of proved reserves to consumption exceeds seven years, as determined by the Colombian Energy Planning Authority (or UPME for its acronym in Spanish).
Decree 1073 of 2015 (amended by Decree 1467 of 2024) establishes a mandatory order of supply when restrictions are placed on the supply of natural gas or serious emergency situations arise that preclude the continued provision of certain services, as follows: (i) essential demand, as established in Decree 1073 of 2015, (ii) non-essential demand under an existing firm agreement, and (iii) firm exports delivery.
The order of priority for the supply of natural gas is as follows: (i) the operation of the compressor stations of the National Transportation System, (ii) residential users and small business users engaged in the distribution network, (iii) vehicular compressed natural gas and (iv) gas refineries, excluding those destined for self-generation of electricity that can be replaced with energy from National Transportation System, which has priority. The Ministry of Mines and Energy also establishes distribution priorities in the event of a natural gas shortfall derived from supply or infrastructure issues. This order of priority is based on the type of contract, with firm supply contracts having priority over interruptible supply contracts.
Natural gas waste restrictions
The Ministry of Mines and Energy issued Resolution 40066 of 2022 as amended by Resolution 40317 of 2023 by means of which it regulates the use of natural gas, establishing the obligation for hydrocarbon producers to carry out the necessary studies for its efficient use. It also establishes that natural gas waste is prohibited in Colombia and provides certain examples of what it considers could constitute natural gas waste during hydrocarbon exploration and exploitation activities.
The Resolution establishes the scenarios in which burning and venting of gas is allowed in the stages of exploration and exploitation of hydrocarbons, as well as the technical parameters to efficiently and responsibly execute these activities, when expressly authorized. This Resolution also sets standards for natural gas leaks detection, quantification, repair, and control in respect of the activities performed on natural gas exploration and exploitation fields. This Resolution regulates the detection and repair programs to prevent leaks, the elements included therein, as well as the reports that must be delivered to Colombian authorities.
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For the Company’s progress in complying with this Resolution, see section Risk Review—Legal and Regulatory Risks—Our operations might be affected by rising climate change and energy transition regulatory developments .
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3.10.5 |
Regulation of the Electric Energy Commercialization Activity |
As determined by article 11 of Law 143 of 1994, commercialization activities, which are developed by commercialization agents, consist of the purchase of electricity in the MEM and the subsequent resale to other participants of the wholesale market such as commercialization agents, generation agents, or to end-customers, both regulated and non-regulated. Ecopetrol Energía S.A.S E.S.P. (“Ecopetrol Energía”), a subsidiary of Ecopetrol S.A., was registered as a commercialization agent before the manager of the commercial exchanges systems and performs commercialization activities within the MEM. However, explained below, Ecopetrol Energía faced winding up procedures due to a possible interpretation of competition rules which could prohibit Ecopetrol’s participation in other complementary activities of the energy sector other than transmission, due to its acquisition of ISA Intercolombia S.A. E.S.P. (ISA) in 2021.
Commercialization activity is regulated by CREG Resolution 156 of 2011, which establishes regulations, rights and duties of agents. The main income of commercialization agents is derived from the variable and fixed components of the unit cost tariff formula described in CREG Resolution 119 of 2007, as modified by CREG Resolutions 156 of 2009, 173 of 2011, 191 of 2014, 30 of 2018, 101-03 of 2022, 101-18 of 2022, and 101-28 of 2023. The variable component considers:
| ● | the costs of commercialization services, as determined by article 12 of CREG Resolution 180 of 2014, |
| ● | the amount that these agents must pay to the manager of the commercial exchanges system, calculated by the Trade Exchange System Administrator (“ASIC,” for its acronym in Spanish) based on the mathematic methodology set forth by CREG Resolution 174 of 2013 (as modified by CREG Resolutions 175 of 2016 and 100 of 2015) and which is paid monthly, |
| ● | the amount that these agents must pay to the Public Utilities Superintendence and to CREG, which is defined every year by CREG following the rules set in article 85 of Law 142 of 1994. These payments must be made each year, |
| ● | the cost of the guarantees that the agent must provide to participate in the MEM by following the rules of CREG Resolution 024 of 1995 (as modified, among others, by CREG Resolutions 116 of 1998, 068 of 1999, 066 of 2000, 019 of 2006, 089 of 2009, 011 of 2010, 038 of 2010, 073 of 2010, 157 of 2011, 110 of 2014, 184 of 2015, 060 of 2019, 044 of 2020, 031 of 2021, 101-028 of 2022, 101-12 of 2023, 101-18 of 2023, 101 040 of 2024 and 101 051 of 2024), this shall be calculated considering article 19 of CREG Resolution 180 of 2014, |
| ● | the total sales to users of the commercialization agent, regulated and non-regulated, and |
| ● | regarding the markets that commercialization agents attend, Law 143 of 1994 divides the market into two segments: regulated market (“Regulated Market”) and the non-regulated market (“Non-Regulated Market”). |
The Regulated Market is comprised of individual and industrial customers, residential or commercial, with electricity demands below 0.10 MW or monthly consumption lower than 55 megawatt-hours (“MWh”). Regulated Customers are free to select any service provider. However, tariffs are subject to a regulated freedom of choice regime, whereby commercialization agents are required to follow the criteria and methodology set forth by the CREG, which establishes the parameters that must be used by electric energy agents in setting forth the maximum applicable charges for the services they provide. Purchases of electricity in the Regulated Market are made through public bids in order to ensure open and free access; however, during 2024, due to the impact of the “El Niño” phenomenon, CREG issued CREG Resolution 101 057 of 2024 implementing a transitory rule. The transition consisted of contracts with a maximum performance term until December 31, 2025. Under this provision, retail agents serving the demand of regulated users were authorized to execute contracts under the pay-as-contracted modality directly, without the requirement to conduct an auction.
The Non-Regulated Market is comprised of electricity consumers that either have a peak demand greater than 0.10 MW or a minimum monthly consumption greater than 55.0 MWh. This segment is attended by companies carrying out the generation and commercialization activities. Purchases of electricity in this segment can be freely agreed among participants at freely negotiated prices for the commercialization and generation components of the tariff’s unitary price.
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Resolution CREG 015 of 2018 establishes the obligations for Network Operators (owner of the physical networks) and commercialization agents for the transportation and distribution of energy. It also regulates the quality standards for the delivery of energy at the point of consumption, and the applicable methodology for calculating the distribution charges of each Network Operator.
As determined by article 74 of Law 143 of 1994, as modified by article 298 of Law 1955 of 2019, any utility company that makes part of the SIN can generate electricity (which consists of the production of electricity through any generation plant connected to the National Interconnected System (SIN as for its acronym in Spanish), activity performed by generation agents, who participate in the MEM by selling electric energy to other generation and commercialization agents, or to Non-Regulated Users), distribution (which consists of transporting and delivering electric energy to end users through the STR, and the Local Distribution Systems (SDL for its acronym in Spanish) deploying tension levels under 220 kV; agents in charge of providing the distribution utility are called Distribution Agents or Grid Operators (OR for its acronym in Spanish)), and commercialization activities in an integrated manner. Nevertheless, these companies are not allowed to perform transmission activities, as it will be explained below.
This provision described above, also applies to companies having the same controlling party or between those where there is a situation of control, which encompasses the real beneficiary rationale applicable under Colombian electric energy regulation (for reference see article 74 of 1994, as amended by Law 1955 of 2019. A situation of control is defined by article 260 of the Code of Commerce, as follows: “ a company will be subordinated or under a situation of control when its decision-making power is subject to the will of another or other persons who will be deemed its parent or controlling company (…) ”. On the other hand, transmission companies are prevented by law from holding market shares in generation, commercialization, or distribution companies (see CREG Resolution 001 of 2006).
In relation with transmission, (which comprises the transportation of electrical energy in the Colombian National Transmission System (STN for its acronym in Spanish), deploying tension levels of 220 kV or higher, guaranteeing the required quality standards and the availability of the transmission assets; the owners of the transmission assets must ensure free access to the transmission networks to the users and to generation agents.) companies carrying out this activity are not able to perform commercialization, distribution or generation activities. However, commercialization, distribution and generation companies are allowed to hold shares, quotas, or equity stakes of transmission companies, as long as they represent no more than 15% of the company’s capital. Please note that, in this case, neither the transmission company nor the other companies may have a control situation over the other.
Exceptionally, commercialization, distribution and generation companies may own more than 15% of a transmission company if the income of the transmission company does not represent more than 2% of the total transmission income from the SIN. If the company engaged in the transmission activity, with a cut-off date of December 31 of each year, exceeds this limit, the commercialization, generation, or distribution company who has shares, quotas or interest shares in the capital of the company must sell, within six months following the occurrence of this fact, the shares, quotas or interest shares that exceed 15% of the capital stock of the transmission company. This, unless within the same period, the transmission company sells the assets that makes it exceed the 2% limit of the total income. (see CREG Resolution 95 of 2007).
As presented above, Ecopetrol Energía and, since August 2021, ISA, were subsidiaries of Ecopetrol S.A. Ecopetrol Energía was a commercialization company and ISA has a significant percentage of the market share of the national transmission activity. Therefore, and considering the competition rules mentioned above, the CREG established that we shall divest from Ecopetrol Energía or cease any commercialization activity as soon as reasonably practicable.
Accordingly, on August 15, 2022, we entered into an electric energy commercialization agreement with Gecelca S.A. E.S.P. to meet the non-regulated energy demand of the Ecopetrol Group. The contract, which term extends until December 31, 2036, is to ensure a service structure for the supply of electric energy through the SIN for the Ecopetrol Group in order to provide the necessary coverage while optimizing costs. Gecelca S.A. E.S.P. was selected through a competitive process to which 17 agents among generators and retailers of the Wholesale Energy Market were invited.
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Law 142 and 143 establish specific rules that apply to ISA regarding its participation in certain activities. Articles 167 of Law 142 and 32 of Law 143 establish that ISA is not allowed to participate in any generation, commercialization, or distribution activity. However, the National Development Plan issued by Law 2294 of May 2023, removed these specific restrictions to ISA. The Constitutional Court admitted a lawsuit against this provision and its final decision is pending. In any case, limitations set forth by article 74 of Law 142 of 1994 described above, may prevent Ecopetrol or any of its subsidiaries from carrying out generation, commercialization, or distribution activities.
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3.10.6 |
Regulation of the Electricity Self-Generation Activity |
Law 1715 of 2014 (amended by Law 2099 of 2021) regulates the integration of non-conventional and renewable energies to the SIN. Among other aspects, this law obliges the Colombian Government and the CREG to develop the regulatory framework for the promotion of the electricity self-generating activity from non-conventional renewable energy sources and the sale of self-generation surpluses.
The self-generation activity is defined as the activity carried out by either persons or legal entities to produce electricity mainly to meet their own needs. In case that there is a surplus of energy, not consumed by the self-generator, such surplus may be delivered to the grid on the terms established by the CREG (See CREG Resolutions 024 of 2015 and 174 of 2021, which application depends on whether the self-generator is a large-scale or a small-scale self-generator, as explained below).
Based on Law 1715 of 2014, Decree 2469 of 2014, as compiled by Section 4 of Decree 1073 of 2015, which established energy policy guidelines regarding the delivery of self-generation surpluses through the SIN. In addition, this decree sets forth the parameters for a person to be considered as an electricity self-generator. Specifically, it states that in order to be considered a self-generator a person must (a) receive electricity for its consumption without it being necessary to use assets of the SIN, (b) the electricity surpluses may be higher in any measure, and without any regulatory limit or restrictions, than the value of its own consumption, (c) for the delivery of surpluses to the SIN it will be necessary for the self-generator to submit itself to the regulation of the CREG, case in which large-scale self-generators must be represented before the wholesale energy market, and (d) the generation assets may be owned by the self-generator and may be owned and operated by third parties.
Decree 348 of 2017, as currently compiled by Section 4A of Decree 1073 of 2015, establishes public policy guidelines on efficient energy management and delivery of small-scale electricity self-generation surpluses. In addition, this regulation establishes the conditions for the connection of small-scale self-generators (AGPE for its acronym in Spanish) to the SIN, the parameters to be an AGPE, the reporting of surpluses to the UPME and the remuneration of surplus energy. Note that, as determined by Resolution UPME 281 of 2015, the maximum electricity generation limit to be considered an AGPE is one (1) MW and will correspond to the installed capacity of the self-generator’s generation system. Above that limit, an electricity self-generator will be considered a big-scale electricity self-generator (“AGGE” as per its acronym in Spanish).
The specific regulation for AGGE is currently determined by CREG Resolution 024 of 2015, whereas the specific regulation for AGPE is currently set by CREG Resolution 174 of 2021.
CREG Resolution 024 of 2015 (modified by CREG Resolution 140 of 2017) sets conditions for surplus sales of an AGGE, connection and metering conditions, and back-up and energy supply conditions. Specifically, this resolution determines that AGGE must follow the general connection rules to the SIN for a generation plant, that they must have a remote telemetry system, and that they must have a back-up power purchase agreement, among others.
CREG Resolution 174 of 2021 establishes the connection conditions for AGPE, and for the AGGE with a capacity under 5 MW surplus sales conditions, metering conditions and energy commercialization rules for AGPE.
The Ecopetrol Group has invested in several projects that are considered projects from AGGE, which means that CREG Resolution 024 of 2015 is the main regulation that applies to our self-generation projects, notwithstanding the rules applicable pursuant CREG Resolution 174 of 2021. As of the date of this annual report, we comply with all regulations, as set forth in the above-mentioned resolution and Decree 2469 of 2014 regarding the delivering of electricity surpluses to the SIN and to its subsidiaries or controlled parties.
In July 2021, Congress issued Law 2099 of 2021, modified by Law 2294 of 2023. These pieces of legislation regulate aspects related to energy transition and updated provisions with respect to the development and promotion of unconventional sources of energy, energy efficiency and clean hydrogen.
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Listed below are certain relevant aspects of Law 2099 of 2021 as amended:
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(i) |
the new law brought amendments to Law 1715 of 2014 on the declaration of public and social interest, which consists in the promotion, stimulation and incentive to the development of generation activities, use, storage, administration, operation and maintenance of non-conventional energy sources, mainly those of renewable sources (“FNCER” for its acronym in Spanish). The qualification of public utility or social interest will have positive impacts in such projects and grant them preference rights in issues related to land use, planning and environmental planning, economic promotion, positive valuation in administrative procedures and forced expropriation. The new regulation includes those projects related to storage within those that can be part of the declaration of public and social interest, which is a nod to the development of such projects for the purposes of energy efficiency and energy transition; |
|
(ii) |
green hydrogen was added as a FNCER and blue hydrogen as FNCE. Green hydrogen is that produced from FNCER such as biomass, wind energy, geothermic energy, solar energy, tidal energy and small hydropower. Nevertheless, Law 2294 of 2023 establishes that green hydrogen can be produced by energy coming from the SIN. On the other hand, blue hydrogen is produced from fossil fuels, especially by the decomposition of methane and its production process has a system of carbon capture, use and storage. Finally, white hydrogen was added as a FNCER through Law 2294 of 2023. White hydrogen is “ associated with geological processes in the earth’s crust and found in its natural form as free gas in different geological environments either in layers of the continental crust, in the oceanic crust, in volcanic gases, and in hydrothermal systems, such as geysers” (definition introduced by Law 2294 of 2023); |
|
(iii) |
the Ministry of Mines and Energy, or the entity designated by it, was appointed as the entity to establish guidelines for the development of geothermal energy in Colombia and must create a geothermal registry in which all projects intended to explore and exploit geothermal energy to generate electricity will be registered. The Ministry of Mines and Energy may establish special registration conditions for already existing projects of co-production of electric energy and hydrocarbons, in order to avoid the overlapping of projects, define the areas that will not be subject to registration and determine conditions, terms, requirements and obligations; |
|
(iv) |
the law states that the Colombian Government will develop the necessary regulations for the promotion and development of carbon capture, use and storage systems (CCUS) technologies. CCUS should be understood as the set of technological processes the purpose of which is to reduce carbon emissions in the atmosphere, capturing the CO 2 generated on a large scale from fixed sources to store it under earth in a safe and permanent manner. Under the same logic, the Colombian Government will design a public policy to promote research and local development of technologies for the production, storage, conditioning, distribution, reelectrification, energy and non-energy uses of hydrogen and other low-emission technologies within six months after the entry into force of this law. Furthermore, the Ministry of Mines and Energy will promote the reconversion of mining and hydrocarbon projects that contribute to the energy transition. For this purpose, the ANH and the National Mining Agency may design mechanisms and agree on conditions in current and future contracts that encourage the generation of energy through FNCE, the use of alternative energy sources, and the capture, storage and use of carbon; |
|
(v) |
the policy for the development of electric energy services in the so-called non-interconnected zones is strengthened through: (i) service reliability, (ii) transfer of resources for lower tariffs, (iii) transfer of assets, and (iv) hybrid solutions. |
In July 2022, the Colombian Government published Decree 1318 of 2022 setting out the general terms and definitions of exploration and production of electric energy from geothermal activities. The provisions of this decree were further developed through CREG Resolution 40302 of 2022. Decree 1598 of 2024, issued by the Colombian MME, amends Decree 1073 of 2015 to establish a regulatory framework aimed at fostering the exploration and utilization of geothermal energy. This initiative is part of Colombia’s broader energy transition strategy to diversify its energy matrix and promote non-conventional renewable energy sources (FNCER), including geothermal energy.
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In August 2022 the Colombian Government issued Decree 1476 of 2022 regulating articles 21 and 23 of Law 2099 of 2021 and adding a new chapter to promote innovation, research, production, storage, distribution and use of low-emission hydrogen. Decree 1598 of 2024, issued by the MME, amends Decree 1073 of 2015 to establish a regulatory framework aimed at fostering the exploration and utilization of geothermal energy. This initiative is part of Colombia’s broader energy transition strategy to diversify its energy matrix and promote non-conventional renewable energy sources (FNCER), including geothermal energy. Among others: (i) it introduced a system to certify the origin of hydrogen, ensuring traceability for both domestic consumption and export markets; (ii) enhanced the Ecosystem H2 Colombia, a national information system to promote and manage the hydrogen value chain and (iii) set forth several regulations regarding Colombia’s commitment to achieve carbon neutrality in 2050 by incentivizing the production and use of low-emission hydrogen.
By means of Resolution MME 40284 of 2022, as amended by Resolution MME 40712 of 2023 and further updated by Resolution MME 40368 of 2024, the Ministry of Mines and Energy established the general terms for granting temporary occupation permits for maritime areas, as well as the granting of maritime concessions intended for the development of offshore wind energy projects. These permits will be awarded through a competitive process to be carried out by the ANH, which began on December 4, 2023. During 2024, the prequalification process was initiated for the first round, qualifying companies such as Parque Eolico Offshore Vientos Alisios SAS ESP, CI GMF III COOPERATIEF UA, JAN DE NUL NV, Ecopetrol SA, Powerchina International Group Limited, CTG Colombia Holding SAS, Duna Energy Latinmerica, Seynekun ESG Solutions SAS, Enterprize Energy (UK Limited), Celsia Colombia SA ESP and DEME Concessions Wind. The successful bidders must form a consortium, temporary association or partnership with a public or mixed company of the oil gas or energy sector (first paragraph of article 18 of MME Resolution 40284 of 2022 as amended by MME Resolution 40368 of 2024).
In November 2024, the MME issued Decree 1403 titled Amending Decree 1073 of 2015 on Energy Policy Guidelines for Self-Generation and Marginal Production of Electricity. This decree allows self-generators and marginal producers to utilize the National Interconnected System (SIN) to consume electricity at locations different from where it is produced, eliminating previous regulatory barriers. These changes aim to foster the use of non-conventional renewable energy sources, supporting Colombia’s transition to a more sustainable energy landscape. For companies engaged in self-generation and potentially entering into distributed marginal production (such as Ecopetrol), Decree 1403 presents significant opportunities to expand operations and optimize energy distribution across various locations, aligning with the country’s commitment to renewable energy integration.
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3.10.7 |
Regulatory Framework for Energy Transmission |
In the countries in which ISA operates, energy transport is a regulated and independent activity within the electricity sector’s production chain and is considered a natural monopoly, although there are different business models in the electricity industry in those countries. In particular, in Colombia and Chile, the transmission companies own the assets and infrastructure. In Peru and Brazil, companies obtain concessions to operate assets and infrastructure and revert ownership to governments once the concessions expire. In each of those models, the companies must provide the service with the quality standards defined by the regulation and, by virtue of this, receive the corresponding remuneration. The revenues are not affected by the supply and demand for electricity or the volume of electricity actually consumed by the end users.
In general, the revenues of transmission companies are comprised of two components: the first remunerates the investment at a regulated revenue, while the second remunerates the administration, operation and maintenance expenses required to provide the service with quality and efficiency. The revenues are adjusted on an annual, semiannual or monthly basis, based on inflation, as measured by the relevant consumer and producer price indexes or in some cases by the PPI or the WPI.
Colombia
Electricity transmission is defined by article 1 of CREG Resolution 24 of 1995 and article 3 of CREG Resolution 11 of 2009, applicable CREG regulations, as the transportation of electricity through national electricity transmission systems at a tension level equal to or greater than 220 kV and is remunerated through usage charges for constructive units that comprise the National Transmission System (STN).
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Colombian regulations establish the responsibility of the State, through Mining and Energy Planning Unit (UPME), to prepare the Reference Generation Transmission Expansion Plan. The projects proposed in the STN expansion plans must be technically and economically feasible and must have the approval of the relevant environmental authorities mentioned above. The STN expansion procedure, as provided in applicable regulations including CREG Resolution 022 of 2001, guarantees a competitive bidding process summoned by UPME with respect to the construction, operation and maintenance of new electricity transmission expansion projects.
Pursuant to number IV of section a of article 4 of Resolution CREG 22 of 2001, ISA must present a proposal to participate in every bidding process summoned by UPME. Such bidding processes are awarded to the investor or bidder who offers the lowest present value to be received as expected annual income (IAE) for a period of 25 years. Once the 25-year payment period elapses, the successful bidder is expected to be compensated through the regulated revenue tariff methodology established by Resolution CREG 011 of 2009 (or the transmission activity methodology that is in effect at that time), for agents who operate existing transmission assets.
The remuneration applicable to existing assets is regulated by CREG Resolution 011 of 2009 by means of a regulated revenue tariff methodology, which establishes usage charges for constructive units, taking into account the reposition value; the administration, operation and maintenance costs; and some asset availability and quality indexes. Thus, the quality of the transmission service is defined according to asset availability and Energy Not Supplied (ENS). Transmission companies may be liable for deductions from their regulated revenue, when they are unable to provide a good service.
In September 2022, the CREG, through Resolutions 101 027 and 101 031, adjusted the indexation scheme for income established in Resolution 011 of 2009. This adjustment was proposed for a transition period of one year and has been voluntarily adopted by companies. The transition period began in November 2022 and ended in October 2023.
On February 16, 2023, President Gustavo Petro issued Presidential Decree 227 of 2023 by means of which he “reassumed” (as stated in such Presidential Decree) the powers to regulate the energy market that were delegated to the CREG, in accordance with article 68 of Law 142 of 1994. Nonetheless, as of the date of this annual report, Presidential Decree 227 of 2023 has been suspended by the High Court for Administrative Matters ( Consejo de Estado ). For a more detailed description and status of such Presidential Decree, see section Regulation of the Natural Gas Market .
Brazil
The public electricity transmission service of the SIN comprises the facilities of the Basic Grid (“RB”), Other Transmission Installations and International Interconnection Installations. In accordance with Regulatory Resolution No. 67 of July 8, 2004, the RB comprises the SIN facilities with voltage level equal to or higher than 230 kV, while the RBF comprises the SIN power transformer units with voltage level higher than or equal to 230 kV on the high voltage side and lower than or equal to 230 kV on the low voltage side. Transmission services are operated exclusively through concessions, in which the Brazilian government grants private agents, through bids, the right to build, operate and maintain the facilities.
The planning for the sector is centralized and conducted by Energy Research Company and National Electric System Operator, which, with the support of the other agents of the sector, evaluate the need for expansion or reinforcement of the transmission system, identifying the necessary works that will be indicated to the Brazilian Ministry of Mines and Energy to compose the concession plan that National Electric Energy Agency ( Agencia Nacional de Energía Eléctrica or “ANEEL”) intends to use to issue reinforcement authorizations or bidding notices. It is ANEEL’s responsibility, based on the indications and definitions of the electricity transmission subsidy plan, to proceed with the concession process of the indicated works, promoting transmission tendering or authorizing existing transmission companies to implement the indicated works in their facilities.
As defined in module 4 of the Transmission Standards in Brazil, the quality of the transmission service is measured by the availability and operational capacity of the Transmission Function. When the Transmission Function is available or operates with capacity restrictions, the transmission company suffers a reduction of its Allowed Annual Revenue proportionate to this unavailability.
Peru
Transmission lines belong to four national systems: Guaranteed, Complimentary, Principal and Secondary, with this last one being the largest one.
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There are basically three transmission plans that allow the expansion of the transmission network: (i) the Transmission Plan that is designed by Committee of Economic Operation of the Electrical System every two years and subject to the approval of MME, (ii) the Investment Plan approved by Energy and Mining Supervisory Authority and (iii) the expansion plan of the network subject to REP’s concession which must filed by REP before the MME.
Once the TP (Transmission Plan) is approved, the Binding Plan projects (facilities that are part of the Guaranteed system) must be tendered through international public bidding for the granting of new concessions through the signing of a contract under the build–own–operate–transfer (BOOT) modality. The bidding processes have been entrusted by the Peruvian Energy and Mines Ministry (MINEM) to the Peruvian Private Investment Promotion Agency (PROINVERSIÓN). The tender is awarded to the investor who offers the lowest investment cost. The works defined as expansions or reinforcements can be granted to those concessionaires who express their right of preference if such expansions or reinforcements involve their facilities.
The quality of the electricity service is governed by the Technical Standard for the Quality of Electricity Services, approved by Supreme Decree 020-97-EM of 1997. This standard establishes the minimum quality levels of the electrical services with regard to the quality of the product, supply, commercial and public lighting; as well as the obligations of the electricity companies and the clients that operate under the regime of the Electricity Concessions Law, Decree Law 25844.
Chile
The public electricity transmission service provided in the National Electric System (“SEN”) includes the installations of the following segments: (i)the National Transmission System, (ii) the Local Transmission System, (iii) the Dedicated Transmission System and (iv) the Transmission Systems for Development Poles.
Regarding the process of planning investments in transmission, the General Law of Electric Services establishes centralized planning directed by the National Energy Commission for the National, Local and Development Poles Transmission Systems. This process is for a term of at least 20 years and is intended to result in the expansion plan which defines new and expansion works will be mandatory. The regulation then defines two types of works, which are remunerated differently: (i) new work is a transmission line or electrical substation that does not exist and is projected to increase the capacity or safety or quality of service of the SEN and (ii) extension work is one that increases the capacity or the safety and quality of service of existing electrical lines and substations.
For new works, the investor is selected through public tenders organized by the National Electric Coordinator (NEC). If the bids exceed the maximum allowed value, the tender is repeated. For expansions/reinforcements, the investor with the lowest bid is awarded. The project is developed under the EPC modality; that is, the awardee must take care of the detailed engineering, the supply of materials, and the construction of the work, and payment is made by milestones during execution.
The conditions of safety and quality of service are contained in the Technical Standard of Safety and Quality of Service. The quality of supply of generation and transmission services is evaluated through the index of unavailability of the transmission facilities.
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3.10.8 |
Regulation of the Toll Roads Concessions |
Colombia
Beginning in the early 1990s, Colombia adopted modernization and economic liberalization policies, and implemented structural, institutional and industry specific reforms. These have included the expansion and promotion of infrastructure and public utilities in conjunction with the private sector. Different regulatory reforms have been implemented, such as Law 80, Law 105 and Law 1508 of 2012 (the Public Private Partnerships Law, “PPP Law”).
The PPP Law is one of the most representative in this sector, by implementing the regulatory framework for the development of public and private partnerships (“PPP”) for different types of infrastructure, including transportation.
Likewise, some laws related to PPP projects and the public procurement regime in general have been enacted, such as Law 1150 of 2007, Law 1474 of 2011, Law 1682 of 2013, Decree 1082 of 2015, Law 1778 of 2016, Law 1882 of 2018, Decree 438 of 2021, Law 2195 of 2022, Law 2294 of 2023 oriented to introduce different mechanisms and procedures to strengthen and streamline the development of PPP projects. Also, Decrees 050 and 2287 of 2023 were issued as means of reducing high inflation by controlling when toll rates/tariffs could be increased.
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Regulation of Public Private Partnerships (PPP)
The PPP Law allows the execution of concession contracts for different types of infrastructure, including transportation infrastructure (i.e. roads highways, airports, seaports, rails, etc.). Under this law, payments to concessionaires are subject to meeting and maintaining key performance indicators (KPIs) defined in any given contract.
PPP contracts assign risks to the party in the best position to control and mitigate its effects. Likewise, it must contain formulas for recognition of economic compensations to the concessionaire for the early termination of the contract and the constitution of a trust fund to manage the project’s resources.
The PPP Law introduced a distinction between public and private initiatives for PPP Projects. Public initiatives are defined by the granting authority and a qualified concessionaire is selected through a competitive bidding process. On the other hand, private initiatives have been introduced to allow the private sector to structure and propose to the granting authority a specific project or service.
The implementing legislation of the PPP Law is compiled by Decree 1082 of 2015 and was modified by Decree 438 of 2021, through which, some definitions associated with PPP were implemented, in order to align rules between projects and national and territorial prioritization, define liquidity mechanisms to avoid early termination of contracts in Private Initiative PPPs, promote competition and establish requirements for the presentation of private initiatives, among others. Decree 1082 of 2015 was also modified by Decree 142 of 2023 to promote access to the Public Procurement system for medium and small size companies (Mipymes), Cooperatives, and other entities of the solidarity economy. It incorporates social and environmental criteria in the contracting processes of State entities and includes the title of communal entrepreneurship.
Furthermore, Law 1682 of 2013 provides tools to overcome common bottlenecks that usually affect the feasibility of transport infrastructure projects. The main contributions of Law 1682 of 2013 are:
| ● | Improved planning . Requiring the public entities and persons responsible for planning transportation infrastructure projects to consider the impact the project will have on utility networks, cultural and archeological heritage sites, protected areas, communities and land acquisition, among other things, during the structuring phase. |
| ● | Land acquisition . Authorizing both administrative and judicial expropriation procedures. Real estate owners are allowed to grant a voluntary irrevocable permission to access and perform the required works in the property and if such permission is not granted within 15 days following the administrative expropriation order, the granting authority may request the eviction of the owner. Judges may seize the property on the grounds of public interest within ten business days following the request of the corresponding granting authority. |
| ● | Utility Networks . Providing guidelines for the relocation of utility networks, in particular regarding the allocation of costs between the infrastructure project and the public utilities suppliers. |
| ● | Environmental licenses . Not requiring environmental licenses for works or activities related to maintenance, rehabilitation and improvement of transportation infrastructure projects. Instead, the concessionaire may prepare an adaptation plan for the environmental guide (Plan de Adaptación de la Guía Ambiental or “PAGA” for its acronym in Spanish). Decree 769 of 2014 provides which works and activities are considered “improvement” of transportation infrastructure projects and do not require an environmental license. |
| ● | PAGA . Pursuant to Decree 769 of 2014, PAGA is an environmental plan that provides, among other things, an identification and evaluation of the environmental impacts that could be caused by the relevant project, activity or work, the related environmental management program, a list of the required environmental permits and a contingency plan. Unlike the environmental licenses, PAGAs do not need to be approved by the environmental authorities. The concessionaire submits PAGAs to the National Agency of Infrastructure (Agencia Nacional de Infraestructura or “ANI”, for its acronym in Spanish) and the intervenor for their approval or non-objection. However, any environmental permits listed on the PAGAs must be requested from and granted by the applicable environmental authorities prior to commencing construction of the respective functional unit. |
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4G – 5G Highway Concessions
In Colombia, five generations of road concessions have been developed since 1994, which have had as a differentiating aspect the allocation of risks between the contracting agency of the State and the private partner, as well as the complexity of the transactions.
The 4G Program, which includes Public and Private Initiative Projects, aims to reduce Colombia’s infrastructure deficit, and consolidate the national road network by creating continuous and efficient connectivity between production centers, the country’s main ports and country boundaries.
Since 2019, some modifications to the 4G program have been promoted, giving rise to the creation of the 5G Program, which was launched through the document CONPES 4060 “Bicentennial Concessions” and seeks to regulate some key aspects for the development of infrastructure, under the premises of project sustainability based on four pillars: institutional, social, environmental, and financial. This 5G Program implements contractual modifications aimed at improving property management, risks associated with natural disasters, climate change, economic compensation for commercial risk, among others. As a characteristic feature, the 5G program comprises not only toll roads concessions, but also river dredging and navigation concessions, airport concessions and railway concessions.
In January 2023, the Ministry of Transportation of Colombia signed Decree 050 of 2023, prohibiting an increase in toll rates based on the 2022 CPI, as defined in the PPP contracts. This decision is based on the government’s effort to control inflation, which led CPI to experience a 13,12% increase in 2022. However, the concession agreements provide mechanisms that compensate the difference between (i) the toll rates structure foreseen when the concessionaire submitted its bid, and (ii) the effects that the Decree 050 of 2023 has on the income of the toll rates; since the risk associated to toll rates increases is contractually assigned to the grantor.
During 2023, the CPI dropped. Thus, on December 29, 2023, the Ministry of Transportation issued Decree 2287 establishing that such entity will issue resolutions regulating toll rates increase beginning in January 2024, for toll stations under the purview of the National Institute of Roads (Instituto Nacional de Vías or “INVIAS” for its acronym in Spanish) and ANI. According to such Decree, toll rates will be adjusted in January in accordance with 2022 CPI. On January 15, 2024, the Ministry of Transportation issued Decree 20243040001125, to increase the toll rates for the INVIAS and ANI stations.
Pursuant to Decree 050 of 2023, the Ministry of Transport, the National Institute of Roads (Invías), and the National Infrastructure Agency (ANI) have been designing mechanisms to restore the toll rates before December 31, 2024, in order to normalize the system. In this regard, they have published a resolution mandating the gradual normalization of toll rates in two phases: the first on January 1, 2025, and the second on April 1, 2025. This aims to implement a gradual transition of toll costs, minimizing the immediate impact on users.
Chile
In order to improve the level of maintenance of the Chilean road infrastructure and reduce the demands on public finances, starting in the early 1990s, the Chilean government began to grant concessions, with a pre-assigned model of obligations and rights between the public and private sectors.
The execution, repair and conservation of public works are governed by the Statute of the Public Works Concessions Law, originally contained in Decree with Force of Law No. 164 of 1991, which allows persons and entities, to exploit the works and services of said public works that are the object of a concession.
Likewise, the following laws and decrees have been promoted in relation to Public and Private Partnerships (PPP) projects: Law No. 19,252 of 1993 Supreme Decree No. 900 of the Ministry of Public Works (MOP), Supreme Decree No. 956 of 1997 of the MOP, Law No. 20,128 of 2006, Law No. 20,190 of 2007 and Law No. 20,410 of 2010, all of which are aimed at facilitating the execution of projects under the PPP scheme.
The provisions of the concession contracts generally govern the term and termination of the concessions, the works to be carried out, the operation and maintenance obligations, government supervision, the maintenance reserve funds, certain fees payable to the government and the fees for toll that can be charged.
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The concessionaire is responsible for the construction, financing, operation, and maintenance of the infraestructure in accordance with the standards, specifications, and designs established by the Ministry of Public Works or, failing that, in the bidding conditions, and is obliged to correct any defect in the road that arises during the term of the concession. In exchange for developing these activities, the concessionaire is entitled to retain substantially all toll revenues derived from the operation of the toll road during the term of the concession. The road itself and the accessories related to its operation remain the property of the government during the term of the concession.
Each concession establishes a schedule of tolls by vehicle category. Most concessions allow concessionaires to increase tolls annually in accordance with Chile’s CPI. Such toll increases can be made without government approval, although supporting documentation must be submitted to the MOP. All other toll rate increases must be approved by the MOP. The MOP has the right to terminate a concession without compensation before the expiration of its term in the event of the occurrence of specified events. Furthermore, the government has the legal right to seize any concession and claim all assets related to it.
Panamá
Panamá developed PPP legislation for long-term contracts between public and private entities, allowing private companies to finance, build, operate, and maintain infrastructure projects or provide public services in exchange for fees.
Law 93 of September 19, 2019 establishes the framework for PPPs in Panama, aiming to promote private investment, social development, and job creation. Furthermore, Executive Decree No. 840 of December 31, 2020, partially modified by Executive Decree No 119 of May 4, 2020, implemented Law 93, providing detailed regulations and guidelines for the execution of PPP projects.
The provisions of the concession contracts generally govern the term and termination of the concessions, the works to be carried out, the operation and maintenance obligations, government supervision and the yearly provisions on Panama’s budget to cover the project costs.
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3.11 |
Technology, Environment, Social and Governance (TESG) |
The TESG pillar of the Strategy 2040: Energy that Transforms, integrates technological innovation to environmental, social, economic and governance issues, enabling the exploration of innovative solutions which accelerate implementation and enhance scalability. Thus, Ecopetrol has a long-standing commitment to make positive economic, social, and environmental contributions, grounding its behavior on a solid corporate governance, and a business conduct based on values and ethical principles, with transparency at the core. For this reason, Ecopetrol has strengthened its metrics and reporting of environmental, social and governance (“ESG”) issues, in line with national regulation and international standards, such as GRI, SASB, TCFD, among others. The company discloses clear short, medium, and long term targets, while also measuring its performance against targets, and trends.
Ecopetrol’s sustainability performance was evaluated through SP Global’s Corporate Sustainability Assessment to participate in the 2024 Dow Jones Sustainability Index (“DJSI”). Initially, on October 10, 2024, Ecopetrol scored 79 points, placing it in the top 5% of peer companies in the Oil Gas Upstream Integrated (OGX) sector. However, on April 16, 2025, DJSI updated the score to 62 points after having carried out a Media and Stakeholder Analysis (MSA), which forms part of the SP Global Corporate Sustainability Assessment (CSA).
In 2023, the Company updated its materiality assessment, which is the basis of the TESG pillar of our corporate strategy, following the double materiality approach, engaging various internal and external stakeholders. This approach provides a comprehensive view of sustainability management by considering (i) the impact Ecopetrol has or may have on its environment, and (ii) the impact ESG issues have or may have on the Company’s financial performance, strategic objectives and reputation, while promoting transparency and accountability with the stakeholders.
As a result, 14 TESG issues were prioritized, and four elements were identified as cross-cutting issues: (i) just transition, (ii) human rights, (iii) corporate governance, and (iv) circularity. These four elements were not considered as issues to be managed, but rather acquired a strategic and enabling character for the material issues, all of which are regarded with equal importance in Ecopetrol’s management. The 14 material issues have a significant impact (positive or negative) on the ability to generate value in the short, medium, and long term and/or a significant relevance to stakeholders.
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The 14 prioritized material issues are:
| ● | Climate change |
| ● | Water |
| ● | Biodiversity and ecosystem services |
| ● | Air quality |
| ● | Materials and waste |
| ● | Occupational health |
| ● | Industrial and process safety |
| ● | Human talent |
| ● | Sustainable territories |
| ● | Responsible supply chain |
| ● | Financial sustainability |
| ● | Cybersecurity and information security |
| ● | Innovation, science and technology |
| ● | Ethics and transparency |
In 2024, the Company formulated corresponding roadmaps for new material issues and revised those for existing material issues to date.
The identification and prioritization of Ecopetrol’s stakeholders was also updated in 2023. This exercise allows the Company to establish more effective relationships based on the generation of trust and mutual benefit. As a result of this identification, the Company went from seven to eleven stakeholders: (i) state, (ii) employees, (iii) communities, (iv) partners, (v) suppliers and their workers, (vi) controlled companies, (vii) shareholders and investors, (viii) media and opinion leaders, (ix) clients, (x) civil society and cooperation organizations, and (xi) scientific and academic community. Corporate Responsibility, which is overseen by Ecopetrol’s Secretary General, is the area responsible for consulting stakeholders’ perceptions and expectations regarding TESG material issues and the Company’s attributes as a corporate citizen.
In 2024, the percentage of respondents who answered “very satisfied” or “satisfied” regarding their relationship with Ecopetrol were as follows: scientific and academic community*: 100%, employees: 93%, suppliers and their workers: 89%, partners*: 86%, clients: 80%, state*: 79%, controlled companies: 75%, communities: 73%, civil society and cooperation organizations*: 70%, media and opinion leaders*: 63%, and shareholders and investors*: 36%. The Company’s annual stakeholder survey collected opinions and perceptions on our sustainability and material issues management, the relationship with Ecopetrol (i.e relevance and satisfaction with the value promises), and prioritization of ESG issues, among other topics. Stakeholders’ perceptions and expectations, along with the results of the annual consultation, are essential inputs that help us update and maintain a current materiality assessment.
* The number of responses required for the data to be statistically significant was not reached.
Human Rights
Throughout 2024, Ecopetrol worked on taking concrete steps to implement its human rights strategy. As a result of this exercise, we achieved the strengthening of public commitment to respect human rights by updating internal guidelines (Human Rights Commitment, Commitment to respect human rights defenders), on the identification and management of human rights risks, as well as on value chain management (both with suppliers and partners). Ecopetrol carried out two human rights risks assessments at a regional level (Andina Oriente and Piedemonte) and followed up on the risk assessments of Orinoquía Regional and of its security process. These due diligence exercises allow the Company to identify, prevent, mitigate and, if applicable, remedy impacts on human rights. As a result, Ecopetrol established actions that counteract the risks and impacts identified. The Company’s human rights management has undergone scrutiny by the Dow Jones Sustainability Index (DJSI), which highlights that Ecopetrol’s performance in this area has steadily improved over the years. This improvement is evident in its alignment with the UNGPs, as well as in the prevention and mitigation of human rights risks at the operational level, in communities, and with other stakeholder groups. It is noteworthy that, in the last measurement conducted in 2024 for the period 2023, the Company demonstrated the best performance in the human rights category with a score of 100/100, surpassing the industry average of 73 in the Oil Gas sector. A perfect score of 100/100 was achieved in four out of the four categories: commitment, due diligence, evaluation and remediation.
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Environmental Planning and Compliance
Based on the mitigation hierarchy principle, Ecopetrol S.A. undertakes a robust field baseline environmental and social sensitivity information within the project’s area of influence and conducts EIAs to identify potential environmental and social impacts at the early stages of project planning and design. Environmental Studies and diagnosis are developed to comply with regulatory requirements for environmental licenses and permits and environmental and social management plans are developed to minimize, mitigate, or compensate impacts.
In 2024, 62 total authorizations were granted, of which 2 were granted by the National Authority for Environmental Licenses (ANLA for its acronym in Spanish) and 60 were granted by the Regional Autonomous Corporations (CAR for its acronym in Spanish). These include environmental licenses and modifications and permits for the use and exploitation of natural resources. Moreover, 53 environmental permits were submitted for local and national authorities’ evaluation, and 20 archaeological programs were developed on site, based on the archaeological permits granted by the Anthropology and History Colombian Institute (ICANH, for its acronym in Spanish).
Climate Change
As part of our efforts to contribute to the Sustainable Development Goals, the Paris Agreement and Colombia’s Nationally Determined Contribution (NDC), on March 25, 2021, we announced our plan to achieve net-zero GHG emissions by 2050 (scopes 1 and 2), in line with our commitment to mitigate climate change and further the energy transition and the TESG agenda.
By 2030, we seek to reduce our CO 2 e emissions by 25% as compared to the 2019 baseline for scopes 1 and 2, which correspond to direct and indirect emissions associated with the purchase of energy. In addition, we intend to reduce 50% of our total emissions (scopes 1, 2, and 3) associated with our value chain, which includes the use of our products, by 2050. However, we cannot offer any assurance on our ability to meet these goals by such dates.
In 2023, Ecopetrol S.A. announced a methane emissions reduction target of (i) 45% by 2025 and (ii) 55% by 2030, with respect to a 2019 baseline. This target applies to direct operations in the upstream. Also, in 2023, Ecopetrol joined the sectorial initiative “Aiming for Zero Methane Initiative” led by the Oil and Gas Climate Initiative (OGCI) and confirmed its commitment to action on climate change by adhering to the Oil Gas Decarbonization Charter (OGDC).
To achieve GHG reduction targets, we launched a decarbonization program focusing on five components: (i) management of GHG emissions information, ensuring the quality, integrity, consistency and transparency of the information reported; (ii) reduction of GHG emissions, identifying and implementing initiatives associated with the optimization of energy consumption, renewable energies, reduction of flaring, fugitive emissions and venting (methane), and development of emerging low-emission technologies; (iii) strategic portfolio management; (iv) emissions offsetting of residual emissions; and (v) climate risk management of physical and transition risks to define adaptation actions and assess business resilience.
In 2024, we verified our scope 1 and 2 GHG emissions inventory for the 2021 – 2023 period through a third-party, SGS. Also, we verified for the first time the most relevant categories of our scope 3 GHG emissions inventory for 2023. The next third-party verification is expected to be carried out in 2025. In 2024, we reduced 462,074 tCO 2 e from new projects implemented during that year, exceeding the established annual target by 71%. The accumulated reduction for the 2020-2024 period is 2,248,846 tCO 2 e. In addition to the efforts on decarbonizing our operations, we took additional measures to manage our climate-related risks and opportunities, through the following actions:
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(i) |
Climate related risks: physical risks have been evaluated in 95 strategic locations of our assets in Colombia, to identify and implement adaptation measures in the comprehensive management of water, ecosystems and biodiversity, infrastructure and to increase the capacity and resilience to extreme weather events. The analysis has considered seven physical risks related to chronic hazards (drought and heat stress) and acute hazards (precipitation, coastal flooding, river flooding, wildfire, and wind speed) under three climate scenarios presented by the Intergovernmental Panel on Climate Change (“IPCC”): (i) SSP 1- RCP 2.6°C, (ii) SSP 2- RCP 4.5, and (iii) SSP 5- RCP 8.5. To assess the resilience of Ecopetrol’s infrastructure to the impacts derived from physical risks, since 2024 we have been developing and applying a methodology that allows a local analysis and the definition of adaptation actions for prioritized assets, which can be considered in the long-term investment plan. |
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(ii) |
For transition risks, in 2024, Ecopetrol developed energy transition scenarios, based on SP Global Market Energy and Climate Scenarios, for monitoring trends in each of the three business lines, which aims to be a solid and unified reference framework that allows the Ecopetrol Group (EG) to anticipate and understand the challenges and opportunities of the energy transition, through the presentation and comparison of three scenarios: |
| o | Climate Alignment (1.7° - 1.8°C), |
| o | Energy Balance (1.9° - 2.3°C), and |
| o | Climate Divergence (2.5° - 2.8°C). |
While the first and third scenarios do not represent the group’s core vision, assessing different perspectives on the global energy transition remains necessary. According to the 2040 Strategy, Ecopetrol considers the second scenario the most likely, aligning with a gradual energy transition.
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(iii) |
Innovation, research, and development: we advanced in further exploring opportunities to implement emerging low-carbon technologies like CCUS, and hydrogen and renewable energy projects, in testing top-down and bottom-up technologies for the detection and measurement of fugitive emissions and vents in the upstream and downstream segments, and natural carbon sinks. |
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(iv) |
Participation in public policy discussions: the company articulates its climate ambition with government plans and strategies and participates in the construction of climate change regulations. |
In 2024, Esenttia and the midstream segment companies (Cenit, ODL, ODC, Oleoducto Central Ocensa), ISA, and Ecodiesel, continued with their commitment to be carbon neutral. To maintain this goal, the companies implemented a work plan under three focus areas: (i) a GHG emissions inventory, which estimates the total tons of CO 2 e emitted by the companies on an annual basis, (ii) an emissions reduction portfolio in energy efficiency and renewable energies, and (iii) applying the Natural Climate Solutions (NCS) as an offsetting alternative, identifying opportunities to restore strategic ecosystems, protect biodiversity, improve ecosystem services and contribute to the construction of more sustainable economies in the regions where they operate.
In 2024, Ecopetrol’s Carbon Trading Desk continued strengthening its strategy for trading carbon offset products.
The company sold more than one million barrels of carbon compensated premium gasoline to wholesale distributors and 32,800 tons of carbon compensated asphalt in Colombia. Ecopetrol’s carbon offset strategy covers direct GHG emissions generated throughout the product’s lifecycle, from its production process to its transportation to the Coveñas terminal in the Colombian Caribbean or to the destination port agreed with our customers.
In 2024, ISA defined an annual consolidated goal relating to the company’s reduction of CO2e emissions. This goal integrated potential CO2e emissions reductions from the “Conexión Jaguar” program and emissions reductions generated from voluntary actions of eco-efficiency for the management of SF6, energy and water consumption, generation of waste, and other emissions reductions relating to remote work. The specific goals of CO2e emissions reductions associated with SF6 and energy consumption were 6,699 tCO2e and 85 tCO2e. By the end of 2024, the consolidated performance of CO2 emissions reduction by SF6 was 11,671 tCO2e, which represents 174% of the goal, and the reduction of CO2 by energy consumption was 312 tCO2e which represents a fulfillment of 367% of the established goal.
In order to achieve these results, ISA has implemented several practices such as the use of real-time meters to identify SF6, preventive maintenance or refurbishing of high voltage circuit breakers to avoid gas leaks, development of a prototype to capture of SF6 before it is released into the atmosphere, reusing this kind of gas when the conditions allow it and appropriating final disposal of it. Moreover, some companies have been implementing different actions to reduce the consumption of energy, such as the installation of solar panels in some of ISA’s locations and electrical substations, the implementation of LED technology, the purchase of international renewable energy certificates I-REC.
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Water Neutrality
Ecopetrol S.A. aims to improve water use efficiency to reduce water-related impacts and potential associated conflicts, as well as promoting water security within the operation’s areas of influence. Water use is optimized also, to ensure production sustainability due to the operation’s dependence on water resources.
In 2023, Ecopetrol ratified its commitment to be water neutral by 2045. The objective is to achieve a balance between the water required to operate, and the actions that reduce the direct water footprint, as much as economically and technically feasible, as well as to replenish the remaining water consumption through conservation, and water, sanitation and hygiene (WASH) actions. To achieve this goal, Ecopetrol has undertaken proactive actions, beyond environmental compliance, which have enabled it to manage water risks in the physical, regulatory, and reputational components, and generate social and environmental benefits.
During 2024, 164 million cubic meters of water were recycled, that is, 81% of the total water required to operate, which means a 7% increase compared to 2023. In addition, 39.4 million cubic meters of freshwater were withdrawn, which account for 19% of the total water required to operate, resulting in a 4.5% decrease compared to 2023, mainly due to an increase in the recycling of industrial waters in the Barrancabermeja and Cartagena Refineries, as well as lower demand for secondary oil recovery in Casabe, Yarigui, and Tren Nare.
These figures indicate a net increase in water efficiency, not only by the increase in water recycling and reuse (the highest in Ecopetrol’s history) but also in terms of freshwater intensity which was reduced to 1.19 barrel of water/barrel of oil (Bbl-water/Bbl-oil) in the Downstream segment (a decrease of 6% compared to 2023) and slightly increased to 0.33 Bbl-water/Bbl-oil in the Upstream segment. These results were leveraged by the fulfillment of the water management efficiency targets for 2024 and allow us to continue on the path towards water neutrality by 2045.
In 2024, Ecopetrol received an “A-” score in CDP Water Security 2024 for the second consecutive year, which ratifies us in the “Leadership” band as one the best company in the oil gas sector in water stewardship practices. In terms of water footprint certifications, in 2024, eight assets were successfully verified by a third-party, based on the NTC-ISO 14046 standard.
Sustainable Production System and Biodiversity
Our biodiversity strategy is based on two components: (i) prevention and mitigation of biodiversity impacts and (ii) implementation of nature-based solutions, to offset residual impacts and actively respond to challenges related to climate change, water resources, and biodiversity management, food security, or disaster risks, among others. Each of these themes is described below.
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(i) |
Prevention and mitigation of biodiversity impacts: |
| ● | Enhancing Biodiversity Information for Decision-Making and Resilience Analysis |
| ● | Incorporate the mitigation hierarchy in the planning and implementation of projects and operations. |
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(ii) |
Implementation of nature-based solutions: |
| ● | Large-scale interventions in priority areas to capture GHG emissions through NCS and generate additional biodiversity and social co-benefits. |
| ● | Conservation efforts aim to improve biodiversity and protect ecosystem services. |
Results related to positive impacts on biodiversity:
| ● | We have designated 20 company-owned areas for conservation, collectively known as “Ecoreserves.” These areas serve as habitats for over 2,426 species, including amphibians, birds, insects, mammals, fish, plants, and reptiles. Among these, 162 species are endemic, and 23 are classified under various threat categories according to the IUCN. |
| ● | We have 290,396 hectares under restoration and/or conservation actions, supported by 1,915 active conservation agreements with local stakeholders. These initiatives include both voluntary and mandatory restoration actions, as well as the registration of civil society nature reserves and Ecoreserves. Additionally, we have developed sustainable cattle grazing systems covering 504.05 hectares and implemented agroforestry practices on 281.56 hectares across different ecosystems. |
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| ● | Through the Wildlife Project, we implemented measures to protect 17 threatened flora and fauna species across three key Colombian ecosystems. These species include palms, fish, monkeys, alligators, manatees, and birds. Our commitment to biodiversity conservation was recognized with the Boscar Award, presented by Reforestamos México during COP16 in acknowledgment of our efforts to preserve forests. |
As early adopters of the Taskforce on Nature-related Financial Disclosures (TNFD), we aim to publish our first biodiversity-related financial report covering 2024, in 2025.
In 2023 we also implemented two pilots to assess impacts, dependencies, risks, and opportunities associated with natural capital, in line with the TNFD – Taskforce on Nature financial disclosure framework.
Circular Economy
The double materiality exercise highlighted circular economy as a transversal issue within the group. Under this approach, the circular economy model was updated.
Our circular economy model is a key driver that contributes to advance in the energy transition, achieve the net-zero emissions and water neutrality targets, and advance in achieving closed-loop cycles of materials and waste, and diversification of new businesses. Specifically, the adoption of a circular economy model allows us to:
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(i) |
further promote the efficiency in the use of materials, waste and resources like water and increase the recovery capacity of ecosystems, |
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(ii) |
foster the identification of new business models that generate economic, environmental, and social benefits, and |
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(iii) |
increase innovation, technological advances and research and development of new products and services. |
Over the course of recent years, Ecopetrol has renewed its commitment to environmental sustainability through the implementation of circular economy strategies, focusing on the optimization of resources and the minimization of environmental impacts.
The First Circular Economy Forum was held in 2024, where the circular economy model was presented, as well as circular initiatives developed and an academic agenda on different topics where 320 people participated, 1,000 digital connections per day were made, and 82 speakers and 42 organizations attended. Likewise, through the circularity training program, more than 470 employees were trained during 2024. Moreover, through the Colombian Institute of Petroleum and Energy for the Transition (ICPET), different research projects are being carried out to strengthen circularity in the areas of water, renewable energies, materials and waste. Finally, the level of maturity in circularity was measured, which is carried out around four dimensions: materials, waste, water and emissions. The result places the company at a “2-eco-conscious” level, which means that it is an organization that develops first circularity initiatives and that begins to perceive the first impacts of circularity on its EBITDA, mainly through cost savings by extending the useful life of materials and reusing resources. To date, Ecopetrol has 223 circular initiatives which are in different stages of maturity; 80 of which have been implemented and another 94 are currently in execution.
Sustainable Territories - Social Investment for Territorial Transformation
In 2024, we allocated resources for the execution of the sustainable territorial development portfolio amounting to COP 606,237 million. This figure includes both strategic and mandatory social, environmental, and relationship investments. Ecopetrol contributed COP 789 billion to the regional GDP in 2024 through the execution of projects, job creation and economic impact of the projects. Moreover, more than 21,081 direct and indirect jobs were generated as a result of the social investment projects.
The Company’s social investment projects are grouped into three strategic options: (i) access to public services, (ii) education improvement, and (iii) dynamization of local economies. The Company contributes comprehensively to the agenda and goals of the United Nations’ Sustainable Development Goals (“SDG”), with SDG 7 (Affordable and Clean Energy), SDG 6 (Clean Water and Sanitation), SDG 4 (Quality Education), and SDG 10 (Reduced Inequalities) being the most impacted, as follows:
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i. |
Access to Public Services: With the purpose of improving access and coverage in basic care of essential public services for vulnerable communities in the areas of influence, in 2024 we obtained the following results: |
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| o | Energy and Gas: Connection of 20,113 new households to gas service in the departments of Meta, Arauca, Casanare, La Guajira, Huila, Cesar, Magdalena, Cundinamarca, Atlántico, Caquetá, Putumayo, Nariño, Valle del Cauca and others. |
| o | Potable Water and Basic Sanitation: 247,107 people benefited from access to potable water in Norte de Santander, Meta, Santander, Atlántico, Cesar, Córdoba, Magdalena, Tolima and Guajira. |
| o | Health: 41,224 people benefited from health sessions and promotion and prevention programs for the most vulnerable population. |
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ii. |
Education: During 2024, we developed various programs and projects focused on achieving greater school permanence and coverage in education, as well as improving educational quality, by which 290,742 children and young people benefited from, equivalent to 4.5% of the 2024 enrollment of public basic and secondary education institutions in the country. This includes interventions such as provision of school kits, school furniture, training for energy transition, teacher training, higher education scholarships, and improvement of educational infrastructure. |
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iii. |
Dynamization of Local Economies: In 2024, we focused efforts on diversifying and dynamizing local economies, promoting programs to encourage productive vocations, job creation, entrepreneurship, and innovation. We also contributed to improving land connectivity and public community infrastructure with the following results: |
| o | Inclusive Rural Development: Ecopetrol benefited 3,142 families with strengthening of productive capacities and connection with markets in the departments of Arauca, Boyacá, Casanare, Cundinamarca, La Guajira, Magdalena, Meta, Norte de Santander, Putumayo and Santander. |
| o | Entrepreneurship and Business Development: Ecopetrol benefited 4,862 entrepreneurs, Micro, Small, and Medium-sized Enterprises (MSMEs), and young people with business strengthening and skills development programs. |
| o | Road Infrastructure: We contributed on 93.10 kilometers of roads in the departments of Cesar, Cundinamarca, Meta, Casanare, Arauca, Atlántico and Tolima. |
| o | Public Infrastructure of Community Interest: We assisted on 53 infrastructures, including spaces for education, sports, recreation, and culture, promoting meetings for coexistence and citizen participation. |
Works in lieu for Taxes: In 2024, the Ecopetrol Group continued leading the implementation of Colombia’s “Works for Taxes” program, obtaining the highest participation in the country, with 41 new projects assigned by the Territory Renewal Agency (ART) in this period, worth COP 387,127 million pesos, which is expected to benefit more than 230,428 Colombians. With the assignment of these projects, since the program’s creation in 2017, the Ecopetrol Group has accumulated a total assignment of 132 projects, worth COP 1.1 trillion pesos, corresponding to 38.7% of the total assigned.
During 2024, the Ecopetrol Group completed 21 projects for an amount of COP 92,452 million pesos, benefiting more than 146,696 inhabitants in 37 municipalities across nine departments. The Works for Taxes projects include the improvement of 10.5 km of road in Tame (Arauca), Lérida and Venadillo (Tolima), the delivery of equipment to 837 educational centers in the departments of Antioquia, Bolívar, Cesar, Santander, Tolima and Valle del Cauca; as well as the comprehensive equipping of the SENA Agroindustrial Center in Monterrey, Casanare and the equipping of ten Child Development Centers (CDIs) of the Colombian Institute of Family Welfare (ICBF) in Meta.
Social Dialogue Processes: Social dialogue is established as the main tool to promote trust relationships, strengthen the social fabric, and build shared visions of territory within a framework of respect and promotion of human rights. During 2024, Ecopetrol carried out 26 social dialogue processes and 122 dialogue spaces with communities and local institutions. Additionally, Esenttia, S.A., developed 108 new meetings with community leaders from Community Action Boards, ethnic communities, local governments, and beneficiaries of social projects, which brought together 1,326 people in 2024.
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Ethnic Relations: In 2024, we carried out the following ethnic relationship activities:
| ● | Ecopetrol maintained the relationship with the new Board of Directors of the Asouwa indigenous community for the period of 2022 to 2025, in order to give continuity to intercultural dialogue. |
| ● | Ecopetrol held the traditional ethnocultural encounter of the Alto Unuma Meta - Yalaki Reserve to strengthen the knowledge of the cultural identity of the Sikuani people (an indigenous community) of the Alto Unuma Meta reserve and the respectful interaction between cultures that recognize themselves as different and find a common language to communicate, highlighting respect and appreciation for difference and peaceful coexistence. |
| ● | Hocol concluded the consultation process that began in 2018 for the GUA 2 exploratory drilling area with 132 Wayuu ethnic communities in the municipality of Maicao. |
Dialogue and Participation Initiatives: During 2024, 99 initiatives were developed by Ecopetrol in the different territories of influence where we have a presence, which allowed direct and timely knowledge of the social, economic, cultural, institutional, political, and environmental realities of the territory, fostering participatory and inclusive spaces for rapprochement, ensuring transparent and timely information, managing to interact with more than 84,635 people in 434 spaces. Additionally, within the framework of developing participation scenarios, 341 participation spaces were held with 6,422 people, with Office of Citizen Participation (OPC) Brigades standing out with 1,463 attendees, the “Protecting My Planet” project with 1,631 participants, and Office of Citizen Participation (OPC) talks with 1,388 attendees.
Clean Air and Quality of Fuels
Ecopetrol seeks to promote prevention and mitigation actions for reducing air quality impacts, through a clean air roadmap which aims to reduce emissions of criteria pollutants, and to ensure environmental compliance based on operational practices.
Air quality was identified as a material issue in the 2023 materiality analysis. In the past three years, specific actions have been defined to improve operational discipline and to identify synergies for reduction of criteria pollutants based on ongoing decarbonization initiatives as well as energy transition and clean fuels agendas.
Actions undertaken include verifying internally the criteria pollutants emissions inventory for the 2021-2024 period and the evaluation of key initiatives in accordance with the best practices related to air quality management. As a result, in 2024, Ecopetrol reduced the emission of 1,745 tons of VOC (Volatile Organic Compound) and NOX (Gases Nitric Oxide). Moreover, 2024-2027 targets were defined for the upstream and downstream segments, aiming to gradually reduce nitrogen oxide, sulfur oxide and volatile organic compound emissions, which are expected to be reviewed and updated on yearly basis.
Ecopetrol is also committed to improving fuels quality to contribute to better air quality across the whole country and comply with and exceed fuel quality regulations. Taking advantage of being an integrated company, after April 2018, we have been significantly reducing the sulfur content in our diesel B2 (98% fossil and 2% biodiesel). In 2024, the diesel and the gasoline that we distributed in Colombia had an average of 11 ppm and 43 ppm of sulfur, respectively, below the current local regulations of 15 ppm in diesel and 50 ppm in gasoline. Moreover, in 2024, Ecopetrol started the distribution of premium gasoline with less than 15 ppm of Sulfur to make the introduction of vehicles with cutting edge emissions control technologies viable.
Waste Management
Ecopetrol aims to substantially act on waste prevention, reduction and reuse, based on a circular economy framework. The waste management strategic pillar has three main objectives: (i) source reduction (ii) material recovery, and (iii) implementation of new technologies.
During 2024 a total of 537,060, tons of waste were generated, this represents a decrease in total waste generation compared to 2023 mainly due to (i) the decrease in the generation of metal scrap, (ii) in the generation of oily sludge due to less periodic maintenance, (iii) less soil contaminated with hydrocarbons due to the decrease in the number of barrels spilled in incidents affecting the environment, among others. Additionally, in 2024, the waste recovery rate was 36%, compared to 34% in 2023.
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Prevention and Remediation of Environmental Impacts caused by Operational Incidents
During 2024, 25.57 total barrels of oil were spilled due to operational causes in operated assets. From these, two incidents were greater than one barrel with 7.83 barrels spilled, representing a 48.8% decrease compared to 2023. The total value was below the maximum internal threshold of 35.6 total barrels that was set for 2024, achieving the Company’s best performance in the last five years. This is the result of the systematic execution of integrity and reliability plans, where more than 200 km of pipes have been replaced between 2022 and 2023, and 80.5 in 2024. Moreover, the following actions were implemented: (i) maintaining line inventory updating, (ii) ensuring coverage of lines’ criticality and risk assessments including environmental sensitivity, as well as the preparation of preventive inspection and maintenance plans, (iii) assurance of compliance with the execution of these plans and reliability-based maintenance actions, and (iv) monitoring the health status of high-impact lines.
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3.11.1 |
Energy Initiatives |
We have been undertaking significant efforts to make efficient and rational use of energy resources in our production processes and to reduce energy consumption, costs, and carbon dioxide emissions. Our pillars are efficiency, reliability, optimization, and energy diversification.
By 2024, the Ecopetrol Group accumulated an incorporation of 610 MW from non-conventional renewable energy sources into its energy portfolio, 108 MW in construction, 99 MW in execution and the remaining 403 MW in operation, including renewable energy purchases.
Production
During 2024, our production segment had an energy consumption of 5.4 TWh (Terawatts per hour) for its direct operation, of which 53% was provided through self-generation and the remaining 47% with non-regulated energy purchased from the National Transmission System.
In renewable energy:
La Cira Solar farm, located in the municipality of Barrancabermeja, incorporated 44 MW in operation since September 2024 and 12 MW in construction, and Quifa solar project in Puerto Gaitan, Meta with an installed capacity of 50 MW under construction by the end of 2024.
Transport
During 2024, our transport segment had an energy consumption of 1.18 TWh (Terawatts per hour) for its direct operation, from which 60% was provided through self-generation and the remaining 40% was provided by non-regulated energy purchased from the National Transmission System.
In renewable energy:
| ● | CENIT had thirteen solar farms in operation, a small hydroelectric power plant and a solar farm under construction for a total of 82 MW; |
| ● | OCENSA had two solar farms in operation for 12 MW; and |
| ● | ODC had one solar farm in operation for 7 MW. |
Refining
During 2024, Barrancabermeja and Cartagena refinery’s average energy consumption was 1.68TWh (Terawatts per hour), provided through self-generation.
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In renewable energy:
The Cartagena Refinery Solar farm, located in the municipality of Cartagena, was under construction with an installed capacity of 18 MW. Its commercial operation date is intended to be in the first half of 2025.
La Iguana Solar farm, located in the municipality of Barrancabermeja with an installed capacity of 26 MW, started construction in 2024 and is expected to start its commercial operation in 2025.
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3.11.2 |
HSE |
This section describes the health, safety and environmental (HSE) practices of Ecopetrol S.A. Subsidiaries guidelines must be consistent with those established by Ecopetrol S.A.
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3.11.2.1 |
Ecopetrol S.A. |
One of the principles that guides Ecopetrol S.A. is the commitment to our employees and the development of the communities in which we operate. For that reason, Ecopetrol S.A. is devoted to improving our health, safety and environmental practices.
The results of the HSE performance in 2024, compared to the prior year, were as follows:
| ● | The severity of occupational incidents decreased in 2024 compared to 2023, with zero fatalities recorded in 2024, as opposed to two fatalities in 2023; |
| ● | The Total Recordable Injuries Frequency (TRIF) was 0.28 in 2024, compared to 0.27 in 2023. The TRIF represents the number of employee or contractor injuries that require minimum medical treatment for every million hours worked, including fatalities, days away from work, restricted work and medical treatment cases; |
| ● | The incidence of road accidents decreased to two road accidents in 2024, as opposed to five accidents in 2023. Ecopetrol has focused its efforts on technology for the control of vehicles and drivers, implementation of a corporate campaign on road safety focused on controlling driver habits. |
| ● | Five Tier 1 process safety incidents in 2024 compared to three incidents in 2023; |
| ● | A decreased of 30.65% in the amount of total barrels of oil spilled due to operational incidents with an impact on the environment. In 2024, 25.57 barrels were spilled as compared to 36.9 barrels in 2023, and |
| ● | A decrease of 48.8% in barrels of oil spilled due to operational incidents greater than one barrel. In 2024, 7.83 barrels were spilled as compared to 15.29 barrels in 2023 |
We have several programs in place aimed at increasing the safety of our industrial processes and minimizing the number of occupational accidents and other major incidents. Our HSE management model is based on key focus areas that are aligned with our integrated management system.
Total Recordable Injuries Frequency – Employees and Contractors
Ecopetrol S.A. places an important emphasis on understanding, monitoring, and controlling the health and safety impacts on workers and contractors.
In 2024, 34 recordable injuries occurred, where 20.58% led to restricted work, 14.71% required medical treatment, 64.71% led to lost days, and none of which were fatal incidents. Additionally, we had a 3% increase in the number of recordable injuries compared to 33 injuries in 2023, primarily because of an assurance of high risk activities, improvement of risk analysis in operational activities, prior assurance of HSE risks and skills development, and strengthening HSE skills in refining.
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Graph 7 – Total Recordable Injuries Frequency – Employees and Contractors (*) (**)
* Number of employee or contractor injuries requiring minimum medical treatment for every million hours worked.
** Includes data for Ecopetrol S.A. but does not include data for subsidiaries of Ecopetrol.
Contingency Plans and Environmental Remediation
To protect and minimize potential damage to people, the environment, or assets, due to contingencies, Ecopetrol has developed emergency and contingency plans to guarantee immediate, timely and effective intervention in the event of emergencies or contingencies that may occur in our facilities and operations. These plans have been appropriately documented, updated, and distributed internally, with our professionals that oversee these plans having been trained to do so.
Emergency and contingency response plans are prepared in accordance with Colombian legal requirements and considering internal emergency guidelines. These plans, which have the approval of the ANLA, are articulated with municipal emergency response strategies and risk management procedures of the territories where we operate.
The main results obtained in the implementation of the emergency and contingency plans for 2024 by Ecopetrol S.A. are presented below:
| ● | 41 updated emergency and contingency plans that include identifying emergency and disaster scenarios, strategies, and procedures to respond to emergencies of a technological origin (spills, fires, explosions, events involving hazardous materials, emergencies of natural origin, socio-natural, anthropic, of electrical origin, events that affect people, among others) caused by other types of operational or environmental risks. |
| ● | Definition and implementation of resources, equipment, and tools. Planning and management of emergencies under the “Incident Command System” model adopted in 2011 under the USAID – BHA (United States Agency for International Development – Bureau for Humanitarian Assistance) methodology. |
| ● | Execution of 19 drill plans in 2024 where all types of emergency scenarios were tested. |
| ● | Definition of mechanisms for activation, notification, reporting to entities and authorities, and early warning system to communities. |
| ● | Signing of seven mutual assistance schemes with formalized cooperation and coordination schemes in various regions of the country signed with other oil and gas companies located in the geographic area of influence of the Company’s facilities. |
| ● | Consolidation and management of geographic, thematic, operational and situational information of emergencies supported by technological enablers such as the OGI (opportunity, geo-positioning and innovation) and COBRA (Ecopetrol’s tool for the creation and operation of an emergency brigade) software. |
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Ecopetrol S.A. continuously implements training programs for all personnel involved in emergency or contingency response plans. In 2024, 4,836 trainings took place to improve our employees’ skills.
Graph 8 – Trained Personnel 2024
Frequency of Process Safety Incidents
Process safety is designed to achieve the best operational performance by intervening in the highest technological risk and implementing the necessary measures and actions to prevent and mitigate the release of dangerous substances or energy. The impact of these measures is focused on the reduction of operational and occupational accidents with the potential of causing major accidents or disasters, providing an effective management framework for Ecopetrol’s operations, and demonstrating commitment to the first principle of the Company’s cultural statement, “Life First”.
Ecopetrol’s ambition is to become a global benchmark in industrial safety, adopting best practices and undertaking operations under tolerable risk levels for process safety. To this end, the Company works on three fronts: (i) comprehensive risk management (include onsite/ offsite risk, notch risk management, risk management high consequence scenarios), (ii) risk awareness (process safety competency management) (iii) efficient and simple HSE management system (contractor management with process safety focus).
We report Tier 1 process safety events per million hours worked, which are the losses of primary containment of greatest consequence causing harm to a member of the workforce, costly damage to equipment or exceeding defined quantities according to API754. The reporting thresholds for API754 Tier 1 is an unplanned or uncontrolled release of any material, including non-toxic and non-flammable materials, from a process that results in one or more health, safety or environmental consequences set forth under those guidelines. In 2024, there were 0.04 Tier 1 process safety incidents per million hours worked an increase from the 0.02 recorded in 2023.
Frequency of Tier 1 process safety incidents per hours worked (per million hours worked):
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Graph 9 – Tier 1 Process Safety Incidents (*) (**)
* Tier 1 process safety incidents per million hours worked (API-754).
** Includes data for Ecopetrol S.A. classified according to the criteria in API-754 Tier 1 but does not include Ecopetrol S.A.’s subsidiaries.
Incidents with an impact on the environment
In 2024, we reported five incidents with hydrocarbon spills greater than one barrel, which affected the environment, with a total spilled volume of 161.49 barrels of hydrocarbon.
Of these five incidents, two were due to operational causes, with a total volume of 7.83 barrels. This represents a 48.8% decrease compared to 2023 (15.29 barrels), an 87.7% decrease compared to 2022 (63.7 barrels), and 95% decrease compared to 2021 (157.76 barrels). The reduction in spilled volume from operational incidents is directly attributed to the implementation of the integrity strategy. The strategy focuses on maintaining an up-to-date pipeline inventory, ensuring adequate coverage of criticality and risk assessments, developing and adhering to preventive inspection and maintenance plans, and monitoring the health of high-impact pipelines. Furthermore, over 200 kilometers of pipelines were replaced between 2022 and 2024 (128 km in 2022 and 2023, and 80.5 km in 2024). The remaining three incidents with spills greater than one barrel were due to attacks and theft by third parties, totaling 153.66 barrels. This represents a 58.67% decrease compared to 371.74 barrels in 2023.
Ecopetrol S.A. monitors performance using the IOGP index for oil spills (1 barrel) per unit of hydrocarbon production. In 2023, the global Onshore index was 5.39, while Ecopetrol’s value was 0.08—reflecting a 98.5% improvement. The 2024 index will be published in Q4 2025.
As of December 31, 2023, reported spills greater than one barrel, whether of operational origin or caused by third parties, are as follows:
| ● | 2022: 141.7 barrels of hydrocarbon |
| ● | 2023: 387.03 barrels of hydrocarbon |
Corrective and mitigation actions implemented by Ecopetrol S.A.
In due course, Ecopetrol S.A. carried out all the social, environmental, and technical actions to fully attend the event and mitigate potential damages and manage the incident, in compliance with corporate practices, contingency plans and national requirements established in Law 1523 of 2012 and the Decree 1868 of 2021.
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Investigations and legal claims
Investigations
As of the date of this annual report the following investigations are being conducted by environmental authorities and control agencies in respect of the incident:
On January 20, 2020, Ecopetrol S.A. was informed that the ANLA, in the course of the administrative process initiated by said authority as a consequence of the events occurred during the Lisama 158 well spill, decided to impose a fine on Ecopetrol S.A. in an amount of COP 5,155 million. In the course of said administrative process, the ANLA exonerated Ecopetrol S.A. from liability for some charges, due to the fact that ANLA evidenced that Ecopetrol S.A. had activated its contingency plan and implemented the corresponding actions. It also mentioned that Ecopetrol S.A.’s environmental control actions were taken in an appropriate manner. Nonetheless, it decided to impose the fine, because the ANLA considered that the actions were not taken in a timely manner and because, it considered that Ecopetrol S.A. did not adopt and implement the necessary actions to correct the mechanic failures in the well, in order to prevent the environmental damage. On February 11, 2020, Ecopetrol S.A. filed a reconsideration appeal before ANLA requesting the reversal of this decision. On February 9, 2021, through Resolution 290, the decision of the ANLA was announced and reduced the fine to approximately COP 3.864 million. The proceeding was closed by the environmental authority.
Ecopetrol S.A. complied with ANLA’S decision and paid the penalty on February 17, 2021. However, Ecopetrol S.A. requested the annulment of the sanction before the High Administrative Court on June 9, 2021. The lawsuit was admitted by the court on February 18, 2022. As of the date of this annual report, the process is ongoing and Ecopetrol S.A. is awaiting the start of the evidence gathering stage.
Ecopetrol S.A. has completed most of the tasks related to the Environmental Recovery Plan for the well Lisama 158 spill, which occurred in 2018. The plan is expected to be fully executed by 2026. The National Specialized Unit against Human Rights Violations – Environmental Crimes Subunit of the Office of The Attorney General opened a criminal investigation into the possible environmental contamination caused by the oil well exploitation, following a request from the Minister of Environment. The case was registered under the file number 110016099043201800044. In August 2021, the prosecutor in charge agreed to grant a conditional suspension of the prosecution, based on a deal with Ecopetrol. We promised to compensate the local fishermen affected by the spill with COP 6,500 million (about 1.4 million dollars) and to restore the environment according to an environmental reparation plan, which consisted of 11 major actions, under the supervision of the ANLA. The first hearing to partially approve the conditional suspension took place on July 28, 2021 before a judge in Barrancabermeja, and the decision was confirmed on November 19, 2021 and March 25, 2022. Later, on May 9 and August 18, 2023, the Sixth Criminal Municipal Judge with Mixed Duties and the Third Criminal Circuit Judge with Knowledge Duties, both from Barrancabermeja, verified in the first and second instance, respectively, that we had fulfilled 100% of the monetary obligations and most of the environmental obligations. The case is currently on hold until we complete the remaining environmental tasks.
Agreement with fishermen and fish traders reviewed by the Prosecutor’s Office
On July 28, 2021, Ecopetrol S.A. and a fishermen group certified by the Fishing and Aquaculture National Authority (“AUNAP” for its acronym in Spanish), made an arrangement for an economic recognition regarding the effects of the Lisama 158 event. Ecopetrol S.A. reached an arrangement with AUNAP, as well with the local fish traders associations from Barrancabermeja ASOCORAMB (Asociación De Comerciantes Del Sector La Rampa De La Ciudad De Barrancabermeja) and ASOCOPROPAL (Asociación de Comerciantes de Pescado). Due to these arrangements, 940 fishermen and 118 fish traders received compensation of COP 8,426,680,523. The Prosecutor’s Office reviewed and approved such agreement in the application of the discretionary prosecution principle (“ Principio de Oportunidad ” in Spanish). Additionally, two criminal judges have also reviewed and approved the agreement and have monitored and verified its full compliance to the present day. The last of these decisions was issued on August 18, 2023 by the Third Criminal Judge of Barrancabermeja Circuit.
Ecopetrol S.A. simultaneously agreed to continue with the actions contained in the Environmental Recovery Plan (PRA for its acronym in Spanish), which were accepted by the ANLA as environmental recovery of the area affected by the event.
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Legal Claims
As of the date of this annual report:
There are two more actions that have been filed before the Administrative Court of Santander, related to the Lisama 158 incident:
Approximately 600 people, members of the community and fishermen who live in the vicinity of where the incident took place, filed a class action in the amount of COP 614,503,232,689, seeking compensation for damages allegedly suffered as consequence of the incident. On September 25, 2020, Ecopetrol S.A. informed Mapfre Seguros Generales de Colombia S.A. that it was seeking to invoke guarantee coverage by the guarantors. As of the date of this annual report the court has not scheduled a hearing date.
Senator Antonio Eresmid Sanguino filed a class action, seeking protection of collective rights (no compensation or indemnification petitions), arguing that the incident led to the destruction of (i) people´s health and (ii) damages to the environment caused by the incident.
On October 2, 2018, the Administrative Court of Santander (competent judge) issued an interim measure whereby the latter ordered different authorities and Ecopetrol S.A. to perform various activities to prevent any additional environmental damage to occur.
On January 16, 2020, the High Court for Administrative Matters (Consejo de Estado) revoked the interim measure imposed by the Administrative Court of Santander, considering that with the abandonment of the well “the risk that caused the production of the spill has been surpassed”. In its ruling, the High Court for Administrative Matters also mentioned that Ecopetrol S.A. has been taking the necessary actions to solve the damages produced by the incident, and also implemented the actions to repair the alleged damage. As of the date of this annual report, both complaints were properly answered, and we are still awaiting for the commencement of the evidentiary stage.
On March 22, 2018, Ecopetrol S.A. made a claim to Mapfre Seguros Generales de Colombia S.A., based on its Control of Well Policy and received the USD 19 million in October 2019. Thereafter, as a result of the third-party liability policy claim objection, Ecopetrol S.A. has taken the relevant actions to obtain the guaranteed coverage of guarantors. On February 27, 2020, Ecopetrol S.A. filed a lawsuit against Mapfre Seguros Generales de Colombia S.A. to obtain recognition and payment of COP 128,807,833,685 based on civil liability. The court admitted the lawsuit on January 20, 2022, but as of the date of this annual report the court has not scheduled a hearing date.
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3.11.2.2 |
Cenit |
Cenit incorporates the Occupational Health and Safety Management System through its “Commitment to Life and Process Safety” element, which defines a set of principles, actions, tools and documentation, articulated among themselves to manage industrial safety risks, health at work, environment and process safety in the Company. The “Commitment to Life and Process Safety” element is based on HSE regulatory compliance, as well as the best practices in the industry, which allows us to protect the integrity of our staff, the environment and infrastructure.
The scope of coverage of the Occupational Health and Safety Management System under its Element Commitment to Life and Safety of Processes, applies to all Cenit workers directly linked, by temporary mission or other type of connection established by law, and/or those who carry out their work in any of the facilities, pipeline network, polyduct network and/or under the control Cenit operation. In addition, it applies to all Cenit processes, activities and tasks carried out by our own personnel, contractors, subcontractors and visitors.
The objective of SG SST Cenit is to define a strategy to achieve results and demonstrating actions that prioritize people’s safety, care for the environment and assurance of the operations, with generation of healthy work environments.
The following table covers CENIT’s TRIF for 2022, 2023 and 2024, which includes direct employees and subcontractors. The table presents statistics related to the maintenance, operation and execution of projects in the transportation of hydrocarbons.
103
Table 48 – Performance Indicators (1)
|
|
|
For the year ended December 31, |
||||
|
Metric |
|
2024 |
|
2023 |
|
2022 |
|
Man-hours |
|
22,324,197 |
|
25,144,351 |
|
22,682,665 |
|
Recordable accidents |
|
12 |
|
3 |
|
4 |
|
Total recordable incidents frequency (TRIF) |
|
0.54 |
|
0.12 |
|
0.18 |
|
(1) |
Includes data for CENIT but does not include data for subsidiaries of CENIT |
|
3.11.2.3 |
Cartagena Refinery |
In 2024, approximately 5,845,318.01 million man-hours were employed conducting Cartagena Refinery’s business activities. Our HSE performance indicators for Total Recordable Incidents Frequency (TRIF), Process Safety Incident (PSI), and Environmental Incident (EI) were well within our established expectations.
The following table covers Cartagena Refinery’s TRIF for 2022, 2023, and 2024 which includes Ecopetrol Operation and Maintenance (OM), Cartagena Refinery and subcontractors. The table presents statistics related to operating and maintenance activities. Cartagena Refinery has not reported fatalities during the period 2022 – 2024.
Table 49 – Performance Indicators
|
|
|
For the year ended December 31, |
||||
|
Metric |
|
2024 |
|
2023 |
|
2022 |
|
Man-hours |
|
5,845,318.01 |
|
4,990,444 |
|
7,254,166 |
|
Recordable accidents |
|
4 |
|
4 |
|
2 |
|
Total recordable incidents frequency (TRIF) |
|
0.68 |
|
0.80 |
|
0.28 |
|
Environmental Incidents (EI*) |
|
1 |
|
— |
|
— |
|
Process Safety Incidents (PSI) |
|
1 |
|
— |
|
— |
*Incident with hydrocarbon spill greater than 1-barrel due operational causes
|
3.11.2.4 |
ISA |
For ISA and its subsidiaries and affiliates, it is important to protect and preserve the health and safety of workers, regardless of the type of contractual relationship, guaranteeing safe work environments, self-care, and the application of good prevention practices. This high commitment to people is expressed in the occupational health and safety policy, which seeks to offer safe working environments and healthy lifestyles.
ISA monitors two main indicators that contain its goals in terms of safety and health at work and that are part of the comprehensive management chart and variable compensation: (i) reduce events with a high potential for seriousness and (ii) Total Recordable Injury Frequency (TRIF), which is calculated as: the number of injuries from all workplace incidents or illnesses that either took place at work or were the result of work-related activities divided by the numbers of hours worked, multiplied by 1,000,000.
There is a process of continuous improvement of the occupational health and safety management system in ISA’s subsidiaries with high-risk activities, whose purpose is to manage occupational hazards and contemplate the execution of activities aimed at protecting the lives of people and that is maintained through the health and safety management systems certified under quality management systems and complying with the provisions of the legislation of each of the countries in which ISA is present.
104
Accident Management
During 2024, exposure to occupational risk decreased by 1.03%, with 458,222 less man-hours of work compared to 2023, primarily as a result of the implementation of the “Conectados con la vida” (Connected to Life) program, new controls and the implementation of the cultural transformation model. Also, in 2024, the integrated accident frequency rate (own personnel and contractors) decreased by 35.10% with the new TRIF methodology specified below compared to 2023. Throughout the year, the number of work accidents per 1,000,000 hours of work has been lower, as set forth in the table below:
Table 50 – Integrated Frequency Index for Employees and Contractors
|
|
|
For the year ended December 31, |
||||
|
Metric |
|
2024 |
|
2023 |
|
2022 |
|
Man-hours worked |
|
43,962,050 |
|
44,400,342 |
|
48,602,913 |
|
Total accidents |
|
88 |
|
137 |
|
347 |
|
TRIF (1) |
|
2.0 |
|
3.09 |
|
5.66 |
|
(1) |
Before 2022 the calculation method used was the frequency rate. |
Fatal Accidents
During 2024, ISA did not have any fatal accidents. However, during 2024, one of ISA’s contractors had a fatal accident.
|
3.12 |
Related Party and Intercompany Transactions |
Set forth below is a description of material related-party transactions. For additional information about transactions with related parties, see Note 30 to our consolidated financial statements.
Oleoducto Central S.A.S. (Ocensa)
Ecopetrol S.A. has entered into several agreements with its 72.65%-owned subsidiary, Ocensa, of which the following are the most significant:
In March 1995, Ecopetrol S.A. entered into an agreement for the transportation of crude oil through the Ocensa pipeline. Pursuant to the terms of this agreement, Ecopetrol S.A. was required to make monthly payments that varied, depending on both the volume of crude oil transported through the pipeline and a tariff imposed by Ocensa based on Ocensa’s financial projections and their expected volumes of crude oil. On January 17, 2013, this agreement was amended as a result of Ocensa’s new business model. Among other changes, this amendment to the transportation agreement establishes the payment of the tariff, calculated according to resolutions issued by the Ministry of Mines and Energy. In 2013, another amendment was executed that modified the terms by which the payments of invoices should be made. In 2020, an amendment including security standards for the supply chain was executed. On July 29, 2014, after Ocensa implemented and carried out an open process to receive offers to enter into transportation agreements for an extended capacity of approximately 135,000 barrels per day in Ocensa’s pipeline (the P135 Project), Ocensa accepted the proposal made by Ecopetrol S.A. to enter into a ship-or-pay transportation agreement for 70,000 barrels per day of crude.
On November 20, 2014, after a total and definitive assignment agreement that was notified to Ocensa on December 15, 2016, Ecopetrol S.A. became the successor of Hocol, of a ship-or-pay transportation agreement for 17,500 barrels per day, thus increasing our contracted capacity in the P135 Project to 87,500 barrels per day. On July 1, 2017, with the consent of Ecopetrol S.A. and Ocensa, and as contemplated in the Act of Commencement of Operations issued by the Ministry of Mines and Energy (Resolution 31344 dated April 27, 2017), Ocensa started supplying increased capacity in the P135 Project.
105
On July 17, 2018, Ecopetrol S.A. and Ocensa entered into an amendment to the P135 Project ship-or-pay transportation agreements mentioned above (consisting of a capacity of 87,500 barrels of crude per day) in order to adjust the standard tariff and monetary conditions. This followed Ocensa having entered into a settlement agreement as approved by an arbitration panel with Frontera Energy Colombia and executed on May 15, 2018, pursuant to which the transportation tariff and monetary conditions in Ocensa’s ship-or-pay transportation agreement with Frontera Energy Colombia in respect of the P135 Project were adjusted. Therefore, in application of regulatory principles, Ocensa offered similar terms to the remaining shippers of the P135 Project, including Ecopetrol S.A., and executed (i) settlement agreements with those who accepted Ocensa’s offer and (ii) the corresponding amendments to the transportation agreements. In 2024, the transportation services provided by Ocensa to Ecopetrol S.A. under these two agreements amounted to USD 1,235.72 million.
On October 28, 2013, Ecopetrol entered into a natural gas supply contract in force until November 30, 2018, pursuant to which Ecopetrol S.A. supplies gas to Ocensa and receives a fixed price per MBTU (Million British Thermal Units). This agreement replaced the contract for natural gas supply in Cusiana entered into in December of 2004, under which Ocensa paid a variable rate to Ecopetrol. Since December 1, 2018, the parties have agreed to extend the term of the agreements for one-year terms, most recently on November 25, 2022, when the term of the agreement was again extended for another one-year term until November 24, 2023. In January 2022, Ecopetrol and Ocensa entered into a crude oil supply contract, pursuant to which Ecopetrol is required to supply blending and light mixing crude oils for the operation of Ocensa’s pumping equipment. The price of the contract is determined by a formula for each type of crude oil. The term of the contract is one year, renewable for an additional one-year term. In 2024, Ecopetrol S.A. received an aggregate sum of USD 21.74 million, with taxes included.
Ecopetrol and Ocensa also have a gas supply agreement for the electricity generation of the Cusiana pump station. The term of the contract is one year, renewable for an additional one-year term. In 2024, Ecopetrol S.A. received an aggregate sum of USD 4.97 million.
Ocensa has entered into the following agreements, among others, with some of our other subsidiaries:
In March 1995, Equion and Santiago Oil Company entered into agreements for the transportation of crude oil through the Oleoducto Central S.A. (Ocensa) pipeline. Equion and Santiago Oil Company held 5% of transportation rights in Ocensa. In 2014, the transportation fees billed by Ocensa were: Equion (USD 44.4 million), Santiago Oil Company (USD 3.8 million) and Hocol (USD 30.8 million). On January 17, 2013, this agreement was amended as a result of Ocensa’s new business model. Among other changes, the amendment to the transportation agreement establishes that tariff payments are to be calculated according to resolutions issued by the Ministry of Mines and Energy, and that the transportation capacity is expressed as a number of barrels for each segment of the pipeline. On May 23, 2013, another amendment was executed that modified the terms by which the payments of invoices should be made. On October 26, 2022, Equion and Santiago Oil Company made a total and definitive assignment of their transportation agreements with Ocensa, to J Energy Colombia SAS. In 2024, Ocensa provided transportation services to Hocol, as assignee of transportation rights from original shippers and was paid USD 23.47 million for such services.
Oleoducto de Colombia S.A. (ODC)
Ecopetrol S.A. entered into the following agreements with its 78.19%-owned subsidiary, ODC: In July 1992, a ship-and-pay agreement was signed for the transportation of hydrocarbons. Pursuant to this agreement, Ecopetrol S.A. must pay a previously agreed tariff for the volume of hydrocarbons transported. The duration of this agreement is indefinite; however, the contract is intended to remain in force as long as Ecopetrol S.A. holds shares in Oleoducto de Colombia S.A., whether directly, or through an affiliate. As of January 2013, the parties agreed that the applicable tariff would be the one set by the Ministry of Mines and Energy (the MME Tariff). The tariff was updated by the MME in September 2024, valid until June 2025. In 2024, payments made by Ecopetrol S.A. under this agreement amounted to USD 168.41 million.
106
ODC has entered into the following agreements with some of our other subsidiaries:
Between March 1992 and January 1993, Hocol, Equion and Santiago Oil Company each entered into agreements with ODC for the transportation of crude oil through the Vasconia-Coveñas pipeline. The term of each of these agreements is indefinite. As of January 2013, the applicable tariff is the one set by the Ministry of Mines and Energy. In 2024, the transportation fees billed by ODC were: Equion (USD 0.03 million) and Hocol (USD 2.67 million). On December 23, 2022, ODC entered into a crude oil transportation contract with Equion. The term of this agreement is one year, effective as of January 1, 2023. The agreement applies the current tariff established by the Ministry of Mines and Energy. On December 26, 2023, an amendment to the agreement was executed to extend its term for an additional year. On December 26, 2024, another amendment to the agreement was executed to extend its term for an additional year. As of December 31, 2023, the advance payment balance is USD 0.004 million.
Oleoducto de los Llanos Orientales (ODL)
Ecopetrol S.A. has entered into the following agreements, among others, with its 65%-owned subsidiary, ODL:
In December 2009, Ecopetrol S.A. entered into a service agreement with ODL to transport crude oil. This agreement was subsequently replaced in January 2014 by a new agreement that expired in December 2020. The contract stipulated a ship-or-pay clause for the transportation of 167,000 barrels per day (bpd) in 2014, 149,000 bpd in 2015 and 139,000 bpd until 2020. In January 2017, the agreement was amended to maintain the economic and commercial balance for the parties, based on changes to the system’s standard condition of the system (to transport crude oil with a 690 cStk viscosity), reducing the “ship-or-pay” capacity from 139,000 bpd to 129,139 bpd until December 2020. On March 5, 2021, Ecopetrol S.A. and ODL entered into an amendment that adjusted terms and definitions, allowing for the transportation of barrels that had been paid but not transported. On November 25, 2021, an amendment was made to adjust terms and definitions of the applicable TRM and to extend the term for providing ship-and-pay transportation services until November 2026. Payments by Ecopetrol S.A. under this contract were COP 1,096.31 billion in 2024.
On August 1, 2015, ODL entered into an indefinite management agreement with Oleoducto Bicentenario by means of which ODL receives legal representation and provides management services to Oleoducto Bicentenario. On August 1, 2017, the agreement was amended in order to change the way ODL is remunerated by this service, improving the structure of the agreement. Pursuant to the terms of this agreement, Cenit paid to ODL COP 4.84 billion plus applicable taxes in 2024, as a result of the merger between Oleoducto Bicentenario and Cenit.
Ecodiesel
Ecopetrol S.A. entered into a supply agreement for the Barrancabermeja refinery, with Ecodiesel Colombia S.A. (“Ecodiesel”), a company in which Ecopetrol S.A. has a 50% equity interest. The current agreement began on February 1, 2021 (“renewed agreement”) and expires on January 31, 2026. Pursuant to the terms of the renewed agreement, Ecodiesel must deliver to Ecopetrol S.A. and Ecopetrol S.A. must, in turn, purchase a minimum of 50,880 barrels of Ecodiesel’s biodiesel production each month. Payments vary depending on the purchased volumes and the prices of biodiesel. In 2024, Ecopetrol S.A. paid a total of COP 516.34 billion under the current agreement.
Additionally, Ecopetrol S.A., as Cartagena Refinery’s legal agent, signed another supply agreement with Ecodiesel on October 1, 2020, that is valid until September 30, 2023 and on October 4, 2023, Ecopetrol S.A. as Cartagena Refinery´s legal agent, signed a new supply agreement with Ecodiesel, that is in effect until March 31, 2025. On March 31, 2025, Ecopetrol S.A. as Cartagena Refinery´s legal agent, signed a new supply agreement with Ecodiesel, that is in effect until March 31, 2028. Pursuant to the terms of the first this agreement, Ecodiesel must deliver to Cartagena Refinery, and Cartagena Refinery must in turn purchase a minimum of 10,400 barrels of Ecodiesel’s biodiesel production each month. In 2023, Cartagena Refinery paid a total of COP 100.2 billion to Ecodiesel under this agreement. Under the terms of the new agreement, Cartagena Refinery must purchase a minimum of 12,000 barrels of Ecodiesel’s biodiesel production on a monthly basis. In 2024, Cartagena Refinery paid a total of COP 120.42 billion to Ecodiesel under this agreement.
In 2024, Ecopetrol S.A. bought COP 516.34 billion worth of biodiesel from Ecodiesel for its own consumption and COP 120.42 billion worth of biodiesel for Cartagena Refinery’s consumption.
107
Savia Perú S.A.
On February 19, 2016, Ecopetrol S.A., as lender and shareholder of 50%, and Savia Perú S.A., as borrower, entered into a five-year loan agreement for an aggregate principal amount not to exceed USD 70 million. The proceeds of the facility were used to (i) repay short term loans and (ii) pay shortfalls related to final judgments (in case they materialize). The loan agreement accrues interest at an annual rate of 4.99%, which can be adjusted on an annual basis, with semi-annual interest payments and principal payments beginning on the 21 st month following the disbursement date. Total disbursement was USD 57 million through the disbursement period ended on December 31, 2017. On December 11, 2019, Ecopetrol S.A. and Savia Perú agreed on an amendment to the terms of the loan agreement, in order to revise the payment schedule of the loan, without changing the original maturity, nor the interest rate. As of December 2020, the outstanding balance of the obligation with Ecopetrol S.A. is USD 28.3 million under the loan agreement. KNOC, as shareholder of the other 50% of Savia Perú S.A., signed a facility under the same terms and conditions as described above.
On January 19, 2021, Ecopetrol S.A. signed a Share Purchase Agreement with De Jong Capital LLC, through one of its subsidiaries as buyer, pursuant to which Ecopetrol S.A. sold its 50% ownership interest in Offshore International Group Inc. (OIG; Savia Perú’s parent company). KNOC also sold its participation on OIG (the remaining 50%) to De Jong Capital LLC, under the same terms and conditions as Ecopetrol S.A.
On the same date, Ecopetrol S.A. and Savia Perú agreed on an amendment to the terms of the loan agreement described above, in order to revise the payment schedule of the loan and its maturity, with the interest rate remaining unchanged.
After the occurrence of an event of default due to failure to make a principal repayment by Savia Perú S.A. on September 2021, a restructuring process began in coordination with KNOC which sought to maximize the possibility of recovering the outstanding loan. The process concluded in February 2022 with the execution of a new set of documentation that incorporates: (i) an increase in the interest rate to 6.5%, (ii) the creation of a pledge over 100% of the shares of Procesadora de Gas Pariñas S.A.C. (a subsidiary of OIG), (iii) the creation of a trust structure holding the collection rights of Savia Perú S.A. derived from its sales to PetroPeru with Ecopetrol and KNOC as beneficiaries, (iv) monthly interest and principal payments, (v) mandatory prepayments under certain specific circumstances, and (vi) the obligation by Savia Perú S.A. to apply commercially reasonable efforts to prepay all the loans with any excess cash. The final maturity of the loan was December 2023.
As of the date of this annual report, Savia Perú has no pending or outstanding obligations to Ecopetrol S.A., under this loan agreement. Savia Perú is no longer a related party to the Ecopetrol Group.
Transactions with Other State-Controlled Entities
In the ordinary course of business, we enter into transactions with other state-owned enterprises that include but are not limited to the following:
| ● | Selling and purchasing goods, including crude oil purchases of ANH royalties (see below); |
| ● | Selling and purchasing properties and other assets; |
| ● | Rendering and receiving services; |
| ● | Leasing assets; |
| ● | Depositing and borrowing money; and |
| ● | Using public utilities. |
We have an agreement with the ANH by which we purchase all crude oil delivered to the ANH as royalties and economic rights by us and by third parties. The purchase price is calculated according to a formula set forth in a contract between Ecopetrol S.A. and the ANH that reflects our crude export sales prices, a quality adjustment for API gravity and sulfur content, transportation rates from the wellhead to the export ports or internal refineries, marketing fee and diluent cost. We export and incorporate into Ecopetrol’s refining segment the physical product purchased from the ANH as part of our ordinary business.
108
For the period between January 2024 and December 2024, we purchased 35.5 million barrels of crude oil from the ANH corresponding to royalties and economic rights paid in kind by oil producers in Colombia. The previous agreement between the ANH and us ended on June 30, 2023, and a new agreement was then executed by ANH and us for a term of July 2023 to June 2026. See section Business Overview—Applicable Laws and Regulations—Regulation of Exploration and Production Activities—Business Regulation—Royalties for a description of the current royalty scheme.
The ANH is a state agency responsible for the administration and regulation of the nation’s hydrocarbon resources and therefore it is controlled by the State. The State’s control of the ANH arises from the fact that it is a state agency and hence a part of the Colombian Government. On the other hand, Ecopetrol S.A. is a state-owned enterprise and the Nation’s control of Ecopetrol S.A. results from the fact that it is one of our shareholders and owns more than a majority of our common shares. Neither Ecopetrol S.A. nor the ANH have the ability to control each other’s actions. Notwithstanding that as a matter of Colombian law neither entity can influence the other, as a matter of U.S. regulation, they are considered to be under common control.
In addition, as an importer and refiner of hydrocarbons in Colombia, Ecopetrol S.A. and Cartagena Refinery are counterparties of the FEPC. See section Business Overview—Applicable Laws and Regulations—Regulation of Refining and Petrochemical Activities—Regulation Concerning Production and Prices—Fuel Price Stabilization Fund (FEPC) . Pursuant to that regulatory framework, for the year ended December 31, 2024, Ecopetrol S.A. recorded COP 5.96 trillion in accounts receivable due from FEPC, while Cartagena Refinery recorded COP 1.66 trillion in accounts receivable due from FEPC.
3.13 Insurance
As part of the risk retention and transfer strategy, the Ecopetrol Group has insurance programs that seek local and international coverage for assets, operations and personnel in the upstream, midstream and downstream segments for hydrocarbons and electric power transmission and toll roads concessions, as summarized below.
Also, as part our insurance strategy, Ecopetrol has a wholly owned subsidiary denominated Black Gold Re Limited (BGRe), which is a Captive Reinsurance company that began operations on August 24, 2006 and is in charge of overseeing and optimizing the management of the Ecopetrol Group’s Corporate insurance program. BGRe meets its objectives by adjusting the levels of transfer and retention of risk, with the goal of protecting the Ecopetrol Group’s assets and operations, strengthening negotiation capabilities in the insurance market and minimizing adverse effects from market cycles.
BGRe designs and implements retention and risk transfer strategies, according to the needs of each business segment, optimizing the placement of the corporate insurance program, generating technical and economic efficiencies for the Ecopetrol Group.
In 2024, BGRe increased its level of retention from USD 145 million to USD 185 million, supported by a retention capacity study, which was carried out in 2024.
As of the date of this annual report, the policies in which retention has been successful are Property All Risk, Sabotage Terrorism (ST), Crime, Cyber, as well as deductible differences (DID Multi).
The Ecopetrol Group also has a directors’ and officers’ (DO) liability insurance policy.
Finally, ISA also has a robust underwriting strategy that provides coverage for the main risks and complies with its risk retention and transfer guidelines. Below you will also find the detailed scope of its program.
|
3.13.1 |
Upstream, Midstream and Downstream |
We have a clear and defined corporate policy based on risk financing guidelines that summarizes the Company’s risk transfer and retention alternatives and provides support and guidance for all the insurance-related issues of all our affiliated and subsidiary companies.
109
As a proactive strategy to deal with the hardening conditions of the worldwide reinsurance market until 2019, in July 2020, Ecopetrol S.A. became a member of the Everen, which is an energy industry mutual insurance company based in Hamilton, Bermuda, established since 1972. This organization operates based on the concept of mutualization, in which several companies threatened by similar risks and with comparable exposure profiles decide to constitute a common fund, based on the individual contribution of each one, depending on the size of their operation and the estimated losses they may suffer as a result of the materialization of such risks. Everen is insuring almost USD 4 trillion of global energy assets. Its credit rating is A (SP) and A2 (Moody’s). Currently, 72 companies in the world are members of Everen. Ecopetrol Group, as a member of Everen, has access to cost-effective insurance capacity with a minimum deductible of USD 10 million and up to USD 450 million per occurrence for all owned assets.
Under the model described above, the corporate insurance program has been consolidated in two main categories:
|
(i) |
Category A: Coverage through Everen and reinsurance market that includes the risks of physical damage, control of wells and leakage, pollution or contamination (which for the purposes of this annual report, are included in the limit of the third-party liability coverage). |
|
(ii) |
Category B: Coverage only through the traditional insurance and reinsurance market that includes third party liability, directors and officers, cargo, crime, charterers’ liability, and cyber-attack insurance. |
These structures provide coverage for our consolidated downstream, upstream, and midstream operations in excess of our local insurance programs (when applicable).
In the tables below, we set forth our insurance program for our downstream, upstream and midstream operations and the companies covered, along with related limits and coverage details.
Table 51 – Category A: Coverages through the Everen and Reinsurance and Insurance Market for the Downstream Segment
|
|
|
Limit (eel / agg) (1) |
|
Deductible |
|
Ecopetrol |
|
|
|
|
||||
|
USD Millions |
|
Onshore |
|
Offshore |
|
Onshore |
|
Offshore |
|
Downstream |
|
Cartagena Refinery |
|
Esenttia |
|
Policies |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Property all risk |
|
2,300 |
|
N/A |
|
5.0 |
|
N/A |
|
X |
|
X |
|
X |
|
Sabotage and terrorism |
|
600 |
|
N/A |
|
0.5 |
|
N/A |
|
X |
|
X |
|
X |
(1) Eel: each and every loss. Agg: Aggregate.
Table 52 – Category A: Coverages through the Everen and Reinsurance and Insurance market for the Upstream segment
|
|
|
Limit (eel / agg) (1) |
|
Deductible |
|
Ecopetrol |
|
|
|
ECP |
|
|
||||
|
USD Millions |
|
Onshore |
|
Offshore |
|
Onshore |
|
Offshore |
|
Upstream |
|
Hocol |
|
America |
|
Permian |
|
Policies |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Property all risk (2) |
|
650 |
|
650 |
|
1.0 |
|
1.0 |
|
X |
|
X |
|
X |
|
X |
|
Sabotage and terrorism |
|
450 |
|
450 |
|
0.5 |
|
0.5 |
|
X |
|
X |
|
N/A |
|
N/A |
|
Control of wells (3) |
|
800 |
|
800 |
|
1.0 |
|
5.0/6.0 |
|
X |
|
X |
|
X |
|
X |
(1) Eel: each and every loss. Agg: Aggregate.
(2) USD 200 million Property All Risk but USD 350 million Maximum Loss limit and in the aggregate in respect of earthquake. Everen limit of USD 450 million applies as primary layer of those limits.
(3) USD 350 million Control of Wells Maximum Loss limit. Everen limit of USD 450 million applies as primary layer of those limits.
110
Table 53 – Category B: Transversal Coverages through the Traditional Insurance and Reinsurance Market for the Downstream, Upstream and Midstream Segments
|
|
|
Limit |
|
|
|
|
|
Cartagena |
|
|
|
Esenttia |
|
|
|
|
|
Santiago |
|
ECP |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ECP |
|
ECP |
|
USD Millions |
|
(eel / agg) (1) |
|
Deductible |
|
Ecopetrol |
|
Refinery |
|
Esenttia |
|
MB |
|
Equión |
|
Hocol |
|
Oil |
|
America |
|
Permian |
|
Brazil |
|
Cenit |
|
Ocensa |
|
ODL |
|
OBC |
|
ODC |
|
Invercolsa |
|
Trading Asia |
|
Trading LLC |
|
Policies |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Third party liability(2) |
|
500 |
|
10.0 |
|
X |
|
X |
|
X |
|
X |
|
N/A |
|
X |
|
N/A |
|
X |
|
X |
|
N/A |
|
X |
|
X |
|
X |
|
N/A |
|
X |
|
N/A |
|
X |
|
X |
|
Crime |
|
60 / 120 |
|
0.5 |
|
X |
|
X |
|
X |
|
X |
|
X |
|
X |
|
N/A |
|
X |
|
X |
|
X |
|
N/A |
|
N/A |
|
N/A |
|
N/A |
|
N/A |
|
X |
|
X |
|
X |
|
Directors Officers |
|
161 |
|
Various |
|
X |
|
X |
|
X |
|
X |
|
X |
|
X |
|
X |
|
X |
|
X |
|
X |
|
X |
|
X |
|
X |
|
X |
|
X |
|
X |
|
X |
|
X |
|
Cargo |
|
50 / 120 |
|
3% dispatch |
|
X |
|
X |
|
N/A |
|
N/A |
|
N/A |
|
X |
|
N/A |
|
N/A |
|
N/A |
|
N/A |
|
N/A |
|
N/A |
|
N/A |
|
N/A |
|
N/A |
|
N/A |
|
X |
|
X |
|
Charterers |
|
750 |
|
0.02 |
|
X |
|
X |
|
N/A |
|
N/A |
|
N/A |
|
X |
|
N/A |
|
N/A |
|
N/A |
|
N/A |
|
N/A |
|
N/A |
|
N/A |
|
N/A |
|
N/A |
|
N/A |
|
X |
|
X |
|
Cyber(3) |
|
85 / 150 |
|
Various |
|
X |
|
X |
|
X |
|
X |
|
X |
|
X |
|
X |
|
X |
|
X |
|
X |
|
X |
|
X |
|
X |
|
N/A |
|
X |
|
X |
|
X |
|
X |
|
(1) |
Eel: each and every loss. Agg: Aggregate. |
|
(2) |
Ecopetrol Permian’s limit is USD 175 million. |
|
(3) |
Coverage through the Everen and reinsurance and insurance market. Coverage under section 1 (buyback for property) does not apply to midstream subsidiaries. |
Our third-party liability insurance policy covers Ecopetrol S.A., our subsidiaries and affiliates in excess of local underlying policy limits for claims made against them by third parties. Our commercial general liability coverage will pay on behalf of or indemnify amounts for which an insured becomes legally obligated to pay, including damages in respect of bodily injury, property, pollution, and product liability. Coverage of bodily injury and property damage is subject to coverage territory during the policy period. The Ecopetrol Group also has a directors’ and officers’ (DO) liability insurance policy.
Ecopetrol S.A.’s midstream subsidiaries continue having an independent program for their oil transportation companies (including crime and DO policies).
Table 54 – Midstream’s Program
|
|
|
Limit (eel / agg) (1) |
|
Deductible |
|
|
|
|
|
|
|
|
|
|
||||
|
USD Millions |
|
Onshore |
|
Offshore |
|
Onshore |
|
Offshore |
|
Cenit |
|
Ocensa |
|
ODL |
|
OBC (7) |
|
ODC |
|
Policies |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Property all risk (2) |
|
200 |
|
200 |
|
0.5 |
|
0.5 |
|
X |
|
X |
|
X |
|
X |
|
X |
|
Sabotage and terrorism (3) |
|
70/25 |
|
30 |
|
0.075 |
|
0.15 |
|
X |
|
X |
|
X |
|
X |
|
X |
|
Third party liability |
|
100 |
|
100 |
|
0.1/0.5 |
|
0.5 |
|
X |
|
X |
|
X |
|
X |
|
X |
|
Environmental Liability (4) |
|
20 |
|
N/A |
|
1.0 |
|
N/A |
|
X |
|
X |
|
X |
|
X |
|
X |
|
Directors Officers (5) |
|
100 |
|
N/A |
|
N/A |
|
N/A |
|
X |
|
X |
|
X |
|
X |
|
X |
|
Crime |
|
50 |
|
N/A |
|
0.175 |
|
N/A |
|
X |
|
X |
|
X |
|
X |
|
X |
|
Cyber (6) |
|
15 |
|
15 |
|
0.5 |
|
0.5 |
|
X |
|
X |
|
X |
|
X |
|
X |
(1) Eel: each and every loss. Agg: Aggregate.
(2) USD 200 million each company and an aggregated excess shared limit of USD 750 million (aggregate for the policy period 18 months).
(3) Does not include Caño Limón – Coveñas (CLC) and Oleoducto Transandino (OTA) systems owned by Cenit.
(4) Environmental liability gradual pollution coverage, which consists of two different policies; one for pipelines and one for stations.
(5) Aggregate limit increased to USD 100 million worldwide coverage. Deductible only for coverage No.2 in the USA.
(6) Cyber Risk. Property damage exclusion which includes buy-back coverage.
(7) All insurance coverages were transferred to Cenit, as a result of the merger between Oleoducto Bicentenario and Cenit on December 28, 2023.
(8) Onshore deductible of USD 0.1 million, except for seepage and pollution of USD 0.5 million.
Regarding the offshore operations in the U.S. Gulf Coast, Ecopetrol America LLC is party to Operating Agreements, or OAs, that include customary conditions, and which contain similar terms and provisions to those in the Model Form of Offshore Deepwater Operating Agreement of the American Association of Professional Landmen. In general, pursuant to these OAs, the obligations, duties, and liabilities of the contract parties are several, and not joint or collective, for all operations covered by the OAs.
Regarding the onshore operations in the U.S., Permian has been included since its beginning in the Control of Wells, DO, and cyber and crime policies. In 2020, we obtained a stand-alone policy for the third-party liability coverage. Ecopetrol S.A. has a contract with an insurance broker for local policies related to domestic operations. The local policies relate to transit, accidents, mandatory policies, liability mandatory policies, and personal accidents policies, among others.
111
Our corporative insurance program is focused on addressing insurance needs related to operating a hydrocarbons-oriented business, however, the “Risk Retention and Transfer” strategy is currently designing and reviewing our current insurance needs in order to get coverage for the new energy transition projects. We are constantly monitoring the international insurance markets to analyze and review alternatives solutions and assure proper coverage for future projects. In 2025, we intend to continue our review of different coverage alternatives for the energy transition segment, seeking to start implementing as soon as the Company gets ready to begin the low emission projects.
3.13.2 Electric Power Transmission and Toll Roads Concessions
ISA and its subsidiaries have a robust insurance program, which sets basic guidelines for its risk retention and transfer policy. Consistent with its insurance guidelines, ISA transfers risk to the traditional market under regional and local insurance programs. We are currently assessing the potential for efficiencies to optimize ISA’s risk retention and transfer strategy.
In order to strengthen its insurance program, in 2014, ISA registered Linear Systems Re as the captive insurance company for the group. As of the date of this annual report, Linear Systems Re has USD 11.5 million as shareholder equity and participated in the placement and risk retention of property damage, sabotage terrorism policies allowing direct access to the commercial reinsurance markets. In 2024, Linear Systems Re increased its level of retention to USD 1 million annually, according to the retention capacity study carried out during 2024.
Likewise, along with the corporate risk team and its brokers, on an annual basis, ISA examines the need to conduct various analyses, such as Probable Maximum Loss studies, Estimated Maximum Losses, to support and/or define coverages, limits and deductibles among others.
The insurance program responds to high placement standards, which include, among many others: (i) hiring policies with reinsurers with a minimum rating standard of A- or higher, and (ii) contracting with insurance companies and brokers that are present across all the countries in which ISA operates.
According to the above, the main policies of the corporate insurance program correspond to the following:
Table 55 – ISA’s Program
|
|
|
Limit (eel / |
|
|
|
ISA |
|
|
|
|
|
|
|
|
|
|
|
USD Millions |
|
agg) (1) |
|
Deductible |
|
Colombia |
|
Perú |
|
Chile |
|
Bolivia |
|
Brazil |
|
Argentina |
|
Policies |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Property all risk (2) |
|
80 |
|
Various |
|
X |
|
70 |
|
80 |
|
10 |
|
22 |
|
N/A |
|
Sabotage and terrorism (ST) |
|
50 |
|
Various |
|
X |
|
20 |
|
20 |
|
10 |
|
N/A |
|
N/A |
|
Equipment Electric (EE) (3) |
|
172 |
|
10 |
% |
X |
|
48 |
|
15 |
|
N/A |
|
N/A |
|
N/A |
|
Construction All Risk |
|
75 |
|
10 |
% |
X |
|
X |
|
X |
|
N/A |
|
X |
|
N/A |
|
Directors Officers |
|
60 |
|
N/A |
|
X |
|
X |
|
X |
|
X |
|
10 |
|
N/A |
|
Cyber (4) |
|
35 |
|
Various |
|
X |
|
X |
|
X |
|
X |
|
X |
|
N/A |
|
Crime |
|
15/30 |
|
0.20 |
|
X |
|
X |
|
X |
|
1 |
|
N/A |
|
N/A |
(1) Eel: each and every loss. Agg: Aggregate.
(2) The deductible of 2% loss and a minimum that depends on the sum insured for machinery and equipment in each country.
(3) A 10% deductible applies on each and every loss above USD 250. Deductible applies 10% each and every loss with a minimum of USD 250.
(4) The policy is composed of two limits: (i) Traditional Cyber, with a limit of USD 35 million, and (ii) cyber damage, with a limit of USD 25 million, excess of 2% insurable value of the asset. The program is placed as a master program in Brazil for regulatory purposes.
Note: Different coverages and conditions may apply in each country for each subsidiary.
The policies detailed above for Ecopetrol Group, are subject to particular conditions, limits, sub-limits, deductibles, guarantees and exclusions applying for each line of insurance and each coverage. For purposes of this annual report, only the main limits and deductibles were mentioned in each group.
112
3.14 Human Resources/Labor Relations
|
3.14.1 |
Employees |
As of December 31, 2024, the Ecopetrol Group had 19,581 employees, a decrease of 0.4% compared to 2023, equivalent to 76 employees, primarily due to a staffing change aligned with the retirement plan and number of retirees.
The table below presents the breakdown of our employees according to the business segments where they work, and the personnel of our subsidiaries for the years ended December 31, 2024, 2023 and 2022.
113
Table 56 – Ecopetrol Group’s Employees
|
|
|
For the year ended December 31, |
||||
|
|
|
2024 |
|
2023 |
|
2022 |
|
|
|
(Number of employees) |
||||
|
Ecopetrol S.A. |
|
|
|
|
|
|
|
Hydrocarbons |
|
|
|
|
|
|
|
Upstream |
|
|
|
|
|
|
|
Exploration |
|
205 |
|
211 |
|
191 |
|
Production |
|
2,563 |
|
2,624 |
|
2,334 |
|
Others |
|
1,273 |
|
1,268 |
|
1,391 |
|
Total Upstream |
|
4,041 |
|
4,103 |
|
3,916 |
|
Downstream |
|
— |
|
— |
|
— |
|
Refining |
|
2,522 |
|
2,576 |
|
2,532 |
|
Marketing |
|
— |
|
— |
|
— |
|
Others |
|
— |
|
— |
|
— |
|
Total Downstream |
|
2,522 |
|
2,576 |
|
2,532 |
|
Transport |
|
— |
|
— |
|
— |
|
Others |
|
123 |
|
— |
|
— |
|
Marketing* |
|
157 |
|
162 |
|
142 |
|
Total Hydrocarbons |
|
6,843 |
|
6,841 |
|
6,590 |
|
Low-Emissions Solutions |
|
138 |
|
108 |
|
95 |
|
Total Operations |
|
6,981 |
|
6,949 |
|
6,685 |
|
Corporate |
|
2,684 |
|
2,901 |
|
2,811 |
|
Total Ecopetrol S.A. |
|
9,665 |
|
9,850 |
|
9,496 |
|
Ecopetrol America LLC. |
|
20 |
|
22 |
|
36 |
|
Ecopetrol Permian LLC. |
|
47 |
|
54 |
|
54 |
|
Ecopetrol USA |
|
37 |
|
37 |
|
36 |
|
Ecopetrol US Trading |
|
6 |
|
3 |
|
— |
|
Capital AG |
|
1 |
|
1 |
|
— |
|
Bioenergy S.A.S. |
|
— |
|
— |
|
— |
|
Bioenergy Zona Franca S.A.S. |
|
— |
|
— |
|
— |
|
Hocol S.A. |
|
397 |
|
400 |
|
367 |
|
Equion Energía Limited |
|
18 |
|
24 |
|
23 |
|
Oleoducto Central S.A. |
|
281 |
|
277 |
|
272 |
|
Oleoducto de Colombia S.A. |
|
40 |
|
28 |
|
26 |
|
Oleoducto de los Llanos S.A. |
|
69 |
|
77 |
|
75 |
|
Oleoducto Bicentenario de Colombia S.A.S.* |
|
— |
|
— |
|
— |
|
Refinería de Cartagena S.A.S. |
|
43 |
|
43 |
|
47 |
|
Ecopetrol Óleo e Gás do Brasil Ltda. |
|
34 |
|
38 |
|
37 |
|
Esenttia S.A. |
|
406 |
|
422 |
|
416 |
|
Esenttia MB |
|
39 |
|
41 |
|
41 |
|
Cenit Transporte y Logistica de Hidrocarburos S.A.S. |
|
1,142 |
|
1,140 |
|
1,107 |
|
Invercolsa |
|
2,226 |
|
2,181 |
|
2,153 |
|
Ecopetrol Energía S.A. E.S.P |
|
— |
|
— |
|
— |
|
Ecopetrol Asia Trading |
|
9 |
|
8 |
|
4 |
|
Electric Power Transmission and Toll Roads Concessions |
|
|
|
|
|
|
|
Interconexión Eléctrica S.A. E.S.P |
|
5,101 |
|
5,011 |
|
4,713 |
|
TOTAL |
|
19,581 |
|
19,657 |
|
18,903 |
*On December 28, 2023, Oleoducto Bicentenario merged with Cenit Transporte y Logística de Hidrocarburos S.A.S., with Oleoducto Bicentenario ceasing to exist and all of its assets and liabilities, rights and obligations being assumed by Cenit Transporte y Logística de Hidrocarburos S.A.S.
114
As of December 31, 2024, Kalixpan Servicios Técnicos, S. de R.L. de C.V. was in liquidation, and Topili Servicios Administrativos S. de R.L. de C.V. was acquired by Esenttia and did not have direct employees. Additionally, Ecopetrol Global Energy and Black Gold RE did not have direct employees.
During 2024, 568 employees left Ecopetrol due to voluntary or dismissal retirement at the professional-technical, operative and management level. Therefore, as of December 31, 2024, the Ecopetrol’s employee turnover rate was 5.88%. We calculate the employee turnover rate by dividing the number of employees who left the company by the total number of employees at the end of the period.
Ecopetrol is implementing a new operating model, referred to as project “Átomo”, designed to support the delivery of its long-term corporate strategy. This group-wide effort focuses on adapting the organization to the differentiated nature of each of its business lines (Hydrocarbons, Energies for the Transition and Transmission), allowing them to be more autonomous, agile, and specialized. This redesigned model is intended to strengthen synergies across our businesses and provide the appropriate level of guidance from the corporate center to the business lines —enabling speed of execution, efficiencies, and value capture.
Loans and investment in training and development for our employees
To improve the quality of life of our employees, Ecopetrol S.A. extends various types of loans to its employees, including housing loans and general-purpose loans and the amount depends on the applicant’s position level and payment capacity. Ecopetrol S.A. does not guarantee any loans made by third parties. In 2024, Ecopetrol S.A. extended 1,662 housing loans for a total of COP 734.95 billion, education loans for a total of COP 2.28 billion and 3,035 general-purpose loans for a total of COP 75.77 billion. In 2024, Ecopetrol S.A. also provided on-site and external training and development, which totaled to COP 34.12 billion, and it extended a total of COP 269.6 billion in subsidies for education.
We have not provided loans (including housing loans), extended, or maintained credit lines, arranged for the extension of credit by third parties, materially modified or renewed an extension of credit lines, in the form of a personal loan to or for any of our executive officers since our ADSs were registered under the Exchange Act.
We do not offer loans to any of our executive officers.
Labor Regulation
In accordance with Article 123 of the Colombian Political Constitution and Article 7 of the Law 1118 of 2006, our employees are considered “public servants,” even though they are subject to the common labor law. As such, their conduct is subject to the rules of those who manage public goods and assets and can be considered responsible for their illegal actions and omissions in accordance with the following regimes: (i) disciplinary (Law 1952 of 2019), (ii) criminal or (iii) civil.
Principles of the Culture Statement.
The Ecopetrol Group has made progress in consolidating the Principles of the Corporate Culture Statement: (i) life first, (ii) ethics and transparency, (iii) excellence, (iv) leadership, (v) innovation and (vi) collaboration.
According to the results of the Culture and Work Environment 2024 survey, made with the support of the Great Place to Work® Institute, with 11,697 persons, 97% (favorability) of the workers affirmed ‘knowing and promoting the six principles of the Ecopetrol Group’s Cultural Statement’.
This survey, of international standard, included questions related to three main topics: (i) “Culture”, focused on the extent to which employees behave in a manner consistent with the “Culture Statement”; (ii) “Leadership”, focused on how people in leadership positions in the Company encourage the behaviors expected of employees and create positive work environments; and (iii) “Work environment”, focused on the experience employees and their satisfied:
| ● | 77.8 is the Ecopetrol Group’s Bonding Index which positions it in an ‘outstanding’ stage according to the valuation scale established by Great Place to Work®. This index summarizes the strength of the bond that unites the employee to the organization, based on the joint consideration of transactional and affective aspects. |
115
| ● | 64.9 is the Work Environment Index of the Ecopetrol Group, which places it in a ‘Very Satisfactory’ stage according to the valuation scale established by Great Place to Work®. This synthesizes the achievement reached by the organization in all aspects that summarize the employee’s experience. |
Diversity and Inclusion
We are committed to adding value to diversity, embracing differences, and fostering the development of increasingly inclusive environments where all individuals feel welcomed, appreciated, treated with fairness and respect, and where they receive equal opportunities to contribute their best. The Company develops workplace practices aligned with this framework, applicable to the Board of Directors, senior executives, and all individuals working in Grupo Ecopetrol (GE). In 2024, Ecopetrol updated its Diversity, Equity, Inclusion and Belonging Strategy (DEIP), called Human Wealth. The purpose of the strategy is to incorporate the DEIP in the culture of the Ecopetrol Group, through products and services that allow territorial dialogue, safe environments for all people and the generation of alliances with actors that value human wealth.
This purpose is leveraged by four strategic lines:
- Human Wealth Approach in the regions: incorporation of relationship models with all stakeholders.
- Vanguard pedagogy: implementing a pedagogical model in line with the needs of the people in the organization.
- Reasonable Adjustments for Human Wealth in all processes.
- Strategic, sensitive and empathetic relationships with communities and group companies.
Also, our strategy is comprised of 6 perspectives, which include: Ethnicity, Gender, Disability and caregiving practices, Generations, Reconciliation y Socio-cultural groups.
We made progress in our objective of providing a more inclusive experience for all our stakeholders and achieving high standards of diversity and inclusion:
| ● | Inclusive environment: people evaluate their experience in terms of diversity and inclusion with a 92% favorability. |
| ● | Ecopetrol was awarded the third ranking company in the practice of Diversity, Equity and Inclusion in Latin America by the CNC ( Centro Nacional de Consultoría ) and received recognition for its progress in the gender perspective from peer companies that participated in the Ranking of Inclusive Companies. |
| ● | Ecopetrol reaffirmed its commitment to gender equity by implementing the Equipares Gold Seal, an initiative of the Ministry of Labor and the United Nations Development Program UNDP. |
|
3.14.2 |
Collective Bargaining Arrangements |
Ecopetrol S.A.
The collective bargaining agreement was signed with the Workers Union of the Petroleum Industry – USO, ADECO, SINDISPETROL, ASINTRAHC, SINTRAMEN, ASOPETROGAS, SUP, ASTECO and UTIPEC, and is valid from January 1, 2023 to December 31, 2026. The agreements reached include improvements in the working conditions of its workers, the commitment to continue promoting diversity, equity and inclusion with a gender focus, new hiring of personnel to strengthen the company’s operation, among other aspects, with criteria of reasonableness, austerity, and efficiency. There are 33 industry unions and 17 company-specific unions, for a total of 50 coexisting unions within Ecopetrol S.A. During 2024, the Company has fully complied with the agreements and commitments derived from the collective bargaining agreements.
The Company manages compliance with union rights regarding the deduction of union dues, permits and union guarantees. Likewise, it fully observes the rules that regulate aspects such as trade union rights and other rights related to freedom of association. As of December 31, 2024, Ecopetrol S.A. had a workforce of 9,665 active workers of which, and in accordance with current legal provisions, 93.24% received benefits from the application of the collective bargaining agreements. In addition, 64.26% of the active workforce of Ecopetrol S.A. was affiliated with at least one of the 50 recognized unions. Moreover, the Company held a total of 571 meetings with union organizations in 2024.
116
Interconexión Eléctrica S.A.
There are 22 labor unions within ISA and its subsidiaries with a total of 1,549 members are covered by 23 collective bargaining agreements that also benefit, per extension, 1,360 additional syndicate members. Additionally, there are two collective bargaining agreements that cover 454 employees (or 8.9% of ISA’s total workforce). The collective bargaining agreements establish certain terms and conditions of employment and are subscribed to on an individual, voluntary basis by employees. Collective bargaining agreements are not negotiated by unions or other representative bodies on behalf of our employees, but rather are developed through informal discussions between management and employees.
Cenit Transporte y Logística de Hidrocarburos S.A.S.
There are fourteen industrial labor unions that coexist within Cenit’s workforce, to which 27.6% of Cenit’s employees are affiliated. In October 2019, Cenit signed a collective bargaining agreement with the Unión Sindical Obrera de la Industria del Petróleo-USO for a term of four years ending on August 30, 2023. The collective bargaining agreement awards union protections and benefits which exceed those established by law. The Agreement was denounced by the Unión Sindical Obrera de la Industria del Petróleo-USO on August 30, 2023. As of the date of this annual report, the union has not delivered a list of demands to Cenit.
|
4. |
Financial Review |
Our consolidated financial statements for the years ended December 31, 2024, 2023 and 2022 were prepared in accordance with IFRS as issued by the IASB.
IFRS differs in certain significant aspects from the current Colombian IFRS (which is the accounting standard we use for local statutory reporting purposes). As a result, our financial information presented under IFRS is not directly comparable to certain of our financial information presented under Colombian IFRS. A description of the differences between Colombian IFRS and IFRS is presented under Financial Review - Summary of Differences between Internal Reporting (Colombian IFRS) and IFRS below.
Our consolidated financial statements were consolidated line by line and all transactions and - balances between subsidiaries have been eliminated. These financial statements include the financial results of all subsidiaries companies controlled, directly or indirectly, by Ecopetrol S.A. See Exhibit 1—Consolidated subsidiaries, associates and joint ventures, to our consolidated financial statements included in this annual report.
|
4.1 |
Factors Affecting Our Operating Results |
Our operating results were affected mainly by: (i) international prices of crude oil, international prices for refined products and local prices for natural gas, (ii) volumes, product mix, and our operational performance, (iii) specific macroeconomics factors, such as inflation, particularly in Latin America, higher interest rates, and the COP/USD exchange rate, (iv) public order situations, (v) regulatory changes, including higher taxes, and (vi) local regulation in Colombia for consumer gasoline and diesel prices and their impact in the Fuel Price Stabilization Fund. Crude oil prices and volumes are particularly important to the results of our exploration and production segments. This is because as export volumes or export prices of crude oil and products decrease or increase, our revenues also do. Results from our refining activities are also affected by the price of crude oil used as raw material, changes in international prices for refined products, drastic changes in demand due to market factors, conversion ratios and utilization rates and refining capacity, all of which affect our refining margins. In the Midstream segment, terrorist attacks by guerillas against our pipelines, illegal valves used to siphon off crude, and other facilities or social unrest can lead to loss of revenues by restricting the availability of transport systems for exports or sales of crude oil and products and/or production activities, in addition to the direct costs of repairing and cleaning.
The inflation rate and the GDP corresponding to countries such as Brazil, Colombia, and Chile, where ISA provides energy transmission services, have a direct effect on the financial results of the Electric Power Transmission and Toll Roads Concessions segment. Results from our electric power transmission and toll roads activities are also affected by availability and competitiveness of alternative energy sources in the markets served by us, expiration or termination of significant contracts or concessions, the operational availability of the electricity transmission systems of other electricity transmission companies that are interconnected with our electricity transmission systems, interest rate fluctuations, changes in regulation and economic policies of the countries where we operate and changes in availability or demand of electricity.
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Finally, changes in the value of foreign currencies, particularly the U.S. dollar against the Colombian Peso, can also have a significant effect on our financial statements. See section Financial Review—Trend Analysis and Sensitivity Analysis for further information.
Sales volumes and prices
Our results from the exploration and production segment depend mainly on our sales volumes and average local and international prices for crude oil and natural gas. Additionally, sales volumes also reflect the purchase of crude oil that we make from third parties and the ANH.
We sell crude oil and natural gas in the local and international markets. We also process crude oil at the Barrancabermeja and Cartagena refineries and sell refined and other petrochemical products in the local and international markets.
Local sales and prices
We have a number of crude oil short-term commercial agreements with local customers, and natural gas short and long-term supply contracts with gas-fired power plants and local natural gas distribution companies. Local sale prices are determined in accordance with existing regulations, contractual arrangements, and the spot market, in turn, linked to international benchmarks. Local sales represented 49.8% of our total revenues, on average, for the past three years.
International sales and prices
Our international sales represented 50.2% of our total revenues, on average, for the past three years.
International sale prices are determined in accordance with contractual arrangements and the spot market, in turn, linked to international benchmarks primarily the ICE Brent benchmark.
A market diversification strategy has allowed us to capture markets where we have been able to obtain higher prices for our crudes and refined products. We sell our crudes and refined products in various regions, such as the U.S., Central America and the Caribbean, Asia and Europe. In our negotiations with potential customers, we seek to use the most liquid benchmark reference prices in each region.
Exploration costs
We account for exploratory drilling costs using the successful efforts method, whereby all costs associated with the exploration and drilling of productive wells are initially capitalized. Costs incurred in exploring and drilling dry or unsuccessful wells are expensed in the period in which the well is determined to be a dry or unsuccessful well and are accounted for under “Exploration and Project expenses.” Consequently, an increase in the number of exploratory wells we declare as dry or unsuccessful are expected to negatively affect our results and may cause volatility in our operating expenses. See Note 4.7 to our consolidated financial statements for a summary of our accounting policy for exploration costs.
Royalties
Each of our production contracts has its own royalty arrangement in accordance with applicable law. Law 141 of 1994 established a royalty fixed rate equivalent to 20% of total production. In 1999, a modification to the royalty system established a sliding scale for royalty percentage linked to the production level of crude oil and natural gas to fields discovered after July 29, 1999, depending on whether the production is crude oil or natural gas, and on the quality of the crude oil produced. Since 2002, as a result of the enactment of Law 756 of 2002, the royalty percentage has ranged from 8% for fields producing up to five mbd to 25% for fields producing more than 600 mbd. Producing fields pay royalties in accordance with the applicable royalty rate at the time of the discovery. Also, Law 756 of 2002 establishes that in the fields of the association contracts that terminate or revert an additional royalty rate of 12% of the basic production applies.
Since January 2014, the ANH has collected natural gas production royalties from producers settled in cash based on a formula, regardless of whether a producer has sold the gas. As a result, we no longer commercialize this gas on behalf of the ANH. In addition, since royalties are now payable to the ANH in cash, all of the gas that we produce is considered part of our reserves and production, without any deduction for royalties. The cost of natural gas royalties totaled COP 995,254 million in 2024.
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On September 30, 2020, Law 2056 of 2020 was issued, (“Whereby the organization and operation of the general system of royalties is regulated”), under which the definition of incremental production was extended to all production from fields in which additional investments have been made to increase the recovery factor. According to above, the total production of these fields of the association contracts benefits from the variable royalty established in article 16 of Law 756 of 2002, and therefore, the additional 12% royalty referred to in article 39 of Law 756 of 2002 does not apply to these fields.
On September 23, 2021, the Ministry of the Interior issued Decree 1142 (“Whereby Decree 1821 of 2020, Sole Regulatory Decree of the General Royalties System, is incorporated and modified”), Article 3.1.1.2.1 of Decree 1142 established that the total volume of hydrocarbons produced that is in excess to that stipulated in the basic production curve of incremental production projects or incremental production contracts will also enjoy the benefits of Article 16 of Law 756 of 2002. On September 2, 2022, Ecopetrol sued for the annulment of Article 3.1.1.2.1 of this Decree, citing legal grounds. The lawsuit against Decree 1142 of 2021 was filed by Ecopetrol on September 2, 2022, before the contentious administrative courts. On January 16, 2024, the lawsuit was admitted and is currently ongoing.
On December 13, 2022, Law 2277 of 2022 was adopted. Law 2277 of 2022 adopted amendments to the Colombian tax system, including the non-deductibility of crude oil and gas royalties. On November 16, 2023, the Constitutional Court in Colombia issued ruling C-489, in which it determined that royalties are a deductible cost of income tax. In December of 2023, the Ministry of Mines and Energy and the Ministry of Finance and Public Credit requested the review of the ruling to the Constitutional Court, alleging a fiscal impact and nullity, respectively. Law 2277 of 2022 came into force on January 1, 2023 and resulted in the payment of higher income taxes and higher effective tax rates by Colombian companies such as Ecopetrol S.A. and Hocol. In March 2024, the Constitutional Court rejected the request for nullity filed by the Ministry of Mines and Energy. With respect to the fiscal impact argument filed by the Ministry of Finance and Public Credit, such ministry filed related correspondence on March 11, 2024.
The Constitutional Court rejected the case of fiscal impact filed by the Minister of Finance and Public Credit, stating that the arguments presented did not meet the constitutional threshold. See section Financial Review—Effect of Taxes, Exchange Rate Variation, Inflation and the Price of Oil on our Results—Taxes and section Risk Review—Risk Factors—Risks Related to Our Business—New or higher taxes resulting from changes in tax regulations or the interpretation thereof in Colombia could adversely affect our results of operations and financial condition.
Purchases of hydrocarbons
We purchase all crude oil delivered to the ANH as royalties by us and by third parties. The purchase price is calculated according to a formula set forth in a contract between Ecopetrol S.A. and the ANH that reflects our export sales prices, a quality adjustment for API gravity and sulfur content, a marketing fee, and transportation rates from the wellhead to ports and refineries. We sell the physical product purchased from the ANH as part of our ordinary business. The contract between the ANH and Ecopetrol S.A. was extended until June 30, 2026.
We import crude oil for Cartagena and Barranca refineries’ feedstock when such imports result in the better operational or economic performance of the Ecopetrol Group.
Electricity transmission rates
Electricity transmission is a regulated activity in all jurisdictions where ISA operates. We must maintain certain quality, safety, and maintenance standards with respect to our businesses. Periodic adjustment of transmission rates or reviews of the methodologies established by applicable regulations for the calculation of such rates may result in a decrease of the revenues of the Electric Power Transmission and Toll Roads Concessions segment and may have a material adverse effect on our consolidated results of operations and financial condition. Regulatory agencies could penalize ISA if we fail to comply with the terms of the rules and regulations applicable to our ISA’s businesses.
Conflict between Russia and Ukraine
On February 24, 2022, Russia launched its military invasion of Ukraine, with strong ramifications for global crude and oil product supply and a surge in prices. Brent crude average prices surged from USD 70.9/Bl in 2021 to USD 82.2/Bl in 2023, peaking at USD 96.6/Bl in September 2023.
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In 2022, the increase in prices had both, positive and negative impacts on our Group. On one hand, the rise in the average price of ICE Brent increased revenues from the sale of our crudes, and higher prices of diesel, gasoline, jet fuel and other refined products were favorable for the 2022 financial results of our Cartagena and Barrancabermeja refineries. However, the increase in prices also had a negative effect on our Group, including the weakening of our crude oil differential versus Brent. To mitigate this, Ecopetrol worked to improve the positioning of our crude oil and diversify destination markets. In addition, the high prices affected our purchases of crude oil and oil products, which are used as inputs and raw materials for our production processes as well as to meet the growing national demand for fuels. Lastly, higher energy costs, coupled with the international logistics crisis, generated pressures on our operating costs and project execution timelines.
In 2023 and 2024, we maintained constant monitoring of various Russia-Ukraine related factors that could impact our financial performance. These factors include the ongoing conflict, interruptions in the export of Russian energy due to sanctions, disruptions in supply chain, price volatility and others. In addition, we continue to monitor potential changes in demand, geopolitical risks, and regulatory changes that could affect its operations. However, despite the conflict persisting throughout 2024, the market corrected the prices downwards.
Fuel Price Stabilization Fund (FEPC)
The Fuel Price Stabilization Fund – FEPC – is a mechanism designed to react to drastic and sudden changes in hydrocarbon prices and prevent substantial increases or decreases in gasoline and diesel prices for Colombian consumers. In this way, the Fund prevents substantial increases or decreases in prices for national consumers by using the difference between the local producer’s income and the parity (market) price, should there be drastic and sudden changes in hydrocarbon prices.
In 2023, the FEPC balance was COP 20.5 trillion due to the difference between the international market prices of regular motor gasoline and diesel, and the regulated prices in Colombia, however, the balance of this account was reduced by COP 12.9 trillion in 2024, resulting in a final balance of COP 7.6 trillion in accounts receivable as of December 31, 2024.
The reduction is partly attributed to the series of gasoline price increases started by the Colombian government in September 2022. In 2022, the gasoline price increased by COP 600 per gallon; in 2023, the gasoline price increased by COP 4,850 per gallon; in 2024, the gasoline price increased by COP 600 per gallon and; in 2024, the diesel price increased by COP 800 per gallon These prices increases were also necessary to mitigate the impact of rising international prices and maintain a stable domestic market.
The FEPC accounts receivable represent 37.3% of Ecopetrol’s total short-term accounts receivable as of December 31, 2024, and created a strain on working capital needs, including payment obligations to suppliers, taxes, payroll, and other short-term expenses. The balance of the FEPC account also impacts the comparison of solvency and liquidity levels against industry peers. Nevertheless, the Government of Colombia has outlined potential ways to manage the payment of outstanding accounts receivable balances and finding structural solutions to close the current gaps in the fund. See section Regulation Concerning Production and Prices - Fuel Price Stabilization Fund (FEPC) .
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4.2 |
[Reserved] |
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4.3 |
Effect of Taxes, Exchange Rate Variation, Inflation and the Price of Oil on our Results |
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4.3.1 |
Taxes |
In December 2016, the Colombian Congress adopted Law 1819, which introduced changes to the Colombian tax system, applicable beginning in 2017.
The 2016 Tax Reform included two tax benefits that are expected to improve the operations of the oil and gas industry:
Certificado de Reembolso Tributario (“CERT”) incentive:
For exploration activities, the CERT incentive was approved, consisting of the reimbursement of part of the investment made in the exploration phase.
The CERT is granted when the income tax return is filed.
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The CERT can only be redeemed to pay taxes at the national level and its effective maturity date is two years after it is issued. Nevertheless, Decree 2253 of 2017 establishes that a CERT redemption can be made from year two to year five, as from the date of the granting of the incentive. The CERT can also be sold and traded in fixed income market.
For production activities, the CERT reimbursement is granted exclusively to investments that increase the recovery factor, i.e., investments that increase the reserves that are currently proved in certain wells.
On December 29, 2017, the Colombian Government issued Decree 2253, which establishes that companies who (i) qualify as operators of association agreements entered into with Ecopetrol S.A., (ii) have exploration and production of hydrocarbons agreements and (iii) are currently involved in the exploration and production of hydrocarbons, among others, can also qualify for the CERT. Additionally, the CERT will not qualify as taxable income or capital gain for the taxpayer receiving or acquiring such incentive.
On March 23, 2018, the following Resolutions were issued in order to regulate the procedures and requirements that companies must comply to claim the CERT: 0860 of Ministry of Finance and Public Credit, 108 of ANH and 40284 and 40285 of Ministry of Mines and Energy.
On December 20, 2019, the Ministry of Finance and Public Credit informed the Company that the PGN includes the resources of CERT. By virtue of Law 2277 of 2022, CERTs ceased to exist as of January 1, 2023.
Refundable VAT on oil and gas exploration:
Taxpayers in the oil and gas industry are entitled to refund VAT paid in the exploration phase for offshore projects. Taxpayers can request for this VAT as of the next fiscal year in which the investment was made. VAT that is reimbursed cannot be used as a higher cost or expense for income tax purposes.
Additionally, in December 2018, the Colombian Congress adopted Law 1943, which introduced the following key changes to the Colombian tax system, applicable beginning in 2019, including the following aspects:
The corporate income tax rates were set to be reduced gradually from 33% to 30% as follows: 33% in 2019, 32% in 2020, 31% in 2021 and 30% from 2022 onward. However, in September 2021, the Colombian Congress adopted Law 2155, which changed the corporate income tax rates to 35% from 2022 onward.
The presumptive income tax rate was reduced to 0% from fiscal year 2021 onward.
Taxpayers must calculate their taxable income taking as initial base the year and result under Colombian IFRS. Accounting profit is reconciled to obtain the net income tax, which is the basis to calculate the income tax.
For fiscal years 2022, 2023, and 2024 the dividends tax applied as follows:
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i. |
In accordance with Article 245 of the Colombian Tax Code, the dividends tax applicable to non-resident shareholders is as follows: (i) a 10% dividend tax for dividends paid out of profits that were accrued as of January 1, 2017 and were taxed at the corporate level, which was increased to a tax rate of 20% for the fiscal year 2023 and 2024; (ii) no dividend tax on dividends paid out of profits that accrued until December 31, 2016 and were taxed at the corporate level; (iii) a withholding tax at the statutory corporate income tax rate (35% as from 2022) on dividends distributed from profits not taxed at the corporate level if the dividend is paid out of profits that accrued as of January 1, 2017, plus an additional, 10% or 20% dividend tax, as applicable, after applying the initial corporate income withholding tax rate . |
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ii. |
In accordance with Article 242 of the Colombian Tax Code, for Colombian individuals: for fiscal years 2021 and 2022, dividends paid greater than 300 UVT (Spanish acronym for Unidad de Valor Tributario ) were taxed at 10%. For fiscal year 2023 and 2024, dividends paid greater than 1,090 UVT were taxed at rate of 15% . |
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iii. |
In accordance with Article 242-1 of the Colombian Tax Code, dividends distributed from taxed profits to local corporations for fiscal years 2021 and 2022 are taxed at 7.5%, or a 31% withholding tax for 2021 and 35% as from 2022 on dividends distributed from untaxed profits, plus an additional 7.5% dividend tax after applying the initial corporate income withholding tax rate. For fiscal year 2023 and 2024, the tax rate increased to 10%. |
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Tax losses accrued as of fiscal year 2017 may be offset against ordinary net income obtained in the following 12 taxable years.
Depreciation and amortization methods and annual percentages must be determined in accordance with accounting rules and are limited to those established in the tax rule and depend on the type of asset. For example, machinery and equipment depreciate at an annual rate of 10%, infrastructure (including pipelines) at 2.22%, vehicles at 10% and computers at 20%, among others.
Income tax for free trade zone users increased from 15% to 20% as of fiscal year 2017. The tax rate for free trade zone users with a legal stability agreement (in which the income tax rate was stabilized) remains at 15% during the term of said agreement.
The general value added tax (VAT) rate increased to 19% and a differential rate of 5% for certain goods and services is maintained. The modification of the general VAT rate is effective from January 1, 2017.
The charge on financial transactions is 0.4%, with half of the tax liability being deductible.
In accordance with Resolutions No. 019 of 2022 and 012 of 2023, issued by the tax authority, the carbon tax accrues on the carbon content of fossil fuels used for combustion. The rate was COP 18,829 and COP 23,394.60 per ton of CO2, for fiscal years 2022 and 2023, respectively.
For additional information related to BEPS (Base Erosion and Profit Shifting), see Note 10 of our consolidated financial statements.
In October 2019, the Constitutional Court declared Law 1943 of 2018 (the Financing Law) unconstitutional effective January 1, 2020. Therefore, the Financing Law continued to have full effect for the full fiscal year 2019.
In December 2019, the Colombian Congress adopted Law 2010, which introduced changes to the Colombian tax system, which became effective in 2020.
The cited law also created a “normalization tax” for 2020 to enable taxpayers to regularize certain omissions of information about their assets and/or incorrect information about their liabilities, subject to the payment of a 15% tax on the value of the amount of the incorrect information.
As of 2020, in accordance with Article 115 of the Colombian Tax Code, taxes are fully deductible if they are effectively paid during the fiscal year, except for: (i) income tax, equity tax and normalization tax are non-deductible; (ii) only 50% of the financial transactions tax is deductible; and (iii) only 50% of the industry and commerce tax can be taken as a discount (tax credit) to income tax.
VAT paid on the acquisition, import, creation or construction of tangible fixed assets used in income generating activities may be treated as discount (tax credit) for income tax purposes, in the same year or in future years.
On September 14, 2021, the Colombian Congress passed Law 2155 which introduced, among others, the following key changes to the Colombian tax system:
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i. |
The Corporate Income Tax rate will be 35% as from 2022 onward. |
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ii. |
The alternative to credit 100% of the Turnover Tax (“ICA” for its acronym in Spanish) against Corporate Income Tax as from 2022 was eliminated (Article 65). However, the current alternative to credit 50% of the ICA remains going forward. |
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iii. |
A “normalization tax” was re-introduced for taxpayers to declare omitted assets or reject nonexistent liabilities subject to the payment of a 17% tax. This tax applies only for 2022 and a 50% prepayment is to be remitted in 2021. |
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iv. |
A new definition of final (effective) beneficiary for tax purposes was created (Article 16). |
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On August 8, 2022, the MHCP submitted a tax reform bill to Congress proposing several changes to the Colombian tax regime. The Colombian Congress adopted Law 2277 of 2022, which introduced the following modifications to the Colombian tax system, applicable from January 1st, 2023: (i) a new permanent equity tax applicable to Colombian individuals and non-residents, at rates ranging from 0.5% to 1.5% based on the level of net equity at January 1st every year, (ii) an increase in the dividend tax rate for local and foreign shareholders (0% to 39% progressive marginal rates for Colombian individuals, and 20% flat withholding for non-resident shareholders), (iii) an increase in the long-term capital gains tax rate (increases from 10% to 15%), (iv) the elimination of specific tax benefits and exemptions, (v) a minimum corporate income tax based on effective tax rate (effective rate calculated on book profit should be at least 15%, considering certain adjustments to accounting profits and certain exempted companies), (vi) the application of taxes based on significant economic presence (primarily for non-resident persons and entities that provide digital services, but including other services and commercial activities), (vii) the elimination of the ability to claim 50% of the ICA as an income tax credit, (viii) an additional percentage points to the nominal tax rate for companies engaged in the extraction of crude oil and coal of 0%, 5%, 10% or 15% and based on international prices. For fiscal year 2023 and 2024, additional percentage points will be applied to the nominal of 10% and 5%, given that the Brent price was USD 80.32 and USD 78.76, according to ANH Resolutions No. 0061 and No. 0044 from January 31, 2024 and 2025, respectively. Note that the revenues from the sale of natural gas are not subject to these additional percentage points to the nominal tax rate, (ix) non-deductibility of royalties, and (x) the modification of section 221 of Law 1819 of 2016, with an adjustment to the taxable event and establishing that the national carbon tax will be levied on the carbon equivalent content (CO2eq) of all fossil fuels, including all petroleum derivatives, fossil gas and solids used for combustion.
Concerning the non-deductibility of royalties, the Colombian Constitutional Court deemed the limiting rule is unconstitutional and inapplicable. In a final effort to mitigate the effect of this ruling to the public finances, the Government recently requested to adjust, modify or defer its decision to the Constitutional Court. As of the date of this annual report, it is uncertain whether the Constitutional Court will amend its ruling.
On November 16, 2023, the Constitutional Court in Colombia issued ruling C-489, in which it determined that royalties are a deductible cost of income tax. In December of 2023, the Ministry of Mines and Energy and the Ministry of Finance and Public Credit requested the review of the ruling to the Constitutional Court, alleging a fiscal impact and nullity, respectively. In March of 2024, the Constitutional Court rejected the request for nullity filed by the Ministry of Mines and Energy. The Constitutional Court rejected the case of fiscal impact filed by the Minister of Finance and Public Credit and granted a term of five business days to correct the written statement and provide additional information. In May 2024, the Constitutional Court rejected the case of fiscal impact filed by the Minister of Finance and Public Credit, stating that the arguments presented did not meet the constitutional threshold. In July 2024, the Constitutional Court rejected the request for insistence filed by the Ministry of Mines and Energy.
On February 22, 2025, the National Government issued Decree 0175, which creates the Catatumbo special tax for the first sales and exports of oil. The rate of this tax is 1%. Additionally, it increases the stamp tax from 0% to 1%. The Decree is valid until December 31, 2025.
Part A: Applicable Taxpayers for the Equity Tax (2023 and onwards)
| ● | Resident individuals with assets located in Colombia and abroad. |
| ● | Non-resident individuals with respect to assets located in Colombia (including assets held indirectly through permanent establishments). |
| ● | Non-residents with non-cash assets in Colombia. |
| ● | Foreign entities that are not income taxpayers in Colombia but who possess assets located in Colombia, other than shares of Colombian companies, accounts receivables sourced in Colombian (i.e., with Colombian debtors), portfolio investments (i.e., investing through a foreign funds administration account (FFAA)), provided that these entities have complied with the foreign exchange regime in respect of such excluded assets. Additionally, non-residents with financial leasing agreements with Colombian borrowers (lessees) are also not liable for the tax (arguably in connection with that specific asset). |
Part B: Tax Accrual Rules
The equity tax will accrue at a rate of 0.5%, 1% and 1.5% every year on January 1 of each fiscal year. The taxable base is the taxpayer’s net equity on each of the accrual dates (gross assets less liabilities and certain exclusions, including a portion of the value of the dwelling house). Note that equity tax will only apply on taxable net equity exceeding 72,000 tax value units (UVTs, per the acronym in Spanish).
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Thin capitalization: A 2:1 debt-to-equity ratio determines the amount of deductible interests on loans with related parties.
Laws 2010, 2155 and 2277 maintain the tax regime for profits derived from indirect transfer of Colombian assets.
A special regime (the Mega Investments Regime) was created for taxpayers who (i) generate at least 400 direct jobs and (ii) make new investments in Colombia in an amount equal to or greater than 30,000,000 UVT (COP 1,140,120,000,000) by 2022, with a view for them to calculate and settle their income tax liability for the next 20 years using the following metrics and/or policies:
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i. |
27% income tax rate; |
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ii. |
Two-year term for the depreciation for fixed assets; |
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iii. |
Exclusion from the presumptive income regime; |
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iv. |
Exclusion from the wealth tax; and |
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v. |
0.75% premium over the investment value to be paid on an annual basis. |
In addition, legal taxpayers who qualify for this Mega Investment Regime are required to enter into agreements with the tax authority.
These rules do not apply to taxpayers engaged in the exploration of non-renewable natural resources.
Law 2277 of 2022 repealed the Mega Investments Regime, which ceased to apply on January 1, 2023. However, taxpayers who met the eligibility requirements or obtained approval under the Mega Investments Regime before January 1, 2023, will maintain the rights acquired under such regime.
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4.3.2 |
Exchange Rate Variation |
The functional currency of each of the companies of Ecopetrol Group is determined in relation to the main economic environment where each company operates; however, our consolidated financial results are reported in Colombian Pesos, which is the Ecopetrol Group’s functional and presentation currency. A substantial part of our consolidated revenues comes from the Ecopetrol Group’s companies whose functional currency is the Colombian Peso. The conversion effect from U.S. dollar to Colombian Peso is mainly due to local sales and exports of crude oil, natural gas, and refined products, whose prices are based on benchmarks quoted in U.S. dollars. Therefore, they are exposed to foreign currency exchange risk on revenues, capital expenditures and financial instruments that are denominated in a currency other than its functional currency.
Fluctuations in the U.S. dollar-Colombian Peso exchange rate have effects on our consolidated financial statements. As crude oil is priced in U.S. dollars, fluctuations in the exchange rate of the Colombian Peso against the U.S. dollar may have a significant impact on revenues, cost, monetary assets, and liabilities held in foreign currency.
An appreciation of the Colombian Peso has a negative impact on our results of operations because our revenues from exports of crude oil, natural gas, and refined products are primarily expressed in U.S. dollars. Costs of imported products and contracted services expressed in U.S. dollars will also be lower when expressed in Colombian Pesos, but on balance, our operating income in Colombian Pesos tends to decline when the Colombian Peso appreciates, other factors being equal. The appreciation of the Colombian Peso against the U.S. dollar will also decrease the debt service requirements of our Companies with the Colombian Peso as their functional currency and with indebtedness in U.S. dollars, as the amount of the Colombian pesos necessary to pay principal and interest on foreign currency debt decreases with the appreciation of the Colombian Peso.
Conversely, when the Colombian Peso depreciates against the U.S. dollar, our reported revenues, costs related to imported products and services, operating income, and debt service requirements of foreign-denominated debt all tend to increase.
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With the acquisition of ISA, an amount of our revenues started being generated in currencies other than the Colombian peso, and some of the operating and other expenses we incur are paid in the local currency of the countries where ISA operates. As a result, we may be exposed to foreign exchange and translation risk when local currency financial statements are translated to Colombian pesos. In addition, around 82% of ISA’s debt is denominated in foreign currency. Therefore, our consolidated financial results could be affected by an increase in financial costs due to the devaluation of the currencies in the jurisdictions where ISA operates. As a result, the devaluation of the Colombian peso would lead to the recognition of currency conversion losses due to the increase in the affected debt balance upon the translation of U.S. dollar-denominated debt or other currencies to Colombian pesos.
During 2024, the Colombian Peso appreciated on average 5.87% against the U.S. dollar. During 2023 and 2022, the Colombian Peso depreciated on average 1.64% and 13.69%, respectively, against the U.S. dollar. Additionally, on December 31, 2024, the Colombian Peso/U.S. dollar exchange rate depreciated 15.36% as compared to the same date in 2023, while the Colombian Peso/U.S. dollar exchange rate had appreciated 20.54% in 2023 as of December 31, 2023, and depreciated 20.82% as of December 31, 2022, in relation to the rate on the same date of the immediately preceding year.
In 2024, our consolidated debt in foreign currency decreased by a total of USD 331 million, due to the repayment of principal at maturity. In 2023, our consolidated debt in foreign currency increased by a total of USD 2,684 million, due to new debt acquired during the year, mainly from the issuance of international bonds. In 2022, our consolidated debt in foreign currency increased by a total of USD 378 million, mainly due to the execution of short-term treasury lines of credit by Ecopetrol S.A.
As of December 31, 2024, our U.S. dollar denominated total debt was USD 24,629 million, recognized in our financial statements at its amortized cost, which corresponds to the present value of cash flows, discounted at the effective interest rate of each loan. Out of the total U.S. dollar denominated debt, USD 18,346 million are in Ecopetrol S.A.’s balance sheet, whose functional currency is the Colombian Peso. Therefore, when the Colombian Peso depreciates against the U.S. dollar, Ecopetrol S.A. is exposed to an exchange rate loss. In contrast, when the Colombian Peso appreciates against the U.S. dollar, Ecopetrol S.A. has an exchange rate gain. Some of the Ecopetrol Group’s companies have the U.S. dollar as their functional currency and are not exposed to a material exchange rate risk resulting from fluctuations in the Colombian Peso against the U.S. dollar. When the financial statements of the Ecopetrol Group are consolidated, the exchange rate differential of the subsidiaries’ assets and liabilities whose functional currency is the U.S. dollar is recognized directly in equity, as part of other comprehensive income.
Since 2015, Ecopetrol adopted hedge accounting, using two types of natural hedges with its U.S. dollar debt as a financial instrument: (i) a cash flow hedge for exports of crude oil, and (ii) a hedge of the net investment in foreign operations. As a result of the implementation of both hedges, 94% (USD 17,224 million) of Ecopetrol S.A.’s debt in U.S. dollars, as of December 31, 2024, was designated as a hedge. Similarly, since 2022, ISA adopted hedge accounting of the net investment in foreign operations. As a result, USD 388 million of ISA’s debt was designated as a hedge as of December 31, 2024. The total debt of foreign currency designated as a hedge as of December 31, 2024, was USD 17,612 million. With the adoption of hedge accounting, the effect of the volatility of the foreign exchange rate on the hedged portion of the debt is recognized directly in equity, as part of other comprehensive income.
The remaining portion of Ecopetrol S.A.’s U.S. dollar-denominated debt, as well as the financial assets and liabilities denominated in foreign currency, continues to be exposed to the fluctuation in the exchange rate, which means that an appreciation of the Colombian Peso against the U.S. dollar could generate a loss for companies whose functional currency is the Colombian Peso that have a net asset position in U.S. dollars or a gain if they have a net liability position in U.S. dollars. Conversely, a depreciation of the Colombian Peso against the U.S. dollar could generate a gain for companies whose functional currency is the Colombian peso that have a net asset position in U.S. dollars or a loss if they have a net liability position in U.S. dollars.
As of December 31, 2024, the Ecopetrol Group’s companies have the equivalent of a net U.S. dollar liability position of USD 299 million after the implementation of the accounting hedges previously mentioned above, minimizing the effect of exchange rate fluctuations in their results for the year.
|
4.3.3 |
Effects of Inflation |
The average annual rate of inflation in Colombia for the past ten years is 5.84%. As measured by the general consumer price index, the annual inflation rate in Colombia for the years ended December 31, 2024, 2023 and 2022 was 5.2%, 9.28%, and 13.12%, respectively. The decrease in inflation in 2024 is mainly driven by (i) a core inflation that continued its downward trajectory, gradually converging toward lower and more stable levels, and (ii) by lower increases in the prices of regulated goods and services, such as public utilities and fuels, reinforcing the effectiveness of economic policies in guiding inflation toward long-term targets.
125
Inflation has had a positive and a negative effect on the Group. On one hand, it has increased revenues for the transmission and roads segment, given that the rates are indexed to inflation, and has also produced higher yields from our investment portfolio. On the other hand, it has increased costs, expenses and capital expenditures mainly due to the rising cost of inputs, higher tariffs in contracts, as well as a higher financial cost of the debt with floating rates (28.9% of the total financial obligations on December 31, 2024). The effects of inflation vary over time and between each market segment.
|
4.3.4 |
Effects of Crude Oil and Refined Product Prices |
The average price of ICE Brent crude in 2024 was USD 79.9 per barrel as compared to USD 82.2 per barrel in 2023 and USD 99.0 per barrel in 2022. See section Strategy and Market Overview.
Our average crude oil basket price was USD 73.4 per barrel in 2024, as compared to USD 73.5 per barrel in 2023 and USD 90.9 per barrel in 2022. There are no significant changes between 2024 compared to 2023 due to the loss of the refined products differential and lower Brent reference price, partially offset by the strengthening of the negotiated crude oil differential. In addition, our average product basket price was USD 86.8 in 2024, USD 96.1 in 2023, and USD 118.2 in 2022. The decrease in 2024 as compared to 2023 was primarily due to weakening ICE Brent benchmark prices, coupled with lower international price indicators, particularly for diesel and jet fuel due to the increase in supply in the Atlantic basin and a diesel market with greater trade flows due to the arrival of Russian product to South America.
In the Operating Results section below, we present the impact of the price decrease on our revenue and cost of sales. Additionally, fluctuations in the price of oil had an impact on the value of our oil and gas reserves. Reserves’ valuation is made in accordance with SEC price regulations. Volatility in hydrocarbon prices, refining margins and reserves, as well as changes in environmental regulations may lead to the recognition of impairment or recovery of non-current assets.
For additional information about impairment charges and reversals, see sections Financial Review—Operating Results—Consolidated Results of Operations—Impairment of Non-Current assets , Segment Performance and Analysis and Note 18 to our consolidated financial statements.
|
4.4 |
Accounting Policies |
Our consolidated financial statements for the years ended December 31, 2024, 2023, and 2022 were prepared in accordance with IFRS. The detail of the accounting policies is described in Note 4 to our consolidated financial statements.
The main accounting regulatory change for 2023 was the adoption of IFRS 17 Insurance Contracts that provides a new general model for accounting for contracts by combining a measurement of the current balance of insurance contracts with the recognition of earnings during the period in which the services are rendered. The standard’s general model requires that insurance contract liabilities be measured using current weighted probability estimates of future cash flows, a risk adjustment, and a contractual service margin that represents the expected gain from fulfilling the contracts. The effects of changes in the estimates of future cash flows and the risk adjustment related to future services are recognized during the period in which the services are rendered and not immediately in profit loss statement. The change did not have any material impact.
There are no new or amended standards or interpretations adopted as of January 1, 2024 that have a significant impact on the consolidated financial statements for 2024. See Note 5 to our consolidated financial statements included in this annual report.
|
4.5 |
Critical Accounting Judgments and Estimates |
Critical accounting policies are those policies that require us to exercise judgment or involve a higher degree of complexity in the application of the accounting policies that currently affect our financial condition and results of operations. The accounting judgments and estimates we make in these contexts require us to calculate variables and make assumptions about matters that are highly uncertain. In each case, if we had made other estimates, or if changes in the estimates occur from period to period, our financial condition and results of operations could be materially affected.
See Note 4 to our consolidated financial statements for a summary of the critical accounting judgments and estimates applicable to us. There are many other areas in which we use estimates about uncertain matters, but we believe the reasonably likely effect of changes or differences within critical accounting judgments and estimates would not have a material impact on our financial statements.
126
|
4.6 |
Operating Results |
The following discussion is based on information contained in our audited consolidated financial statements and should be read in conjunction therewith.
|
4.6.1 |
Consolidated Results of Operations |
The following table sets forth components of our income statement for the years ended December 31, 2024, 2023, and 2022.
Table 57 – Consolidated Income Statement
|
Income Statement |
|
For the year ended December 31, |
|
% Change |
||||||
|
(COP Million) |
|
2024 |
|
2023 |
|
2022 |
|
2024/2023 |
|
2023/2022 |
|
Revenue |
|
133,330,428 |
|
143,189,602 |
|
159,611,078 |
|
(6.9) |
|
(10.3) |
|
Cost of sales |
|
86,481,154 |
|
88,178,198 |
|
89,458,148 |
|
(1.9) |
|
(1.4) |
|
Gross Profit |
|
46,849,274 |
|
55,011,404 |
|
70,152,930 |
|
(14.8) |
|
(21.6) |
|
Operating expenses |
|
9,253,705 |
|
11,154,090 |
|
9,635,178 |
|
(17.0) |
|
15.8 |
|
Impairment of non-current assets, net |
|
(867,428) |
|
2,098,333 |
|
287,999 |
|
(141.3) |
|
628.6 |
|
Operating Income |
|
38,462,997 |
|
41,758,981 |
|
60,229,753 |
|
(7.9) |
|
(30.7) |
|
Finance results, net |
|
(8,519,948) |
|
(5,665,384) |
|
(6,834,757) |
|
50.4 |
|
(17.1) |
|
Share of profit of companies |
|
764,366 |
|
805,349 |
|
768,422 |
|
(5.1) |
|
4.8 |
|
Income before income tax |
|
30,707,415 |
|
36,898,946 |
|
54,163,418 |
|
(16.8) |
|
(31.9) |
|
Income tax |
|
(12,208,540) |
|
(11,515,875) |
|
(18,963,938) |
|
6.0 |
|
(39.3) |
|
Net Income |
|
18,498,875 |
|
25,383,071 |
|
35,199,480 |
|
(27.1) |
|
(27.9) |
|
Net income attributable to: |
|
|
|
|
|
|
|
|
|
|
|
Company’s shareholders |
|
13,841,153 |
|
21,060,798 |
|
31,604,781 |
|
(34.3) |
|
(33.4) |
|
Non-controlling interest |
|
4,657,722 |
|
4,322,273 |
|
3,594,699 |
|
7.8 |
|
20.2 |
|
Net Income |
|
18,498,875 |
|
25,383,071 |
|
35,199,480 |
|
(27.1) |
|
(27.9) |
|
4.6.1.1 |
Total Revenues |
The following table sets forth our principal sources of third-party revenues by business segment for the years ended December 31, 2024, 2023, and 2022. An explanation of how we classify our operations into business segments is included in section 4.6.1.8 below.
127
Table 58 – Third-Party Revenues by Business Segment
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2024 |
|
2023 |
|
2022 |
|
% change sales revenues |
||||||||||||||
|
|
|
Volume |
|
|
|
|
|
Volume |
|
|
|
|
|
Volume |
|
|
|
|
|
|
|
|
|
|
|
(barrels |
|
Average price |
|
Sales revenues |
|
(barrels |
|
Average price |
|
Sales revenues |
|
(barrels |
|
Average price |
|
Sales revenues |
|
|
|
|
|
Revenue by segment |
|
equivalent) |
|
US dollars / Barrels |
|
(COPS Million) |
|
equivalent) |
|
US dollars / Barrels |
|
(COPS Million) |
|
equivalent) |
|
US dollars / Barrels |
|
(COPS Million) |
|
2024/2023 |
|
2023/2022 |
|
Local Crude oil |
|
1,151 |
|
65.4 |
|
301.7 |
|
433,524 |
|
65.4 |
|
129,157 |
|
1,137,432 |
|
75.5 |
|
375,790 |
|
(99.8) |
|
(65.6) |
|
Foreing Crude oil (1) |
|
159,096,981 |
|
73.4 |
|
47,516,575.9 |
|
151,460,951 |
|
73.2 |
|
47,650,996 |
|
145,916,897 |
|
91.0 |
|
56,155,120 |
|
(0.3) |
|
(15.1) |
|
Natural gas local |
|
31,071,560 |
|
32.1 |
|
4,096,126.4 |
|
33,432,168 |
|
30.7 |
|
4,358,266 |
|
35,032,930 |
|
27.6 |
|
4,162,876 |
|
(6.0) |
|
4.7 |
|
Foreging natural gas |
|
5,146,252 |
|
2.0 |
|
43,539.1 |
|
3,629,325 |
|
6.7 |
|
105,413 |
|
2,121,931 |
|
27.7 |
|
254,054 |
|
(58.7) |
|
(58.5) |
|
Other income (2) |
|
9,984,441 |
|
— |
|
903,308 |
|
9,005,330 |
|
— |
|
185,670 |
|
7,211,899 |
|
— |
|
(227,937) |
|
386.5 |
|
(180.0) |
|
Exploration and production sales |
|
205,300,385 |
|
— |
|
52,559,851 |
|
197,961,298 |
|
— |
|
52,429,502 |
|
191,421,089 |
|
— |
|
60,719,903 |
|
0.3 |
|
(13.7) |
|
Local refined products (1) |
|
125,038,118 |
|
97.4 |
|
49,543,812 |
|
126,731,492 |
|
108.5 |
|
59,318,743 |
|
128,369,639 |
|
129.8 |
|
70,911,613 |
|
(16.5) |
|
(16.3) |
|
Foreing refined products (1) |
|
35,813,033 |
|
68.1 |
|
9,967,516 |
|
36,672,668 |
|
70.9 |
|
11,166,887 |
|
27,956,878 |
|
86.4 |
|
10,113,351 |
|
(10.7) |
|
10.4 |
|
Foreing Crude oil |
|
4,087,113 |
|
77.1 |
|
1,281,956 |
|
5,776,131 |
|
79.9 |
|
2,027,551 |
|
200,332 |
|
105.1 |
|
92,147 |
|
(36.8) |
|
2,100.3 |
|
Other income (2) |
|
— |
|
— |
|
1,458,056 |
|
2,516 |
|
— |
|
1,103,460 |
|
— |
|
— |
|
1,611,764 |
|
32.1 |
|
(31.5) |
|
Refining and petrochemicals |
|
164,938,264 |
|
— |
|
62,251,340 |
|
169,177,775 |
|
— |
|
73,616,641 |
|
156,526,849 |
|
— |
|
82,728,875 |
|
(15.4) |
|
(11.0) |
|
Transportation services |
|
— |
|
— |
|
2,716,164 |
|
— |
|
— |
|
2,978,937 |
|
— |
|
— |
|
2,807,031 |
|
(8.8) |
|
6.1 |
|
Other income (2) |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
Transportation and logistics |
|
— |
|
— |
|
2,716,164 |
|
— |
|
— |
|
2,978,937 |
|
— |
|
— |
|
2,807,031 |
|
(8.8) |
|
6.1 |
|
Electric Power Transmission and Toll Roads services |
|
— |
|
— |
|
15,803,073 |
|
— |
|
— |
|
14,164,522 |
|
— |
|
— |
|
13,355,269 |
|
11.6 |
|
6.1 |
|
Electric Power Transmission and Toll Road (3) |
|
— |
|
— |
|
15,803,073 |
|
— |
|
— |
|
14,164,522 |
|
— |
|
— |
|
13,355,269 |
|
11.6 |
|
6.1 |
|
Total sales |
|
370,238,649 |
|
— |
|
133,330,428 |
|
367,139,073 |
|
— |
|
143,189,602 |
|
347,947,938 |
|
— |
|
159,611,078 |
|
(6.9) |
|
(10.3) |
|
Crude Oil |
|
163,185,245 |
|
73.5 |
|
48,798,834 |
|
157,670,606 |
|
73.4 |
|
49,807,704 |
|
147,254,661 |
|
90.9 |
|
56,623,056 |
|
(2.0) |
|
(12.0) |
|
Natural gas |
|
36,217,812 |
|
27.8 |
|
4,139,665 |
|
37,061,493 |
|
28.4 |
|
4,463,679 |
|
37,154,861 |
|
27.6 |
|
4,416,930 |
|
(7.3) |
|
1.1 |
|
Refined products |
|
170,835,592 |
|
86.8 |
|
60,414,636 |
|
172,409,490 |
|
96.1 |
|
70,671,300 |
|
163,538,416 |
|
118.2 |
|
80,797,027 |
|
(14.5) |
|
(12.5) |
|
Other |
|
— |
|
— |
|
19,977,293 |
|
2,516 |
|
— |
|
18,246,919 |
|
— |
|
— |
|
17,774,064 |
|
9.5 |
|
2.7 |
|
Total sales |
|
370,238,649 |
|
— |
|
133,330,428 |
|
367,139,073 |
|
— |
|
143,189,602 |
|
347,947,938 |
|
— |
|
159,611,078 |
|
(6.9) |
|
(10.3) |
|
(1) |
Includes strategic and tactical hedges, which are related to crude oil, fuel oil and Diesel. |
|
(2) |
In the case of the exploration and production segment, other income corresponds mostly to natural hedges, services and sales of refined products (mainly LPG and asphalt). In the case of the refining and petrochemicals segment, other income corresponds mostly to industrial services. |
|
(3) |
The electric power transmission and toll roads concessions segment’s revenues mainly include: (i) electricity transmission services, (ii) designing, building, operating and maintaining road concessions infrastructure roads, and (iii) telecommunications services. |
In 2024, total revenues decreased by 6.9% as compared to 2023, primarily as a result of a COP 6,125,045 million decrease in revenues mainly due to (i) 9.3%, or USD 9.4 per barrel decrease of our average refined products basket price and a 0.1 %, or USD 0.1 per barrel decrease of our average crude oil basket price, which in turn was primarily due to a lower Brent benchmark price and narrower spreads against Brent for refined products partially offset by the strengthening of the negotiated crude oil differential., (ii) a COP 5,340,766 million decrease in revenues resulting from a 5.87% appreciation of the Colombian Peso against the U.S. dollar, from an average exchange rate of COP 4,325.05 / USD 1.00 in 2023 to an average exchange rate of COP 4,071.35 /USD 1.00 in 2024, resulting in a decrease in revenue from exports. This decrease was partially offset by (i) a COP 1,515,600 million increase in service revenue, primarily due to enhanced results in energy transmission due to the recognition of non-recurring income from the tariff review of ISA Subsidiaries in Brazil, toll roads, transport, the positive impact of contractual escalators and the entry into operation of projects, and (ii) a COP 88,498 million increase in revenues attributable to an increase in our sales volume (as further explained below).
The increase of our sales volume in 2024 as compared to 2023 was the result of a 3.5%, or 5.5 mmboe increase in our crude sales, primarily associated with higher crude oil production. This increase was partially offset by (i) a 0.9% or 1.6 mmboe in refined products volumes due to scheduled major maintenance of the Hydro-cracking unit the effect of the electrical failure in the Cartagena Refinery, and (ii) a 2.3%, or 0.8 mmboe decrease in our natural gas sales associated with the natural decline of the Guajira, Floreña and Cusiana fields.
128
In 2023, total revenues decreased by 10.3% as compared to 2022, primarily as a result of a COP 26,900,952 million decrease in revenues mainly due to a 19.1%, or USD 17.4 per barrel decrease of our average crude oil basket price and a 18.7%, or USD 22.1 per barrel decrease of our average refined products basket price, which in turn was primarily due to a lower Brent benchmark price and narrower spreads against Brent, primarily for refined products. This decrease was partially offset by (i) a COP 1,851,149 million increase in revenues resulting from a 1.64% depreciation of the Colombian Peso against the U.S. dollar, from an average exchange rate of COP 4,257.12/USD 1.00 in 2022 to an average exchange rate of COP 4,325.05/USD 1.00 in 2023, resulting in an increase in revenue from exports, (ii) a COP 1,098,169 million increase in service revenue, primarily due to enhanced results in energy transmission, toll roads, transport, and other services, and (iii) a COP 7,530,157 million increase in revenues attributable to an increase in our sales volume (as further explained below).
The increase of our sales volume in 2023 as compared to 2022 was the result of: (i) a 4.7%, or 19.8 mmboe increase in refined products volumes, which in turn was primarily due to the recovery in domestic demand and a higher operational performance of Reficar, and (ii) a 6.9% or 27.6 mmboe increase in our crude sales, primarily associated with an increase in the production of crude oil and products and higher trading operations.
|
4.6.1.2 |
Cost of Sales |
Our cost of sales was principally affected by the factors described below. See Note 26 to our consolidated financial statements for more detail.
Cost of sales in 2024 was COP 86,481,154 million, representing a COP 1,697,044 million or 1.9 % decrease as compared to 2023, primarily as a result of the following factors:
| ● | A COP 4,640,226 million decrease in the purchase costs of crude oil, natural gas and refined products, which were purchased for sales or for refining, resulting primarily from (i) lower average purchase prices by COP 2,520,925 million, which in turn was primarily due to the decrease in international benchmark prices for crude oil and refined products, (ii) a COP 2,692,030 million decrease in costs of the Colombian Peso terms due to the appreciation of the average exchange rate of the Colombian Peso against the U.S. dollar, mentioned above, and (ii) an decrease in crude oil and gas volumes purchased by COP 1,114,804 highlighting the decrease in crude oil import requirements resulting from lower trading operations. This were partially offset by a COP 1,687,532 million increase in volumes purchased of refined products given the programmed maintenance and operational events of Reficar. |
| ● | A COP 329,021 million decrease in inventory fluctuation primarily due to the realization of 100% of inventories in transit by the end of 2024. |
The decrease in cost of sales was partially offset by a COP 3,272,203 million increase as a result of:
(a) A COP 1,440,744 million increase in depreciation, amortization, and depletion expenses primarily due to: (i) a higher level of capital investment, and (ii) the increase in production of Permian. The above was partially offset by a lower depreciation rate associated with the mitigating effect of the higher incorporation of reserves during 2023 and the exchange rate effect in appreciation for the Group’s subsidiaries, which use the U.S. dollar as a functional currency, given the revaluation of the Colombian peso against the U.S. dollar.
(b) A COP 985,147 million increase in construction services mainly explained by: (i) increase in construction activity of ISA in Brazil, and (ii) the inflationary effect on the contracts.
(c) A COP 322,504 million increase in labor cost primarily related to higher salary increase in 2024 as compared to 2023.
(d) A COP 243,698 million increase in maintenance activities, contracted services, operation supplies and other operational activity costs, as a result to the net effect between: (i) greater execution of operational support activities, (ii) the inflation effect on costs, and (iii) lower average exchange rate for costs.
(e) A COP 227,972 million increase in transportation costs primarily related to: (i) higher volume of crude oil transported for tanker trucks due to an increase in the production from Caño Sur in Colombia, and (ii) higher transportation tariffs impacted by the inflationary effect.
(f) A COP 52,138 million increase in other minor items, including higher taxes and contributions, and general costs.
129
Cost of sales in 2023 was COP 88,178,198 million, representing a COP 1,279,950 million or 1.4% decrease as compared to 2022, primarily as a result of the following factors:
| ● | A COP 10,603,976 million decrease in the purchase costs of crude oil, natural gas and refined products, which were purchased for sales or for refining, resulting primarily from (i) lower average purchase prices by COP 11,000,671 million, which in turn was primarily due to the decrease in international benchmark prices for crude oil and refined products, and (ii) a COP 7,425,831 million decrease in volumes purchased of refined products given the higher operational availability of Reficar. Decreases in purchase prices and volumes purchased of refined products were partially offset by(i) an increase in crude oil and gas volumes purchased by COP 6,597,552 highlighting the increase in crude oil import requirements resulting from additional operational capacity of Reficar and higher trading operations, and (ii) a COP 1,157,335 million increase in costs of the Colombian Peso terms due to the appreciation of the average exchange rate of the Colombian Peso against the U.S. dollar, mentioned above. |
| ● | The decrease in cost of sales was partially offset by a COP 9,324,026 million increase as a result of: |
(a) A COP 3,577,654 million increase in inventory fluctuation primarily due to: (i) a lower valuation in line with the decrease in benchmark prices in 2023 versus 2022; (ii) higher crude throughputs required to cover the enhanced refinery operations; and (iii) an increase in the use of refined products resulting from higher production levels.
(b) A COP 2,650,981 million increase in contracted services, maintenance activities, operation supplies and other operational activity costs, as a result of an increase in operating activities, higher average exchange rate and the inflation effect in contracts.
(c) A COP 1,794,711 million increase in depreciation, amortization, and depletion expenses primarily due to: (i) a higher level of capital investment, (ii) the exchange rate effect in depreciation for the Group’s subsidiaries, which use the U.S. dollar as a functional currency, given the revaluation of the Colombian peso against the U.S. dollar, and (iii) the increase in production of Ecopetrol S.A. and Permian. The above was partially offset by a lower depreciation rate associated with the mitigating effect of the higher incorporation of reserves during 2022.
(d) A COP 540,203 million increase in labor cost related to higher salary increase in 2023 as compared to 2022.
(e) A COP 437,067 million increase in transportation costs primarily related to: (i) higher volume of crude oil and products transported for cabotage and tanker trucks due to an increase in economic activity during 2023 and (ii) higher transportation tariffs impacted by the inflationary effect.
(f) A COP 323,410 million increase in other minor items, including higher payments of royalties, taxes and contributions, and construction service.
|
4.6.1.3 |
Operating Expenses, net of other income before Impairment of Non-Current Assets Effects |
Operating expenses, net of other income include selling, general and administrative expenses and other income before impairment or recovery of non-current assets. For 2024 amounted to COP 9,253,705 million, a COP 1,900,385 million or 17% decrease as compared to 2023, mainly as a result of the following factors (see Notes 27 and 28 to our consolidated financial statements for more detail):
| ● | A COP 1,727,130 million income mainly from the profit of the transaction with Repsol Colombia Oil Gas Limited to acquire the remaining 45% of its participation in the CPO-09 Block, with economic effects as of December 31, 2024 that generated a positive effect on the year-end 2024 results due to the market prices valuation of both the acquired portion and Ecopetrol S.A.’s existing 55% participation interest, in compliance with International Financial Reporting Standards for Business Combinations. |
| ● | A COP 173,255 million decrease in exploration expenses and other operational expenses in 2024 as compared to 2023. |
For 2023, operating expenses, net of other income amounted to COP 11,154,090 million in 2023, a COP 1,518,912 million or 15.8% increase as compared to 2022, mainly as a result of the following factors (see Notes 27 and 28 to our consolidated financial statements for more detail):
| ● | A COP 576,654 million increase in exploration expenses mainly due to the write-off of exploratory assets in the Cusiana Subthrust, Cupiaga XD, and Cusiana deep, and that of unconventional reservoirs, such as La Luna and Kalé. |
| ● | A COP 395,403 million increase in labor expenses, mainly due to a 14.6% salary increase in 2023 as compared to 2022. |
130
| ● | A COP 356,418 million increase in commissions, fees and services, mainly due to effect of the inflation and additional operations, primarily in subsidiaries such as ISA and Permian. |
| ● | A COP 337,833 million increase in general operating expenses mainly due to customs operation expenses primarily because of the higher sales volumes under the DAP (Delivery at Place) modality. |
The increase in operating expenses in 2023 was partially offset by a COP 147,396 million decrease in other minor items, which mainly includes depreciation, amortization, and depletion expenses, tax and provisions and contingencies.
Each of our operating segments bears the costs and expenses incurred for product use and marketing and each segment assumes administrative expenses and all non-operational transactions related to its activity. Discussion of operating expenses by business segment is included in the section Financial Review—Operating Results—Consolidated Results of Operations—Segment Performance and Analysis .
|
4.6.1.4 |
Impairment of Non-Current Assets |
The impairment of our non-current assets includes losses (or recovery) of impairment of property, plant and equipment and natural resources, investments in companies, goodwill, and other non-current assets. The Company is exposed to future risks derived mainly from variations in: (i) oil prices outlook, (ii) refining margins and profitability, (iii) cost profile, (iv) investment and maintenance expenses, (v) amount of recoverable reserves, (vi) market and country risk assessments reflected in the discount rate, and (vii) changes of local and international regulations, among others.
Any change in the foregoing variables used to calculate the recoverable amount of a non-current asset can have a material effect on the recognition of either losses or recovery of impairment charges in the profit or loss statement in any given fiscal year. In our business segments highly sensitive variables can include, among others: (i) in the exploration and production segment, variations of hydrocarbon prices, (ii) in the refining segment, changes in finished products and crude oil prices, the discount rate, refining margins, (iii) in the transport and logistics segment, transported volumes and exchange rate, and (iv) in electric power transmission and toll roads concessions, internal and external factors that affect the recoverable value of the assets versus the book value of the assets, such as currency devaluation, network capacity, modest economic growth, among others.
In 2024, we recognized impairment recovery of non-current assets of COP 867,428 million, as compared to impairment losses of COP 2,098,333 million in 2023 and COP 287,999 million in 2022. These impairments are a non-cash accounting effect and consequently do not involve any disbursement or cash inflow. Further, any cumulative impairment amount of non-current assets, except for goodwill, is susceptible to reversion when the fair value of the asset exceeds its book value. On the contrary, in the event that the book value exceeds the fair value of the asset, an additional impairment expense could be recognized.
The 2024 impairment gains, net of non-current assets of COP 867,428 million, corresponds to the net result of:
| i. | A recovery of impairment in the Cartagena Refinery of COP 1,271,120 million, due to (i) improvement in the price differentials of refined products in the medium and long term due to market conditions, (ii) prioritization of local crude oils for the Cartagena Refinery, (iii) lower discount rate versus 2023 and (iv) a lower net book value of fixed assets due to the partial recovery of the cost of the modernization project as a result of the recognition of McDermott’s financial instrument settled in the arbitration with CBI (see section Legal Proceedings—Reficar Investigations for information on the arbitration with CBI). |
| ii. | A recovery in the transportation and logistics segment of COP 127,206 million mainly due to (i) the effect of the higher exchange rate by year-end 2024 compared to year-end 2023 that impacts revenues from oil pipelines that have rates in dollars and (ii) the positive adjustment in the oil pipeline rate due to macroeconomic effects given the resolution of the Ministry of Mines and Energy of September 2024. |
| iii. | An impairment in the Exploration and production segment of COP 480,180 million mainly in Ecopetrol America LLC given the lower short- and long-term prices. |
| iv. | An impairment of non-current assets in the electric power transmission and toll roads concessions segment of COP 45,351 million primarily in ISA Bolivia due to an increase in WACC from country risk and the effect of exchange rate differences on the dollar-denominated cash flow. |
131
The 2023 impairment losses, net of non-current assets of COP 2,098,333 million, corresponds to the net result of:
| i. | An impairment of non-current assets in the exploration and production segment of COP 2,741,092 million, mainly due to (i) capital expenditure variables, operational expenditure effects and prices mainly in cash-generating units (“CGU”) such as Casabe, Llanito, Suria, and Tibú; (ii) a recovery mainly in the Piedemonte unit, which was the subject of unification of the Floreña, Cupiagua and Cusiana assets during 2023, considering that these fields share facilities with each other, possess synergies, and jointly manage the surface fluids across the three large infrastructures, (iii) impairment losses were recognized in Hocol S.A. in the Cicuco, Toldado, La Hocha, Espinal, and Chenche CGUs and a recovery in Upía CGU, and (iv) in the CGUs abroad, an impairment loss was recognized in K2 CGU of Ecopetrol America LLC. |
| ii. | An impairment of non-current assets in the transportation and logistics segment of COP 630,134 million, primarily due (i) the decrease in the exchange rate for year-end 2023 versus 2022, (ii) the tariffs regulated by the Ministry of Mines and Energy and the Energy and Gas Regulation Commission (CREG, for its acronyms in Spanish), (iii) an increase in discount rates; and (iv) volumetric projection based on the financial plan and the long-term volumetric balance. |
| iii. | An impairment of non-current assets in the electric power transmission and toll roads concessions segment of COP 209,551 million mainly due to: (i) an impairment of COP 85,168 million in Consorcio Transmantaro due to lower fair market value in Yaros project, (ii) an impairment of COP 85,568 million in Internexa Brazil and COP 12,593 million in Intenexa Argentina, considering the update of the business plan that reflected a decrease in revenues and operating margins. |
This impairment loss was partially offset by an impairment recovery in Refining and Petrochemicals Segment of COP 1,482,444 million, primarily due to an impairment recovery in Cartagena Refinery, which in turn is due to (i) higher price differentials in middle distillates in the medium and long-term projection, (ii) imported crude oils more discounted on the brent marker, and (iii) operational improvements executed in 2023, which together with energy efficiency initiatives, have managed to optimize the operational costs of the refinery and reduce energy consumption.
The 2022 impairment losses, net of non-current assets of COP 287,999 million, corresponds to the net result of:
|
i. |
An impairment of non-current assets in the exploration and production segment of COP 890,248 million, mainly due to: (i) a decline in the reserves of Ecopetrol’s Cusiana and Llanito fields, (ii) lower prospects in Hocol’s Upía and Cicuco fields, (iii) an increase in the discount rate, and (iv) the impact of the tax reform. |
|
ii. |
A recovery of impairment in the Cartagena Refinery of COP 1,096,021 million, primarily as a result a better operating performance and higher refining margins captured in the short and medium term, which have partially offset the increase of the discount rate. |
|
iii. |
An impairment of non-current assets in the transportation and logistics segment of COP 406,229 million, primarily due to a lower volume outlook, which results in a decrease of the utilization of the Southern Cash Generating Unit (Puerto Tumaco and TransAndino pipeline) and the Northern Cash Generating Unit (Caño Limón). |
|
iv. |
An impairment of non-current assets in the electric power transmission and toll roads concessions segment of COP 87,543 million mainly due to lower margins and decreased performance of Internexa Brazil. |
For more information regarding impairment by segment, see section Financial Review—Operating Results—Consolidated Results of Operations—Segment Performance and Analysis .
|
4.6.1.5 |
Finance Results, Net |
Finance results, net, mainly includes exchange rate gains or losses, interest expense, yields and interest from our investments and non-current liabilities financial costs (asset retirement obligation and post-benefits plan).
Finance results, net, amounted to a loss of COP 8,519,948 million in 2024, as compared to a loss of COP 5,665,384 million in 2023. This increase in loss was mainly due to:
|
(i) |
A COP 2,346,145 million decrease in foreign exchange gain primarily driven by the lower exposure presented in 2024, managed through natural accounting exchange rate hedges. In 2024, our exchange rate gain was COP 51,567 million, as compared to a gain of COP 2,397,712 million in 2023. |
132
|
(ii) |
A COP 453,255 million increase in financial expenses related to long term obligations, primarily due to higher interest rates in refinancing operations during 2024. |
|
(iii) |
A COP 297,109 million decrease in financial income related primarily to valuation and yields of the investment portfolio and bank accounts derived from a decrease in market yield rates. |
|
(iv) |
A COP 268,664 million increase in financial update of long-term liability mainly due to the liability for cost of retirement obligation and the net interest on post-employment benefits and other long-term employee benefits. |
The decrease in foreign exchange gain and increase in financial expense were partially offset by a COP 510,609 million decrease in other minor items expenses, primarily due to the recognition of interests from a tax litigation ruling against Ecopetrol.
Finance results, net, amounted to a loss of COP 5,665,384 million in 2023 as compared to a loss of COP6,834,757 million in 2022. This decrease in loss was mainly due to:
|
i. |
A COP 2,522,362 million increase in foreign exchange gain primarily driven by the positive impact that the appreciation of the Colombian Peso against the U.S. dollar in 2023 had on our U.S. dollar net liability position. In 2023, our exchange rate gain was COP 2,397,712 million, as compared to a loss of COP 124,650 million in 2022. |
|
ii. |
A COP 975,542 million increase in financial income related to valuation and yields of the investment portfolio and bank accounts derived from an increase in market yield rates. |
The increase in foreign exchange gain and financial income were partially offset by:
|
iii. |
A COP 1,406,414 million increase in financial expenses related to long term obligations, primarily due to (i) higher indebtedness levels by the Ecopetrol Group; and (ii) higher interest rates. |
|
iv. |
A COP 922,117 million increase in other minor items expenses, primarily due to the recognition of interests from a tax litigation ruling against Ecopetrol. |
For more details on our financial income and expenses see Note 29 to our consolidated financial statements.
|
4.6.1.6 |
Income Tax |
Income taxes amounted to COP 12,208,540 million in 2024, COP 11,515,875 million in 2023, and COP 18,963,938 million in 2022. The above is equivalent to an effective tax rate of 39.8%, 31.2%, and 35.0% in 2024, 2023, and 2022, respectively.
The increase in the effective tax rate from 2023 to 2024 was mainly due to lower profits generated by lower average prices for the basket of crude oil, natural gas and refined products, the effect of the exchange rate on companies with a dollar functional currency in Colombia, the adjustment in the projections for the calculation of the surcharge for the following years and the effect of the acquisition of 45% participation interest of CPO-09 Block by Ecopetrol S.A., from Repsol Colombia Oil Gas Limited, among others.
The decrease in the effective tax rate from 2022 to 2023 was mainly due to: (i) the effect Ecopetrol Group’s subsidiaries with profit that have a nominal tax rate different from the parent company COP 841,937 million for Refineria de Cartagena, COP 39,489 million for Ecopetrol Capital AG, COP 47,781 million for Esenttia MB, COP 133,579 million for Ecopetrol USA, COP 179,955 million for Ecopetrol Permian, and COP 183,485 million for the other subsidiaries, and (ii) the decrease in results obtained in the year in Ecopetrol S.A and Hocol, generated by the decrease in revenues given the lower average prices of the crude basket oil, natural gas, and products, and, (iii) the adjustment IAS 12.41 due to decrease the 20.5% in the exchange rate, among others.
See Note 10 to our consolidated financial statements for more details.
|
4.6.1.7 |
Net Income (Loss) Attributable to Owners of Ecopetrol |
As a result of the foregoing, in 2024, net income attributable to owners of Ecopetrol was COP 13,841,153 million. In 2023, net income attributable to owners of Ecopetrol was COP 21,060,798 million, whereas in 2022, net income attributable to owners of Ecopetrol was COP 31,604,781 million.
133
|
4.6.1.8 |
Segment Performance and Analysis |
In this section, including the tables below, we present our financial information by segment: Exploration and Production, Refining and Petrochemicals, Transportation and Logistics, and Electric Power Transmission and Toll Roads Concessions. See section Business Overview for a description of each segment.
The following tables present our revenues and net income by business segment for the years ended December 31, 2024, 2023 and 2022:
Table 59 – Revenues by Business Segment
|
|
|
For the year ended December 31, |
|
% Change |
||||||
|
|
|
2024 |
|
2023 |
|
2022 |
|
2024/2023 |
|
2023/2022 |
|
|
|
(COP Million) |
||||||||
|
Exploration and Production |
|
81,087,523 |
|
81,514,915 |
|
91,020,464 |
|
(0.5) |
|
(10.4) |
|
Third parties |
|
52,559,851 |
|
52,429,502 |
|
60,719,903 |
|
0.2 |
|
(13.7) |
|
Local crude oil |
|
302 |
|
129,157 |
|
375,790 |
|
(99.8) |
|
(65.6) |
|
Foreign crude oil |
|
47,516,576 |
|
47,650,996 |
|
56,155,120 |
|
(0.3) |
|
(15.1) |
|
Local natural gas |
|
4,096,126 |
|
4,358,266 |
|
4,162,876 |
|
(6.0) |
|
4.7 |
|
Foreign natural gas |
|
43,539 |
|
105,413 |
|
254,054 |
|
(58.7) |
|
(58.5) |
|
Other income (2) |
|
903,308 |
|
185,670 |
|
(227,937) |
|
386.5 |
|
(181.5) |
|
Inter-segment net operating revenues |
|
28,527,672 |
|
29,085,413 |
|
30,300,562 |
|
(1.9) |
|
(4.0) |
|
|
|
|
|
|
|
|
|
|
|
|
|
Refining and Petrochemicals |
|
69,220,206 |
|
82,147,926 |
|
89,178,947 |
|
(15.7) |
|
(7.9) |
|
Third parties |
|
62,251,340 |
|
73,616,641 |
|
82,728,875 |
|
(15.4) |
|
(11.0) |
|
Local refined products |
|
49,543,812 |
|
59,319,485 |
|
70,911,613 |
|
(16.5) |
|
(16.3) |
|
Foreign refined products |
|
9,967,516 |
|
11,166,887 |
|
10,113,351 |
|
(10.7) |
|
10.4 |
|
Foreign crude oil |
|
1,281,956 |
|
2,027,551 |
|
92,147 |
|
(36.8) |
|
2,100.4 |
|
Other income |
|
1,458,056 |
|
1,102,718 |
|
1,611,764 |
|
32.2 |
|
(31.6) |
|
Inter-segment net operating revenues |
|
6,968,866 |
|
8,531,285 |
|
6,450,072 |
|
(18.3) |
|
32.3 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Transportation and Logistics |
|
15,133,721 |
|
15,509,732 |
|
13,955,992 |
|
(2.4) |
|
11.1 |
|
Third parties |
|
2,716,164 |
|
2,978,937 |
|
2,807,031 |
|
(8.8) |
|
6.1 |
|
Inter-segment net operating revenues |
|
12,417,557 |
|
12,530,795 |
|
11,148,961 |
|
(0.9) |
|
12.4 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Electric Power Transmission and Toll Roads Concessions (1) |
|
15,805,647 |
|
14,168,266 |
|
13,357,506 |
|
11.6 |
|
6.1 |
|
Third parties |
|
15,803,073 |
|
14,164,522 |
|
13,355,269 |
|
11.6 |
|
6.1 |
|
Inter-segment net operating revenues |
|
2,574 |
|
3,744 |
|
2,238 |
|
(31.2) |
|
67.3 |
|
Eliminations of consolidations |
|
(47,916,669) |
|
(50,151,237) |
|
(47,901,832) |
|
(4.5) |
|
4.7 |
|
Net Income |
|
133,330,428 |
|
143,189,602 |
|
159,611,078 |
|
(6.9) |
|
(10.3) |
| (1) | The electric power transmission and toll roads concessions segment’s revenues mainly include: (i) electricity transmission services, (ii) designing, building, operating and maintaining road concessions infrastructure roads, and (iii) telecommunications services. |
| (2) | mostly to industrial services. |
134
Table 60 – Operating and Net Income by Business Segment
|
|
|
For year ended December 31 |
|
% Change |
||||||
|
|
|
2024 |
|
2023 |
|
2022 |
|
2024/2023 |
|
2023/2022 |
|
|
|
(COP Million) |
||||||||
|
Exploration and Production |
|
|
|
|
|
|
|
|
|
|
|
Operating Income |
|
20,818,745 |
|
20,090,025 |
|
37,358,934 |
|
4 |
|
(46) |
|
Net income |
|
9,162,709 |
|
10,208,130 |
|
21,761,164 |
|
(10) |
|
(53) |
|
Refining and Petrochemicals |
|
|
|
|
|
|
|
|
|
|
|
Operating Income |
|
373,796 |
|
5,455,703 |
|
7,694,598 |
|
(93) |
|
(29) |
|
Net income |
|
(1,407,810) |
|
5,352,446 |
|
4,686,009 |
|
(126) |
|
14 |
|
Transportation and Logistics |
|
|
|
|
|
|
|
|
|
|
|
Operating Income |
|
9,594,762 |
|
9,486,076 |
|
8,732,561 |
|
1 |
|
9 |
|
Net income |
|
5,112,271 |
|
4,829,051 |
|
4,483,060 |
|
6 |
|
8 |
|
Electric Power Transmission and Toll Roads Concessions |
|
|
|
|
|
|
|
|
|
|
|
Operating Income |
|
7,655,571 |
|
6,646,289 |
|
6,345,153 |
|
15 |
|
5 |
|
Net income |
|
966,738 |
|
674,968 |
|
673,688 |
|
43 |
|
0 |
|
Eliminations of consolidations |
|
|
|
|
|
|
|
|
|
|
|
Operating Income |
|
20,123 |
|
80,888 |
|
98,507 |
|
(75) |
|
(18) |
|
Net income |
|
7,245 |
|
(3,797) |
|
860 |
|
(291) |
|
(542) |
|
TOTAL |
|
|
|
|
|
|
|
|
|
|
|
Operating Income |
|
38,462,997 |
|
41,758,981 |
|
60,229,753 |
|
(8) |
|
(31) |
|
Net income |
|
13,841,153 |
|
21,060,798 |
|
31,604,781 |
|
(34) |
|
(33) |
We are currently organized into three corporate business lines: (A) Hydrocarbons, which includes four operational divisions: (i) Exploration and Production, (ii) Transportation and Logistics, (iii) Refining Petrochemicals and Biofuels, (iv) and Sales and Marketing; (B) Energies for the Transition, which includes natural gas, biogas, LPG, power, renewables, hydrogen and CCUS; and (C) Transmission and Toll Roads. However, as discussed above in Our Corporate Strategy—2025 Investment Plan, given the transformation of our Company with the ISA acquisition and in line with our 2040 Strategy, in 2022, we started a process to align our current segments more closely to the vision of the 2040 Strategy for the Ecopetrol Group and such process is undergoing.
However, for purposes of this annual report, the financial information included in this annual report is organized by the following segments: (i) exploration and production, (ii) transportation and logistics, (iii) refining and petrochemicals, and (iv) energy transmission and roads, which is consistent with previous Company annual reports. The Company’s management is currently reviewing different options to update the operating and financial reporting model of the Company to be better aligned with the 2040 Strategy.
|
4.6.1.9 |
Exploration and Production Segment Results |
In 2024, exploration and production segment sales were COP 81,087,523 million, compared to COP 81,514,915 million in 2023. In 2024, our segment sales decreased by 0.5 % as compared to 2023, mainly as a result of:
(i) A 1.9 % decrease in inter-segment revenues in 2024 as compared to 2023 mainly due to: (i) the decrease in Brent reference prices partially offset by the strengthening of the negotiated crude oil differential, and (ii) the depreciation of the Colombian Peso against the U.S. dollar.
(ii) A 0.3% increase in sales of crude oil to third parties in 2024 as compared to 2023 primarily due to: (i) higher sales volumes of 19.7 mbd, due to an increase in the production from Permian and Caño Sur in Colombia, and (ii) higher price of our crude oil basket of USD 0.1 per barrel; partially offset by (iii) the appreciation of the Colombian Peso against the U.S dollar.
135
In 2023, our segment sales decreased by 10.4% as compared to 2022, mainly as a result of:
(i) A 13.7% decreased in sales of crude oil to third parties in 2023 as compared to 2022 primarily due to: (i) a decrease in the price of our crude oil basket of USD 17.4 per barrel, and (ii) the appreciation of the Colombian Peso against the U.S dollar, resulting in a decrease in sales revenue recorded in U.S. dollars; and offset by higher sales volumes of 17.9 mbd, due to (i) an increase in the production from Rubiales and Caño Sur in Colombia, as well as increased production of Permian, and (ii) higher trading operations.
(ii) A 4.0% decrease in inter-segment revenues in 2023 as compared to 2022 mainly due to: (i) the decrease in Brent reference prices, and (ii) the appreciation of the Colombian Peso against the U.S. dollar.
Cost of sales affecting our exploration and production segment are mainly related to: (i) the amortization and depletion of our production assets, (ii) contracted services and (iii) costs related to maintenance, operational services, electric power, projects, and labor cost. In addition, this segment’s costs are impacted by the purchases of crude oil from ANH and third parties, naphtha for dilution and transportation services.
In 2024, the cost of sales for this segment increased by 5.9% as compared to 2023 due to the net effect of:
(i) Fixed costs increasing by 2.5%, or COP 352,125 million in 2024 as compared to 2023, mainly due to: (i) higher activity including well interventions, maintenance and contracted services to support the production including the preparation and operational support for the start-up of the Orotoy station and the new Caño Sur facilities, as well as the specific maintenance required in the Gunflint and K2 fields of Ecopetrol America LLC; and (ii) an increase in depreciation, amortization and depletion, associated with higher production and Capex.
(ii) Variable costs increasing by 7.1%, or COP 2,683,039 million in 2024 as compared to 2023, as a result of (i) higher energy consumption, chemical treatment and transportation costs associated with production increase, (ii) inflationary effect on the rates of materials needed for well interventions and chemical treatment; (iii) transportation costs associated with the execution of reversal cycles in the Bicentenario Pipeline, resulting from fewer days of operation of the Caño Limón Pipeline, and (vi) higher purchased volumes from third parties. These increases were partially offset by lower average exchange rate on cost denominated in dollar.
In 2023, the cost of sales for this segment increased by 10.9% as compared to 2022 due to the net effect of:
(i) Fixed costs increasing by 17.2%, or COP 2,084,693 million in 2023 as compared to 2022, mainly due to: (i) an increase in transportation tariffs in pipeline as a result of the appreciation of the Colombian Peso against the U.S dollar, (ii) higher activity including well interventions, maintenance and contracted services to support the operation and improvements in wells with production decline; and (iii) higher in labor expenses aligned with inflation effect.
(ii) Variable costs increasing by 8.6%, or COP 2,993,771 million in 2023 as compared to 2022, as a result of (i) higher electricity fees impact associated with the El Niño phenomenon; (ii) inflationary effect on the rates of materials needed for well interventions and chemical treatment; (iii) higher consumption of electricity and chemical treatment associated with production increases, (iv) higher transportation costs due also to an increase in production, (v) costs associated with the execution of reversal cycles in the Bicentenario Pipeline, resulting from fewer days of operation of the Caño Limón Pipeline, and (vi) higher purchased volumes from the ANH and third parties. These increases were partially offset by a lower purchase costs due to: (i) lower purchase prices and volumes of diluents; and (ii) decreases in domestic purchases due to lower prices.
In 2024, operating expenses, net of other income before impairment of non-current assets decreased by 28.2% as compared to 2023 primarily as a result of: (i) profit of the transaction with Repsol Colombia Oil Gas Limited to acquire the remaining 45% of its participation in the CPO-09 Block, due to the market prices valuation of both the acquired portion and Ecopetrol S.A.’s existing 55% participation interest in compliance with International Financial Reporting Standards for Business Combinations, (ii) lower updating of provisions and contingencies, and (iii) lower write-off of exploration assets in 2024 versus 2023.
In 2023, operating expenses before impairment of non - current assets increased by 13.9% as compared to 2022 primarily as a result of: (i) higher exploratory expenses mainly as a result of the recognition exploratory and seismic activity of Ecopetrol S.A., (ii) the implementation of new environmental legal provisions and addressing contingencies, (iii) higher sales volumes under the Delivery at Place (DAP) modality by subsidiaries dedicated to commercialization activities, (iv) higher expenses capitalized due to an incremental execution of investment projects, and (v) increase in labor expenses due to inflation. This increase was partially offset by write - off of investments in Ecopetrol America LLC’s Rydberg asset registered in 2022.
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In 2022, operating expenses before impairment of non-current assets increase by 34.2% as compared to 2021 primarily as a result of: (i) higher exploratory expenses in 2022 mainly as a result of the recognition of spending on exploratory and seismic activity in Brazil, (ii) increase in asset write-off after the completion of a viability analysis in the Saturno and Rydberg fields, (iii) increase in freight costs for exports to America, Europe and Asia under the “delivery at place” model, (iv) increase in maintenance of external roads and facilities and attention to operational contingencies, (v) increase in labor expenses due to salary increases, and (vi) loss of crude due to damages by third parties to our infrastructure. This increase was partially offset by (i) lower expenses related to the updating of processes, resulting from new legal, tax and environmental provisions, and (ii) the profit from the sale of the Casanare, Estero, Garcero, Orocue and Corocora fields in 2022.
The impairment of non-current assets recognized in the exploration and production segment in 2024 was COP 480,180 as compared to COP 2,741,092 million recognized in 2023. The impairment in this segment in 2024 was mainly in Ecopetrol America LLC due to lower short- and long-term prices as well as the reclassification of reserves.
The impairment of non-current assets recognized in the exploration and production segment in 2023 was COP 2,741,092 as compared to COP 890,248 million recognized in 2022. This impairment loss was mainly due to (i) capital expenditure variables, operational expenditure effects and prices mainly in CGUs such as Casabe, Llanito, Suria, and Tibú; (ii) a recovery mainly in the Piedemonte unit, which was the subject of unification of the Floreña, Cupiagua and Cusiana assets during 2023, considering that these fields share facilities with each other, possess synergies, and jointly manage the surface fluids across the three large infrastructures; (iii) impairment losses were recognized in Hocol S.A. in the Cicuco, Toldado, La Hocha, Espinal, and Chenche CGUs and a recovery in Upía CGU; and (iv) in the CGUs abroad, an impairment loss was recognized in K2 CGU of Ecopetrol America LLC.
There was an impairment of non-current assets recognized in the exploration and production segment in 2022, totaling COP 890,248 million in 2022 as compared to a recovery of COP 438,020 million in 2021. The impairment loss in this segment in 2022 was mainly due to: (i) the decline in reserves of the Cusiana and Llanito fields, (ii) lower prospectivity in the Upía and Cicuco fields in Hocol, (iii) the increase in discount rates, and (iv) the impact of the tax reform in terms of non-deductibility of royalties and higher tax rate.
The segment recorded a net income attributable to owners of Ecopetrol of COP 9,162,709 million in 2024 as compared to net income attributable to owners of Ecopetrol of COP 10,208,130 million in 2023 and net income attributable to owners of Ecopetrol of COP 21,761,164 million in 2022.
Lifting and Production Costs
The aggregate average production cost, on a Colombian Peso basis, increased from COP 50,098 per boe during 2023 to COP 54,274 per boe during 2024. Moreover, this indicator increased from USD 11.58 per boe in 2023 to USD 13.33 per boe in 2024.
The aggregate average lifting cost, on a Colombian Peso basis, increased from COP 47,204 per boe during 2023 to COP 50,833 per boe during 2024. On a dollar basis, the cost increased from USD 10.91 per boe in 2023 to USD 12.49 per boe in 2024, partially offset by a 6.2% appreciation of the Colombian Peso against the U.S. dollar in 2023.
In 2024, both the aggregate average production cost and the aggregate average lifting cost increased compared to 2023, mainly due to:
|
(i) |
Increased number of surface maintenance operations as well as number of well interventions to recover base production. |
|
(ii) |
Growth of surface facilities due to development of new production fields (CPO-09 and Caño Sur). |
|
(iii) |
Increase of power energy consumption due to greater production oil in the fields and consequently of water production (BSW - Basic Sediment and Water) |
|
(iv) |
Rise of liquid fuels prices required for self-generation of electricity in non-interconnected production fields. |
|
(v) |
Increase in contractual rates associated with chemical treatment in the extraction and treatment of fluids processes (crude oil, water and gas). |
The difference between the production and lifting costs is that first one additionally includes the production cost of the refineries and natural gas liquid plants located in the production fields.
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The following table sets forth crude oil and natural gas average sales prices, the average lifting cost and the average production cost for the years ended December 31, 2022, 2023 and 2024.
Table 61 – Crude Oil and Natural Gas Average Prices and Costs
|
|
|
2024 |
|
2023 |
|
2022 |
|
Crude Oil Average Sales Price (USD per barrel) (1) |
|
73.5 |
|
73.4 |
|
90.9 |
|
Crude Oil Average Sales Price (COP per barrel) (1) |
|
299,040 |
|
315,947 |
|
384,525 |
|
Natural Gas Average Sales Price (USD per barrel equivalent) |
|
27.8 |
|
28.4 |
|
27.6 |
|
Natural Gas Average Sales Price (COP per barrel equivalent) |
|
114,299 |
|
130,361 |
|
118,828 |
|
Aggregate Average Unit Production Costs (USD per boe) (2) |
|
13.33 |
|
11.58 |
|
9.83 |
|
Aggregate Average Unit Production Cost (COP per boe) (2) |
|
54,274 |
|
50,098 |
|
41,841 |
|
Aggregate Average Lifting Costs (USD per boe) (3)(4)(5) |
|
12.49 |
|
10.91 |
|
9.21 |
|
Aggregate Average Lifting Costs (COP per boe) (3)(4)(5) |
|
50,833 |
|
47,204 |
|
39,187 |
|
(1) |
Corresponds to our average sales price on a consolidated basis. |
|
(2) |
Unit production costs correspond to consolidated average costs on total production volumes net of royalties. Production costs do not include costs related to transport, commercialization and administrative expenses. |
|
(3) |
Lifting costs per barrel are calculated based on total production (excluding production tests and discovered undeveloped fields), which are net of royalties, and correspond to our lifting costs on a consolidated basis. |
|
(4) |
The cost indicator is calculated by using the cost of production (does not include costs related to hydrocarbons consumption by Ecopetrol in the production process, such as by our refineries and natural gas liquid plants) and dividing by the net produced volume (excluding royalties) as the denominator. |
|
(5) |
As a result of the evaluation of control over companies under IFRS, Ecopetrol does not consolidate Equion. |
|
4.6.1.10 |
Transportation and Logistics Segment Results |
In 2024, our transportation and logistics segment sales were COP 15,133,721 million compared to COP 15,509,732 million in 2023. The 2.4% decrease in 2024 as compared to 2023 was mainly due to: (i) lower average COP/USD exchange rate, and (ii) completion in September 2023 of the “ship or pay” contract with Oleoducto Bicentenario. This decrease was partially offset by: (i) the tariff update on oil pipelines, (ii) higher incomes from contingent operation, and (iii) the increase in industrial services.
In 2023, our transportation and logistics segment sales were COP 15,509,732 million compared to COP 13,955,992 million in 2022. The 11.1% increase in 2023 as compared to 2022 was mainly due to: (i) higher volumes transported due to the increase in production of crude oil and refined products, along with operational efficiencies in the transportation systems; (ii) higher average COP/USD exchange rate; (iii) annual fees update; and (iv) the execution of 13 contingent reversal cycles in the Bicentenario pipeline, versus only one cycle executed in the previous year.
The cost of sales for our transportation and logistics segment is mainly related to: (i) project costs associated with the maintenance of transportation networks, and (ii) operating costs related to these systems, including the costs of labor, energy, fuels and lubricants and others.
The cost of sales amounted to COP 4,377,897 million in 2024 as compared to COP 4,380,195 million in 2023. The cost of sales for this segment decreased by 0.1% in 2024 as compared to 2023 mainly due to lower depreciation derived from the update of the useful life of the Bicentenario Pipeline; offset by: inflationary effect on maintenance contract fees, operating support area costs, and personnel costs, among others.
The cost of sales amounted to COP 4,380,195 million in 2023 as compared to COP 3,893,210 million in 2022. The cost of sales for this segment increased by 12.5% in 2023 as compared to 2022 mainly due to: (i) the inflationary effect on maintenance contract fees, operating support area costs, and personnel costs, among others, (ii) higher operation and maintenance activities, and (iii) the increase in variable costs of materials and electricity, mainly associated with higher volumes transported and increases in energy prices, consistent with market conditions.
In 2024, operating expenses before the impairment of non-current assets increased by 27.1% as compared to 2023 mainly due to (i) higher emergency response, social investment activities and technology expenses, (ii) inflationary effect, and (iii) impairment of materials inventories.
In 2023, operating expenses before the impairment of non-current assets increased by 9.7% as compared to 2022 mainly due to (i) higher emergency response and social investment activities expenses, and (ii) an increase in personnel expenses and insurance policies.
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The recovery of impairment loss of non-current assets recognized in the segment in 2024 was COP 127,206 million, compared to the impairment loss of non-current assets of COP 630,134 million in 2023. This recovery of impairment was primarily due to (i) the increase in the exchange rate for year-end 2024 versus 2023; (ii) the new tariffs for oil pipes regulated by the Ministry of Mines and Energy; and (iii) volumetric projection based on the financial plan and the long-term volumetric balance.
The impairment loss of non-current assets recognized in the segment in 2023 was COP 630,134 million, compared to the impairment loss of non-current assets of COP 406,229 million in 2022. This impairment loss was primarily due to (i) the decrease in the exchange rate for year-end 2023 versus 2022; (ii) the tariffs regulated by the Ministry of Mines and Energy and the Energy and Gas Regulation Commission - CREG; and (iii) volumetric projection based on the financial plan and the long-term volumetric balance.
The segment recorded net income attributable to owners of Ecopetrol of COP 5,112,271 million in 2024, as compared to a net income of COP 4,829,051 million in 2023 and COP 4,483,060 million in 2022.
|
4.6.1.11 |
Refining and Petrochemicals Segment Results |
In 2024, the refining and petrochemical segment sales were COP 69,220,206 million compared to COP 82,147,926 million in 2023. In 2024, sales of refined products and petrochemicals decreased by 15.7% as compared to 2023, mainly due to: (i) lower prices of middle distillate products and gasoline, and a decrease of refined product spreads, in both cases associated with market factors, (ii) scheduled major maintenance of the hydrocracking unit and the effect of the electrical failure at Cartagena Refinery, and (iii) lower average COP/USD exchange rate. Invercolsa’s revenues increased as a result of the higher commercialization of natural gas volumes. Esenttia’s sales volume decreased 108 tons, due to a strategy based on pursuing sales with higher margins instead of pursuing the target volume, increasing year-on-year sales results and total margin of USD 85.9 per ton in 2023 to USD 177.6 per ton in 2024.
In 2023, the refining and petrochemical segment sales were COP 82,147,926 million compared to COP 89,178,947 million in 2022. In 2023, sales of refined products and petrochemicals decreased by 7.9% as compared to 2022, mainly due to: (i) lower prices of middle distillate products and gasoline, and (ii) decrease of refined product spreads, in both cases associated with market factors. Invercolsa’s revenues increased as a result of the higher commercialization of natural gas volumes. Esenttia’s sales volume decreased 32,000 tons due to an increase in polypropylene (PP) prices due to moderating demand and high inventories, reducing year-on-year sales results and total margin of USD 214.9 per ton in 2022 to USD 85.9 per ton in 2023.
The cost of sales for our refined products and petrochemicals segment is mainly related to the purchase of crude oil and natural gas for our refineries, imported crude oil and products to supply local demand, feedstock transportation services, services contracted for maintenance of the refineries and the amortization and depreciation of refining assets.
Cost of sales amounted to COP 67,717,757 million in 2024, compared to COP 75,716,453 million in 2023 and COP 80,331,998 million in 2022. In 2024, the cost of sales for this segment decreased 10.6% as compared to 2023, mainly due to (i) lower crude feedstock cost, (ii) higher savings associated with the cost optimization strategy, and (iii) lower crude oil purchases associated with inventory management at the refineries.
Cost of sales amounted to COP 75,716,453 million in 2023, compared to COP 80,331,998 million in 2022 and COP 48,535,388 million in 2021. In 2023, the cost of sales for this segment decreased 5.7% as compared to 2022, mainly due to (i) lower crude feedstock cost, and (ii) decrease in refined product spreads, associated with market factors, partially offset by (i) cost associated with the higher cargo volumes; and (ii) the higher average COP/USD exchange rate.
In 2024, operating expenses, net of other income and before the impairment reversal of non-current assets decreased by 2.6% as compared to 2023, mainly due to the incorporation of efficiencies and optimizations in administrative expenses.
In 2023, operating expenses, net of other income and before the impairment reversal of non-current assets increased by 9.3% as compared to 2022, mainly due to higher sales and marketing expenses due to the increase in volumes sold abroad.
In 2024, we recognized an impairment recovery of non-current assets in this segment totaling COP 1,265,753 million, as compared to an impairment recovery of COP 1,482,444 million in 2023. The recovery recorded in 2024 was generated primarily due to an impairment recovery in Cartagena Refinery due to (i) higher price differentials in middle distillates in the medium and long-term projection, (ii) prioritization of local crudes, and (iii) lower discount rate versus 2023, according to market conditions.
139
In 2023, we recognized an impairment recovery of non-current assets in this segment totaling COP 1,482,444 million, as compared to an impairment recovery of COP 1,096,021 million in 2022. The recovery recorded in 2023 was generated primarily due to an impairment recovery in Cartagena Refinery due to (i) higher price differentials in middle distillates in the medium and long-term projection, (ii) imported crude oils more discounted on the brent marker, and (iii) operational improvements executed in 2023, which together with energy efficiency initiatives have managed to optimize the operational costs of the refinery and reduce energy consumption.
In 2022, we recognized an impairment recovery of non-current assets in this segment totaling COP 1,096,021 million, as compared to an impairment loss of COP 305,466 million in 2021. The recovery recorded in 2022 was generated for the Cartagena Refinery, mainly due to better operating performance and the capture of higher refining margins in the short and medium term. The above was partially offset by the effect of the increase in the discount rate.
As mentioned earlier, the refining segment is highly sensitive to changes in product prices and feedstock in the international market, discount rate and refining margins, among others.
The refining and petrochemicals segment recorded net loss attributable to owners of Ecopetrol of COP 1,407,810 million in 2024, compared to a net income of COP 5,352,446 million in 2023 and a net income of COP 4,686,009 million in 2022.
|
4.6.1.12 |
Electric Power Transmission and Toll Roads Concessions Segment Results |
In 2024, the electric power transmission and toll roads segment revenues from contracts with customers were COP 15,805,647 million, which included COP 12,998,524 million for electricity transmission, COP 2,352,336 million for toll road concessions and COP 454,787 million for telecommunication technologies and other operating revenues.
In 2024, income increased mainly due to the energy business due to the one-off recognition of the Periodic Tariff Review (“RTP”) in Brazil. Additionally, new operative projects, the positive impact of contractual escalator clauses and the end of the provisions applied by the CREG associated with the voluntary decrease in fees, resuming the use of the PPI as a revenue escalator in Colombia. Likewise, the telecommunications business increased its revenues mainly due to the “National Connectivity Plan” at Internexa Colombia.
In 2023, the electric power transmission and toll roads segment revenues from contracts with customers were COP 14,168,266 million, which included COP 10,940,721 million for electricity transmission, COP 2,752,383 million for toll road concessions and COP 475,162 million for telecommunication technologies and other operating revenues.
In 2023, income increased mainly due to the energy business with projects that began operations, the positive impact of contractual escalator clauses, and higher returns on contractual assets. Additionally, adjustments to construction margins, along with new energizing improvements and reinforcement in Brazil projects, contributed positively, and the end of the provisions applied by the CREG associated with the voluntary decrease in fees, resuming the use of the PPI as a revenue escalator in Colombia. These effects were partially offset by (i) the revenue decreases in the toll road business due to the financial impact in the valuation of financial assets in Chile changed from UF (Unidad de Fomento) to CLP (Chilean pesos) in 2022, along with the end of the Ruta del Bosque concession; and (ii) in the telecommunications business, due to lower customer acquisitions, disconnections, reduced capacities, and loss of internet service users in Brazil, Colombia, and Peru.
In 2022, the electric power transmission and toll roads segment revenues from contracts with customers were COP 13,357,506 million, which included COP 10,004,902 million for electricity transmission, COP 2,867,499 million for toll road concessions and COP 485,105 million for telecommunication technologies and other operating revenues.
In 2022, electricity transmission revenues were positively affected by the completion of projects under construction that enabled a cleaner energy matrix in the region. Seven power transmission projects, one battery project, and 76 expansions and reinforcements were activated. Together, these projects are expected to generate annual revenues of USD 167 million and add more than 2,200 km of circuit to the transmission network. Toll road concession revenues were positively affected by the change in the treatment of financial assets from Chilean pesos to UF, together with higher revenues associated with the operation and management of road infrastructure. Telecommunication technologies were positively affected by higher sales of connectivity, sales of capacity, Internet and Ethernet services and other telecommunications services in Colombia and Peru, and the growth of the over the top operators segment in Colombia.
In 2024, the cost of sales amounted to COP 6,952,104 million, compared to COP 5,928,905 million for 2023. These costs primarily encompass construction expenses associated with concession contracts, as well as operation and maintenance costs within our electric power transmission and toll roads concessions segment.
140
The operating costs for our electric power transmission and toll roads concessions segment, which is mainly related to construction costs of concession contracts, operation and maintenance costs, amounted to COP 6,769,380 million for 2024, compared to COP 5,741,590 million for 2023
Administrative expenses amounted to COP 1,150,596 million in 2024, compared to COP 1,182,380 million for 2023. The administrative expenses include depreciation, personnel services, commissions, fees expenses and services.
The increase in cost of sales and administrative expenses are mainly due to (i) in the energy business, inflationary pressures on costs, higher maintenance and conservation services for transmission lines and substations, personnel services and fees expenses, and (ii) in the telecommunications business, higher costs mainly due to the “National Connectivity Plan” at Internexa Colombia, these effects were offset mainly by lower costs in the telecommunications business due to the sale of subsidiaries in Brazil, Argentina and Chile. The above was partially offset by the effect of the lower DDA cost due to the lower depreciation during 2024 due to the closure of operations in Brazil, Argentina and Chile in the telecommunications business.
The electric power transmission and toll roads segment and its companies continue to implement initiatives aimed at controlling these expenses by monitoring productivity indicators and designing a cost model based on the asset’s life cycle.
In 2024, the share of profit of associates and joint ventures caused a positive effect in our results of COP 540,102 million, which corresponded to the participation in the results mainly of Transmissora Aliança de Energia Elétrica , Interligação Elétrica do Madeira and Interligação Elétrica Ivaí , energy transport companies in Brazil .
In 2023, the share of profit of associates and joint ventures caused a positive effect in our results of COP 529,536 million, which corresponded to the participation in the results mainly of Transmissora Aliança de Energia Elétrica , Interligação Elétrica do Madeira and Interligação Elétrica Garanhuns , energy transport companies in Brazil.
In 2022, the share of profit of associates and joint ventures caused a positive effect in our results of COP 515,746 million, which corresponded to the participation in the results mainly of Transmissora Aliança de Energia Elétrica , Interligação Elétrica do Madeira and Interligação Elétrica Garanhuns , energy transport companies in Brazil.
The impairment of non-current assets recognized in the segment in 2024 was COP 45,351 million. This impairment was primarily due to: (i) impairment COP 26,606 million in ISA Bolivia due to an increase in WACC from country risk and the effect of exchange rate differences on the dollar-denominated cash flow, (ii) impairment COP 16,255 in Internexa Colombia due to in the right to submarine capacity, as a consequence of price erosion in the market due to the substantial increase in supply.
In 2023, we recognized an impairment loss of non-current assets in this segment totaling COP 209,551 million mainly due to: (i) impairment COP 85,168 million in Consorcio Transmantaro due to a lower fair market value in Yaros project, (ii) impairment of COP 96,593 million in Internexa Brazil, COP 11,248 in Internexa Colombia, and COP 14,592 million in Intenexa Argentina, considering the update of the business plan that reflected decrease in revenues and operating margins to the South Cash Generating Unit.
The electric power transmission and toll roads concessions segment recorded net income attributable to owners of Ecopetrol of COP 966,738 million in 2024, as compared to net income attributable to owners of Ecopetrol of COP 674,968 million in 2023 and a net income of COP 673,688 million in 2022.
|
4.7 |
Liquidity and Capital Resources |
Our principal sources of liquidity in 2024 were: (i) cash flows amounting to COP 45,127,516 million from our operations and payments received from the FEPC for balances receivable at the end of 2023, (ii) cash flows from our investing activities mainly due to interest received amounting to COP 1,627,135 million and (iii) cash flow from dividends amounting to COP 425,191 million.
Our main uses of cash in 2024 were: (i) 21,807,981 million in capital expenditures, which included investments in property, plant and equipment, natural and environmental resources and intangibles, (ii) dividend payments amounting to COP 15,565,064 million, which included dividends of COP 12,802,893 million to Ecopetrol’s shareholders, including minority shareholders, and dividends paid to the non-controlling shareholders of our subsidiaries totaling COP 2,762,171 million, and (iii) COP 6,528,891 related to net effect of proceeds and payments of principal and payments of interest. For more information regarding our debt, see section Financial Review—Financial Indebtedness and Other Contractual Obligations .
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|
4.7.1 |
Review of Cash Flows |
Cash from operating activities
Net cash provided by operating activities increase by 127.9% in 2024 as compared to 2023, mainly as a result of:
|
(i) |
Largest source of cash generation through working capital management by COP 32,201,352 million mainly due to the payment received from FEPC and lower tax payments between 2024 and 2023. |
|
(ii) |
A COP 6,575,711 million decrease in our operating income before depreciation, depletion and amortization (DDA) and impairment of non-current assets primarily due to: i) lower market prices for refined products, ii) lower average exchange rate, iii) the effect of inflation on costs and expenses, factors that were offset by better operational performance reflected in increased production and sales given commercial management and iv) new businesses integrated into the consolidated results of the Ecopetrol Group, mainly the impact of increased participation in the CPO-09 Block. |
Net cash provided by operating activities decreased by 45.4% in 2023 as compared to 2022, mainly as a result of:
|
(i) |
A COP 14,977,042 million decrease in our operating income before depreciation, depletion and amortization (DDA) and impairment of non-current assets primarily due to: (i) unfavorable crude and refined product prices in the international, Asian and European markets, and (ii) inflation and the exchange rate effect on operating costs and expenses. The above was partially offset by higher sales volumes by 5.5% as compared to 2022, associated with increases in production, a positive performance by the refineries, and higher volumes transported. |
|
(ii) |
Higher working capital needs by COP 4,071,109 million due to an increase in tax payments between 2023 and 2022 which corresponds mainly to the better results obtained by Ecopetrol S.A. in 2022, generated by the growth of revenue given the increase in the average prices of the crude basket oil, natural gas. |
Cash used in investing activities
In 2024, net cash used in investing activities increased by 10.1% as compared to 2023, mainly resulting from a 9.5% increase in capital expenditures due to: (i) development wells in Rubiales, Caño Sur, Castilla, Floreña, (ii) acquisition of CPO09, (iii) higher investment in Permian, (iv) investments focused on operational continuity in the midstream and downstream segments, among others.
In 2023, net cash used in investing activities increased by 10.6% as compared to 2022, mainly resulting from a 10.1% increase in capital expenditures mainly in development wells in Rubiales, Caño Sur, Castilla, Casabe, and Permian in the upstream segment, investments focused on operational continuity in the midstream and downstream segments, investments in the construction of power lines, and investments to increase the reliability of the grid and comply with regulation.
Cash used in financing activities
Net cash used in financing activities increased by 6,298% in 2024, as compared to 2023, from 354,609 million used in financing activities in 2023 to 22,687,122 million used in financing activities in 2024. The difference was mainly due to (i) a COP 12,323,566 million increase from borrowings, net of related repayments of principal and payments of interest, as compared to 2023 due mainly to the devaluation of the Colombian peso against the dollar, and (ii) a COP 9,994,188 million increase in dividend payments in 2024 as compared to 2023 is mainly explained by the partial offset of the 2023 payment to the majority shareholder against accounts receivable from the Nation under the Fuel Price Stabilization Fund (FEPC), which reduced the cash outflow during that year.
Net cash used in financing activities decreased by 98.1% in 2023, as compared to 2022, mainly due to: (i) a COP 7,786,071 million decrease in cash dividend payments in 2023 as compared to 2022, and (ii) a COP 10,852,391 million increase from borrowings, net of related repayments of principal and payments of interest, as compared to 2022.
142
|
4.7.2 |
Capital Expenditures |
Our consolidated capital expenditures in 2024, 2023, and 2022 were COP 22,917,280 million, COP 24,090,916 million, and COP 21,877,770 million, respectively. These investments were distributed by business segment on average, for the past three years as follows 76.8% for the exploration and production segment, 10.7% for the transportation and logistics segment, 4.6% for the electric power transmission and toll roads concessions segment, and 7.4% for refining and petrochemicals, mainly in development wells in Rubiales, Caño Sur, Castilla, Floreña, and Permian in the upstream segment, investments focused on operational continuity in the midstream and downstream segments, investments in the construction of power lines, and investments to increase the reliability of the grid and comply with regulation. See Note 33.3 to our consolidated financial statements for more detail about capital expenditures by segment.
The amount of our investment plan approved for 2024-2026 is USD 20.2 billon. See section Strategy and Market Overview—Our Corporate Strategy—2025 Investment Plan for further information and implicit Brent prices.
The resources required for the investment plan can be funded through internal cash generation, collection of the accounts receivable from the FEPC and loans.
|
4.7.3 |
Dividends |
In the General Assembly of Shareholders held on March 28, 2025, a distribution of ordinary dividends for the fiscal year ended December 31, 2024, was approved as follows: COP 8,798,972,663,702, or COP 214 per share, based on the number of outstanding shares as of December 31, 2024. The total dividends approved corresponds to an ordinary dividend pursuant to our current dividend policy. The payment is expected to be made in two installments on April 4, 2024 and April 29, 2024 to our minority shareholders. The payment to the majority shareholder is expected to be made in three installments as follows: i) COP 2,200,000 on April 4, 2025, ii) COP 2,300,000,000,000 on April 29, 2025, and iii) the total of COP 3,286,344,378,880 on June 27, 2025., taking into account the payment schedule of the balance of the Fuel Price Stabilization Fund (FEPC) corresponding to its 2024 accumulation.
In 2024, we paid dividends of COP 12,802,893 million to our shareholders, including the Nation, and dividends paid to non-controlling shareholders of our subsidiaries totaling COP 2,762,171 million. COP 7,352,053 million in dividends corresponding to the Nation were offset against the FEPC accounts receivable owed to Ecopetrol.
In 2023, we paid dividends of COP 24,323,410 million to our shareholders, including the Nation, and dividends paid to non-controlling shareholders of our subsidiaries totaling COP 2,806,020 million. COP 21,576,179 million in dividends corresponding to the Nation were offset against the FEPC accounts receivable owed to Ecopetrol.
In 2022, we paid dividends of COP 11,622,778 million to our shareholders, including the Nation, and dividends paid to non-controlling shareholders of our subsidiaries totaling COP 1,734,169 million. COP 6,788,385 million in dividends corresponding to the Nation were offset against the FEPC accounts receivable owed to Ecopetrol.
|
4.8 |
Summary of Differences between Internal Reporting Policies (Colombian IFRS) and IFRS |
We prepare our interim and annual statutory financial information in accordance with our internal reporting policies, which follow Colombian IFRS and differ in certain significant aspects from IFRS. The following table sets forth our consolidated net income and equity for years ended December 31, 2024, 2023 and 2022, in accordance with Colombian IFRS and IFRS:
143
Table 62 – Consolidated Net Income and Equity
|
|
|
For the year ended December 31, |
|
% Change |
||||||
|
|
|
2024 |
|
2023 |
|
2022 |
|
2024/2023 |
|
2023/2022 |
|
|
|
(COP Million) |
||||||||
|
Net income attributable to owners of Ecopetrol (IFRS) |
|
13,841,153 |
|
21,060,798 |
|
31,604,781 |
|
(34.3) |
|
(33.4) |
|
Cash flow hedge for future company exports |
|
— |
|
(54,174) |
|
(104,567) |
|
(100.0) |
|
(48.2) |
|
Exchange rate effects on tax bases – Deferred tax |
|
1,096,090 |
|
(1,940,770) |
|
1,906,077 |
|
(156.5) |
|
(201.8) |
|
Insurance Contracts IFRS 17 |
|
(2,538) |
|
(3,763) |
|
— |
|
(32.6) |
|
— |
|
Net income Attributable to owners of Ecopetrol (Colombian IFRS) |
|
14,934,705 |
|
19,062,091 |
|
33,406,291 |
|
(21.7) |
|
(42.9) |
|
Net Equity (IFRS) |
|
105,913,439 |
|
100,252,480 |
|
113,903,089 |
|
5.6 |
|
(12.0) |
|
Exchange rate effects on tax bases – Deferred tax |
|
4,062,556 |
|
2,845,139 |
|
5,183,961 |
|
42.8 |
|
(45.1) |
|
Insurance Contracts IFRS 17 |
|
— |
|
1,185 |
|
— |
|
(100.0) |
|
— |
|
Net Equity (Colombian IFRS) |
|
109,975,995 |
|
103,098,804 |
|
119,087,050 |
|
6.7 |
|
(13.4) |
As noted above, certain differences exist between our net income and equity as determined in accordance with our internal reporting policies, which follow Colombian IFRS, which are used for management reporting purposes, as presented in the business segment information, and our net income and equity as determined under IFRS, as presented in our consolidated financial statements.
The primary differences between Colombian IFRS and IFRS as they apply to our results of operations are summarized below:
Cash flow hedge for future company exports . In September 2015, in order to hedge the effect of exchange rate volatility on our foreign currency debt, Ecopetrol S.A.’s Board of Directors approved a cash flow hedge for future crude oil exports. According to IAS 39 – Financial Instruments, we implemented this hedge beginning on October 1, 2015, the date on which we formally completed the related hedging documentation.
Under Colombian IFRS, the General Accounting Office of the Nation (CGN for its acronym in Spanish) issued Resolution 509, which allows companies to apply hedge accounting for non-derivative financial instruments from any date within the transition period or the first period of application of International Accounting Standards in Colombia, even if such company has not yet formally documented the hedging relationship, the objective or the risk management strategy. Under these rules, we applied cash flow hedge accounting from January 1, 2015, in our financial statements under Colombian IFRS.
For the year ended December 31, 2024, there is no adjustment in cash flow hedge for future company exports, considering that the hedging operation related to exports till 2024 was settled.
Exchange rate effects on tax bases – Deferred tax . According to IAS 12.41, companies with a U.S. dollar functional currency and profit or tax loss in Colombian Pesos are required to recognize deferred taxes attributable to the difference between the carrying amounts of non-monetary assets in their financial statements and their respective tax bases converted from Colombian Pesos to U.S. dollars using the exchange rate on the closing date. The effect of the temporary difference is charged to profit and losses without a cash outflow expected in the future. Under local accounting principles (The General Accounting Office opinion No. 20162000000781 dated January 18, 2016), the result attributable to the aforementioned difference in accounting policies does not generate any deferred taxes.
Our functional currency is the Colombian Peso and it consolidates some subsidiaries whose functional currency is the U.S. dollar but who settled their taxes in Colombian Pesos. As a result of the application of paragraph 41 – IAS 12, such subsidiaries are required to calculate deferred taxes under IFRS.
As a result of this accounting policy difference, for the year ended December 31, 2024, our net income loss attributable to owners of Ecopetrol as reported under IFRS was COP 1,096,090 million lower than our net income attributable to owners of Ecopetrol as reported under Colombian IFRS.
144
In May 2017, the International Accounting Standards Board issued IFRS 17 which replaced IFRS 4 that was issued in 2005. IFRS 17 applies to all types of insurance and reinsurance contracts, regardless of the type of entities issuing them, as well as certain guarantees and financial instruments with discretionary participation features. The standard should be applied as of January 1, 2023. This standard applies specifically to our subsidiary Black Gold Re, domiciled in Bermuda. That entity provides, through a dual insurance program structure (World General Package (WUP) program and Global Energy Package (GEP) program), reinsurance to the Ecopetrol group. Since this standard has not been introduced in Colombian regulations by decree, the accounting policy based on IFRS 4 continues to be applied in the Financial Statements of the Business Group disclosed under the standards of the local accounting regulatory entities. As a result of this accounting policy difference, for the year ended December 31, 2024, our net income attributable to owners of Ecopetrol as reported under IFRS was COP 2,538 million higher than our net income attributable to owners of Ecopetrol as reported under Colombian IFRS.
As a result of these accounting policy differences described above, for the year ended December 31, 2024, we reported net income attributable to the owners of Ecopetrol under IFRS of COP 13,841,153 million as opposed to a net income attributable to the owners of Ecopetrol of COP 14,934,705 million reported under Colombian IFRS for the same period. For the year ended December 31, 2023, we reported net income attributable to the owners of Ecopetrol under IFRS of COP 21,060,798 million as opposed to a net income attributable to the owners of Ecopetrol of COP 19,062,091 million reported under Colombian IFRS for the same period. For the year ended December 31, 2022, we reported net income attributable to the owners of Ecopetrol under IFRS of COP 31,604,781 million as opposed to a net income attributable to the owners of Ecopetrol of COP 33,406,291 million reported under Colombian IFRS for the same period.
|
4.9 |
Financial Indebtedness and Other Contractual Obligations |
As of December 31, 2024, we had outstanding consolidated indebtedness of USD 26.85 billion, which corresponded primarily to the following long-term transactions:
145
Table 63 – Consolidated Financial Indebtedness
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Outstanding |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Dec. 31, 2024 |
|
Company |
|
Type |
|
Initial Date |
|
Original Amount |
|
Maturity |
|
Interest Rate |
|
Amortization |
|
(in nominal values) |
|
Ecopetrol S.A. |
|
Bonds |
|
September 18, 2013 |
|
USD 850 million |
|
September 18, 2043 |
|
7,375 |
% |
Bullet |
|
USD 850 million |
|
|
|
|
|
May 28, 2014 |
|
USD 2,000 million |
|
May 28, 2045 |
|
5,875 |
% |
Bullet |
|
USD 2,000 million |
|
|
|
|
|
April 29, 2020 |
|
USD 2,000 million |
|
April 29, 2030 |
|
6,875 |
% |
Bullet |
|
USD 2,000 million |
|
|
|
|
|
October 27, 2021 |
|
USD 1,250 million |
|
November 2, 2031 |
|
4,625 |
% |
Bullet |
|
USD 1,250 million |
|
|
|
|
|
October 27, 2021 |
|
USD 750 million |
|
November 2, 2051 |
|
5,875 |
% |
Bullet |
|
USD 750 million |
|
|
|
|
|
January 13, 2023 |
|
USD 1,528 million |
|
January 13, 2033 |
|
8,875 |
% |
Bullet |
|
USD 1,528 million |
|
|
|
|
|
January 13, 2023 |
|
USD 472 million |
|
January 13, 2033 |
|
8,875 |
% |
Bullet |
|
USD 472 million |
|
|
|
|
|
July 6, 2023* |
|
USD 300 million |
|
January 13, 2033 |
|
8,875 |
% |
Bullet |
|
USD 300 million |
|
|
|
|
|
July 6, 2023 |
|
USD 1,200 million |
|
January 19, 2029 |
|
8,625 |
% |
Bullet |
|
USD 1,200 million |
|
|
|
|
|
January 19, 2024 |
|
USD 1,850 million |
|
January 19, 2036 |
|
8,375 |
% |
Bullet |
|
USD 1,850 million |
|
|
|
|
|
October 21, 2024 |
|
USD 1,750 million |
|
February 1, 2032 |
|
7,750 |
% |
Bullet |
|
USD 1,750 million |
|
|
|
|
|
August 27, 2013 |
|
COP 347,500 million |
|
August 27, 2028 |
|
Floating |
|
Bullet |
|
COP 347,500 million |
|
|
|
|
|
August 27, 2013 |
|
COP 262,950 million |
|
August 27, 2043 |
|
Floating |
|
Bullet |
|
COP 262,950 million |
|
|
|
|
|
December 1, 2010 |
|
COP 284,300 million |
|
December 1, 2040 |
|
Floating |
|
Bullet |
|
COP 284,300 million |
|
|
|
Bank Loans |
|
December 30, 2011** |
|
USD 440 million |
|
December 20, 2025 |
|
Floating |
|
Semi-annual |
|
USD 114 million |
|
|
|
|
|
December 20, 2022 |
|
USD 576 million |
|
December 20, 2027 |
|
Floating |
|
Bullet |
|
USD 576 million |
|
|
|
|
|
December 20, 2022 |
|
USD 247 million |
|
December 20, 2027 |
|
Floating |
|
Bullet |
|
USD 247 million |
|
|
|
|
|
May 16,2023 |
|
USD 250 million |
|
May 15, 2028 |
|
Floating |
|
Bullet |
|
USD 250 million |
|
|
|
|
|
May 16,2023 |
|
USD 150 million |
|
May 15, 2028 |
|
Floating |
|
Bullet |
|
USD 150 million |
|
|
|
|
|
June 20, 2023 |
|
USD 124 million |
|
December 20, 2027 |
|
Floating |
|
Bullet |
|
USD 124 million |
|
|
|
|
|
June 20, 2023 |
|
USD 53 million |
|
December 20, 2027 |
|
Floating |
|
Bullet |
|
USD 53 million |
|
|
|
|
|
July 2, 2024 |
|
USD 1,200 million |
|
April 12, 2029 |
|
Floating |
|
Bullet |
|
USD 1,200 million |
|
|
|
|
|
October 7, 2024 |
|
USD 250 million |
|
October 5, 2029 |
|
Floating |
|
Bullet |
|
USD 250 million |
|
|
|
|
|
July 10, 2024 |
|
USD 160 million |
|
July 9, 2025 |
|
Floating |
|
Bullet |
|
USD 160 million |
|
|
|
|
|
June 16, 2023 |
|
COP 1,000,000 million |
|
June 16, 2028 |
|
Floating |
|
Bullet |
|
COP 1,000,000 million |
|
|
|
|
|
July 26,2024 |
|
COP 642,478 million |
|
July 26, 2031 |
|
Floating |
|
Semi-annual |
|
COP 642,478 million |
|
|
|
|
|
July 26,2024 |
|
COP 207,523 million |
|
July 26, 2031 |
|
Floating |
|
Semi-annual |
|
COP 207,523 million |
|
|
|
|
|
July 26,2024 |
|
COP 150,000 million |
|
July 26, 2031 |
|
Floating |
|
Semi-annual |
|
COP 150,000 million |
|
|
|
ECAs |
|
December 30, 2011** |
|
USD 2,650 million |
|
December 20, 2027 |
|
Fixed |
|
Semi-annual |
|
USD 311 million |
|
|
|
|
|
December 30, 2011** |
|
USD 100 million |
|
December 20, 2027 |
|
Floating |
|
Semi-annual |
|
USD 12 million |
|
|
|
|
|
December 30, 2011** |
|
USD 97 million |
|
December 20, 2027 |
|
Fixed |
|
Semi-annual |
|
USD 11 million |
|
|
|
|
|
December 30, 2011** |
|
USD 210 million |
|
December 20, 2027 |
|
Floating |
|
Semi-annual |
|
USD 25 million |
|
Invercolsa Subsidiaries |
|
Bank Loans |
|
Various |
|
COP 1,063,829 million |
|
Various |
|
Various |
|
Various |
|
COP 562,982 million |
|
Ocensa |
|
Bond |
|
July 14, 2020 |
|
USD 500 million |
|
July 14, 2027 |
|
4.000 |
% |
Bullet |
|
USD 400 million |
|
ODL |
|
Lease |
|
November 5, 2015 |
|
COP 308,221 million |
|
November 4, 2032 |
|
Floating |
|
Monthly |
|
COP 157,445 million |
|
ISA Subsidiaries |
|
Bonds |
|
Various |
|
USD 2,859 million |
|
Various |
|
Various |
|
Various |
|
USD 2,707 million |
|
|
|
|
|
Various |
|
USD 2,986 million† |
|
Various |
|
Various |
|
Various |
|
USD 3,083 million† |
|
|
|
|
|
Various |
|
COP 3,980,000 million |
|
Various |
|
Various |
|
Various |
|
COP 3,604,220 million |
|
|
|
Bank Loans |
|
Various |
|
USD 359 million |
|
Various |
|
Various |
|
Various |
|
USD 261 million |
|
|
|
|
|
Various |
|
USD 612 million† |
|
Various |
|
Various |
|
Various |
|
USD 401 million† |
|
|
|
|
|
Various |
|
COP 3,324,799 million |
|
Various |
|
Various |
|
Various |
|
COP 2,434,036 million |
|
Ecopetrol USA |
|
Bank Loans |
|
Various |
|
USD 370 million |
|
Various |
|
Various |
|
Bullet |
|
USD 371 million |
|
Total |
|
|
|
|
|
|
|
|
|
|
|
|
|
COP 118.37 billion |
* Reopening of Notes due 2033
** Debt originally obtained by Cartagena Refinery for the refinery modernization and voluntarily assumed by Ecopetrol.
*** For the total outstanding balance as of Dec. 31, 2024, in amortized values, please refer to page F-73 of the notes to our financial statements.
† Equivalent USD amount of debt issued/acquired in other currencies, except COP.
The Financial Superintendence of Colombia ( Superintendencia Financiera de Colombia or “SFC” for its acronym in Spanish), through Resolution 1654 of November 18, 2022, authorized the renewal of the term of the Issuance and Placement Program of Internal Debt Bonds and Commercial Papers of the Company for five (5) additional years, until December 22, 2027. This authorization itself does not constitute an approval for the issuance of securities or any financing transaction.
146
The short and long-term debt transactions executed in 2024 were as follows:
| ● | On January 19, 2024, Ecopetrol issued 8.375% Notes due in 2036 in an aggregate amount of USD 1,850,000,000 (COP 7.1 trillion according to the COP/USD exchange rate as of December 31, 2023); in a SEC-registered transaction. The notes were listed on the NYSE. In addition, on January 9, 2024, the Company announced a tender offer for any and all of the outstanding 4.125% notes due 2025. |
| ● | On March 20, 2024, the Ministry of Finance and Public Credit authorized the execution of a loan agreement for up to USD 1,200 million. The loan agreement was executed among Banco Bilbao Vizcaya Argentaria, S.A, Itaú Chile New York Branch, Bank of America, N.A, JP Morgan Chase Bank, N.A, New York Branch, Banco Santander S.A, JP Morgan Chase Bank, N.A, The Bank of Nova Scotia and Standard Chartered Bank (Hong Kong) Limited, as lenders. |
| ● | On June 14, 2024, Ecopetrol received the authorization of the Ministry of Finance and Public Credit to enter into a one billion Colombian pesos (COP) credit with Banco de Bogotá, Banco de Occidente and Banco Popular. |
| ● | On August 20, 2024, Ecopetrol received the authorization of the Ministry of Finance and Public Credit to enter into a USD 250 million credit with SMBC. |
| ● | On September 5, 2024, the Company redeemed USD 250 million of its 5.375% senior notes due 2026. |
| ● | On October 8, 2024, the Company announced a tender offer for any and all of the outstanding 5.375% senior notes due 2026. |
| ● | On October 21, 2024, Ecopetrol issued 7.750% Notes due in 2032 in an aggregate amount of USD 1,750,000,000 (COP 7.7 billion according to the COP/USD exchange rate as of December 31, 2024); in a SEC-registered transaction. The notes were listed on the NYSE. |
| ● | On October 18 and 28, 2024, the Company prepaid the USD 1 billion loan with Deutsche Bank due 2030. |
| ● | On November 21, 2024, the Company redeemed the remaining amount of USD 450,579,892 of its 5.375% senior notes due 2026. |
For more detail on these transactions, see Financial Statements - Subsequent and relevant events .
The short and long - term debt transactions executed in 2023 were as follows:
| ● | On January 10, 2023, Ecopetrol priced a 10 - year, 8.875% coupon note, due on January 13, 2033. In addition, on January 17, 2023, the Company announced a tender offer for up to USD 1 billion nominal amount of its notes due on September 18, 2023; offers for an aggregated amount of USD 976 million were received. |
| ● | On March 16, 2023, Ecopetrol received the authorization of the Ministry of Finance and Public Credit to enter into a one trillion Colombian pesos (COP) committed line of credit with Bancolombia. |
| ● | On May 10, 2023, the Ministry of Finance and Public Credit authorized the execution of a loan agreement for up to USD 400 million. The loan agreement was executed among Banco Bilbao Vizcaya Argentaria, S.A. New York Branch and MUFG Bank LTD, as lenders. |
| ● | On July 6, 2023, Ecopetrol issued (i) 8.875% Notes due 2033 in an aggregate amount of USD 300,000,000 (COP 1.2 trillion according to the COP/USD exchange rate as of December 31, 2023), and (ii) 8.625% Notes due 2029 in an aggregate amount of USD 1,200,000,000 (COP 4.6 trillion according to the COP/USD exchange rate as of December 31, 2023); in a SEC - registered transaction. The notes were listed on the NYSE. |
| ● | On July 7, 2023, Ecopetrol announced the redemption of its 5.875% Notes due 2023, which were issued in 2013. |
| ● | On August 24, 2023, the Ministry of Finance and Public Credit authorized the execution of a loan agreement for up to USD 1 billion to be executed among Deutsche Bank AG, Banco Inbursa S.A., Banco Latinoamericano de Comercio Exterior S.A., and ICBC Standard Bank Plc, as lenders. |
147
| ● | The short and long-term debt transactions executed in 2022 were as follows: |
| ● | Between March and August 2022, Transelec S.A. and Internexa S.A., subsidiaries of ISA in Colombia, raised an aggregate of COP 279,907 million by executing several loan transactions with different maturities, in the local market. |
| ● | Between March and December 2022, several of ISA’s subsidiaries in Perú (CTM, Internexa, Red de Energía del Perú, ISA Perú) raised an aggregate of USD 166.2 million and PEN 249.3 million by means of bank loans with different maturities, executed with local and international counterparties. |
| ● | On April 4, 2022, Consorcio Transmantaro S.A. (“CTM”), one of ISA’s electric power transmission subsidiaries in Perú issued 5.200% amortizing notes due 2038 in an aggregate amount of USD 500 million under an unregistered Rule 144A/Regulation S notes offering (COP 1.89 trillion according to the COP/USD exchange rate as of April 04, 2022). The notes were listed on the Official List of the Luxemburg Stock Exchange. This follows CTM’s announcement on March 22, 2022, of an any and all tender offer with allocation codes and consent solicitation to holders of CTM’s 4.375% senior notes due 2023.On April 18, 2022, Companhia de Transmissão de Energia Elétrica Paulista (“ISA CTEEP”), ISA’s electric power transmission subsidiary in Brazil, issued BRL 700 million of local amortizing notes (debentures) due in 2026. The notes bear an interest rate of CDI 1.55%. In addition, the Company raised BRL 233.7 million by means of a 20-year loan bearing an interest rate of TLP 2.01%. |
| ● | Between June and December 2022, Internexa Brazil raised an aggregate of BRL 65.6 million. |
| ● | The toll roads operated by Intervial Chile, executed the following debt transactions during 2022: |
| ● | On November 15, 2022, Ruta del Loa Sociedad Concesionaria S.A. issued local inflation-linked bonds due 2050, with a face value of Unidad de Fomento (“UF”) 1,927,500. The bonds bear an interest rate of 3.85%. |
| ● | On March 15, 2022, Ruta del Bosque Sociedad Concesionaria S.A., prepaid its notes due June 15, 2022. The outstanding nominal value as of the prepayment date amounted to UF 1,500,500. |
| ● | On September 15, 2022, Ruta de la Araucanía Sociedad Concesionaria S.A., raised funds through an inflation-linked loan for an aggregate amount of UF 1,347,515. The bonds bear a floating interest rate of TAB (180) 1.28%. |
Contractual Obligations
We enter into various commitments and contractual obligations that may require future cash payments. The following table summarizes our contractual obligations as of December 31, 2024.
Table 64 – Our Material Contractual Obligations
|
|
|
Payments due by period |
||||
|
|
|
|
|
Short Term |
|
Long Term |
|
|
|
|
|
(Less than 1 |
|
(More than 1 |
|
COP Millions |
|
Total |
|
year) |
|
year) |
|
Employee Benefit Plan |
|
68,811,053 |
|
2,169,838 |
|
66,641,215 |
|
Contract Service Obligations |
|
37,755,056 |
|
12,007,265 |
|
25,747,791 |
|
Natural Gas Supply Agreements |
|
17,639,470 |
|
15,438,543 |
|
2,200,927 |
|
Purchase Obligations |
|
3,967,218 |
|
1,863,812 |
|
2,103,406 |
|
Energy Supply Agreements |
|
14,853,636 |
|
1,418,217 |
|
13,435,419 |
|
Capital Expenditures |
|
51,909,266 |
|
17,376,852 |
|
34,532,414 |
|
Financial Sector Debt |
|
23,554,914 |
|
4,185,319 |
|
19,369,595 |
|
Bonds |
|
94,074,311 |
|
5,922,852 |
|
88,151,459 |
|
|
|
|
|
|
|
|
|
Total |
|
312,564,924 |
|
60,382,698 |
|
252,182,226 |
148
|
4.10 |
Off Balance Sheet Arrangements |
As of December 31, 2024, we did not have off-balance sheet arrangements of the type that is required to be disclosed under Item 5 of Form 20-F.
|
4.11 |
Statements of Financial Position |
Table 65 - Consolidated Balance Sheet
|
|
|
As of December 31, |
|
% Change |
||||||
|
Balance sheet |
|
2024 |
|
2023 |
|
2022 |
|
2024/2023 |
|
2023/2022 |
|
(COP million) |
|
|
|
|
|
|
|
|
|
|
|
Total assets |
|
298,242,156 |
|
280,141,090 |
|
302,792,431 |
|
6.46 |
|
(7.48) |
|
Liabilities |
|
192,328,717 |
|
179,888,610 |
|
188,889,342 |
|
6.92 |
|
(4.77) |
|
Equity |
|
105,913,439 |
|
100,252,480 |
|
113,903,089 |
|
5.65 |
|
(11.98) |
|
Total liabilities and equity |
|
298,242,156 |
|
280,141,090 |
|
302,792,431 |
|
6.46 |
|
(7.48) |
In 2024, assets increased by 6.5% or COP 18,101,066 million compared year-on-year, mainly due to:
| ● | An increase in property, plant, equipment, natural resources, and intangibles by COP 16,431,393 million, due to the net effect between higher CAPEX, the conversion effect of subsidiaries with currencies of origin other than the Colombian peso and depreciation. |
| ● | An increase in taxes of COP 5,722,881 million, primarily associated with the update of the deferred taxes resulting from the exchange rate effect and advance payment of income tax and value added tax. |
| ● | An increase in cash and cash equivalents of COP 1,718,360 million, mainly because of operational activity |
| ● | A decrease in accounts receivable of COP 10,529,729 million, primarily because of resources received corresponding to the 2023 balance of the Fuel Price Stabilization Fund (FEPC) account receivable for COP 20,514,037 million, compared to the balance recorded in 2024 of COP 7,631 million. The decrease in the balance of the FEPC account is due to the gradual increase in diesel prices in Colombia. |
In 2024, liabilities increased by 6.9% or COP 12,440,107 million compared to 2023, mainly due to:
| ● | An increase in financial liabilities of COP 14,149,504 million mainly due to re-expressing debt in foreign currency at the closing rate recognized mainly in equity due to hedge accounting |
| ● | A decrease in provision for abandonment cost by COP 1,811,719 million due to lower rates. |
| ● | A decrease in other minor liabilities by COP 102,322 million. |
In 2023, assets decreased by 7.5% or COP 22,651,342 million compared year-on-year, mainly due to:
| ● | A decrease in accounts receivable of COP 8,288,474 million, primarily because of the offsetting of the balance of the account receivable of the Fuel Price Stabilization Fund account (FEPC) against dividends to be paid to the Republic of Colombia for COP 21,576,179 million, and funds received for COP 4,770,351 million. Additionally, the balance of the FEPC account has decreased because of the gradual increase in gasoline prices in Colombia and the decrease in benchmark prices (COP 20,505,603 million). |
| ● | A decrease in property, plant, equipment, natural resources, and intangibles by COP 6,365,469 million, resulting from the net effect of a lower exchange rate and its implications on subsidiaries with a functional currency other than the Colombian peso, the depreciation for the period, and a higher CAPEX. |
| ● | A decrease in taxes of COP 1,544,306 million, primarily associated with the update of the deferred taxes resulting from the exchange rate effect. |
149
| ● | A decrease in inventories of COP 1,677,586 million, mainly because of prices, increased throughput in the refineries, and higher sales. |
In 2023, liabilities decreased by 4.8% or COP 9,000,732 million compared to 2022, mainly due to:
| ● | A decrease in financial liabilities of COP 9,319,312 million, net effect between higher debt and the revaluation of the Colombian peso against the U.S. dollar. |
| ● | Lower current tax liabilities associated with lower net income of COP 6,469,807 million. |
Total equity of the Ecopetrol Group for year-end 2024 was COP 105,913,439 million. Equity attributable to Ecopetrol’s shareholders was COP 79,854,603 million, an increase of COP 4,147,976 million compared to December 2023, mainly as a result of the distribution of dividends for the period and the effect of the exchange rate on subsidiaries with a functional currency other than the Colombian peso.
In 2023, Ecopetrol equity as of December 2023 was COP 100,253,665 million. Equity attributable to Ecopetrol shareholders was COP 75,707,812 million, a decrease of COP 10,447,115 million compared to December 2022, mainly as a result of the distribution of dividends for the period and the effect of the exchange rate on subsidiaries with a functional currency other than the Colombian peso.
|
4.12 |
Trend Analysis and Sensitivity Analysis |
We updated our 2025 Investment Plan on November 29, 2024. See section Strategy and Market Overview—Our Corporate Strategy—2025 Investment Plan for a discussion of the trends recognized in the development of that plan.
Sensitivity Analysis
Sensitivity Analysis of our Results
The following table provides information about the sensitivity of our results as of December 31, 2024, due to variations of USD 1 in the price of ICE Brent crude and of 1% in the COP / USD exchange rate.
Table 66 – Sensitivity Analysis of our Results
|
|
|
|
|
Income |
|
Difference |
|
Income |
|
Difference |
|
|
|
|
|
Statement |
|
Between |
|
Statement |
|
Between |
|
|
|
Income |
|
Case ICE |
|
Real 2024 |
|
Case |
|
Real 2024 |
|
|
|
Statement |
|
Brent (1) + |
|
and Case |
|
TRM (2) |
|
and Case |
|
COP$ Billion |
|
2024 |
|
USD1 |
|
ICE Brent |
|
+1% |
|
TRM |
|
Revenue |
|
133,330.43 |
|
134,690.46 |
|
1,360.03 |
|
134,474.71 |
|
1,144.28 |
|
Cost of sales |
|
86,481.15 |
|
87,042.48 |
|
561.33 |
|
86,928.62 |
|
447.47 |
|
Gross Income |
|
46,849.28 |
|
47,647.98 |
|
798.70 |
|
47,546.09 |
|
696.81 |
|
Operating expenses |
|
9,253.71 |
|
9,253.71 |
|
0.00 |
|
9,253.71 |
|
0.00 |
|
Impairment of non-current assets |
|
(867.43) |
|
(867.43) |
|
0.00 |
|
(867.43) |
|
0.00 |
|
Operating income |
|
38,463.00 |
|
39,261.70 |
|
798.70 |
|
39,159.81 |
|
696.81 |
|
Finance results, net |
|
(8,519.95) |
|
(8,519.95) |
|
0.00 |
|
(8,519.95) |
|
0.00 |
|
Share of profit of associates and joint ventures |
|
764.37 |
|
764.37 |
|
0.00 |
|
764.37 |
|
0.00 |
|
Income before income tax |
|
30,707.42 |
|
31,506.12 |
|
798.70 |
|
31,404.23 |
|
696.81 |
|
Income Tax |
|
(12,208.54) |
|
(12,526.08) |
|
(317.54) |
|
(12,485.58) |
|
(277.04) |
|
Net Income |
|
18,498.88 |
|
18,980.04 |
|
481.16 |
|
18,918.65 |
|
419.77 |
|
(1) |
ICE Brent = USD 80 per barrel |
|
(2) |
Exchange rate (TRM) = COP 4,071 / USD 1.00 |
Assumptions for the Sensitivity Analysis of our Results:
| ● | Our sensitivity analysis is based on the Consolidated Statement of Profit or Loss for 2024, as presented elsewhere in this annual report. |
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| ● | The sensitivity of the ICE Brent price index is in reference to an increase of USD 1 per barrel of crude oil in the average ICE Brent reference price based on a 366-day year for 2024. Prices assumed correspond to realized prices for crude oil, natural gas and refined products for 2024, adjusted to account for the differences between such realized prices and the ICE Brent reference price. |
| ● | The sensitivity of our results to changes in the exchange rate is in reference to a 1% average depreciation of the Colombian Peso against the U.S. dollar during 2024. Prices are the realized prices of crude oil, natural gas and refined products in 2024 and are expressed for the sensitivity using the adjusted exchange rate (i.e. a 1% average depreciation of the Colombian Peso against the U.S. dollar during 2024). |
| ● | The income tax for each of our sensitivity analyses (price of ICE Brent and COP / USD exchange rate) is estimated using the effective corporate tax rate of 39.8% for 2024. |
| ● | This sensitivity analysis keeps everything constant. In the case of significant variations of the ICE Brent price, we will perform interventions in our operating expenditures. |
The table below sets forth the line items that are being affected by the variation on the reference prices or the average exchange rate.
Table 67
|
VARIATION ON ICE BRENT REFERENCE PRICE |
|
VARIATION ON AVERAGE EXCHANGE RATE |
|---|---|---|
|
REVENUE |
||
|
Sales of crude oil |
|
Sales of crude oil |
|
Sales of refined products |
|
Sales of refined products |
|
Sales of natural gas |
|
Sales of natural gas |
|
COST OF SALES |
||
|
Local purchases from business partners |
|
Local purchases from business partners |
|
Local purchases of hydrocarbons from the ANH |
|
Local purchases of hydrocarbons from the ANH |
|
Local purchases of natural gas |
|
Local purchases of natural gas |
|
Imports of products |
|
Imports of products |
|
5. |
Risk Review |
|
5.1 |
Risk Factor Summary |
The following is a summary of the principal risks we face:
Risks Related to Our Business
| 1. | Our crude oil and natural gas reserve estimates involve some degree of uncertainty and may prove to be incorrect over time. |
| 2. | Achieving our long-term growth depends on our ability to execute our strategy, transition to a low carbon economy, manage sustainability risks and opportunities, having cutting edge knowledge and technologies, diversify our portfolio and develop additional hydrocarbon reserves. |
| 3. | Sharp movements of prices for crude oil, natural gas and refined products could adversely affect our business prospects, results and cash position. |
| 4. | Foreign currency exchange rate fluctuations may affect our financial results. |
| 5. | Increased competition may negatively impact our ability to access additional crude oil and natural gas reserves in Colombia and abroad. |
| 6. | Operational risks may materialize and affect the health and safety of our workforce, the local community and the environment, and cause disruptions or shutdowns. |
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| 7. | Our involvement in deep-water drilling, either directly or indirectly, involves risks and costs, which may be out of our control. |
| 8. | We are exposed to the credit, political and regulatory risks of our key customers. |
| 9. | Our ability to access credit markets may be limited by the deterioration of these markets, changes in credit ratings, and limited offering from financial institutions to participants in the oil and gas industry. |
| 10. | We may be exposed to increases in interest rates, thereby increasing our financial costs. |
| 11. | Our current and planned investments, divestments and business activities outside Colombia are exposed to political and economic risks. |
| 12. | Our future performance depends on successful selection, development and deployment of new technologies and our knowledge about them. |
| 13. | Our performance could be negatively affected by the lack of employees with the skills needed to execute our business strategy. |
| 14. | If the strategic plans associated to natural gas fail or underdeliver, we may be unable to keep pace with increasing domestic demand. |
| 15. | Our operations could be affected by demonstrations and other actions of labor unions, social organizations, communities and contractors. |
| 16. | Our activities may be interrupted or affected by external factors, such as climate change and its effect on weather and natural disasters. |
| 17. | Our operations, including our activities in indigenous reserves and Afro-Colombian lands, could face opposition from various communities. |
| 18. | We have made and may make significant investments and divestments, and we may not realize their expected value. |
| 19. | We might be required to provide financial support to our subsidiaries or affiliates in Colombia or abroad. |
| 20. | Investigations and other actions by Colombian administrative control entities involving our current or former employees or those of our current or former subsidiaries may impact our reputation. |
| 21. | Our results may be affected by supply chain disruptions and high price volatility impacting our suppliers, partners and other third-parties. |
| 22. | Our insurance policies do not cover all liabilities and may not be available for all risks. |
| 23. | New trends in the insurance sector in the face of climate change may impact our financial condition and results of operations. |
| 24. | A failure in our information technology systems or cybersecurity attacks may adversely affect our financial results. |
| 25. | We are exposed to behaviors incompatible with our ethics and compliance standards. |
| 26. | The performance of our partners, subsidiaries and affiliates in Colombia and elsewhere may negatively impact our image and reputation. |
| 27. | The reliability and capacity of national power supply systems may affect or limit the continuity of our operations or limit growth. |
| 28. | Rising water production levels may affect or constrain our crude oil production. |
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Risks Related to Colombia’s and the Region’s Political Environment
| 29. | Changes in economic, energy transition and oil gas policies in Colombia, Peru, Brazil, Chile and the United States of America could materially affect our financial condition and results of operations. |
| 30. | Our business operations and financial condition could be negatively affected by pandemic or epidemic diseases and other health events. |
| 31. | The Colombian Government could seize or expropriate our assets under certain circumstances for fair compensation. |
| 32. | Colombia has experienced internal security issues that have had or could have a negative effect on the Colombian economy and on us. |
| 33. | Despite the current government’s announcement of a bilateral ceasefire with some armed groups, non-conformism may arise in the process of these dialogues spoken out through illegal and terrorist activities. |
| 34. | Regional and global events may have an impact on Colombia’s social, economic and political situation as well as on us and our operations. |
| 35. | We are subject to the prevailing economic conditions and investment climate in Colombia, which may be less stable than those in developed countries. |
Legal and Regulatory Risks
| 36. | Our operations are subject to extensive regulation, which is subject to change from time to time by the applicable regulatory authorities. |
| 37. | More stringent environmental regulation may lead to increased expenses or reduced demand for our products, as well as affect timely permits. |
| 38. | We may not be able to keep pace with changing environmental requirements related to impacts to Colombia’s biodiversity and nature. |
| 39. | Our operations might be affected by rising climate change and energy transition regulatory developments. |
| 40. | New or higher taxes resulting from changes in regulations or their interpretation could adversely affect our results of operations and financial condition. |
| 41. | We may incur losses and spend time and money defending pending lawsuits and arbitrations and responding to administrative investigations. |
Risks Related to Our ADSs
42. Holders of our ADSs may encounter difficulties in protecting their interests.
| 43. | Our ADS holders may be subject to regulations on foreign investment in Colombia. |
| 44. | Holders of our ADSs may not be able to effect service of process on us, our directors, or executive officers within the United States, which may limit your recovery in any foreign judgment you obtain against us. |
| 45. | The protections afforded to minority shareholders in Colombia are different from those in the United States and may be difficult to enforce. |
| 46. | ADSs do not have the same tax treatment as other equity investments in Colombia. |
153
| 47. | Judgments of Colombian courts with respect to our ADSs will be payable only in Colombian Pesos. |
| 48. | The relative volatility and illiquidity of the Colombian securities markets may substantially limit our investors’ ability to sell our ADSs at the price and time they desire. |
| 49. | We are not required to disclose as much information to investors as a U.S. issuer is required to disclose. |
Risks Related to the Controlling Shareholder
| 50. | Our controlling shareholder’s interests may differ from those of certain minority shareholders or may affect our long-term strategy. |
|
5.2 |
Risk Factors |
The risks discussed below could have a material adverse effect, separately or in combination, on our business’s operating results, cash flows, liquidity, and financial condition. Investors should carefully consider these risks.
|
5.2.1 |
Risks Related to Our Business |
This section describes the most significant potential risks to our business.
Our crude oil and natural gas reserve estimates involve some degree of uncertainty and may prove to be incorrect over time.
Reserves estimates are prepared using generally accepted geological and engineering evaluation methods and procedures. Estimates are based on geological, topographical, and engineering facts. Actual reserves and production may vary materially from estimates shown in this annual report, and downward revisions in our reserve estimates could lead to lower future production which could affect our results of operations and financial condition.
Hydrocarbon reserves presented in this annual report were calculated in accordance with SEC regulations. As required by those regulations, reserves were valued based on the unweighted average of closing prices for the first day of each month in the 12-month periods ended December 31, 2024, 2023, and 2022, as well as other conditions in existence at those dates. The average of closing prices of ICE Brent crude oil for the first day of each month in the 12-month periods was USD 98/Bl in 2022, USD 83/Bl in 2023, and USD 79.7/Bl in 2024. In 2024, the Company recognized an increase in oil and gas proven reserves of 0.5% as compared to 2023, to 1,892.7 mmboe in 2024 from 1,883 mmboe in 2023. For more information, see section Business Overview—Exploration and Production—Reserves .
Furthermore, at least once a year, or more frequently if the circumstances require, the Company ascertains whether there are indicators of impairment to its assets or CGUs due to the difference between the carrying amount of such assets or CGUs against to their recoverable amounts, using reasonable assumptions, based on internal and external factors, which reflect market conditions. The recoverable amount is considered to be the higher of the fair value less costs of disposal and value in use, based on the free cash flow method, discounted at the Weighted Average Cost of Capital (WACC). Whenever the recoverable amount of an asset or CGU is lower than its net carrying amount, such amount is reduced to its recovery amount, recognizing a loss for impairment as an expense in the consolidated statement of profit or loss. External and internal sources of information may indicate that an impairment loss recognized for an asset, other than goodwill, may no longer exist or may have decreased, in this case, the reversal is recognized as an impairment recovery in the consolidated statement of profit or loss.
The 2024 impairment gains, net of non-current assets of COP 867,428 million, corresponds to the net result of:
| i. | Recovery of impairment in the Cartagena Refinery of COP 1,271,120 million, due to (i) improvement in the price differentials of refined products in the medium and long term due to market conditions, (ii) prioritization of local crude oils for the Cartagena Refinery, (iii) lower discount rate versus 2023, and (iv) a lower net book value of fixed assets due to the partial recovery of the cost of the modernization project as a result of the recognition of McDermott's financial instrument settled in the arbitration with CBI (see section Legal Proceedings—Reficar Investigations for information on the arbitration with CBI). |
154
| ii. | A recovery in the transportation and logistics segment of COP 127,206 million mainly due to (i) the effect of the higher exchange rate by year-end 2024 compared to year-end 2023 that impacts revenues from oil pipelines that have rates in dollars and (ii) the positive adjustment in the oil pipeline rate due to macroeconomic effects given the resolution of the Ministry of Mines and Energy of September 2024. |
| iii. | An impairment in the Exploration and production segment of COP 480,180 million mainly in Ecopetrol America LLC given the lower short- and long-term prices as well as the reclassification of reserves. |
| iv. | An impairment of non-current assets in the electric power transmission and toll roads concessions segment of COP 45,351 million primarily in ISA Bolivia due to an increase in WACC from country risk and the effect of exchange rate differences on the dollar-denominated cash flow. |
Any significant change in estimates, including capital expenditures reductions related to upstream projects, and judgments could have a material effect on the quantity and present value of our proved reserves and subsequently on the recognition or recovery of impairment charges. Changes to estimations of reserves are applied prospectively to the amounts of depreciation, depletion and amortization charged and, consequently, the carrying amounts of exploration and production assets.
On the contrary, any upward revision in our estimated quantities of proved reserves would indicate higher future production volumes, which could result in lower expenses for depreciation, depletion, and amortization for properties to which we apply the units of production method for calculating these expenses. These lower expenses, and any higher revenues as a result of actual production volumes and realized prices, could benefit our results of operations and financial conditions.
Achieving our long-term growth depends on our ability to execute our strategy, our capacity to adapt our business to the transition to a low carbon economy, generate value by managing sustainability-related risks and opportunities, as well as on having cutting edge knowledge and technologies and our ability to successfully diversify our portfolio and develop additional hydrocarbon reserves.
Our long-term growth objectives depend largely on our ability to strengthen the competitiveness of our oil and gas business, diversify our portfolio into energy transition businesses, and achieve decarbonization targets. Our 2040 Strategy, “Energy that Transforms” aims to position the Ecopetrol Group as a leading integrated energy group in the Americas, focusing on energy diversification. This strategy seeks to bolster the company´s oil and gas business, while decarbonizing its processes through technological advancements. Additionally, our growth relies on developing the recovery potential of existing fields and discovering or acquiring new reserves. We strongly believe that successfully developing these reserves is key for contributing to energy security and achieving our long-term ambitions.
Our exploration activities expose us to inherent geological and drilling risks including the possibility of not discovering commercially viable crude oil or natural gas reserves. There is also the risk that some initially budgeted exploratory wells, may be drilled later than planned or not drilled at all. Despite our efforts to control drilling costs, these expenses are often uncertain, and numerous factors beyond our control can cause drilling operations to be curtailed, delayed, or cancelled.
Our ability to add and develop reserves also depends on our capacity to structurally reduce costs to maintain the profitability of oil fields already being exploited without compromising infrastructure integrity and HSE performance. See section Strategy and Market Overview——Our Corporate Strategy—2025 Investment Plan and section Strategy and Market Overview—Our Corporate Strategy—2040 Strategy: Energy That Transforms . If we are unable to maintain the competitiveness of our oil and gas business and achieve expected recovery factors in our existing fields, add projects with proven reserves, successfully develop our current projects, acquire new exploration assets, or successfully execute our exploration plans (whether as a result of the impossibility of obtaining or extending exploratory licenses, capital restrictions, or any other limitation), our ability to discover and develop additional reserves may be affected and our reserves portfolio could be expected to decline. Failure to secure additional reserves may impede us from achieving or maintaining production targets and may have a negative impact on our results of operations and financial condition. In addition, changes in the operation and development costs of the projects could impact the reserves.
We face the challenge of ensuring our assets generate value across the oil and gas segments. We assess their financial attractiveness and strategic relevance using an index methodology that considers two key elements: financial attractiveness (contribution to profitability, payback period of investments, and viability in the short, medium, and long term) and strategic relevance (synergies and complement to the hydrocarbon chain, resilience in different energy transition scenarios, and contribution to the decarbonization of the Ecopetrol Group).
155
Regarding our energy transmission business line, we face risks associated with energy transition. To achieve our energy transition objectives, we have developed the “Grid of the Future” vision with three main priorities: adaptation of the existing grid and better utilizing available capacity; connecting renewable energy sources to transmission networks; and developing interconnections that enable regional electrical integration. This vision faces long-term risks associated with changes in remuneration schemes and political instability in the region. Additionally, greater social and environmental requirements for business development, may impose more restrictions on our operations and growth expectations. Market and competition risks in our electric power transmission and toll roads businesses may result in new projects not being awarded, affecting our medium-term growth.
In terms of energy transition, we face the risk of not successfully incorporating alternative options into our portfolio as traditional businesses or segments lose their capacity to maintain value due to changes in global or local energy consumption patterns. Specifically, we face risks related to our ability to implement measures to reduce and offset carbon and methane emissions and adapt to climate variability and climate change. We also face regulatory risks related to new climate change regulations in Colombia, such as the updated NDC, the oil gas industry’s climate change plan and the implementation of the National Program of Tradable GHG Emissions Quotas (PNCTE, for its acronym in Spanish). Other regulatory risks include the incorporation of new low-carbon businesses within our portfolio, due insufficient regulation that may impact their proper development.
Ecopetrol has developed energy transition scenarios, based on SP Global Market Energy and Climate Scenarios, to monitor trends in each of the three business lines, which aims to provide a solid and unified reference framework that is expected to allow the Ecopetrol Group to anticipate and understand the challenges and opportunities of the energy transition by presenting three scenarios(i) Climate Alignment (1.7° - 1.8°C): Transformation to low-emission economies aligns governments and institutions around climate change. In addition, developed countries reach a net zero goal, while other countries follow a slower path. This is not enough to achieve the global net-zero goal of 1.5 ℃; (ii) Energy Balance (1.9° - 2.3°C): Fundamental changes in governments, markets, and society set in motion a long-term energy transition, the debate continues between energy security and accelerating the transition; and (iii) Climate Divergence (2.5° - 2.8°C): Dissimilar interests in decarbonization despite policy, regulation and market changes. Global public policy decisions are insufficient to close the climate ambition gap. While the first and third scenarios do not represent the group’s core vision, assessing different perspectives on the global energy transition remains necessary. According to the 2040 Strategy, Ecopetrol considers the second scenario the most likely, aligning with a gradual energy transition. However, we are not certain about the alignment between strategic decision making, considering the analysis derived from the use of these scenarios.
These changes could lead to increased costs and investments in the short and medium term. We have already incurred costs related to these regulations and it is expected that to comply with this evolving regulatory framework we may have additional costs and investments in the short term. This could impact the achievement of the Company’s growth targets and its resilience. See section Risk Review —Risk Factors—Legal and Regulatory Risks—Our operations might be affected by rising climate change and energy transition regulatory developments . Our business growth and sustainability depend on our ability to manage our capital investments and operate efficiently, in accordance with our corporate strategy guidelines. See section Strategy and Market Overview—Our Corporate Strategy for a discussion of our strategic plan.
To successfully achieve our Corporate Strategy, we are venturing into low-emission energy-diversification businesses. These investments will help us achieve our decarbonization targets and generate value while incorporating these new businesses into our business plan. This requires the development of new technologies at competitive costs, and the growth of potential markets, such as demand for these alternative sources in the transportation segment or mobility. However, we cannot assure that the pace of technological developments or the regulation required to incorporate energy transition businesses within our portfolio will meet our expectations, nor that they will be successful or that demand growth will occur as expected.
Furthermore, we are subject to physical risks related to climate change. We are exposed to Colombia’s current climate conditions which may affect water availability and increase the vulnerability of our assets and operations to potential damages. These conditions could result in water shortages, floods, fires, storms, hurricanes, and rising sea levels that change in frequency and intensity. Extreme weather events could damage our assets and negatively affect our operations and financial condition. Additionally, the exposure of our assets under the three climate scenarios presented by the Intergovernmental Panel on Climate Change (SSP 1- RCP 2.6°C, SSP 2- RCP 4.5, and SSP 5- RCP 8.5 could result in potential damage to our assets or cause business disruptions such as water availability, limited transportation and access, and workforce disruptions.
156
Sharp movements of prices for crude oil, natural gas and refined products could adversely affect our business prospects, results and cash position.
In 2024, approximately 85% of the revenues came from sales of crude oil, natural gas, and refined products and 96% of the total volume sold of these products was indexed to international reference prices or benchmarks such as ICE Brent. Consequently, fluctuations in those international indexes have a direct effect on our financial condition and results of operations.
Prices of crude oil, natural gas and refined products have traditionally fluctuated as a result of various factors including, among others, competition within the international oil and natural gas industry, long-term changes in the demand for crude oil, natural gas and refined products, notably associated to the transition to a low carbon economy, the economic policies in the United States, China, India and the European Union, regulatory changes, changes in global supply, inventory levels, changes in the cost of capital, adverse or favorable economic conditions, global financial crises, substitute sources of energy, development of new technologies, global and regional economic and political developments in the OPEC+, the willingness and ability of the OPEC+ and its members to set production levels, local and global demand and supply for crude oil, refined products and natural gas, trading activity in oil and natural gas; weather conditions, natural events or disasters, which are changing in intensity and frequency due to climate change, and terrorism and global conflict. In particular, disagreements among OPEC+ members on production levels, changes in the trade policies from the US administration, and the continued hostilities between Russia and Ukraine and the escalation of the Middle East conflict since the Hamas attack triggered the conflict with Israel could impact international reference prices.
The Russia-Ukraine conflict has also increased volatility in the oil and refining business. Although the conflict has generally had a positive effect on crude oil prices and refining margins globally, the global economy has been adversely affected, which could lead to a rapid price correction in the future. Additionally, in the medium term, it could create incentives to accelerate decarbonization strategies, especially in Europe given its intention to cut hydrocarbon imports from Russia, thus potentially leading to a deterioration of the outlook for oil demand.
The conflict between Hamas and Israel in late 2023 has disrupted the supply of crude, refined products, LNG, and other commodities, which have risen as a result of the attacks in the Red Sea against US and UK-related vessels, in particular, instigated by Houthi forces located in Yemen. However, as of the date of this Annual Report, the supply of crude, refined products, and LNG has not been affected by the war, but time and costs related to its shipment have risen to avoid conflicted areas by diverting transportation to Africa.
During 2024, our crude oil basket average price was USD 73.3/Bl versus USD 73.4/Bl in 2023, the refined product basket average price was USD 86.8/Bl versus USD 96.1/Bl in 2023; and the natural gas average price was USD 27.8 per barrel equivalent in 2024 versus USD 28.4 per barrel equivalent in 2023. However, it is important to consider that the margin on refined products can result either in higher or lower margins due to a change in price of crude the same way gas prices can be impacted by local conditions, such as local demand and weather conditions.
Moreover, our prices are indexed to international benchmarks such as the Brent and light distillates in the Gulf of Mexico (aka Gulf of America), therefore our revenues are affected by the fluctuation of those prices. The difference between the producer revenue and the international parity price recognized by the government to Ecopetrol S.A. for diesel and gasoline can fluctuate significantly due to: (i) volatility in international oil prices, (ii) the methodology to determine the reference price of gasoline and diesel, and (iii) the sensitivity of retail price to monthly variations. As a result, these differences generate account receivables or account payables for Ecopetrol to or from the FEPC. A significant and permanent increase in the prices of gasoline and diesel in international markets, as compared to the regulated price in Colombia, can substantially increase the size of the receivable account corresponding to the FEPC. As a result, this increase could impact Ecopetrol’s solvency and liquidity metrics in absolute terms as well as relative to its industry peers; consequently, the Company might not be able to reduce its financial leverage, or capture value through cash flow derived from oil prices which are relatively higher than those budgeted internally. The easing of the account receivable problem is conditioned on the willingness of the Colombian Government and availability of sources to make direct payments and/or the ability to make quick and significant increases in the regulated price in Colombia. As settlement and payments dates are not regulated, the Ecopetrol Group’s cash flow could be affected, increasing its financial cost of debt, challenging the ability to execute the investment plan and the capacity to pay dividends. While producer’s rights are protected by law, we cannot provide any certainty as to when we would receive any such payments due to us.
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Additionally, the rating agencies’ perception associated with the accumulation of FEPC balances, as a stand-alone credit baseline (without assuming the support of the National Government), represents a credit risk. The following metrics of Ecopetrol’s rating could be reassessed at any time given a perception of higher liquidity/cash risk: (i) liquidity and hedging metrics due to lower cash availability; (ii) indebtedness metrics in case of additional borrowing, resulting in financial ratios different from those forecasted in Ecopetrol’s financial plans; (iii) Ecopetrol’s relative situation compared to peer companies at the same rating level; and (iv) Ecopetrol’s rating in the event of a possible adjustment in the sovereign’s rating, based on the rating agencies’ perception of the impact of the FEPC on public finances. As of December 31, 2024, Ecopetrol S.A. recorded COP 5.96 trillion in accounts receivable due from FEPC and Cartagena Refinery recorded COP 1.66 trillion in accounts receivable due from FEPC. For further information see section Business Overview—Applicable Laws and Regulations—Regulation Concerning Production and Prices—Fuel Price Stabilization Fund (FEPC).
A reduction of international crude oil prices could also result in a delay or a change in our capital expenditure plan, in particular delaying exploration and development activities, thereby delaying the development of reserves and affecting future cash flows. In order to maintain a profitable operation and preserve the cash flow of the Company at certain oil price levels, some of our producing fields may have to be closed or their operations temporarily suspended, which would affect our production levels and expected revenues.
Foreign currency exchange rate fluctuations may affect our financial results.
Most of our revenues are derived from sales of products quoted in or with reference to U.S. dollars and other currencies such as Brazilian real (BRL), the Peruvian Sol (PEN) and the Chilean peso (CLP). Therefore, when the Colombian Peso depreciates against the U.S. dollar, our revenues converted into Colombian Pesos, increase. Conversely, when the Colombian Peso appreciates against the U.S. dollar, our revenues decrease.
On the other hand, imported goods, oil services and the debt, which is mainly denominated in U.S. dollars, become less expensive when the Colombian Peso appreciates against the U.S. dollar and more expensive when the Colombian Peso depreciates against the U.S. dollar.
As of December 31, 2024, our U.S. dollar-denominated total debt aggregate principal amount was USD 21.2 billion; recognized in our consolidated financial statements at its amortized cost, which corresponds to the present value of cash flows discounted by an annual effective interest rate. Out of this total, a principal of USD 17.4 billion corresponds to Ecopetrol S.A., whose functional currency is the Colombian Peso. Therefore, when the Colombian Peso depreciates against the U.S. dollar, Ecopetrol S.A. is exposed to an exchange rate loss. In contrast, when the Colombian Peso appreciates against the U.S. dollar, Ecopetrol S.A. is exposed to an exchange rate gain. Some of the Ecopetrol Group’s affiliates have the U.S. dollar as functional currency and are not exposed to a material exchange rate risk resulting from fluctuations in the Colombian Peso against the U.S. dollar. On the asset side, when the financial statements of the Ecopetrol Group are consolidated, the exchange rate differential of the affiliates’ assets and liabilities whose functional currency is the U.S. dollar is recognized directly in the equity, as part of other comprehensive income.
The U.S. dollar/Colombian Peso exchange rate has fluctuated during the last several years. On average, the Colombian Peso appreciated 5.87% in 2024, depreciated 1.64% in 2023, and depreciated 13.61% in 2022. Additionally, as of December 31, 2024, the Colombian Peso had depreciated 15.36%; as of December 31, 2023, the Colombian Peso had appreciated 20.54%; as of December 31, 2022, it had depreciated 20.82%; in each case in relation to the year-end exchange rate for the immediately preceding year. In addition, given the possible effects of rising inflation, increasing interest rates in the U.S. and Colombia, different global growth perspectives, political tensions in the world’s largest economies, geopolitical conflicts, current and expected crude oil prices in the next few years and political uncertainty in Colombia, there is no clear view of how the U.S. dollar and the Colombian peso will behave in the medium to long-term. Continued market volatility is expected to lead U.S. dollar fluctuations that remain difficult to forecast.
A continued depreciation trend in the exchange rate of the Colombian Peso against the U.S. dollar may affect our financial results when converted into Colombian Pesos, given our current net position in U.S. dollars, the fact that most of our revenues are collected in U.S. dollars and the portion of our U.S. dollar debt that is not designated as hedge instrument and the future debt we may acquire whenever translation affects the debt balance. Please see our sensitivity analysis on our results of operation to exchange rate fluctuations in the section Financial Review—Effect of Taxes, Exchange Rate Variation, Inflation and the Price of Oil on our Results—Exchange Rate Variation and in Note 30.1 to our consolidated financial statements.
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Increased competition from local and foreign oil companies may have a negative impact on our ability to gain access to additional crude oil and natural gas reserves in Colombia and abroad.
Access to new reserves is focused on the existing areas under production or exploration contracts. The access to new areas depends on available opportunities in the market and their potential. The financial resources available for this purpose is a key factor that can impede the inorganic growth of reserves in Colombia and abroad.
We are also exposed to international competition as a result of our international exploratory and production activities. Currently, we are exploring and producing in Brazil and the United States, where we partner and compete with other oil and gas companies operating in those locations. If we are unable to adequately compete with local and foreign oil and gas companies, or if we cannot enter into joint ventures with market players having high potential exploration and production projects, our exploration and production activities may be limited. This could reduce our market share and our reserves to production ratio, and adversely affect our financial condition.
Operational risks may materialize and affect the health and safety of our workforce, the local community and the environment, and cause disruptions or shutdowns.
Our exploration, production, refining, transportation and electric power transmission and toll roads concessions businesses in Colombia and in the foreign countries in which we operate are subject to industry-specific operating risks, some of which, despite our internal procedures and adherence to industry best practices, are beyond our control. Our operations may be curtailed, delayed or cancelled due to adverse or abnormal weather conditions and natural disasters (mainly due to climate variability or climate change), strikes and demonstrations by local actors aimed at blocking operations, equipment failures or accidents, oil or natural gas spills or leaks, shortages or delays in the availability or in the delivery of equipment, delays or cancellation of environmental licenses or other government authorizations or judicial decisions, fires, explosions, ruptures, surface cratering, pipeline failures, sabotage, thefts, damage and attacks to our transportation and production infrastructure caused by terrorist acts of illegal armed groups. Additionally, external factors, such as disagreements over local or national government policies or decisions may cause roads and infrastructure blockades, among other factors beyond the Company’s control.
Some of our operations in Colombia and abroad could be conducted in remote and uninhabited locations that involve health and safety risks that could affect our workforce. By our own Company policy and practices, as well as under Colombian law and international industrial safety regulations, we are required to have health and safety practices that minimize risks and health issues faced by our workforce. Failure to comply with health and safety regulations in the jurisdictions where we operate may lead to investigations by health officials that could result in lawsuits or fines.
We may be required to incur in additional costs and expenses to allocate funds to industrial safety and health compliance under Colombian law and international industrial safety regulations. Additionally, if any operational incident occurs that affects local communities and/or ethnic communities in nearby areas, we will need to incur in additional costs and expenses to return affected areas to normality and to compensate for any damages we may cause. These additional costs may have a negative impact on the profitability of current operations and the projects we may decide to undertake. See Our Business – Production Activities – Unconventional Hydrocarbons for a summary of community issues related to the PPIIs.
The occurrence of any of these operating risks could result in substantial losses or slowdowns to our operations, including injury to our employees, malfunction or destruction of property, equipment and infrastructure, clean-up responsibilities, third-party liability claims, government investigations and imposition of fines, withdrawal of environmental licenses and other government permits, suspension or shutdown of our activities and loss of revenue. The occurrence of any of these events may have a material adverse effect on our financial condition and results of operations.
Our involvement in deep-water drilling either as direct operator or in conjunction with our business partners involves risks and costs, which may be out of our control.
Our deep-water drilling activities present severe risks, such as loss of primary containment, blow out, ignition, fire and explosions, marine collision, weather, platform instability and natural disasters. The occurrence of any of these unwanted events or other incidents could result in personal injuries, loss of life, severe environmental damage, property damage, clean-up and repair expenses, equipment damage and liability in civil and administrative proceedings. As a result, more stringent government regulation may result in increased costs and longer exploration and development timeframes for our deep-water drilling operations and consequently, heightened risks and costs associated with deep-water drilling may have a negative effect on our results of operations and financial condition and in our reputation.
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See section Business Overview—Exploration and Production for a summary of our current deep-water drilling activities.
We are exposed to the credit, political and regulatory risks of our key customers.
Some of our customers may experience financial problems that could have a significant negative effect on their creditworthiness. Severe financial problems encountered by our customers could limit our ability to collect amounts owed to us, or to enforce the performance of obligations owed to us under contractual arrangements. In addition, many of our customers finance their activities through their cash flows from operations, short- and long-term debt or equity.
The combination of decreasing cash flows as a result of declines in commodity prices, a reduction in borrowing bases under reserve-based credit facilities, government sanctions which may include monetary penalties, executive orders and/or trade restrictions, and the lack of availability of debt or equity may result in a significant reduction of our customers’ liquidity and limit their ability to make payments or perform their obligations to us according to their contractual terms.
Furthermore, some of our customers may be highly leveraged and subject to their own operating expenses. Therefore, the risk we face in doing business with these customers may increase. Other customers may also be subject to regulatory changes, which could increase the risk of defaulting on their obligations to us. We also could have disagreements with customers regarding tariffs, excusable events, or other aspects of our commercial relations that could lead to contract breaches by our clients. See Note 30.7 to our consolidated financial statements for more details.
Such financial problems experienced by our customers or deterioration in our relations with our customers could result in the impairment of our assets, a decrease in our operating cash flows and may also reduce or restrict our customers’ future use of our products and services, which may have an adverse effect on our revenues and our ability to make payments under our existing debt obligations.
Our ability to access credit markets may be limited by the deterioration of these markets, changes in credit ratings, and limited offering from financial institutions to participants in the oil and gas industry.
Our and our subsidiaries’ ability to access international and local capital markets and finance our operations and potentially refinance our debt maturities on terms acceptable to us could be adversely affected due to the volatility in prices in the oil and gas sector, the continued military conflict between Ukraine and Russia, the disruptions on Russia’s energy exports as a result of sanctions, conflicts in the Middle East and their impact on global supply chains, the global economy impacts due to energy supply shocks, the potential impacts on demand of future pandemics or epidemics, the spread of protectionist policies in the United States, the lack of consensus among OPEC+ members, the political uncertainty in Latin America and other parts of the developed world, the awareness of corruption by governments and private companies in emerging markets, which in turn could worsen risk perception with respect to the emerging markets, or the occurrence of any of the risks described in the section Risk Review—Risk Factors—Risks Related to Colombia’s Political and Regional Environment . These conditions, along with the possibility of systemic banking crises, significant write-offs in the financial services sector and the re-pricing of credit risk, can make it difficult for us to obtain funding for our capital needs on favorable terms. Our cost and ability to obtain capital might be affected as well if our creditors and potential investors believe that we are not actively responding to the new low carbon economy, integrating TESG considerations in our operation and management, addressing risks related to climate change and energy transition, and meeting TESG targets; considering further the evolving restrictions to invest in pure fossil fuels companies announced by certain investors worldwide.
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Access to credit and capital markets depends on a number of factors, many of which we cannot control, including changes in: our credit ratings because of external factors, interest rates, the structured and commercial financial markets, tax rates due to new or changes to existing tax laws, foreign exchange and investment controls and restrictions, market perceptions of the industries in which we operate, which are mainly determined by our financial and operational strength, and the support that could be provided by the Colombian Government. We cannot assure that our credit ratings will continue for any given period of time or that the ratings will not be further lowered or withdrawn. An assigned rating may be raised or lowered depending, among other things, on the respective rating agency’s assessment of our financial strength. In addition, a downgrade in the rating of the Republic of Colombia could also trigger a downgrade on ours, as it is capped by the rating of the Republic of Colombia and the implicit support that can potentially be provided to the Company. On September 22, 2023, Moody’s Investors Service re-affirmed our rating at Baa3, with a negative outlook and re-affirmed our Baseline Credit Assessment (BCA) at ba3. On November 6, 2023, Fitch Ratings reaffirmed our rating at BB+ with a stable outlook and modified our individual credit rating (stand alone credit profile) to bbb- and affirmed the national long-term and short-term ratings of the Company at ‘AAA’ with a stable outlook and ‘F1+’, respectively. On January 18, 2024, SP Global Ratings modified the outlook of Ecopetrol’s credit rating from stable to negative, as a result of the review in the outlook of Colombia’s credit rating, also from stable to negative. On May 31, 2024, Moody’s Investors Service updated our rating at ba1 with a stable outlook. On November 6, 2024, Fitch Ratings reaffirmed our rating at BB+ with a stable outlook. On February 24, 2025, Moody’s Investors Services reaffirmed our Ba1 rating with a stable outlook. On, March 14, 2025 Fitch Ratings, modified the outlook of Ecopetrol’s credit rating from stable to negative, as a result of the review in the outlook of Colombia’s credit rating (on March 6, 2025), also from stable to negative. With respect to our renewable energy and low carbon emission project portfolio, we cannot assure that the projects will be able to raise financing on the terms expected or required to develop such portfolio.
As a result of these factors, we may be forced to revise the timing and scope of our capital projects as necessary to adapt to existing market and economic conditions, downgrades to our credit ratings or to access the financial markets on terms less favorable, therefore negatively affecting our results of operations and financial condition.
In addition, under applicable regulation, most of our indebtedness must be previously authorized by the Colombian Ministry of Finance and Public Credit and the National Planning Department and local bond issuances by the Financial Superintendence of Colombia. Likewise, our equity offerings must abide by the terms set forth in Law 1118 of 2006 and any operation within the domestic equity capital market must be previously approved by the Financial Superintendence of Colombia. As such, our access to debt and equity funding is subject to the Government’s time frames and policies, and we cannot guarantee that such authorizations would be granted in a timely fashion or granted at all.
We may be exposed to increases in interest rates, thereby increasing our financial costs.
We may incur debt locally and in the international capital markets and, consequently, may be affected by changes in prevailing interest rates.
When market interest rates increase, our financing expenses are likely to increase, which could have an adverse effect on our results of operations and financial condition. Our future success depends on our ability to access capital markets and obtain financing at cost effective rates.
As of December 31, 2024, approximately 29.5%, or a principal of USD 7.9 billion (COP 34.9 trillion, using a COP 4,409.15/1.00 U.S. exchange rate as of December 31, 2024), of our total indebtedness consisted of floating rate debt. If market interest rates rise, our financing expenses could be expected to increase and our cost of capital could be expected to deteriorate, which could have an adverse effect on our ability to execute certain projects, and our results of operations and financial condition. In addition, as we refinance our existing debt in the coming years, the mix of our indebtedness may change, specifically as it relates to the ratio of fixed to floating interest rates, the ratio of short-term to long-term debt, and the currencies in which our debt is denominated in or indexed to. We cannot assure that such changes will not result in increased financing expenses borne by us. Finally, as we incur new debt in the future to fund our working capital, capital projects or inorganic acquisitions, or pursue liability management transactions, the prevailing interest rates and spreads at any specific time could be less favorable in terms of cost when compared to our previous financing transactions, which could adversely affect our financial condition and results of operations.
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Our current and planned investments, divestments and business activities outside Colombia are exposed to political and economic risks.
We began exploration activities outside Colombia in 2006 through our Brazilian subsidiary, Ecopetrol Óleo e Gás do Brasil Ltda. We operate through business partners, subsidiaries, or affiliates outside Colombia. We currently have investments, joint ventures and direct and indirect subsidiaries incorporated in Peru, Brazil, Chile, Argentina, Bolivia, Mexico, Bermuda, Panama, the Cayman Islands, Switzerland, Spain, the United Kingdom, Singapore, and the United States, and we are continuously assessing our investments, including any potential divestments, in these countries, as well as investments in other countries. Our investment and divestment decisions may be subject to risks related to economic and political conditions, as well as potential governmental actions, such as investigations or legal proceedings. Furthermore, we cannot predict the positions of foreign governments relating to the oil and gas industry, electricity transmission, toll roads concessions, land tenure, protection of private property, environmental standards, regulation, or taxation; nor can we assure that future governments will maintain policies favorable to foreign investment or repatriation of capital. Additionally, we may face new and unexpected risks involving environmental and other legal requirements beyond those we currently experience.
The results of operations and financial condition of our subsidiaries in these countries also may be adversely affected not only by risks associated with hydrocarbon exploration and production or electricity transmission and toll roads, but also by fluctuations in their local economies, political instability and government actions, including: the imposition of price controls, the imposition of restrictions on hydrocarbon exports, electricity transmission limitations, fluctuation of local currencies against the Colombian peso, the nationalization of oil and gas reserves or electricity transmission, increases in export and income tax rates for crude oil and oil products, electricity transmission, toll roads concessions, and unilateral (governmental) institutional and contractual changes, including controls on investments and limitations on new projects.
Any of these conditions occurring could disrupt or terminate our operations, causing our development activities to be curtailed or terminated in these areas, or our production to decline, limit our ability to pursue new opportunities, affect the recoverability of our assets, cause us to incur additional costs or delay the timeline of our projects, be unable to realize the original expected value or recover the value of our initial investment, or be unable to divest assets at acceptable prices or within the planned business timelines because of economic or political conditions or market risk.
Our future performance depends on successful selection, development and deployment of new technologies and our knowledge about them.
Technology, knowledge, science, and innovation are essential to our business, especially for the addition of reserves in complex settings, reducing operational costs, reducing the carbon footprint of our operations and adapting to the energy transition. If we do not develop the right technology, or do not secure access to required third-party technology, or if we fail to deploy the right technology, do not obtain the expertise to operate our deployed technology or to improve our processes, or do not deploy the knowledge necessary to improve such technology effectively, the achievement of our corporate goals, our profitability, and our earnings may be adversely affected. Furthermore, as we address climate change and the transition to a lower-carbon economy, we face the risk that our progress may be curtailed due to the high cost or limited access to low-carbon and water management technologies. In the case of our enhanced oil recovery program, we depend on the successful selection, adaptation, demonstration, and deployment of appropriate technologies that are also energy and environmentally efficient.
Our performance could be negatively affected by the lack of employees with the skills needed to execute our business strategy.
As the oil and gas industry and the energy sector faces an increasing number of challenges, the ability to react quickly to these challenges has become a key factor in achieving efficiency, profitability, growth, and sustainability. Our ability to achieve these goals could be negatively affected by a lack of key skilled employees that can execute our business strategy and transition to a low carbon economy with competency, creativity, and determination. This situation poses a risk if we are unable to timely strengthen or develop the capacities of management at all levels of the organization or attract new employees with the necessary skills to implement climate-resilient initiatives and to achieve our decarbonization goals.
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If the strategic plans associated to natural gas fail or underdeliver, we may be unable to keep pace with increasing domestic demand.
In June 2024, the Mining and Energy Planning Unit ( Unidad de Planeación Minero Energética , “UPME” for its acronym in Spanish) published the Natural Gas Supply Plan. The UPME has established a possible deficit of natural gas in Colombia between late 2025 and early 2026 in some scenarios. Considering the CREG Resolution 186 of 2020, the natural gas market is a physical market, which means that suppliers must comply with the quantities agreed in their contracts with firm gas commitments.
We are currently developing offshore projects to incorporate gas reserves; we cannot assure that they will go into operation in the short term. Additionally, we are party of several national gas supply contracts that have firm gas commitments. If we were unable to deliver natural gas to these clients because of cuts in operations or higher decline rates in our gas fields, among other reasons, we may be required to compensate our customers for our failure to supply natural gas.
Delays in the implementation of our strategic plans associated to natural gas and NGL could result in us losing market share if clients choose to secure their supply with other sources instead (such as third-party gas suppliers or imports). As a result, our financial condition, results of operations and market share could be impacted.
We depend on others for the construction and availability of natural gas transportation infrastructure for the transport of our gas, which may limit our ability to develop new or existing fields or lead to the deterioration of related assets and may not allow us to recover the cost of capital invested in natural gas discoveries.
Ecopetrol S.A. can only hold up to 25% of the equity of any natural gas transportation company according to Article 5 of CREG Resolution 057 of 1996 (except for transportation assets acquired before this Resolution). Therefore, there can be no assurance that the transportation infrastructure necessary to transport natural gas from the fields to distribution points and our customers will be built by third parties, or that if built in that location, there will be sufficient capacity available to us for the exploitation of new natural gas discoveries or the development of existing fields due to the non-financial closure of transport projects or lack of signed contracts with transporters. The failure to commercially exploit new or existing discoveries may result in impairment of the related assets and our inability to recover the capital expenditures invested to make these natural gas discoveries.
Our operations could be affected by demonstrations and other actions of labor unions, social organizations, communities and contractors.
Social organizations, including those in the communities where we operate, individuals representing specific communities, contractors and their workers, labor unions and other social movements may, exercising their rights, engage in demonstrations, protests, and other actions related to climate, labor (including expectations to increase the local employment or a higher spend on goods and services), health, indigenous rights and other social issues of local, national, or global significance. Such demonstrations, protests and actions may disrupt our operations, escalate into conflicts, lead to increased or unexpected costs, or otherwise have a material adverse effect on our business.
Regarding the emerging environmental and climate change concerns, some communities have shown strong opposition to the development of PPIIs, leading their representatives to propose bills aimed at banning Integral Research Pilot Projects (“PPIIs” from its acronyms in Spanish). Although none of these bills has materialized into a law, we cannot guarantee that similar bills will not continue to be proposed or that none of them may eventually gain sufficient support to be enacted.
We cannot guarantee that the actions taken by labor unions will not affect the normal development of our operations, that we will not experience strikes or labor unrest, or that our labor costs will not increase significantly. The occurrence of any of these events could have an adverse effect on our operations and financial condition.
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Our activities may be interrupted or affected by external factors, such as climate change and its effect on weather and natural disasters.
In the past decade, the “El Niño” and “La Niña” have intensified, increasing the risk of extreme climate events, such as floods, landslides, wildfires, droughts, increased temperature and rising sea and river levels, among others, as well as related water scarcity, which may affect our infrastructure and business operations.
“El Niño” phenomenon is characterized by: (i) the lack of rainfall, may drastically decrease surface waterbodies flows, affecting both freshwater use and wastewater discharges because of the reduction on dilution potential of receiving waterbodies, (ii) increased temperatures, which causes heat waves and could have a direct impact on the health of our workers and cause an increase in epidemics and diseases, and (iii) potential negative impact on energy supply due to the decrease in the level of the rivers that feed the hydroelectric generation system of the country. In addition to the “El Niño” climate phenomenon, some basins in Colombia may be affected by seasonal variability in some periods of the year (normally January to March - June to July), which could reduce water flows, affecting freshwater withdrawals and surface discharges, as mentioned previously. Moreover, such adverse weather events can result in transmission restrictions caused by the increase in a transmission line’s load from the coast to the center of the country and negatively impact our electric power transmission business.
Furthermore, “La Niña” climate phenomenon is characterized by increased rainfall, which can generate frequent landslides and flooding, which may cause delays on transportation due to road blockades, increase pipeline integrity risks that may cause hydrocarbon spills and limit operations in our production fields and facilities, as well as cause infrastructure loses, such as collapse of transmission towers and lines that restrict our electric power transmission business’ operations.
These risks could result in fatalities, property damage, project delays, production deferrals, loss of revenue, pollution, and harm to the environment, damage roads as well as temporary disruptions to our services, among others. If any of these occur, we may be exposed to economic sanctions, damages, fines, or penalties in addition to the negative effects these events may have on our operations and the costs required to repair or remediate the related damage. These costs, fines and penalties may adversely affect our financial condition, reputation, and results of operations. Natural disasters or similar events could also result in substantial volatility in our results of operations or the interruption of our essential services for our country, such as our ability to transport natural gas and transmit electricity.
During 2024, ENSO conditions were not consolidated; meteorological conditions were modulated by the reference climatology.
Our operations, including our activities in areas classified as indigenous reserves and Afro-Colombian lands, could be subject to opposition from members of various communities.
We currently carry out and plan to continue carrying out activities in areas classified by the Government as indigenous reserves and Afro-Colombian lands. To undertake these activities, we must first comply with prior consultation processes, set forth by Colombian law. These prior consultation processes are required for obtaining environmental licenses to start our projects, works or activities in areas inhabited by ethnic communities. In addition, consultations can be seen as a potential instrument to involve communities in the decision of developing extracting industry and infrastructure projects in their territories. Generally, these consultation processes last between six months to one year depending on the community expectations but may be significantly delayed if we cannot reach an agreement with the communities. We strive to be respectful of the Constitution and laws and the autonomy of indigenous and afro-descendant communities, and we therefore do not enter their territories until we have reached an agreement with them. We also strive to structure management plans to prevent, mitigate, repair or offset the impact of our projects, as identified by local communities. Issued environmental licenses for these projects are subject to scrutiny as a result of claims filed by local community interest groups.
In recent years, indigenous communities have also been claiming their ancestral territories and requesting recognition of their right to be consulted about projects already in operation before the Indigenous and Tribal Peoples Convention number 169 started to apply in Colombia. This opposition results from, among other factors, the communities’ view on the exploitation of natural resources, the environment, and the effects on their cultures, territories and spiritual beliefs. According to this, we may be exposed to operational restrictions as a result of the opposition of these communities.
No certainty can be given that we will be able to reach an agreement with the different communities that do not agree and object to our operations or that such communities will participate in consultation processes if available. We may be exposed to similar delays due to the objection from local communities in other countries where we carry out our activities.
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Our activities may be subject to objection, including protests by not-ethnic communities. We are also subject to other participation mechanisms, such as popular consultation “acción popular”, where local communities vote against the development of extractive industry projects. Any such similar situation may affect our future projects. See section Risk Review—Legal Proceedings and Related Matters for detailed information related to consultation processes with Afro-descendant communities.
We have made and may make significant investments and divestments, and we may not realize their expected value.
We continuously analyze investments and joint ventures in Colombia and abroad and will continue to do so as part of our 2040 Strategy. We have made investments and may continue to do so from time to time depending on the environment and strategic needs of the Company. Some of our investments, joint ventures and new business lines may be less profitable than planned and, as a result, we may not achieve consistent profitability in the future.
Obtaining the expected benefits of acquisitions, including ISA’s, or joint venture investments, will depend, in part, on our ability to: (i) obtain the expected results of operations and financial condition from these acquisitions or joint venture investments, (ii) manage different sets of assets and operations and integrate distinct corporate cultures or investment goals, (iii) manage our objectives as a corporate group, and (iv) institute our corporate governance rules as well as other factors beyond our control such as the economic and regulatory environment in countries in which we have made acquisitions or joint venture investments, as well as all other risks affecting the oil and gas industry or the industries of the businesses we acquire or invest in. See section Risk Review–– Legal Proceedings and Related Matters––Interconexión Eléctrica S.A.
Similarly, in our shale operations in the U.S., the ability to drill and develop different locations is subject to uncertainties such as natural gas and oil prices, drilling and production costs, availability of drilling services and equipment, lease acquisitions and expirations, processing capacity constraints, pipeline transportation bottlenecks, access to and availability of water sourcing and distribution systems, regulatory approvals, among others. We cannot assure that all the well locations we have identified will ever be drilled or if we will be able to produce natural gas or oil at the planned levels. As a result, our efforts may not succeed and our failure to successfully obtain the expected results from our acquisitions or joint venture investments could adversely affect our financial condition and results of operations.
In addition, as a result of strategic reassessments of our core operations and portfolio management analysis, in the past we have executed and may determine as part of our short- or long-term strategy to execute partial or total divestments in our current businesses, and the sale prices for these transactions may not be enough to realize the original expected value or recover the value of our initial investment. We may also retain liabilities following a divestment or be held liable for past acts, failures to act or liabilities that are different from those foreseen.
We might be required to provide financial support to our subsidiaries or affiliates in Colombia or abroad.
Although currently we are not the sponsor and have not provided guarantees to third parties to support the financing activities of any of our subsidiaries or affiliates, some financial support at any point in time might be needed to assure the long-term viability of such subsidiaries or affiliates when exposed to unexpected conditions, results, or when it is utterly required to support projects in their developing phase, in particular with respect of those pre-operative affiliates.
Any situation that could affect the operations of our subsidiaries or affiliates, or make them financially non-viable, particularly for those that are about to enter into their development phase or for those that recently entered into operations, may have a negative impact on their profitability as well as on their ability to pay their liabilities, which in turn could adversely affect our financial condition and results of operations.
Investigations and other actions by Colombian administrative control entities involving our current or former employees or those of our current or former subsidiaries may impact our reputation.
As a majority-owned state entity, Ecopetrol’s current or former employees, as they are considered public servants, and those from its current or former subsidiaries are subject to oversight by various administrative control entities in Colombia, including the Office of the Comptroller General ( Contraloría General de la República ), The Attorney General’s Office ( Procuraduría General de la Nación ) and/or The Prosecutor’s Office ( Fiscalía General de la Nación ). Such oversight could result in proceedings, the imposition of fines or penalties, or other actions by Colombian administrative control entities and may ultimately also impact our reputation.
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Investigations against Mr. Ricardo Roa for alleged actions that would have taken place before he joined the Ecopetrol as its Chief Executive Officer, and not during his time as the Ecopetrol’s Chief Executive Officer or the Ecopetrol itself, may impact our reputation. On October 8, 2024, the National Electoral Council opened a formal investigation for alleged irregularities in the financing and presentation of the income and expenditure report of Mr. Gustavo Petro’s 2022 presidential campaign, of which Mr. Ricardo Roa Barragán was the campaign manager. Separately, on December 12, 2023, the Attorney General’s Office initiated a disciplinary investigation for the same reasons, after a Colombia citizen filed a petition before Colombia’s Prosecutor’s Office. According to public records, the investigation by the National Electoral Council is in the evidentiary phase, and the investigation by the Attorney General’s Office is in the evidentiary phase.
On January 26, 2024, the Attorney General’s Office initiated a preliminary investigation against Mr. Roa, in his capacity as Chief Executive Officer, for alleged irregularities occurred on December 2022, before he joined Ecopetrol as its Chief Executive Officer, in the purchase of an apartment from an oil and gas businessman from Venezuela that has business interests with Ecopetrol Group. The Attorney General’s Office has not issued a formal accusation or decided to dismiss the proceeding definitively.
On December 16, 2024, the Attorney General’s Office initiated a disciplinary investigation against Mr. Roa in his capacity as Chief Executive Officer, based on a complaint alleging that his statements of April 24, 2023, regarding the signing of oil and gas exploration and exploitation contracts and the intention to import gas from Venezuela, could have affected Ecopetrol’s finances, such as loss of share value on markets that Ecopetrol participates in. The investigation is in the evidentiary phase.
As a result of these developments concerning our Chief Executive Officer, our Board of Directors commissioned a report from an external risk consultant. The key recommendations of the report were the need for the Board of Directors and management of Ecopetrol to constantly monitor publicly available information for any new developments regarding the CEO; evaluate potential risks and the likelihood of their coming to pass; and maintaining a continuing dialogue with external counsel expert in regulatory issues in the United States to ensure a prompt response of Ecopetrol and the Board of Directors of any recommendations made.
There are also investigations of certain employees and former employees of Ecopetrol, Bioenergy and Reficar and certain members of the board of directors of Offshore International Group, where Ecopetrol formerly held a stake, which remain ongoing. Ecopetrol is not aware of any allegations related to acts of corruption, bribery or fraud in connection therewith. See section Risk Review—Legal Proceedings and Related Matters and Risk Review—Risk Factors—Legal and Regulatory Risk—We may incur losses and spend time and money defending pending lawsuits and arbitrations and responding to administrative investigations for additional information.
Our results may be affected by supply chain disruptions and high price volatility impacting our suppliers, partners and other third-parties.
Global supply chains have been strongly impacted due to a combination of factors like geopolitical issues, global trade, economic factors, raw materials, breakthrough technologies, logistics disruptions, and the continued conflicts between Israel and Palestine, Russia and Ukraine and in the Middle East. These factors have resulted in substantial commercial disruption in the flow of goods and services across regions. Coupled with the tightening of monetary policy to curb inflationary trends, these factors continue to impact the global energy markets. A set of 32 most relevant supply indexes have been identified and monitored. While some international indexes show corrections, certain domestic indexes are experiencing high inflationary pressure. These include the Consumer Price Index (CPI), Producer Price Index (PPI), cement, copper, logistics, transportation, fuel (diesel and gasoline), among others. This situation has affected and could continue to affect suppliers and agreed commercial conditions and might contribute to spiral inflationary trends in the short term.
The above-mentioned factors are expected to have a potential impact between 4.2% and 4.7% inflation, equivalent to USD 129 million and USD 144 million. These scenarios could result in a deficit of 0.5 to 0.75 million barrels per day of crude oil, placing Brent prices in a range of USD 79 to USD 88 per barrel. This would impact the categories of oil services, technology, logistics, deveolpment of new projects, construction materials and equipment. This means, in inflationary terms, a potential resistance to the price level are expected to extend the soaring prices in the medium term, possibly fueling a scenario of slight economic slowdown.
Likewise, the global logistics situation has generated record increases in international and domestic freight transport rates, limited capacity in ports, and delays in the delivery times. The combination of inflationary impact, the logistical situation and the other shocks create complex environment that may affect our results and the performance of our suppliers, subcontractors, and third-party service providers. Some of our suppliers may face financial or operational problems that could led them to a breach of their obligations settled under contractual arrangements. Other suppliers may also be subject to regulatory changes or sanctions that could increase the risk of defaulting on their obligations to us, which could have an adverse effect on our operations and financial condition.
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Most of our activity depends on suppliers, sub-contractors and third-party service providers that provide goods and services for our operations and projects. In addition, some of our operations and projects are performed through joint ventures or other contractual arrangements with our business partners or third-party service providers. Consequently, we depend on the performance of our business partners or third-party service providers. The weak performance of our suppliers, or our business partners or third-party providers, in any criteria such as operational efficiency, deadlines, administrative aspects, HSE, especially in those projects in which we do not act as operator, could negatively impact the execution of projects and operating performance, which in turn could have a negative impact on our results of operations and financial condition. We are exposed to the risk of not finding business partners or suppliers with the proper skills and performance we require for our projects. We are also indirectly exposed to supply agreements and other third-party services contracted by our business partners acting as operators under joint venture agreements.
Our insurance policies do not cover all liabilities and may not be available for all risks.
Our insurance policies do not cover all liabilities, and insurance may not be available for all risks. There can be no assurance that incidents will not occur in the future, that insurance will adequately cover the entire scope or extent of our losses or that our employees or former employees will not be found liable by investigations by Colombian State control entities in connection with claims arising from these and other events, which could adversely affect our financial condition and results of operations.
Notwithstanding the increase in coverage that has been achieved in recent years, due to worldwide market conditions and limitations associated to interpretations and decisions made by the Colombian Surveillance and the Office of the Comptroller General with regards to directors and officers insurance, in recent years the terms and conditions of our directors and officers insurance policy have been affected as such coverage has become more costly, which could affect future decisions expected to be made by such directors and officers.
New trends in the insurance sector in the face of climate change may impact our financial condition and results of operations.
We have identified three main insurance trends arising from the transition to a lower carbon economy and climate change that could have a negative impact on the Company: (i) insurance and reinsurance companies are imposing new requirements regarding decarbonization targets, which may affect the insurability of assets or higher premiums, (ii) policy coverage may change as climate risk modeling and assessment advance, leading to changes in underwriting policies and new policy exclusions, and (iii) increase frequency or intensity of climate related events may lead to increase in premium prices. We have been strengthening communications with the reinsurance market, in relation to the TESG strategy and its commitment to comply with it, which allows us to support the negotiations of the corporate insurance program. However, we cannot assure that these trends will not increase our insurance costs or reduce our insurance coverage, which could adversely affect our financial condition and results of operations.
A failure in our information technology systems or cyber security attacks may adversely affect our financial results.
We depend on the reliability and security of our information technology systems to conduct certain exploration, development and production activities, process financial records and operating data and communicate with our employees and business partners, and for many other activities related to our business. Our information technology systems may fail or have other significant shortcomings due to operational system flaws or employee misuse, tampering or manipulation. In addition, we may become the target of cyber-attacks or information security breaches that could result in the unauthorized release, gathering, monitoring, misuse, loss, or destruction of proprietary and other information. Any of these occurrences could disrupt our business, result in potential liability or reputational damage, or otherwise have an adverse effect on our financial results.
During 2024, our internal cybersecurity systems identified and contained cybersecurity attacks such as malware, phishing and denial of service. We did not have any critical incidents during the year required to be reported in accordance with the new SEC rules, as we included in the cybersecurity guidelines that all cyber incidents must be assessed in accordance with the RAM (risk assessment matrix). Although we have not experienced any material losses related to failures of our information technology systems or cyber incidents, there can be no assurance that we will not suffer such losses in the future.
Information and processing systems are vital to the ability to monitor the operation and network performance of assets, achieve operating efficiencies, and meet service targets and standards. Any failure of any of these information and processing systems could have a material adverse effect on our financial condition and results of operations. In addition, we may become the target of cyber-attacks or information security breaches that could result in the unauthorized release, gathering, monitoring, misuse, loss or destruction of proprietary and other information. Any of these occurrences could disrupt our business, result in potential liability or reputational damage or otherwise have an adverse effect on our financial results.
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We are exposed to behaviors incompatible with our ethics and compliance standards.
Given the extent, dimension and nature of our business and corporate sector, the frequent interaction with national and foreign Government Officials, the large number of contracts that we are a party to in Colombia and abroad with local and foreign suppliers, the geographic distribution of our operations and the great variety of actors that we interact within the course of our business, we are subject to possible violations of our Codes of Ethics and Conduct, as well as applicable legal provisions related to compliance with regulations of anti-money laundering, U.S. Foreign Corrupt Practices Act (“FCPA”), fraud, corruption and bribery. Such acts may impact our reputation, and eventually could affect the commercial relations of the Company.
The performance of our partners, subsidiaries and affiliates in Colombia and elsewhere may negatively impact our image and reputation.
As part of our strategy, we have carried out and plan to carry out substantial investments, divestitures, partnerships and joint ventures in Colombia and elsewhere. Failures, errors, accidents in the performance of such partners, affiliates and subsidiaries, among other factors, could potentially negatively impact our image and reputation.
There may be situations wherein product failures and/or accidents are not properly mitigated, making our relationship with our stakeholders difficult. We cannot ensure that there will be no impact on our relationship with local governments, customers and third parties as a result of such product failures and/or accidents, which could affect our image and reputation, negatively impacting us in the business environment and challenging the implementation of our strategies and achievement of our objectives.
The reliability and capacity of national power supply systems may affect or limit the continuity of our operations or limit growth.
Our energy consumption in 2024 was 8.26 TWh/year, of which 60% was supplied through self-generation, and the remaining 40%through power grid. Our demand is 10% of the total energy demand in the SIN. Our self-generation is subject to fuel and solar availability. In addition, several producing fields are connected to the national transmission system and depend on its expansion and reliability to keep steady production levels. The national electricity market is volatile due to changes in hydrology and availability of fuels (natural gas, diesel, etc.), bringing uncertainty to prices. If energy were to become unavailable or difficult to obtain, our results of operation and financial condition could be adversely affected.
Rising water production levels may affect or constrain our crude oil production.
During 2024, the Ecopetrol Group produced approximately 12.8 million barrels of water per day which includes direct operations, and operations with partners and subsidiaries. Taking into account the nature of our reservoirs, the water production levels to be managed by the Company may increase in the future. In order to achieve our oil and gas production goals and to avoid any production restrictions going forward, we will need to secure the required capacity to manage water levels. Factors that may trigger a possible constraint in our crude oil production due to the rising water production levels are: (i) ineffective project management of the required facilities, (ii) the Company’s and its partners’ ability to timely obtain the environmental permits related to water management, (iii) social and community interactions that could affect the development and operation of these projects, and (iv) the availability of capital to execute the required projects.
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5.2.2 |
Risks Related to Colombia and the Region’s Political and Regional Environment |
This section discusses potential risks related to our extensive operations in Colombia, as well as our operations in other countries of Latin America.
Changes in economic, energy transition and oil gas policies in Colombia, Peru, Brazil, Chile and the United States of America could materially affect our financial condition and results of operations.
Our financial condition and results of operations may be adversely affected by changes in the political climate of Colombia, Peru, Brazil and Chile to the extent that such changes affect the economic policies, growth, stability, outlook or regulatory environment of these countries.
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With respect to Colombia, for the year ended December 31, 2024, revenues derived from Colombia represented 47% of our total revenues. The Colombian Government has historically exercised substantial influence on the local economy, and governmental policies are likely to continue to have an important effect on companies operating in Colombia and on market conditions. Natural resources are owned by the state, but they can be exploited by a third party and pay grants to the Government for that exploitation. The President of Colombia and the Colombian Central Bank have considerable power and independence as policymakers to determine governmental policies, regulations and actions relating to the economy and may adopt policies that may negatively affect us. We cannot predict which policies will be adopted by the Government and whether those policies would have a negative impact on the Colombian economy or our business and financial performance.
In December 2023, the Minister of Mines and Energy, Andrés Camacho, announced the progress made by the Colombian Government in relation to energy and hydrocarbons, as well as the challenges that are yet to be overcome in these sectors. The Colombian Government developed the “Roadmap for an Equitable Energy Transition,” after having presented the “Construction of principles, methodology and launch of the Social Dialogue to define the Roadmap for the Just Energy Transition in Colombia” during the United Nations Conference on Climate Change COP27 in Egypt in November 2022. This roadmap has been built through technical analysis and together with existing regulations such as Law 2099 of 2021 and CONPES 4075 of 2022. Moreover, the Colombian Government has presented a bill to definitively prohibit fracking in Colombia. At this time, it is unclear how such policies may affect our business, what form they could take, or whether we would need to adjust our business strategy to any such policies.
Furthermore, although throughout recent history elected governments (and the Colombian Congress as well) have pursued free market economic policies with almost no economic interventions, we cannot predict which policies, if any, will be adopted by the new Government and/or congress and whether those policies would have a negative impact on the Colombian economy or our business and financial performance. See section Business Overview—Applicable Laws and Regulations—Regulation of Exploration and Production Activities—Business Regulation—Temporary regulation for the Comprehensive Research Pilot Projects (PPII) .
On August 2022, the MHCP submitted a tax reform bill to Congress proposing changes to the Colombian tax regime. The tax reform bill was sanctioned by President Petro as Law 2277 of 2022 on December 13, 2022, and became effective starting January 1, 2023. The law is expected to increase tax collection to approximately COP 20 trillion by the end of 2023 (approximately 3% of the country GDP). The tax reform includes, among others: (i) a new permanent equity tax applicable to Colombian individuals and non-residents, at rates ranging from 0.5% to 1.5% based on the level of net equity at January 1st every year, (ii) an increase in the dividend tax rate for local and foreign shareholders (0% to 39% progressive marginal rates for Colombian individuals, and 20% flat withholding for non-resident shareholders), (iii) an increase in the long-term capital gains tax rate (increases from 10% to 15%), (iv) the elimination of specific tax benefits and exemptions, (v) a minimum corporate income tax based on effective tax rate (effective rate calculated on book profit should be at least 15%, considering certain adjustments to accounting profits and certain exempted companies), (vi) the application of taxes based on significant economic presence (primarily for non-resident persons and entities that provide digital services, but including other services and commercial activities), (vii) the elimination of the ability to claim 50% of the ICA as an income tax credit, (viii) an additional percentage points to the nominal tax rate for companies engaged in the extraction of crude oil and coal of 0%, 5%, 10% or 15% and based on international prices. For fiscal year 2023 and 2024, additional percentage points will be applied to the nominal of 10% and 5%, given that the Brent price was USD 80.32 and USD 78.76, according to ANH Resolutions No. 0061 and No. 0044 from January 31, 2024 and 2025, respectively. Note that the revenues from the sale of natural gas are not subject to these additional percentage points to the nominal tax rate, (ix) non-deductibility of royalties, and (x) the modification of section 221 of Law 1819 of 2016, with an adjustment to the taxable event and establishing that the national carbon tax will be levied on the carbon equivalent content (CO2eq) of all fossil fuels, including all petroleum derivatives, fossil gas and solids used for combustion.
Decree 175 of February 14, 2025 (“Decree 175”) introduced tax measures intended to address the state of internal commotion declared by the National Government through Decree 062 of 2025. These measures include the introduction of two new taxes: (i) the special tax for the Catatumbo; and (ii) the reactivation of the stamp tax rate. Both taxes are temporary and will be in effect from February 22, 2025, through December 31, 2025.
Additionally, the Colombian Congress recently approved the bill on pension reform (which restructures the pension system into a “pillar system” which manages and assigns funds in accordance with age, the condition of the affiliates, among others, as well as changes to pension schemes applicable to women). Furthermore, on March 6, 2025, the Chamber of Representatives voted in favor of the healthcare reform presented by President Petro for review by the Colombian Congress and as of the date of this report, it is currently being reviewed by the Senate. On March 19, 2025, the Colombian Congress voted to shelve the labor reform. The Colombian government has publicly stated its intention to conduct a public consultation process in the event that these reforms are not approved by Congress to determine the public’s stance on the reforms. The Colombian government has stated its intention to file the public consultation before Congress in April 2025. As of the date of this annual report, it is unclear how these proposals could affect the Colombian economy or our business.
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With respect to Brazil, for the year ended December 31, 2024, revenues derived from our consolidated subsidiaries in this country represented 5% of our total revenues. On January 8, 2023, demonstrators invaded the Planalto presidential palace, the National Congress and the Federal Supreme Court (STF) in Brasilia, protesting the defeat of then-president Jair Bolsonaro in the 2022 Brazilian general election and the inauguration of his successor Luiz Inácio Lula da Silva. As of February 4, 2025, 374 people had been tried and sentenced with up to 17 years of imprisonment in the cases involving the most serious crimes related to the events of January 8, 2023. On November 19, 2024, the Federal Police conducted the Counter-Coup Operation and indicted 37 people, amongst them former president Jair Bolsonaro, as well as various former high-ranking officials from his time in office. On electoral aspects, on October 6, 2024, municipalities held elections for mayors and city council members. A second round of voting took place on October 27, 2024 in 51 municipalities in which none of the mayoral candidates obtained more than half of the valid votes (excluding blank and invalid votes) in the first round. The elected mayors and city council members were sworn into office on January 1, 2025. The National Congress enacted a tax reform on December 20, 2023 (the “Brazil Tax Reform”). The Brazil Tax Reform includes: (i) merging four levies into value-added tax (VAT) rates managed in a dual format (partially federal and partially regional), (ii) changing tax collection from a tax on production to a tax on consumption, (iii) reduced tax rates on certain sectors of the economy, (iv) sets the framework for a creation of a cashback system, and (v) increases tax rates on luxury vehicles and inheritances. On April 25, 2024, the Federal Government submitted the bill for the first complementary law regulating aspects of the Brazil Tax Reform to the National Congress for consideration. The bill provides for a “cashback” or rebate mechanism for low-income families on certain goods and utility services, such as gas, electricity and water, and a “split payment” system that electronically splits tax payments relating to transactions by recipient. On January 16, 2025, the bill was enacted by President Lula as Complementary Law 214/2025 after having gone through its congressional approval process. On June 5, 2024, the Federal Government submitted bill No. 108/2024, the second complementary law regulating aspects of the Brazil Tax Reform to the National Congress for consideration. The bill creates the IBS Steering Committee ( Comitê Gestor do Imposto sobre Bens e Serviços or “CG-IBS”, for its acronym in Portuguese), and regulates the administrative proceedings within the CG-IBS, as well as the collection and distribution of the tax on goods and services and the transition to the new tax system. On October 20, 2024, the bill was approved by the Lower House and remitted to the Senate for consideration. The objective of the Federal Government is to obtain Senate approval in 2025, so that the test period can begin in 2026. Changes in economic or other policies by the government of the president Luiz Inácio Lula da Silva could negatively affect our industry in general, or our Brazilian subsidiaries’ results of operations, in particular.
With respect to Peru, for the year ended December 31, 2024, revenues derived from our consolidated subsidiaries in this country represented 2% of our total revenues. Peru’s most recent general presidential elections took place in April 2021. Following a run-off between the two top contenders on June 6, 2021, Pedro Castillo was elected as Peru’s president. On December 7, 2022, Mr. Castillo announced his intention to dissolve the Peruvian Congress and to intervene, among others, the Peruvian judicial branch and Superior Court. Mr. Castillo’s actions were deemed to constitute an attempted coup, which led to his destitution and arrest. Mr. Castillo was succeeded by his then vice-president, Dina Boluarte. Following Mr. Castillo’s destitution, a wave of protests in support of Mr. Castillo erupted across the country, which led President Boluarte to declare a state of emergency across several regions in Peru on December 12, 2022 and call for congressional approval of a bill to permit early elections in 2024. After several legislative attempts to approve early elections, on June 15, 2023, President Boluarte declared that elections would not be held early, and that she would hold office until July 28, 2026. In March 2024, Congress approved a constitutional reform reinstating the bicameral system in the Legislative Branch. Starting with the 2026 general elections, Peru will have a House of Representatives with 130 members and a Senate with 60 members. This reform also limited the president’s power to dissolve Congress, restricting it to the House of Representatives only. In June 2024, the Congressional Constitution Committee approved a reform proposal to eliminate the National Board of Justice, transferring the power to appoint and remove judges, prosecutors, and electoral authorities to the Senate. However, the reform has yet to be fully approved, and it has been widely criticized by human rights organizations, which view it as a threat to judicial independence. These events have further increased the environment of political uncertainty in Peru, and gave way to further discussions about a possible reform of the Peruvian Constitution, which is based on free market, contractual liberty, and minimal governmental intervention in the economy. These events have further increased the environment of political uncertainty in Peru, and gave way to further discussions about a possible reform of the Peruvian Constitution, which is based on free market, contractual liberty, and minimal governmental intervention in the economy. There is uncertainty as to whether President Boluarte will obtain the required qualified majorities in order to modify the Peruvian Constitution. We cannot assure that policies against free market and minimal intervention of the government in the Peruvian economy will not be taken by the new administration or any new congress. Any changes in the Peruvian economy or the Peruvian government’s economic policies may have a negative effect on our business, financial condition, and results of operations. Changes in economic or other policies by the Peruvian government or other political developments in Peru could adversely affect the business, financial condition, and results of operations of our subsidiaries.
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With respect to Chile, for the year ended December 31, 2024, revenues derived from our consolidated subsidiaries in this country represented 2% of our total revenues. In 2019, following social unrest and protests, the Chilean government called for a constitutional assembly to reform the Chilean constitution. In May 2021, the Chilean government established a constitutional assembly to write a new constitution, which was rejected by 61.86% of the votes cast on a referendum that took place on September 4, 2022. On January 17, 2023, Law No. 21,533 was published in the Official Gazette of Chile, setting forth the procedure for the drafting and approval of the new Constitution. Law No. 21,533 contains 12 fundamental principles and criteria for the drafting of the potential new Constitution. It also provides for an experts’ commission (the “Experts’ Commission”) of 24 members that were appointed by the Chilean Congress, in proportion to the current political forces and parties represented in Congress, which was in charge of preparing a pre-draft of a constitutional text. This pre-draft in under discussion of the constitutional council ( Consejo Constitucional ) elected on May 7, 2023 (the “Constitutional Council”). On October 30, 2023, the Constitutional Council approved the draft of the new constitution and delivered it to President Gabriel Boric on November 7, 2023. On December 17, 2023, a new referendum on the approval or rejection of the draft constitution proposed by the Constitutional Council took place, with 55.76% of voters rejecting the new constitution and 44.24% approving it. Given that the proposed draft was rejected, the current constitution remains in effect. Additionally, the Chilean government announced that the process for the promulgation of a new constitution was closed and no initiatives on this matter would be proposed during the current presidential term, which ends on March 11, 2026. The election for regional governors took place on October 26 and 27, 2024. With the exception of Tarapacá, Ñuble, Los Ríos, Aysén and Magallanes, where the candidates were elected on their respective first round, a second-round election was held on November 24, 2024 between the two candidates with the highest number of votes. The results of the regional governor elections held on October 26 and 27, and November 24, 2024, show a political landscape shift in Chile. The ruling center-left political alliance, “ Por Chile y sus Regiones ,” secured victory in seven governorships, reaffirming its position as the dominant political party. Moreover, the center-right coalition “ Chile Vamos ,” which won six governorships, showed a notable strengthening of its regional influence, too. Additionally, independent candidates secured two governorships, while the “ Tu Región Radical ” movement claimed one, bringing the total to sixteen regional administrations. We cannot predict what policies will be adopted by Mr. Boric’s government and whether those policies would have a negative impact on the Chilean economy or our industry sector in Chile or our Chilean subsidiaries’ business and financial performance.
We cannot provide any assurances that political or social developments in Colombia, Peru, Brazil, or Chile over which we have no control, will not have an adverse effect on our respective economic situations and will not adversely affect the business, financial condition and results of operations of our consolidated subsidiaries and their ability to pay dividends or make other distributions to us. This could have a material adverse effect on our business, results of operations, financial condition.
With respect to United States of America, for the year ended December 31, 2024, revenues derived from our consolidated subsidiaries in this country represented 20% of our total revenues. On April 2, 2025, U.S. President Donald J. Trump announced new tariffs on imports into the United States of America. These tariffs include a “baseline” tariff of 10% on imports from many countries, including Colombia. The imposition of these tariffs may have significant adverse effects on global trade, which could have a material adverse effect on Colombia’s economy, trade balance, and key industries. A significant portion of Colombia’s exports are directed to the United States of America, making it vulnerable to changes in U.S. trade policy. Higher tariffs could reduce demand for Colombia’s goods in the United States of America, disrupt supply chains, and lead to job losses in affected industries. Additionally, retaliatory measures by other nations could exacerbate economic uncertainty, impacting investor confidence and foreign direct investment, and countries facing even higher tariff rates could decide to sell excess products into the Colombian market, adversely affecting Colombian producers. The tariffs may also contribute to global trade tensions and volatility in currency markets, which could put pressure on exchange rates and inflation. If Colombia is unable to negotiate exemptions or mitigate the effects through alternative trade agreements, these factors could have a material adverse impact on Colombia’s economic growth and fiscal stability. These developments could have a material adverse effect on our business, financial condition, or results of operations in Colombia.
Our business operations and financial condition could be negatively affected by pandemic or epidemic diseases and other health events.
Pandemic diseases and other health events, have the potential to negatively impact economic activities in many countries, including those in which we operate or have trade links, with consequent adverse effects on our customers and business by causing changes in the demand for energy, the movement of people and availability of services and our ability to address such future conditions, could again disrupt our business and operations.
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As the potential impact of a new pandemic or other diseases is difficult to predict, the extent of the impact on our business and financial results will ultimately depend largely on future developments, including the duration, characteristics of the new outbreak (e.g., new diseases, new variants of the virus, capacity for infection and transmission, treatment developments and vaccination coverage), the impact on capital and financial markets and the related impact on consumer confidence and spending, and the actions taken by authorities to contain it, all of which are highly uncertain and cannot be accurately predicted.
The Colombian Government could seize or expropriate our assets under certain circumstances for fair compensation.
Pursuant to Articles 58 and 59 of the Colombian constitution, the Government can exercise its eminent domain powers in respect of private property assets in the event such action is deemed by the Government to be required in order to protect public interests. According to Law 388 of 1997, eminent domain powers may be exercised through: (i) an ordinary expropriation proceeding, or (ii) an administrative expropriation. In all cases we would be entitled to a fair compensation for the expropriated assets. Also, as a general rule, compensation must be paid before the asset is effectively expropriated. However, the compensation may be lower than the price for which the expropriated asset could be sold in a free-market sale or the value of the asset as part of an ongoing business. The aforementioned Article 59 of the Colombian constitution establishes a temporary expropriation for war reasons, which does not require that compensation be paid before expropriation.
Colombia has experienced internal security issues that have had or could have a negative effect on the Colombian economy and on us.
Colombia has experienced internal security issues, primarily due to the activities of guerrillas, paramilitary groups, drug cartels and organized armed groups known as GAOs. From time to time, guerrillas target crude oil and multi-purpose pipelines, including the Transandino Pipeline, Caño Limón - Coveñas and Oleoducto Bicentenario pipelines, and other related infrastructure disrupting our activities and those of our business partners.
During 2024, the attacks against our pipeline infrastructure increased by 5.3% in relation to 2023 (41 attacks in 2024 compared to 39 attacks in 2023). Nonetheless, the attacks especially affected infrastructure located in the Norte de Santander, Santander, Arauca, and Nariño departments, and the Caño Limón – Coveñas and Trasandino pipelines. As a result, there was a deferred production of 114,505 barrels directly related to these attacks in 2024, as compared to 56,378 barrels in 2023. As of March 14th, 2025, nine attacks against our pipeline infrastructure have been identified.
Terrorist attacks have resulted in unscheduled shutdowns of our transportation systems to repair or replace sections of pipelines that have been damaged, with deferral of production in certain fields, as well as caused us to undertake environmental remediation. In respect of the pipeline infrastructure, the direct cost of repairs due to terrorist attacks in 2024 was approximately COP 325,189.26 million (USD 73.75 million using a COP 4,409.15/1.00 US exchange rate as of December 31, 2024).
During 2024, we also experienced 2 attacks to our production infrastructure in Santander, specifically on Meta and Santander on: flow line of the Castilla-2 well and 12” Line of the OLC – GRB Pipeline respectively. As a result, there was a deferred production of 1,021.33 barrels directly related to these attacks in 2024, as compared to 582 barrels in 2023. In respect of the production infrastructure, the direct cost of repairs due to guerrilla attacks in 2024 was approximately COP 193.706.399,0 (USD 43.9 million using a COP 4,409.15/1.00 USD exchange rate as of December 31, 2024).
Likewise, the theft of refined products and crude oil, as a result of security issues, may impact our operating and financial results in the future, as well as our reputation, due to the potential use of these products within the alkaloid chain production and the possible impact to communities and the environment, derived from this illegal practice. As a result, and as part of the strategy against the theft of crude oil, as of November 2023, Ecopetrol Group (EG) deployed an operational adjustment to transport south crude production through Ecuador pipelines while keeping Trasandino System in contingency mode. Associated with the above, the theft of crude oil has decreased from approximately 3,552 bpd in 2023 to 1,483 bpd in 2024. Crude oil theft is directly related to illicit activities, such as those relating to illegal crops, mining and smuggling, as well as the presence of guerilla dissidents and other illegal groups in the areas of influence of the main crude transportation systems, such as Caño Limón – Coveñas System (Catatumbo and Norte de Santander) and the Trasandino System (Tumaco and Nariño). Furthermore, the theft of refined products is mainly related to the presence of common crime that illegally markets these products, presenting losses of approximately 179 bpd and 58.42 bpd in the years ended December 31, 2024 and 2023, respectively.
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In recent years, social protests have resulted in blockades of the country’s main roads and isolated incidents against certain of our infrastructure, which in turn has momentarily adversely affected the operations of our upstream, midstream, and downstream and sales and marketing segments, leading to decreases in our crude oil and refined products production and transported volumes.
These activities and their possible escalation and the effects associated with them have had, and may have in the future, a negative impact on the Colombian economy or on us, which may affect our customers, employees, assets, or the environment, with resulting containment, clean-up and repair expenses.
Despite the current government’s announcement of a bilateral ceasefire with some armed groups, non-conformism may arise in the process of these dialogues spoken out through illegal and terrorist activities.
The dynamics of security in Colombia in 2024 were characterized by processes and public order situations led primarily by the ELN and the FARC dissidents or Estado Mayor Central (EMC). The six-month extension of the bilateral ceasefire between the Colombian Government and the ELN in February 2024 was initially met with optimism, particularly in conflict-stricken areas such as Arauca, Chocó, Cauca and Norte de Santander. This agreement offered temporary relief to affected communities, facilitated humanitarian access in critical zones, and reinforced the government’s commitment to negotiated solutions. However, challenges in verification and mutual distrust jeopardized its implementation, underlining the need for improved monitoring mechanisms. The ceasefire, initiated on August 3, 2023, ultimately lapsed on August 3, 2024, without renewal, sparking uncertainty and rising tensions in regions like Arauca and Norte de Santander. The cessation of the agreement led to a resurgence of violence, including a wave of terrorist attacks targeting oil infrastructure and security forces, exacerbating instability. A significant blow to the process occurred when the ELN’s Domingo Laín Sáenz Front carried out an attack, killing two soldiers on September 17, which prompted the government to suspend negotiations, reflecting its zero-tolerance stance toward violence during peace talks. The event further eroded trust, reignited violence in vulnerable regions, and diminished prospects for regional stability.
In 2024, the peace process with the Estado Mayor Central (EMC) of the FARC dissidents faced considerable challenges, such as intensified violence in areas like Catatumbo. This group is not currently engaged in dialogue with the government. Driven by clashes between the EMC and ELN, which have caused numerous casualties and mass displacement, undermining public confidence in the peace talks process. Despite these setbacks, the EMC peace process aimed to promote territorial transformation by strengthening state presence, advancing economic development, and addressing social disparities in Catatumbo Norte de Santander. Plans included reintegrating ex-combatants, providing essential services such as health and education, and supporting sustainable economic projects to replace illicit economies. The success of these initiatives depends on political will, the fulfillment of agreements, and governmental capacity to ensure security and economic alternatives.
At the beginning of 2025, security conditions deteriorated significantly due to numerous clashes between the ELN and dissident factions of the FARC in the Catatumbo region. These confrontations, driven by ideological differences and territorial disputes, created a severe crisis affecting both security and humanitarian conditions, with the municipality of Tibú, in Norte de Santander, being one of the most impacted areas.
The persistent confrontations between armed groups and the government have further intensified instability in the country, directly affecting Ecopetrol’s operations in regions such as Arauca and Norte de Santander. These areas have witnessed most terrorist acts carried out by these groups, posing serious risks to both the safety of the employees, contractor´s employees and the Company’s infrastructure. As a result, Ecopetrol’s operations are frequently disrupted by the volatile security environment.
Government decisions and security dynamics in those regions are the key factors that impact stability in the areas where Ecopetrol operates. For this reason, the Company must maintain constant communication with security state organizations, such as the Colombian army, and the National Police Force; however, despite these efforts, we cannot ensure the safe development of our operations.
Regional and global events may have an impact on Colombia’s social, economic and political situation as well as on us and our operations.
Regional and global events, such as humanitarian crises, conflicts and natural disasters, may have an impact on Colombia’s social, economic and political situation as well as on us and our operations. In addition, borders with some of Colombia’s neighboring countries have been, may remain or be in the future shut down or restricted, affecting the economy and migration patterns in towns and cities close to such borders and commerce with those countries . We cannot make any assurances that such events will not negatively impact Colombia’s social, economic and political situation, nor on our company and its operations .
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We are subject to the prevailing economic conditions and investment climate in Colombia, which may be less stable than those in developed countries.
Market prices of securities issued by Colombian companies, including us, are subject to the prevailing economic conditions in Colombia. A large portion of our assets and operations are located in Colombia and most of our sales are currently derived from our local crude oil and natural gas production and the production of our refineries located in Colombia. Accordingly, our financial condition and results of operations depend on a significant extent on macroeconomic and political and regulatory conditions prevailing from time to time in Colombia and on the exchange rates between the Colombian Peso and the U.S. dollar.
If the perception of improved overall security in Colombia deteriorates or if the investment climate worsens, the Colombian economy may face lower growth rates than the ones posted recently, which could negatively affect our financial condition and results of operations.
Furthermore, the market price of our shares and American Depositary Shares, or ADSs, may be adversely affected by changes in governmental policies, particularly those affecting economic growth, exchange rates, interest rates, inflation, and taxes. Furthermore, the proposed bill for pension reform may affect the assets under management of private funds, which could affect the market of our shares. The Government has changed monetary, fiscal, taxation, labor and other policies over time and has thus influenced the performance of the Colombian economy. We have no control over the extent and timing of changes in these variables or government intervention and policies.
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5.2.3 |
Legal and Regulatory Risks |
This section discusses potential legal and regulatory risks to us, including the risk of having to comply with new laws and regulations.
Our operations are subject to extensive regulation, which is subject to change from time to time by the applicable regulatory authorities.
The Colombian hydrocarbons industry is subject to extensive regulation and supervision by the Government and regulatory agencies in matters including the award of exploration and production blocks by the ANH, the imposition of specific drilling and exploration obligations, restrictions on production, price controls, capital expenditures, liquidation of the Net Position of each refiner or importer with respect to the FEPC and required divestments. Existing regulation applies to virtually all aspects of our operations in Colombia and abroad. The commercialization activities of some of our products also face extensive regulation. Such regulation is subject to change by the applicable regulator affecting our ability to commercialize our products. See section Business Overview—Applicable Laws and Regulations. In particular, under Decree 1068 of 2015, as amended by Decree 1451 of 2018, the Ministry of Mines and Energy is required to calculate and liquidate each refiner and/or importer of fuel’s participation differential (i.e., this arises when the International Parity Price is lower than the reference price established by the Ministry of Mines and Energy, leading to a “Net Position” every three months to be paid by the FEPC). Accordingly, Ecopetrol S.A. and Cartagena Refinery rely on the FEPC settling their respective Net Position each year in connection with amounts due to them from FEPC. As of December 31, 2024, Ecopetrol S.A. recorded COP 5.96 trillion in accounts receivable due from FEPC and Cartagena Refinery recorded COP 1.66 trillion in accounts receivable due from FEPC. We cannot offer any assurance as to when or if Ecopetrol S.A.’s or Cartagena Refinery’s Net Position will be settled by FEPC and such amounts will be paid. If their respective Net Position is not settled, the Ecopetrol Group’s consolidated financial statements and results of operations could be adversely impacted. See section Business Overview—Applicable Laws and Regulations—Regulation of Refining and Petrochemical Activities—Regulation Concerning Production and Prices—Fuel Price Stabilization Fund (FEPC).
The terms and conditions of the agreements with the ANH under which we explore and produce crude oil and natural gas generally reflect negotiations with the ANH and other governmental authorities and may vary by fields, basins and hydrocarbons discovered. We are required, as are all oil companies undertaking exploratory and production activities in Colombia, to pay a percentage of our production to the Government as royalties. The Colombian Congress has modified the royalty program for crude oil and natural gas production several times in the last 20 years, as it has modified the regime regulating new contracts entered into with the Government. In the future, the Colombian Congress may once again amend royalty payment levels and such changes could have an adverse effect on our future exploration and production in Colombia. See section Business Overview—Applicable Laws and Regulations—Regulation of Exploration and Production Activities—Business Regulation—Royalties for a description of the current royalty scheme.
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Our operations in Colombia are subject to extensive national, state, and local environmental regulations. Environmental rules and regulations are applicable to our exploration, production, refining, transportation, supply, and marketing activities, as well as the biofuels we produce. These regulations establish, among other things, quality standards for hydrocarbon products, air emissions and greenhouse gases, water discharges and waste disposal, soil remediation, water pollution and the general storage, handling, transportation, and treatment of hydrocarbons in Colombia. Currently, all exploratory drilling projects in areas that do not yet have a license must undergo an environmental impact assessment and must receive an environmental license from the governmental agency responsible for awarding environmental licenses, the ANLA. Environmental authorities with jurisdiction over our activities routinely inspect our crude oil fields, refineries, and other production sites, and they may decide to open investigations or sanction proceedings, which may result in the imposition of fines, restrictions on operations or other sanctions in connection with potential non-compliance with environmental laws.
We are also subject to control and monitoring by the regional autonomous corporations (CAR for its acronym in Spanish), which are regional environmental authorities that grant permits for the use and exploitation of natural resources in areas or fields that have an Environmental Management Plan (PMA for its acronym in Spanish), in the same way they establish compensation measures for the use of these resources and perform monitoring, control, and impose sanctions as result of investigations.
If we fail to comply with any of these national or regional environmental regulations, we could be subject to administrative and criminal penalties, including warnings, fines, or closure orders of our facilities. Any such criminal penalty would be imposed on the legal representatives of the Company, including any legal representative, director or worker who participated or failed to take action related to the activities that lead to environmental damage. See section Business Overview—Applicable Laws and Regulations—Regulation of Exploration and Production Activities—Business Regulation—Environmental Licensing and Consultations .
Some of the companies in the business group perform exploratory activities outside of Colombian territory. As such, those companies are subject to foreign environmental regulations for the exploratory activities conducted by the business group outside of Colombia. Failure to comply with foreign environmental regulations may result in investigations by foreign regulators, which could lead to fines, warnings or temporary suspensions of our operations, which could have a negative impact in the consolidated financial statements and results of operations of the Ecopetrol Group.
In addition, the companies of the Ecopetrol Group conducting upstream activities outside Colombia may be subject to foreign health, safety, and environmental regulations. Foreign health and safety regulations may be more severe than those established under Colombian law and, therefore, we may be required to make additional investments to comply with those regulations.
Furthermore, our electric power transmission and toll roads concessions segment, carried on by ISA and its subsidiaries are heavily regulated in Colombia, Brazil, Peru and Chile by government ministries and authorities, as well as various other national, state, and local regulatory agencies. Regulatory actions taken by those agencies and, in particular, tariff reviews and revised compensation terms of transmission investments, could materially adversely affect the profitability of these businesses. In addition, increased regulatory requirements relating to the integrity of our facilities or the quality of the services provided by ISA and its subsidiaries may require additional spending in order to maintain compliance with these requirements.
We are subject to a broad range of environmental laws, which require us to incur ongoing costs and capital expenditures and expose us to substantial liabilities in the event of non-compliance. These laws and regulations require us to, among other things, minimize natural and socio-environmental risks, while maintaining the quality, safety, and efficiency of our facilities. These laws and regulations also require us to obtain and maintain environmental permits, licenses, and approvals for the operation of our business, which can lead to cost overruns or to changes in our investment plans. Some of these permits, licenses and approvals are subject to periodic renewal. Government environmental agencies could take enforcement actions against us for any failure to comply with applicable laws and regulations. Such enforcement actions could include, among other things, the imposition of fines, revocation of licenses, suspension of operations or imposition of criminal liability for non-compliance.
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Environmental laws and regulations can also impose strict liability for the environmental remediation of spills and discharges of hazardous materials and waste and require us to indemnify or reimburse third parties for environmental damages. We cannot assure that we will obtain approval for any future projects, or that existing approvals, authorizations, licenses, and permits will not be questioned, revoked or otherwise suspended due to any alleged non-compliance or legal action. Environmental regulation has become more stringent in the countries where we operate in recent years. As a result, our operating costs have increased to comply with these new technical environmental requirements as well as the need to strengthen our specialized team in charge of environmental compliance in project and operations. If environmental laws continue to impose additional costs on us, we may need to reduce our investments on strategic projects to allocate funds to environmental compliance, delaying projects or having an adverse effect on our results of operations and financial condition. Moreover, more stringent environmental protection programs in the countries or industries where we operate could impose constraints and additional costs on our operations and require us to make significant capital expenditures in the future. We cannot assure that future legislative, regulatory, international law, industry, trade, or other developments will not have a material adverse effect on our business, properties, results of operations, financial condition or prospects.
Finally, under certain of our credit agreements, we are under an obligation to comply with international environmental standards established by our lenders or by multilateral institutions. Failure to comply with such environmental standards could result in an event of default under the relevant credit agreements that we, or our subsidiaries, have entered into, which would affect our financial condition.
More stringent environmental regulation may lead to increased expenses or reduced demand for our products, as well as affect timely permits.
In terms of climate change, the Colombian Government enacted the Climate Action Law (Law 2169) in 2021 which advances Colombia’s focus on strengthening its strategy and actions against climate change, when considering the initiatives being taken at a global level. The Carbon Neutrality Colombian Strategy launched in April 2021 by the Ministry of Environment and Sustainable Development reaffirmed its commitment to these initiatives and accelerated Colombia’s goal to reduce GHG emissions to reach carbon neutrality by 2050. In 2023, the Ministry of Energy and Mines issued guidelines for the formulation of the Comprehensive Corporate Climate Change Plan, which seeks to advance the identification, definition, implementation and monitoring of initiatives or measures for climate change management associated with (i) the reduction of greenhouse gas (GHG) emissions, (ii) the reduction and management of climate risks, and (iii) internal governance actions. This regulatory framework may establish new requirements at the operational level that seek to accelerate the reduction of GHG emissions such as methane, reduction of fugitive emissions and venting, reduction of flaring, and the implementation of specific actions in adaptation to climate change, which may be reflected in the increase of operating and production costs. In order to anticipate these changes, we participate in different spaces of discussion and regulatory construction to prepare and respond to these requirements and not be affected by the fulfillment of our climate objectives. However, we cannot make any assurances that we will be able to achieve our goals or those set out in government climate change and sustainability initiatives (e.g., proposed Colombian Climate Action Law, carbon tax, carbon offsets, among others) or meet other stakeholders’ expectations with respect to such requirements, or that we will be able to apply reliable and cost-effective green alternatives. If we are unable to reach our carbon neutrality goals or governments’ or other stakeholders’ expectations with respect to such goals, our energy diversification portfolio and strategic priorities would be adversely impacted and could lead to increased expenses related to low-carbon initiatives and reduced demand for our core products.
We may not be able to keep pace with changing environmental requirements related to impacts to Colombia’s biodiversity and nature.
As we operate in a country that is recognized as a megadiverse territory where complexity, fragility, and biological diversity are interwoven with a rich history and a dynamic and complex social, economic, and political landscape, and where the government looks to businesses to participate in the country’s sustainability development goals implementation, we may not be able to adequately adapt and align our technology capabilities and strategy (e.g., Nature Based Solutions, Big Data Analytics, Remote Sensing, Robotics and Drones, Artificial Intelligence) to effectively enable, assess, and report on the reduction of its impact to Colombia’s biodiversity and nature (e.g., contamination, habitat loss, deforestation, and GHG emissions), considering the increase in Colombian sustainable development commitments leading to increased regulatory scrutiny and impacting our strategic efforts and operations for minimizing its impacts to relevant ecosystems.
In 2024, Ecopetrol introduced the Taskforce on Nature-related Financial Disclosures (TNFD) recommendations framework, in which it actively participates as member. This engagement has allowed us to better identify environmental impacts and dependencies related to nature while effectively managing the associated risks and opportunities.
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Our operations might be affected by rising climate change and energy transition regulatory developments.
The increase in global temperature due to the substantial increase of GHG is a concern worldwide. The Paris Agreement calls for immediate and forceful actions to be taken to limit the increase of global temperature below 1.5°C. In response, government agendas have increasingly been defining normative and regulatory frameworks that determine local actions related to climate change.
As a result, companies are increasingly subject to regulatory risks and public policy changes related to climate change. In Colombia, the climate change regulatory framework has developed substantially, defining goals, measures, and means of implementation that bind companies. In 2021, the Climate Action Law (Law 2169 amended by Law 2294 of 2023) was issued, which promotes the low-carbon development of the country through establishing goals and measures related to carbon neutrality and climate resilience. This law is aligned with the country’s NDCs (51% GHG reduction by 2030) and its Long-Term Climate Strategy (E2050). The above is binding for Ecopetrol, among other aspects in: (i) mandatory reporting of GHG, (ii) National Registry of GHG Emissions Reduction and Removal, and (iii) low carbon development, carbon neutrality, and climate resilience implementation and monitoring plan. This regulation will be under continuous review by Ecopetrol to mitigate the potential financial effects and the impact on the company’s climate goals. To this end, the company has developed a decarbonization roadmap to achieve medium and long-term goals. However, developments and new regulations could affect the fulfillment of company’s climate goals, increasing costs and negatively impacting financial and operational results.
Moreover, in 2022, the Energy Transition Policy (CONPES 4075), which promotes strategies for sustainable economic development, was issued. The Government also issued a regulation associated with fugitive emissions and venting and routine flaring (Resolution 40066 of 2022). To this end, the Company has been making progress in improving activities to detect and measure these emissions in the different operating areas, through top-down and bottom-up technologies, and in closing these leaks. However, the implementation and enforcement of these regulations could generate additional costs for the company. These regulations will be under continuous review by Ecopetrol; however, we cannot assure that the Company is able to mitigate the potential financial effects and the impact on the Company’s climate goals.
New or higher taxes resulting from changes in tax regulations or the interpretation thereof in Colombia could adversely affect our results of operations and financial condition.
New tax laws and regulations, and uncertainties in the interpretation with respect to existing and future tax policies pose risks to us. In recent years, the Colombian Congress and tax authorities have enacted modifications to taxes related to financial transactions, income, value added tax (VAT), and taxes on net worth. In December 2019, Congress passed Law 2010 called “ Ley de Crecimiento Económico ” or “Economic Growth Law”, which largely maintains the changes of the previous tax reform (Law 1943 of 2018) along with some changes to tax legislation. On September 14, 2021, the Colombian Congress enacted a tax reform called “ Ley de Inversión Social ” or “Social Investment Law”, which became effective as of January 1, 2022. This law increased the tax rate from 30% to 35%, which generated in Ecopetrol a deferred tax income of COP 306,312 million, recognized in the financial statements for the fiscal year ended 2021.
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On December 13, 2022, the Colombian Congress enacted a tax reform (Law 2272 of 2022) effective from January 1, 2023. The tax reform includes, among others: (i) a new permanent equity tax applicable to Colombian individuals and non-residents, at rates ranging from 0.5% to 1.5% based on the level of net equity at January 1st every year, (ii) an increase in the dividend tax rate for local and foreign shareholders (0% to 39% progressive marginal rates for Colombian individuals, and 20% flat withholding for non-resident shareholders), (iii) an increase in the long-term capital gains tax rate (increasing from 10% to 15%); (iv) the elimination of specific tax benefits and exemptions, (v) a minimum corporate income tax based on effective tax rate (effective rate calculated on book profit should be at least 15%, considering certain adjustments to accounting profits and certain exempted companies), (vi) the application of taxes based on significant economic presence (primarily for non-resident persons and entities that provide digital services, but including other services and commercial activities) that took effect on January 1, 2024, (vii) the elimination of the ability to claim 50% of the Industry and Commerce Tax as an income tax credit, (viii) an income tax surcharge for companies engaged in the extraction of crude oil and coal of 0%, 5%, 10% or 15% and, based on international prices. For fiscal year 2023, the surtax of 5%, 10% or 15% applied when the Brent price reaches USD 66.36, USD 74.20 and USD 80.73, respectively, according to ANH Resolution No. 0061 of January 31, 2024 (revenues from the sale of natural gas are not subject to this surtax). For fiscal year 2023, the surtax applied was 10%, (ix) the introduction of a minimum tax based on effective tax rate determined on accounting profits, (x) non-deductibility of royalties. However, the Colombian Constitutional Court ruled that the limitation rule is unconstitutional, thus, not applicable. In a final effort to mitigate the effect of this ruling on the public finances, the Ministry of Mines and Energy and the Ministry of Finance and Public Credit requested the review of the ruling to the Constitutional Court in December of 2023, alleging a fiscal impact and nullity, respectively. In March 2024, the Constitutional Court rejected the request for nullity filed by the Ministry of Mines and Energy. The Constitutional Court rejected the fiscal impact claim filed by the Minister of Finance and Public Credit, stating that the arguments presented did not meet the constitutional threshold.
On February 14, 2025, the Colombian Government issued Decree 175 of 2025, which temporarily reinstated the stamp tax at a rate of 1% on public and private documents exceeding certain amounts, except for specific exemptions provided by law.
For a description of taxes affecting our results of operations and financial condition in 2024, see section Financial Review—Effect of Taxes, Exchange Rate Variation, Inflation and the Price of Oil on Our Results—Taxes . Changes in tax-related laws and regulations, and interpretations thereof, can affect tax burdens by increasing tax rates and fees, creating new taxes, limiting tax deductions, and eliminating tax-based incentives and untaxed income. In addition, tax authorities and tax courts may interpret tax regulations differently than we do, which could result in tax litigation and associated costs and penalties.
In relation to income tax applicable to our shareholders, until 2016, for Colombian income tax purposes, dividends that were distributed from profits taxed at the corporate level were not taxed or subject to withholding tax at the shareholder level. However, beginning in 2017, the regulation changed so that dividends paid to non-resident shareholders are subject to a withholding tax. For further detail and a description of such changes, see section Financial Review—Effect of Taxes, Exchange Rate Variation, Inflation and the Price of Oil on our Results – Taxes . Further changes to Colombian tax laws may subject us and our shareholders to higher taxes and could adversely affect our results of operations and financial condition.
We may incur losses and spend time and money defending pending lawsuits and arbitrations and responding to administrative investigations.
We are currently a party to several legal proceedings filed against us. We are also subject to labor-related lawsuits filed by current and former employees in connection with pension plans and retirement benefits. As of December 31, 2024, Ecopetrol S.A. was a party to 7,730 legal proceedings relating to civil, criminal, administrative, environmental, tax, constitutional, arbitration and labor claims, of which 5,435 were filed against us in the Colombian courts and arbitration tribunals and of which 388 had an accrual provision. We allocate substantial amounts of money and time to defend against these claims, in which the claimants often seek substantial sums of money as well as other remedies. See Note 22 to our consolidated financial statements and see section Risk Review—Legal Proceedings and Related Matters . In addition, in accordance with Colombian law, we and our employees are subject to surveillance and investigations by certain administrative control entities in Colombia, which are intended to determine whether public funds have been misused, mismanaged, or misappropriated or whether they have been used in compliance with applicable law. Such investigations may divert the attention of management and subject the Company to reputational risk and increase difficulties in retaining talent. See section Risk Review—Legal Proceedings and Related Matters .
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5.2.4 |
Risks Related to Our ADSs |
This section discusses potential risks associated with an investment in our American Depository Shares (as opposed to our common shares) by investors outside Colombia.
Holders of our ADSs may encounter difficulties in protecting their interests.
Holders of our ADSs do not have the same voting rights as holders of our common shares. As set forth in the amended and restated deposit agreement, dated January 12, 2018 (as amended on December 30, 2021), among Ecopetrol S.A., JP Morgan Chase Bank, N.A., as depositary (the Depositary), and all holders from time to time of our American Depositary Receipts (as amended and restated, the “Deposit Agreement”), holders of our ADSs may instruct the Depositary, to vote on shareholder matters prior to a shareholders’ meeting.
Colombian law is not clear about the need to request proxies from existing shareholders. Thus, holders of our ADSs may not become aware of some matters in time to instruct the Depositary to vote their shares.
The Deposit Agreement provides holders of our ADSs with the right to instruct the Depositary to vote common shares separately. Pursuant to certain regulations and opinions issued by Financial Superintendence of Colombia, it is currently understood that the depositary may vote common shares of a Colombian corporation in an American Depositary Receipt, or ADR, program separately. Notwithstanding this, if new opinions or regulations are issued which prevent either the custodian or the Depositary to vote the common shares (including the right to receive common shares in the form of ADRs) deposited under the Deposit Agreement and any other securities, cash or property from time to time held by the Depositary in respect or in lieu of deposited common shares (the “Deposited Securities”) separately, all such Deposited Securities shall be voted based on the majority vote of the voting instructions timely received from holders of ADRs. In the case of such single block voting, all holders of ADRs, including holders of ADRs for which no voting instructions are timely received and holders of ADRs with voting instructions contrary to the voting instructions of a majority of the Deposited Securities timely received, should be aware that the Deposited Securities shall all be voted as a single block and that the voting instructions of such holders of ADRs will be deemed given in the manner stated above.
The Depositary will not itself exercise any voting discretion in respect of any Deposited Securities. The holders of our ADRs will be solely responsible for any exercise of the voting rights of the Deposited Securities represented by the ADRs if such vote is made pursuant to the procedures described in the Deposit Agreement. Holders of ADRs are strongly encouraged to forward their voting instructions as soon as possible as voting instructions will not be deemed received until such time as the ADR department responsible for proxies and voting has received such instructions, notwithstanding that such instructions may have been physically received by the Depositary, prior to such time.
In the future, the Colombian regulatory authorities may clarify their interpretation as to how the voting rights should be exercised by holders of our ADSs, and such possible interpretation could adversely affect the value of the common shares and ADSs.
Our ADS holders may be subject to regulations on foreign investment in Colombia.
Colombia’s International Investment Statute (the set of rules and regulations which govern the international investment and the foreign exchange regime, which include Decree 1068 of 2015, Resolution 1 of 2018 and External Circular DCIP83 issued by the Colombian Central Bank among others), regulates the manner in which non-Colombian residents can invest in Colombia and participate in the Colombian securities market. Among other requirements, Colombian law requires foreign investors to register certain foreign exchange transactions with the Colombian Central Bank and outlines the necessary procedures to authorize certain types of foreign investments. Colombian law requires that certain foreign exchange transactions, including international investment in foreign currency between Colombian residents and non-Colombian residents, must be made through the foreign exchange market, either through authorized intermediaries for the foreign exchange market or compensation accounts, which are regular bank accounts held abroad by Colombian residents and registered with the Colombian Central Bank. Any income or expenses under our ADR program must be made through the foreign exchange market.
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Investors acquiring our ADRs are not required to register with the Colombian Central Bank directly, as they will benefit from the registration to be obtained by the custodian for our common shares underlying the ADRs in Colombia. If foreign investors in ADRs choose to surrender their ADRs and withdraw common shares, they must register their investment with the Colombian Central Bank in the common shares as a portfolio investment through their local representative, which may be a brokerage firm, trust company or investment management companies supervised by the Financial Superintendence of Colombia. Foreign investors will only be allowed to transfer dividends abroad after their foreign investment registration procedure with the Colombian Central Bank has been completed. Investors withdrawing common shares could incur expenses and/or suffer delays in the application process. The failure of an investor to report or register foreign exchange transactions with the Colombian Central Bank on a timely basis may prevent the investor from remitting dividends abroad or result in the initiation of an investigation and in the imposition of fines.
Colombian residents who acquire ADRs and either receive profits from this investment, surrender their ADRs or liquidate their investment in ADRs, must register their investment by means of the procedures set forth in section 7.4.1. and 7.4.2. of the External Regulation of the Circular DCIP-83 of the Colombian Central Bank.
The Colombian Government, the Colombian Congress, or the Colombian Central Bank may amend Colombia’s International Investment Statute or the foreign exchange regime, which could result in more restrictive rules and could negatively affect trading of our ADSs or any transfer of currencies from Colombia to other countries or vice versa.
Colombia currently has a free convertibility system. If a more restrictive convertibility system is implemented, the Depositary may experience difficulties when converting Colombian Peso amounts into U.S. dollars to remit dividend payments. Also, currently Colombia has a floating exchange rate system that might be subject to change in the future. See section Shareholder Information—Exchange Controls and Limitations .
Holders of our ADSs may not be able to effect service of process on us, our directors, or executive officers within the United States, which may limit your recovery in any foreign judgment you obtain against us.
We are a mixed economy company organized under the laws of Colombia. In addition, most of the members of our Board of Directors (Directors) and executive officers reside outside the United States. All or a substantial portion of our assets and the assets of these persons are located outside of the United States. As a result, it may not be possible for ADSs holders to effect service of process within the United States upon us or these persons or to enforce judgments against us or them in U.S. courts obtained in such courts predicated upon the civil liability provisions of the U.S. federal securities laws. Colombian courts determine whether to enforce a U.S. judgment predicated on the U.S. securities laws through a procedural system known as exequatur. For a description of these limitations, see section Shareholder Information—Enforcement of Civil Liabilities .
The protections afforded to minority shareholders in Colombia are different from those in the United States and may be difficult to enforce.
Under Colombian law, the protections afforded to minority shareholders are different from those in the United States. In particular, while regulation provides, among others, the possibility of initiating class actions against issuers such as Ecopetrol, the legal framework with respect to shareholder disputes is substantially different under Colombian law than U.S. law and there are different procedural requirements for commencing shareholder lawsuits, such as shareholder derivative suits. As a result, it may be more difficult for our minority shareholders to enforce their rights against us or our Directors or controlling shareholder than it would be for shareholders of a U.S. company.
ADRs do not have the same tax treatment as other equity investments in Colombia.
Although ADRs represent Ecopetrol S.A.’s common shares, for Colombian tax purposes, ADRs are securities different from their underlying assets. Therefore, ADR holders are not entitled to the tax treatment granted to holders of the common shares. Such tax treatment includes, among others, benefits relating to dividends and to profits derived from sale of Colombian common shares. For further information, see section Shareholder Information—Taxation—Colombian Tax Considerations .
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Judgments of Colombian courts with respect to our ADSs will be payable only in Colombian Pesos.
If proceedings are brought in the courts of Colombia seeking to enforce the rights of ADS holders of common shares, we will be required to discharge our obligation amounts in Colombian Pesos. Colombian law provides that an obligation in Colombia to pay amounts denominated in foreign currency may only be satisfied in Colombian currency at the Representative Market Exchange Rate of the date the judgment is rendered, and such amounts are then adjusted to reflect exchange rate variations through the effective payment date.
The relative volatility and illiquidity of the Colombian securities markets may substantially limit our investors’ ability to sell our ADSs at the price and time they desire.
Investing in securities that are traded in emerging markets, such as Colombia, often involves greater risk when compared to other world markets, and these investments are generally considered to be more speculative in nature. The Colombian securities market is substantially smaller, less liquid, more concentrated, can be more volatile, and subject to greater political, economic and market risk than other securities markets in the United States. As an example, in the past, the value of our shares has experienced sharp intra-day declines, as a result of political risk and the lost in value of the Colombian peso against the dollar. These conditions have triggered declines in our market capitalization and our removal from commonly followed indexes.
As of December 31, 2024, the Colombian Stock Exchange ( Bolsa de Valores de Colombia or “BVC” for its acronym in Spanish) had a market capitalization of approximately COP 320,567,563 million (USD 73 billion using the rate as of December 30, 2024), and 4.27% increase when compared to the amount at the end of 2023 taking into account COP figures. By comparison, the New York Stock Exchange (the “NYSE”) had a market capitalization of USD 40 trillion as of December 31, 2024, and a daily trading volume of approximately USD 203 billion in 2024.
As of December 31, 2024, our shares represented the third highest market capitalization of the BVC accounting for 10.32% of the total MSCI COLCAP index. Measures taken by Ecopetrol in this regard include fulfilling issuer responsibilities through the publication of periodic and relevant information, holding meetings with investors/shareholders, and participating in initiatives/working groups aimed at boosting market liquidity. In November 2022, Ecopetrol was removed from the MSCI Colombia (USD) index due to market variables such as changes in the COP/USD exchange rate and our stock price, which adversely affect an increased market capitalization in U.S. dollars, and therefore affect our compliance with the Minimum Free Float Market Capitalization Requirement of such index. As of the date of this Annual Report, we cannot determine when we may try to be re-included in the MSCI Colombia (USD) index. Nevertheless, in 2024, Ecopetrol remained in the FTSE Emerging index, FTSE indices rank second after MSCI, with a combined share of 17.8% of total investments in referenced funds and 24.8% of investments in indexed funds.
Our subsidiaries listed on the Colombian Stock Exchange (“BVC” for its acronym in Spanish) such as ISA, are also exposed to these risks. As of December 31, 2024, ISA’s shares accounting for 9.24% of the total MSCI COLCAP index.
Given the current ownership structure of our shares, it may be difficult for you to purchase large quantities of shares from a single shareholder. We cannot assure you that a liquid trading market for our ADSs will develop or, if developed, that it will be maintained. Without a liquid trading market coupled with the volatility of the Colombian securities market, the ability of investors in our ADSs to sell them at the desired price and time could be substantially limited.
We are not required to disclose as much information to investors as a U.S. issuer is required to disclose.
We are subject to the reporting requirements set by Law 964 of 2005, Decree 2555 of 2010, the SFC and the BVC. The corporate disclosure requirements that apply to us may not be equivalent to the disclosure requirements that apply to a U.S. issuer and, as a result, you may receive less interim information about us than you would receive from a U.S. issuer.
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5.2.5 |
Risks Related to the Controlling Shareholder |
Our controlling shareholder’s interests may differ, from time to time, from those of certain minority shareholders, or may affect our long-term strategy.
The Nation currently holds 88.49% of our outstanding capital stock, making it our controlling shareholder. The Nation as our controlling shareholder has majority voting rights at the General Shareholders Assembly to elect the members of our Board of Directors and may propose and approve decisions that may be in its own interest and that may not necessarily benefit minority shareholders or be aligned with our long-term strategic goals.
For example, our controlling shareholder may suggest and approve dividend proposals at the ordinary General Shareholders Assembly, notwithstanding the interest of certain minority shareholders, in an amount that results in us having to reduce our capital expenditures or increase our debt levels. In addition, our controlling shareholder may support decisions to undertake projects that may diverge resources from the company’s long-term strategic goals or make announcements about its intentions related to its holding of the Company’s stock, which may not be in our best interest or in the best interest of our minority shareholders, including holders of our ADSs, and could affect the price of our shares or ADSs. Consequently, to the extent permitted by law, the actions of our controlling shareholder may thereby negatively affect our prospects, results of operations and financial condition. See section Shareholder Information—Dividend Policy .
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5.3 |
Risk Management |
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5.3.1 |
Integrated Risk Management System and Internal Control System |
Under the leadership of the Corporate Compliance Department and its Risk Office, in 2024, Ecopetrol S.A. kept strengthening its Integrated Risk Management System based on the international technical standard ISO 31000, which establishes a set of principles, frame of reference and process or cycle that allow the organization to manage the effects of uncertainty on meeting objectives, to maximize opportunities and assist in establishing strategies and making informed decisions.
Our risk management approach consists of four main stages: planning, identifying, evaluating, and managing risks, as well as cross-cutting stages of communication and consulting, record and reporting and monitoring. This cycle is supported by the principles of risk management: integration, continuous improvement, structure, information, culture, organizational structure, and normative and management tools.
Three of our most important tools within our risk management approach are:
| (i) | Risk Assessment Methodology: In order to properly prioritize mitigation, treatment and monitoring efforts of risk management at the process level, a standardized methodology was established to assess inherent and residual risk levels. The risk level (Very High, High, Medium, Low or None) is obtained from the combination of the risks (impacts) and the probability of occurrence of those consequences. According with the level of risk, action plans for management and mitigation are defined. |
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(ii) |
Mitigation Plans: Each year, by performing the stages of the risk management cycle, we define and implement mitigation plans to reduce the levels of exposure to risk through mitigation or elimination of some of its causes. Metrics and goals must be defined during the development of each plan to ensure its effectiveness and to prioritize our efforts on those with the greatest impacts. |
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(iii) |
Monitoring Indicators: As part of the monitoring stage of the risk management cycle, we have implemented Key Risk Indicators (KRIs) which are metrics used to provide early signals of increasing risk exposures. These signals constitute information for preventative decision making to avoid risk materialization. |
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The Integrated Risk Management System establishes the definition of risk as the effect of uncertainty on the fulfillment our objectives, considering the effect as the deviation positive, negative or both, compared to what is expected. Our risks can be classified as:
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(i) |
Enterprise Risks: Risks that are directly associated with the business strategy plan of the Company and are systematically monitored by the Management Committee. When defining the enterprise risks, the analysis of the internal and external environment is carried out to determine the topics and trends that could have potential or real impact on our strategy. The management of those risks is led by the person accountable for the process and each risk has a defined treatment plan and monitoring indicators. Further information can be found in our Enterprise Risk Map on our website. |
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(ii) |
Processes Risks: Risks that tend to identify potential failures in the activities related to our core and support business processes that drive us to achieve our objectives. At this level, our processes have identified risks with their respective mitigation methods, including financial and non-financial controls, treatment plans and/or monitoring indicators. |
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(iii) |
Operational Risks: Risks that are at an operational level of detail and occur in our day-to-day activities and tasks. |
On the other hand, emerging risks are those that are expected to have a long-term future impact on the company (three to five years and beyond) or, in some cases, have already started to impact Ecopetrol. Emerging risks are considered those that meet some of the following characteristics: (i) the risk is new, developing, or significantly increasing in relevance, (ii) a known risk in a new or unknown context or under re-emerging conditions, (iii) the potential financial or reputational impact of the risk is long-term and significant, (iv) it is an external risk arising from events outside the company’s influence or control, (v) the risk and its impact on the company are specific, and (vi) it has a high potential impact to Ecopetrol S.A. and may require it to adapt its strategy and/or business model.
We have also continued consolidating our internal control systems into a unified system that integrates the best practices called for by the Committee of Sponsoring Organizations of the Treadway Commission (COSO 2013), Sarbanes–Oxley Act (SOX), governance and management of enterprise IT (COBIT), Enterprise Risk Management (COSO 2017) and our ethics and compliance rules, with the aim of establishing an integrated management system for all control components, thereby allowing us to strengthen all of our control system.
We have also defined guidelines and implemented an Internal Control System (which includes subsidiaries), the main purpose of which is to provide reasonable assurance regarding the achievement of all the Company’s objectives relating to operations, strategy, reporting and compliance, through the appropriate risks management and ensuring the effectiveness of our controls and the scope of which includes our subsidiaries. Under those guidelines, each subsidiary must implement and report the performance of its Internal Control System to Ecopetrol S.A. to ensure compliance with the above measures, and the subsidiaries have methodological support from Ecopetrol S.A. when requested. Ecopetrol S.A. also performs preventive monitoring in selected subsidiaries to assure all the components and principles of their Internal Control Systems are present and operating. The system performance is systematically monitored by the Board of Directors.
The risk management component of our Internal Control System is in charge of identifying negative events or situations that may affect our defined objectives, assessing and prioritizing them to implement the most appropriate response. This component has been designed and implemented across the organization, with a two-level focus: Enterprise Risk and Processes Risks.
Ecopetrol S.A.’s Internal Control System is aligned to the Company’s strategy and business processes and gives responsibility to all employees to manage risk, to maintain the effectiveness of controls, to report incidents to preventively correct possible deficiencies and to provide reasonable assurance of achieving corporate objectives and goals. The scope of this system includes the Company’s subsidiaries who must implement and report on the performance of its internal control system to the Company to ensure compliance with the above measures.
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5.3.2 |
Managing Low Carbon Economy and Climate Change Risks |
To manage and mitigate the risks related to the transition to a low carbon economy and climate change, Ecopetrol, in line with the goal of generating value through TESG, expects to invest approximately COP 2.3 trillion pesos in 2025, 35% of which is expected to be used for climate change, alternative energy use, and air quality; 18% is expected to be used for territorial development; 12% in biodiversity and ecosystem services; 12% in innovation, science and technology; 7% in industrial and process safety and the remaining 16% is expected to be used for other TESG projects. Additionally, we have set shadow price on carbon at USD 40/TCO 2 for the years between 2025 and 2029, and USD 50/TCO 2 from 2030 onwards, which is expected to be used to assess and evaluate current and future projects and investments. See section Strategy and Market Overview—Our Corporate Strategy—2040 Strategy: Energy That Transforms for detailed information on our strategy and carbon shadow price.
To properly adapt the Ecopetrol Group’s business strategy to the transition to a low carbon economy and ensure long-term value creation, we have been conducting energy transition scenario analyses since 2018. These analyses are being updated and refined reflecting changes that we anticipate for the years to come and that are aligned with the IEA’s latest scenarios. This allows for the definition of actions to manage the risks and opportunities involved in transitioning to a low-carbon economy and adapting the business strategy to ensure long-term value creation. Within the framework of the 2040 Strategy, scenario trends and sensitivities were translated into three business scenarios: (i) Benchmark Scenario: It considers the same trends identified in the Energy Transition Benchmark Scenario, which is also the baseline scenario for the Company’s 2040 Strategy, (ii) High Price Scenario: Associated with Decelerating Sensitivity trends in terms of energy transition. Seeks to reflect a business scenario in which the current trend is maintained, and climate targets are not met by 2030 or 2050, and (iii) Stress Test Scenario: It reflects the trends of the Accelerated Transition Scenario and some developments of the Sensitivity to a 2°C Scenario. Energy transition scenarios were developed following the formulation of the 2040 Strategy and its ratification in 2023.
As a result of the construction of energy transition scenarios, which aims to be a solid and unified reference framework and to allow us to anticipate and understand the challenges and opportunities of the energy transition, in 2024 we began monitoring trends based on such scenarios. The three scenarios Ecopetrol presented and used for comparison are: (i) Climate Alignment (1.7° - 1.8°C): Transformation to low-emission economies aligns governments and institutions around climate change. In addition, developed countries reach a net zero goal, while other countries follow a slower path. This is not enough to achieve the global net-zero goal of 1.5 ℃; (ii) Energy Balance (1.9° - 2.3°C): Fundamental changes in governments, markets, and society set in motion a long-term energy transition, the debate continues between energy security and accelerating the transition; and (iii) Climate Divergence (2.5° - 2.8°C): Dissimilar interests in decarbonization despite policy, regulation and market changes. Global public policy decisions are insufficient to close the climate ambition gap.
Ecopetrol finds it essential to compare the three potential scenarios. While the first and third scenarios do not represent the group’s core vision, assessing different perspectives on the global energy transition remains necessary. According to the 2040 Strategy, Ecopetrol considers the second scenario the most likely, aligning with a gradual energy transition. This transition envisions increased use of low-emission energy sources while retaining conventional energy in the overall energy mix. Additionally, this scenario is expected to enhance sustainability and resilience in energy supply. In this context, the Ecopetrol Group is committed to diversifying its energy portfolio, emphasizing the incorporation of low-emission energy sources, such as renewables and natural gas, to mitigate climate change and reduce reliance on traditional fossil fuels.
On November, 2024, we presented our third specialized report on climate change management following the recommendations of the Task Force on Climate-Related Financial Disclosures (TCFD) highlighting progress in strengthening climate-related risk and opportunity management processes through discussions on governance, strategy, risks and metrics and targets. Our climate risk strategy is also being aligned with the recommendations of the TCFD and includes the addition of a new climate-related risk to our 2024 enterprise risks, in respect of inadequate response to environmental challenges associated with climate change, water and biodiversity.
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5.3.3 |
Managing Information Security and Cybersecurity |
Ecopetrol S.A. has a dedicated management team specialized in information security issues such as risk analysis, information processing, secure information management practices and classification of critical business information, compliance with control systems, effectiveness of available information security technologies, and
Ecopetrol S.A. has incorporated cybersecurity risk as one of its primary business risks. Currently, there is a
The cybersecurity team continues to integrate practices aimed at enhancing risk awareness and adjusting current information security capabilities in response to evolving cyber threats.
Ecopetrol S.A. has a Security Operations Center (SOC) service, to enhance the organization´s ability to predict and identify trends in attacks on both its information technology and Operation Technology infrastructure, while also monitoring its online reputation. Throughout 2024, the SOC capabilities remained operational, with an expanded scope of services covering Operational Technology (OT) digital assets. This expansion included cybersecurity risk assessments and advanced security testing exercises (RedTeam) conducted on Ecopetrol’s IT/OT infrastructure and its subsidiaries, enabling the identification of gaps to improve the overall cybersecurity posture. Additionally, specialized monitoring capabilities such as User Behavior Analysis (UBA) remains. Despite cyberattacks occurring in 2024, all reported events were successfully controlled, resulting in no material effects on processes, equipment, products, services, customer or supplier relationships, competitive conditions, or critical information. Ecopetrol, S.A.
We update our cybersecurity policies and cyberincident response procedures from time to time, as shown by several wargames that cover all business segments and their subsidiaries. These exercises document how to manage the activation of the Cyber Insurance policy, the PMU (Unified Command Post), and the operation model for cyberincident response with Ecopetrol’s internal teams. The action protocol for business crisis scenarios is also regularly revised, establishing timely notification to, and communication processes with, internal and external entities, as well as the roadmap for defining and analyzing the materiality of a cybersecurity incident. The management guide includes two annexes that detail the roles, responsibilities, and activities of those involved in responding to a cyberincident event or alert.
Furthermore, during 2024, the internal audit department conducted audits of cybersecurity processes to follow up on previous improvement plans. Consequently, an action plan was developed with the main objectives of enhancing threat identification, access management, and improving specific technical components of the cybersecurity program.
Ecopetrol S.A. remains committed to using the ONG–C2M2 (Oil Gas - Cybersecurity Capability Maturity Model) framework to manage its maturity and uphold its cybersecurity management system. This entails implementing practices and focus our capabilities domains such as access, response, third parties, and architecture.
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Ecopetrol S.A. has also strengthened its cybersecurity capabilities in 2024 by continuing to incorporate foundational “Zero Trust” practices and advanced critical information protection controls to mitigate cyber risks across its business units. Another significant initiative throughout 2024 was the cultural awareness campaign focusing on three management pillars: (i) training, that consists of development of new skills, (ii) mobilization, that consists of promotion and ownership of change, and (iii) communication, that consists of promotion of understanding and conviction of behaviors). Additionally, the information assurance cycle was executed to identify, evaluate, and manage the cybersecurity risks associated with critical information assets. Finally, our cybersecurity strategy defined for the period 2022 to 2026 where a quantitative cyber risk model was applied was updated and aligned with the Science, Technology and Innovation strategy, as well as the Ecopetrol Group’s 2040 strategy, defining the following 5 pillars with a customer and country centric approach and vision:
1. Digital trust as a cross-cutting axis of excellence, innovation, and cyber collaboration.
2. Secure operations in our different ecosystems (apps, cloud, identity, among others).
3. Incident response capacity and continuous monitoring of cyber threats.
4. Data security and privacy and safe use of AI.
5. Industrial Cybersecurity, aligned with the protection of business infrastructures.
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5.3.4 |
Managing Financial Risk |
We are exposed to certain risks associated with the nature of our operations and the financial instruments we use. Among the risks that affect our financial assets, liabilities and expected future cash flows are changes in commodity prices, currency exchange rates, interest rates and the credit quality of our counterparties.
Commodity price risk is associated with our day-to-day operations as we export and import crude oil, natural gas, and refined products. We occasionally use hedges to partially protect our financial results from price fluctuations considering that part of our financial exposure under purchase contracts for crude oil and refined products depends on international oil prices. We believe that the risk of such exposure is partially naturally hedged since we are an integrated group (with operations in the upstream, midstream, downstream, and electric power transmission and toll roads concessions segments) and either export crude oil at international market prices or sell refined products at prices that are correlated to international market prices. During 2024, Ecopetrol Permian executed strategic hedging operations oriented to secure the value promise of the company for a total of 6.9 million barrels; additionally Ecopetrol S.A. and Ecopetrol Trading Asia Pte Ltd executed tactical hedging operations due to its exposure to pricing indices different from the commercialization benchmark and different pricing periods between the buying and the selling of physical barrels. A total of 50.4 million barrels were the subject of tactical hedges oriented at mitigating risks associated with crude oil imports, supply to refineries and international sales delivered at the destination port. We do not use derivative financial instruments for speculative or profit-generating purposes.
Currency risk arises in our operations given the fact that most of our revenues are derived from sales of products quoted in or with reference to U.S. dollars. Therefore, when the Colombian Peso depreciates against the U.S. dollar, our revenues converted into Colombian Pesos increase. Conversely, when the Colombian Peso appreciates against the U.S. dollar, our revenues decrease. On the other hand, imported goods, oil services and the debt, which is mainly denominated in U.S. dollars, become less expensive when the Colombian Peso appreciates against the U.S. dollar and more expensive when the Colombian Peso depreciates against the U.S. dollar.
As of December 31, 2024, our total debt denominated in U.S. dollar and other currencies (excluding debt denominated in Colombian pesos) amounted to USD 24.7 billion principal, which we recognize in our consolidated financial statements at its amortized cost, which corresponds to the present value of cash flows, discounted at the effective interest rate. Out of this total, USD 17.4 billion is owed by Ecopetrol S.A., whose functional currency is the Colombian Peso. Therefore, when the Colombian Peso depreciates against the U.S. dollar, the Colombian debt denominated in Colombian Pesos increases year-over-year, and Ecopetrol S.A. is exposed to an exchange rate loss. In contrast, when the Colombian Peso appreciates against the U.S. dollar, the Colombian debt denominated in Colombian Pesos decreases year-over-year, and Ecopetrol S.A. is exposed to an exchange rate gain. Some of the Ecopetrol Group’s subsidiaries have the U.S. dollar as functional currency and are not exposed to a material exchange rate risk resulting from fluctuations in the Colombian Peso against the U.S. dollar. On the asset side, when the financial statements of the Ecopetrol Group are consolidated, the exchange rate differential of the subsidiaries’ assets and liabilities whose functional currency is the U.S. dollar is recognized directly in equity, as part of other comprehensive income. The total consolidated debt expressed in Colombian Pesos as of December 31, 2024, increased 15.2% on a year-to-year basis, meanwhile the total debt denominated in U.S. dollars and other currencies (excluding debt denominated in Colombian pesos) had no representative changes.
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Taking previous considerations into account, we seek to identify and manage currency risk in a comprehensive manner, using an integrated analysis of natural hedges to benefit from the correlation between income or investments in a foreign operation and debt denominated in foreign currency. We adopted accounting hedge as part of our risk management strategy, using two types of natural hedges with our U.S. dollar denominated debt as a financial instrument: (i) cash flow hedge for exports of crude oil, and (ii) hedge of a net investment in a foreign operation. In addition, we may involve the use of financial derivative instruments, and non-derivative financial instruments. As a part of its risk management strategy, using the natural hedge between exports and dollar-denominated debt, in October 2015, USD 5.4 billion of Ecopetrol S.A.’s debt in U.S. dollars was designated as hedge instrument of its future export sales for the period 2015 – 2023. During the second half of 2021, Ecopetrol S.A. hedged a new portion of the dollar-denominated debt against future revenues in an amount of USD 3.7 billion, and during 2021 Ecopetrol S.A. hedged USD 4.9 billion with its foreign investments and future revenues. In 2023, Ecopetrol S.A. hedged (i) a new portion of the dollar-denominated debt against future revenues in an amount of USD 1.9 billion, and (ii) USD 2.2 billion with its foreign investments and future revenues. Likewise, in 2024, Ecopetrol S.A. hedged (i) a new portion of the dollar-denominated debt against future revenues in an amount of USD 1.1 billion, and (ii) USD 0.6 billion with its foreign investments and future revenues.
As of December 31, 2024, the outstanding value of the natural accounting hedges was USD 17.6 billion. With the adoption of hedge accounting, the effect of the volatility of the foreign exchange rate on the hedged portion of the debt is highly mitigated and is recognized directly in equity, as part of other comprehensive income.
The remaining portion of our dollar-denominated debt, as well as the financial assets and liabilities denominated in foreign currency continue to be exposed to the fluctuation of the exchange rate. Finally, the Company maintains enough cash in Colombian pesos and U.S. dollars to meet its expenses in each currency (see Note 4.1.5 to our financial statements for further explanation of our accounting policy and Note 30.1 for details of the hedge accounting adopted).
Interest rate risk arises from our exposure to changes in interest rates mainly because of the issuances of floating rate debt linked to SOFR, CPI, IPCA, IBR, CDI and others (with 13.6%, 4.6%, 5.0%, 3.2%, 2.6%, and 0.5% respectively, of the nominal debt balance as of December 31, 2024). Thus, volatility in interest rates may affect the fair value of and cash flows related to our investments and floating rate debt. For 2024 our analysis of credit risk events and global financial markets led us to decide not to hedge interest rate risk. Nevertheless, our capital markets office continuously monitors the performance of interest rates and the effect of interest rates on our financial statements.
The trust funds linked to Ecopetrol S.A.’s pension obligations (PAP for its acronym in Spanish) are also exposed to changes in interest rates, as they include fixed and floating-rate instruments that are marked to market. This exposure is continuously monitored by our treasury office given the potential impact volatility may have on our financial results. The treasury office’s information is gathered from reports provided by the asset managers. These reports refer to regulatory limits as well as market, credit and liquidity risks. The investment guidelines with respect to the PAPs are issued by the Colombian regulation for pension funds, as stipulated in Decree 941 of 2002 and Decree 1913 of 2018, where it is indicated that they must follow the same regime as the regular obligatory pension funds in their moderate (i.e., neither conservative nor aggressive) portfolio. For further information regarding the trust funds linked to the pension obligations of the company, see Note 30.8 to our consolidated financial statements.
Regarding liquidity risk, Ecopetrol S.A. forecasts and monitors its cash position daily in order to review updated expectations for liquidity conditions and the capacity to attend short term obligations. This forecast mainly includes operational income and expenses, capital expenditures expectations, debt and dividend related cash-flows, and other financial cash movements. Additionally, on a monthly basis, management reviews cash evolution, availability and forecasts under different scenarios.
Finally, counterparty risk is the potential probability that a borrower or counterparty defaults on any obligation. In our case, we are exposed to this risk as we invest in different financial instruments and receive letters of credit to mitigate our exposure with our commercial counterparties. We manage this risk by monitoring and analyzing the counterparty’s creditworthiness, stock price behavior, spreads on credit default swaps, probability of default, among others.
Hedging guidelines for Ecopetrol S.A. and its subsidiaries
Ecopetrol S.A.’s management established a set of guidelines for hedging strategies for Ecopetrol S.A. and its subsidiaries. These guidelines allow us to use financial instruments to mitigate the impacts in our financial statements as a result of the fluctuation of risk factors, such as commodity prices, exchange rate, interest rate and others.
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These guidelines determine general principles governing hedging operations, corporate governance, the process for implementing operations which includes the identification of risk exposition as an integrated group, the identification and design of the financial structures, and execution and monitoring, among others.
The guidelines also include a list of allowable financial assets, such as forwards, futures, options, and swaps and describe the differences between strategic and tactical hedging, where the former focus on protecting our financial results from market volatility and the latter is mainly designed to hedge the market risk of specific trading in physical markets.
Investment Guidelines Ecopetrol S.A.
Ecopetrol S.A.’s management established guidelines for our investment portfolios. These guidelines determine that investments in Ecopetrol S.A.’s U.S. dollar portfolio and the Colombian Peso portfolio may be invested in fixed income securities issued by entities with a rating equal to or greater than Ecopetrol S.A’s credit risk rating, but which at all times must be a minimum of investment grade as rated by any of the internationally recognized rating agencies (Standard Poor’s, Moody’s, and Fitch Ratings). In order to diversify risk in both our U.S. Dollar and Colombian Peso portfolios, Ecopetrol S.A.’s management will determine both short- and long-term limits by issuer and issuance based on internal analyses and external risk ratings.
Additionally, the portfolios in U.S. Dollar and Colombian Peso of Ecopetrol S.A. is expected to be segmented in the tranches determined by Ecopetrol S.A.’s management, meeting the Company’s working capital and liquidity needs, benchmarks and cash flow projections.
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5.4 |
Legal Proceedings and Related Matters |
We are a party to various legal proceedings in the ordinary course of business. Other than the proceedings disclosed in this annual report, we are not involved in any pending (or, to our knowledge, threatened) litigation or arbitration proceeding that we believe will have a material adverse effect on our Company. Other legal proceedings that are pending against or involve us and our subsidiaries are incidental to the conduct of our and their business. We believe that the ultimate disposition of such other proceedings individually or in an aggregate basis will not have a material adverse effect on our consolidated financial condition or results of operations.
As of December 31, 2024, Ecopetrol S.A. was a party to 7,730 legal proceedings relating to civil, criminal, administrative, environmental, tax, constitutional, arbitration and labor claims, out of which 5,435 were filed against us in the Colombian courts and arbitration tribunals, of which 388 had an accrual provision. We allocate enough money and time to defend these claims. Historically, we have been successful in defending lawsuits filed against us. Other than the environmental administrative proceedings described in the last paragraph of this section, based on the advice of our legal advisors, it is reasonable to assume that the litigation procedures brought against us will not materially affect our financial position or solvency regardless of the outcome. See Note 23 to our consolidated financial statements included in this annual report for a discussion of our legal proceedings.
Caño Limón – Coveñas Crude Oil Pipeline Spill
On December 11, 2011, the Caño Limón - Coveñas oil pipeline ruptured and caused the spill of approximately 3,267 barrels of crude oil into the Iscala creek, which connects with the Pamplonita River that provides water to the city of Cúcuta. The incident did not cause any fatalities or injuries.
In 2012, a class action lawsuit was filed against Ecopetrol S.A. and against employees of the Company, and the First Administrative Court of Cúcuta has jurisdiction to conduct the case, which is in the evidentiary stage, pending a first instance judgment.
The Regional Environmental authority of Norte de Santander, or Corporación Autónoma Regional de la Frontera Nororiental (CORPONOR) also filed a lawsuit against Ecopetrol S.A. before the Administrative Court of Norte de Santander claiming for (i) the environmental loss caused by the incident and (ii) for compensation costs relating to the environment damage for approximately COP 33 billion. Ecopetrol S.A.’s legal counsel filed a motion to dismiss the lawsuit on June 2, 2014, based on three grounds: (i) there is no proof of environmental loss, (ii) CORPONOR does not have the authority to file this lawsuit and (iii) CORPONOR’s petition for direct compensation is not the proper legal action according to the applicable procedural rules. In July 2020 the evidentiary stage closed. On July 27, 2023, the Administrative Court of Norte de Santander issued its ruling and denied the compensation claims for damages by CORPONOR. As of the date of this annual report, no appeal has been filed in connection to this decision.
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Ecopetrol S.A. and national and local authorities agreed to develop a project consisting of an alternative to the water supply intake of the aqueduct in Cúcuta. In December 2011, our Board of Directors approved our participation in the project as part of the support of our contingency plans and relationship with stakeholders. On November 10, 2017, an agreement was signed with the purpose of building the alternative water supply at a cost of approximately COP 425.09 billion. According to the agreement, we are in charge of the construction of the aforementioned infrastructure. As of the date of this annual report, the construction projects continue their progress. Their statuses are currently the following: (i) for subproject 1, the initial delivery process was made official to the municipality of Cúcuta and overall progress is of 100%, and (ii) for subprojects 3 and 4, functional tests are undergoing and overall process is of 98.3%, without including complementary works and the scope of the sludge plant.
BT Energy Challenger
On October 22, 2014, we were served with a class action suit against us seeking monetary damages of approximately COP 7.4 trillion related to an incident that occurred on August 21, 2014, during the loading operations of the BT Energy Challenger vessel. The claimants alleged possible damage to the port area of Ecopetrol S.A.’s terminal in Coveñas, as well as of marine and submarine areas and beaches that form the geographical area of the Morrosquillo Gulf. This allegation is currently under investigation by the Harbor Master of Coveñas. Ecopetrol S.A. filed a motion requesting the judge to require the claimants to amend their claim to more precisely set forth the facts and evidence that allegedly support Ecopetrol S.A.’s liability.
On March 3, 2015, Ecopetrol S.A. filed its statement of defense arguing the exclusive fault of a third party. On October 20, 2015, the Court denied a class action of more than 100 informal traders in the region because there is no common identity with the initial class (hotel employees). However, during 2016 the Sucre Administrative Court accepted another 1,208 informal traders and fishermen as claimants.
On March 10, 2017, a mandatory settlement hearing was held in order to seek an agreement, but it failed.
In January 2018, a judicial order was issued to commence the evidence production phase, a decision which was objected by the parties.
In September 2018, all the ordered statements were made, the evidentiary stage was finalized and the parties filed their final closing arguments.
Afterwards, once the requests and appeals were resolved, the Court admitted the evidence, closed the evidentiary period, and the final arguments were presented. The closure of evidentiary period was appealed by several parties on the grounds that it was premature.
As of the date of this annual report, a first instance judgment is pending. The Court has consolidated several process-related judicial proceedings related to the class action suit, despite some objections and annulment motions from some of the involved parties and is currently reviewing the arguments on the appeals against its decision.
Salgar-Cartago Multi-purpose Pipeline Spill
On December 23, 2011 our Salgar-Cartago pipeline ruptured. Internal and external experts believe this incident occurred due to creep movement of soil caused by severe weather conditions, causing the soil surrounding the pipeline to exert strong pressure on the pipeline and rupture it. As of the date of this annual report, there are two lawsuits related to this incident with possible damages of approximately 6.0 COP billion.
It is important to mention that the third lawsuit that was reported in the previous report (2023), has already concluded with a final judgment.
Class Action of the AWA Indigenous Community
On April 2, 2018, a class action lawsuit was filed against Ecopetrol S.A. and Cenit by the Inda Guacaray and Inda Sabaleta reservations of the AWA Indigenous community who claim damages to their communities by environmental contamination and damage to natural resources that the defendants supposedly caused by act or omission during various environmental incidents. In August 2018 Ecopetrol S.A. answered the complaint. The parties are currently waiting for the evidentiary stage to start.
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On November 14, 2020, the Administrative Court of Cundinamarca declared that an inadequate claim was filed by the AWA community, considering that the claims related to the reestablishment of measures specific to restitution, rehabilitation, satisfaction and guarantees of non-repetition, could not be sought through a class action.
Although the plaintiffs did not clearly determine the amount of their claims, Ecopetrol S.A. and the National Agency for Legal Defense of the State ( Agencia Nacional de Defensa Jurídica del Estado or “ANDJE”) had initially estimated the amount to be approximately COP 358,201,371,800. As of the date of this annual report, a compliance agreement hearing was still pending.
On February 2024, the AWA people filed a constitutional protection action against Ecopetrol, Cenit and other entities, for the alleged violation of the fundamental rights to a healthy environment, health, water, food, rights of future generations and comprehensive reparation of the plaintiffs, due to crude oil spills that have occurred in their territory derived, mainly, from the installation of illicit valves and the perpetration of terrorist attacks on the Pipeline Transandino (“OTA”). Therefore, the lawsuit invokes the same facts and claims of the class action that was filed by the same Indigenous people. The constitutional protection lawsuit, which was denied in the first and second judicial instances, was selected for review by the Constitutional Court and is in the evidentiary stage.
Consultation Process with Afro-Wilches
On April 21, 2022, the First Section of the Administrative Court of Barrancabermeja – Santander ordered Ecopetrol S.A., ANLA and the Ministry of the Interior to carry out a consultation process with the Afro-Colombian Corporation of Puerto Wilches – Afro Wilches in connection with the Comprehensive Research Pilot Projects (PPII for its acronym in Spanish) Kalé and Platero projects. The ruling was appealed by Ecopetrol S.A, ANLA and the Ministry of the Interior, among others. On June 2, 2022, the Administrative Court of Santander revoked the ruling of the First Section of the Administrative Court of Barrancabermeja – Santander. On June 20, 2023, the Constitutional Court admitted this matter for review. On August 20, 2024, the Constitutional Court in the review court ruled that since the plaintiffs were an ethnic population (Afro-Colombian community), a direct impact was evident and, consequently, confirmed the protection of the fundamental right to prior consultation because it was of minority groups, historically excluded and discriminated against. On August 23, 2024, Ecopetrol asked for an amendment and clarification, arguing that the prior consultation required by the protective ruling should only take place if the PPII comprehensive research pilot projects were to be implemented, considering that no such projects were planned at the time. The Constitutional Court rejected this request on October 23, 2024. On November 1, 2024, Ecopetrol filed a petition for modulation before the first instance judge. On November 7, 2024, the judge ruled that the prior consultation did not have to be done immediately, but only if there was interest in pursuing the project. This decision concluded this legal proceeding.
Foncoeco
On March 18, 2019, Ecopetrol S.A. received judicial notice of a lawsuit filed by the Fund of Workers and Former Workers of Ecopetrol for Participation in Utilities (“Foncoeco”) on behalf of workers and former workers alleging that between 1997 and 2017 the company allocated part of its profits for the wellbeing of their workers. The plaintiffs considered that they had the right to receive those profits up to COP 3,157,461,510,000. This lawsuit is similar the one that was ruled in favor of Ecopetrol S.A. in 2011.
The final arguments and sentencing hearing were held on March 2, 2022, in which a first instance ruling was issued in favor of Ecopetrol, which was confirmed by the Superior Court of Bogotá on June 29, 2022. Foncoeco filed a judicial review before the Supreme Court of Justice, which was rejected on March 30, 2023. The rejection of the Supreme Court completed all legal stages possible. The ruling has now become “res judicata.”
Environmental Administrative Proceedings
As of December 2024, Ecopetrol S.A. was part of 179 environmental administrative proceedings, of which 166 were initiated before 2023 and 13 during 2024. It is not possible for us to determine whether the pending proceedings could have a material effect on Ecopetrol S.A. During 2024, eight proceedings were concluded, in two of them, we were subject to monetary fines through resolution 355 of March 7, 2024, confirmed by resolution 1695 of August 12, 2024, for an aggregate amount of COP 465,851,480, resolution 3065 of December 22, 2023, confirmed by resolution 390 of March 12, 2024, for an aggregate amount of COP 16,348,104. Finally, two monetary fines are suspended pending appeal through resolution 2943 of December 27, 2024, for aggregate amount of COP 93,703,928 and resolution 1277 of December 30, 2022, for an aggregate amount of COP 182,061,180. The Environmental Authority has not issued a statement regarding this matter up to date.
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Bioenergy Special Audit
The Office of the Comptroller General, in exercise of its fiscal monitoring duties and authority as set forth in Article 267 of the Political Constitution, has undertaken audits of the performance of the Bioenergy S.A.S. and Bioenergy Zona Franca S.A.S. investments.
On February 6, 2017, the Office of the Comptroller General initiated a Special Intervention (Special Audit) in order to evaluate the use of public funds in the project carried out by Bioenergy Zona Franca S.A.S. and Bioenergy S.A.S. On July 10, 2017 the Office of the Comptroller General issued its final report with 15 findings related to: (i) acquisition, lease payments and the use of agricultural lands, (ii) loss of profits due to the project’s delay; and (iii) execution of contracts related with the building, commissioning and start-up of the industrial plant and the agricultural component of the project. On December 28, 2018, Bioenergy completed all of the activities set forth in the remediation plan to address the 15 findings.
As a result of some of the findings, the Office of the Comptroller General opened several actions of fiscal liability ( proceso de responsabilidad fiscal ) against former members of Bioenergy’s administration and third-party companies.
In 2018, the Office of the Comptroller General initiated a financial audit of Bioenergy’s financial statements for the year ended December 31, 2018. On May 21, 2019, the Comptroller General delivered its financial audit final report, issuing: (i) an unqualified opinion on Bioenergy’s financial statements, (ii) an efficient and effective internal control process opinion, and (iii) a reasonable opinion, since the budget was prepared and executed, in all relevant matters, according to Bioenergy’s budgeting internal regulation. Finally, the Office of the Comptroller General determined three findings related to: (i) plots of land pending to legalize, (ii) ethanol imports and (iii) the leasing agreement of the Casa Roja plot of Land. On December 31, 2020, Bioenergy completed all of the activities set forth in the remediation plan to address the three findings.
In 2019, the Office of the Comptroller General initiated and ended a compliance audit of Bioenergy S.A.S for the period starting July 1, 2017 to May 31, 2019. The Comptroller General notified Bioenergy on February 4, 2020 its compliance audit final report determining seven findings related to: (i) agricultural lands productivity, (ii) income and expenses from rental payments of subleased agricultural lands, (iii) balanced scorecard results for 2017-2018, (iv) update of laboratory procedures, (v) transport contract number 0029-17 settlement, (vi) document handling and (vii) Campo Victoria plot of Land. Bioenergy filed the remediation plan on February 25, 2020.
Until June 24, 2020, when the Superintendence of Companies of Colombia gave the order to start the Bioenergy’s liquidation proceeding, Bioenergy S.A.S. completed activities as scheduled in the remediation plan according to the June 30, 2020 deadline. Any pending activities related to the aforementioned remediation plan, are in charge of the liquidator appointed by the Superintendence of Companies of Colombia in Bioenergy’s liquidation proceeding.
During 2021, such judicial liquidation proceeding continued under surveillance and instruction of the Superintendence of Companies of Colombia, in compliance of the applicable law. On December 15, 2021, the adjudication hearing for both companies (Bioenergy SAS and Bioenergy Zona Franca SAS) was not successful, so the Superintendence of Companies of Colombia, appointed March 4, 2022 for a new hearing, which was suspended and then completed on March 9, 2022 with the approval of (i) the Adjudication Agreement of Bioenergy SAS; and (ii) the Reorganization Agreement of Bioenergy Zona Franca SAS respectively.
On December 16, 2021, a reorganization agreement of Bioenergy Zona Franca SAS was filed in the Superintendence of Companies of Colombia, with favorable vote of 75% of the creditors, to be authorized by such Superintendence. On January 24, 2022, Superintendence of Companies of Colombia authorized the continuity of the activities and corporate purpose of Bioenergy Zona Franca SAS until April 2022.
After the fulfillment of the agreement for the administrative liquidation of Bioenergy and the agreement regarding Bioenergy Zona Franca, neither Ecopetrol S.A. nor any of its affiliates will be considered shareholders of the aforementioned companies. Therefore, legal contingencies associated to those companies are now limited.
On April 3, 2024, the Superintendency of Companies of Colombia ended the liquidation proceeding and ordered the cancellation of the Commercial Registration of Bioenergy S.A.S which was completed on December 27, 2024.
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Ecopetrol’s stake in Offshore International Group investigation
In 2009, Ecopetrol acquired a 50% ownership interest in Offshore International Group Inc. (OIG). OIG carries out crude oil exploration and production activities in Peru. This equity interest was recognized as an investment in a joint venture (entity over which the Ecopetrol Business Group had significant influence but not control and as a result was not considered an affiliate or subsidiary) and recorded using the equity method of accounting. On January 19, 2021, Ecopetrol consummated the sale of all of its shares in OIG.
On December 7, 2022, the Office of the Comptroller General (Contraloría General de la República) commenced a formal investigation ( Proceso de Responsabilidad Fiscal ) against certain members of OIG’s Board of Directors, which as of the date of this annual report, is ongoing. According to the Comptroller General’s public statements, the investigation relates to “possible insufficient oversight of the investment by the members of OIG’s Board of Directors to prevent the materialization of related risks”.
As of the date of this annual report, the Office of the General Comptroller’s investigation names two former members of senior management—the Chief Operating Officer of Ecopetrol (until May, 2024), and the Chief Executive Officer of Cenit S.A. (until July, 2024), in each case, in their capacity as members of OIG’s Board of Directors.
Although the content and status of the investigation is confidential, Ecopetrol has collaborated and provided the information requested by the General Comptroller’s Office, and Ecopetrol is not aware of any allegations related to acts of corruption, bribery or fraud in connection therewith.
Reficar Investigations
According to Colombian regulations, Ecopetrol and Reficar employees are public servants, and as such can be held liable for negligent use or mismanagement of public funds. In this context, given that Ecopetrol is majority owned by the Colombian Government and Reficar is a wholly owned subsidiary of Ecopetrol, Ecopetrol and Reficar administer public funds.
As a result, Ecopetrol and Reficar employees are subject to the control and supervision of the following control entities, among others:
The Office of the Comptroller General (Contraloría General de la República) oversees the adequate use of public funds and has the authority to investigate public employees or private sector employees that manage public resources.
The Attorney General’s Office (Procuraduría General de la Nación) supervises compliance with applicable law by public employees and private sector employees that carry out public functions. The Attorney General’s Office investigates and sanctions individuals for such compliance failures.
The Prosecutor’s Office (Fiscalía General de la Nación) investigates infringements and prosecutes alleged crimes before the court in judicial proceedings.
The following are the most significant investigations and proceedings carried out by the aforementioned state entities:
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1. |
The Office of the Comptroller General’s investigations and proceedings. |
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1.1 |
Because of the amendment of the schedule and budget related to Cartagena refinery’s expansion and modernization project (the “Project”), the Office of the Comptroller General conducted a special audit action of the Project in 2016 and issued a final report to Reficar on December 5, 2016. The report detailed 36 findings most of which were related to increased costs compared to the budget for services, labor and materials. As required, Reficar executed an action plan addressing the 36 findings. See section on The Attorney General’s Office Investigations below, which describes the Attorney General’s Office decision on December 10, 2021, in relation to the 36 findings. |
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As a result of the findings described above, on March 10, 2017, the Office of the Comptroller General opened an investigation pertaining to the financial responsibility ( proceso de responsabilidad fiscal ) of 36 individuals involved in the Project, including former members of Ecopetrol’s Board of Directors, former members of Reficar’s Board of Directors, former employees of Ecopetrol S.A., and former employees of Reficar, along with four contractors who provided their services during the execution of the Project CBI Americas Ltd., CBI UK Limited, CBI Colombiana S.A. and, Foster Wheeler USA Corporation and Process Consultants Inc. |
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These investigations were conducted based on the Office of the Comptroller General’s thesis that lower than expected profitability at Reficar could have been caused by (i) amendments to the schedule and, (ii) the increase of the budget for the Project.
On June 5, 2018, the Office of the Comptroller General split the initial proceeding into two different proceedings. The first one is related to the increase of the Project’s budget and the second one is related to the lost profits due to extension in the Project’s schedule:
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1.2.1. |
Regarding the first proceeding, on June 5, 2018, the Office of the Comptroller General indicted: (i) 15 individuals, which include former members of Reficar’s Board of Directors, a former employee of Ecopetrol, and former employees of Reficar, (ii) CBI Americas Ltd., CBI UK Limited, CBI Colombiana S.A., Foster Wheeler USA Corporation and Process Consultants Inc, and the following insurance companies, Compañía Aseguradora de Fianzas S.A, Coaseguro Confianza S.A., Liberty Seguros S.A., CHUBB de Colombia Compañía de Seguros S.A., Seguros Colpatria S.A. and Mapfre Seguros Generales de Colombia S.A., as third parties with joint liability. |
As for the other 21 individuals initially investigated in 2017, the Office of the Comptroller General closed the investigations.
On April 26, 2021, the Office of the Comptroller General decided on the charges for violation of financial responsibility for an amount of COP 2.95 trillion in connection with the approval of the capital expenditure modifications to the Project. This decision was issued against seven former members of Reficar’s Board of Directors, five former Reficar employees, four contractors that rendered their services during the execution of the Project and four insurance companies. They were found liable among others, for: (i) having approved additions to the Project’s capital expenditures, knowing that the value proposition and profitability of the investment would be affected; (ii) not having ensured the adequate application of the business group investment guidelines. See The Attorney General’s Office Investigations below, which describes the Attorney General’s Office pronouncement on May 4, 2021.
Nonetheless, in the ruling there was no allegation related to acts of corruption, bribery or fraud. As of the date of this annual report, no current or former member of Ecopetrol’s Board of Directors has been charged or found guilty in the first proceeding related to the increase in the Project budget.
The decision is of an administrative nature. Consequently, those deemed financially responsible have filed lawsuits before the judges of the Republic of Colombia to seek the annulment of the ruling. In connection with one of these lawsuits related to Hernando José Gómez Restrepo, a former member of the Board of Directors of Reficar from March 29, 2012 to April 19, 2013, on November 8, 2024, the Administrative Court of Cundinamarca issued a first-instance judgment annulling the decision of the Office of the Comptroller General, citing, among other reasons, the absence of pecuniary damage. The annulment of the Comptroller General’s decision applies exclusively to Mr. Hernando José Gómez Restrepo. On December 13 and 18, 2024, the Office of the Comptroller General and the Attorney General’s Office filed appeals against the judgment. The appeals will be decided by the High Court for Administrative Matters ( Consejo de Estado ). Reficar is not a party to these legal proceedings.
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In relation to the second proceeding, on February 3, 2022, the Intersectoral Delegate Comptroller’s Office concluded the investigative proceedings, with a favorable decision for the individuals that were under investigation. |
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The Office of the Comptroller General also ordered the commencement of an additional investigation in relation to amounts executed in the Project and its sources of funding. In this investigation, on August 24, 2021, the Comptroller’s Office started a new financial responsibility proceeding pursuant to which eight former employees of Reficar are under investigation (three former presidents and five former financial vice presidents). |
On February, 2023, the Office of the Comptroller General conducted a special visit to the refinery to investigate expenses related to the destination of financial costs, among others, which according to the Comptroller’s Office, entered the project, and their allocation remained unidentified. On April 14, 2023, the Office of the Comptroller General released a technical report of the visit, which, based on information provided by Reficar, concluded that all expenses were properly identified, supported, and associated with services provided by third parties.
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On April 19, 2023, it was mandated to include the technical report in the process and make it accessible to the parties involved in the proceedings.
Subsequently, on October 2, 2024, the proceedings were formally closed. The Intersectoral Delegate Comptroller 15 determined that the facts in the case did not constitute damage to public assets.
Currently there is no allegation related to acts of corruption, bribery, or fraud.
As of the date of this annual report, both Ecopetrol and Reficar have not been found liable under these proceedings.
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1.4. |
From 2017 until 2024 the Office of the Comptroller General has performed and reported on special and financial audits to Reficar concluding that Reficar’s financial statements from 2016 to 2023 do not reasonably represent the entity’s financial position as of the end of each year. This situation originates in the difference in interpretations, of Reficar and of the Comptroller General, concerning the applicable accounting principles. Historically, Reficar’s external and independent auditors have issued unqualified opinions on Reficar’s financial statements during and after the Project. As of the date of this annual report, such auditors have not informed Reficar that there has been any change to their opinions to the financial statements. As of the date of this annual report, to the best of Ecopetrol’s knowledge, the financial statements continue to fairly represent the financial and operational condition of the Company in all material aspects and its internal controls remain effective. |
As of the date of this annual report, the current Boards of Directors of Ecopetrol and Reficar are not part of the Comptroller General proceedings.
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The Attorney General’s Office investigations: |
Reficar was officially informed that the Attorney General’s Office had initiated four investigations related to the Project. As of the date of this annual report, all four investigations have been closed.
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2.1. |
Regarding the first of these investigations, on September 12, 2017, the Attorney General’s Office indicted certain former members of Reficar’s Board of Directors, as well as certain former officers of Reficar. The charges were related to the failure to fulfill some of their duties as administrators and/or for acting “ultra vires” in the exercise of their functions against: (i) Javier Genaro Gutiérrez (Ecopetrol CEO, 2007-2015); (ii) Felipe Laverde (Reficar General Counsel, 2009-March 2017); (iii) Pedro Rosales (Ecopetrol Downstream Executive Vice President, 2008-2015); (iv) Diana Constanza Calixto (Ecopetrol Head of the Corporate Finance Unit, 2009-2014), (v) Orlando José Cabrales (Reficar CEO, 2009-2012) and (vi) Reyes Reinoso Yánez (Reficar CEO, 2012-2016). The Attorney General’s Office closed the case against certain former members of Reficar’s Board of Directors and former officers of Reficar. |
On January 17, 2020, the Attorney General’s Office issued its judgment against Reyes Reinoso Yánez for acting “ultra vires” in the exercise of his functions promoting a special billing procedure without the due diligence required to protect Reficar’s resources. As for the other four individuals initially investigated, they were acquitted of the charges. Mr. Reinoso submitted an appeal against the decision, which was decided in favor of Reyes Reinoso Yánez and the other individuals that were under investigation. With this ruling, the process was formally closed.
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2.2. |
In the second investigation, on October 21, 2020, the Attorney General’s Office issued its judgment against a former employee of Reficar, Nicolas Isaksson Palacios, related to the failure to fulfill some of his duties for acting “ultra vires” in the exercise of his functions. The Attorney General’s Office closed the case against the rest of the former members of Reficar’s Board of Directors and the other Reficar employees. |
On October 31, 2022, the Attorney General’s Office dismissed the process pursuant to the applicable statute of limitation.
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2.3. |
On May 4, 2021, the Attorney General’s Office closed the third proceeding related to the increase of the budget of the Project, against former members of the Board of Directors and former employees of Ecopetrol considering, amongst others: (i) that the capital expenditure modifications that were approved during the execution of the Project were necessary and that the public servants who approved them acted in accordance with their duties, (ii) that the costs and schedule presented to Reficar by CBI were wrong, and (iii) if the capital expenditure modifications had not been approved, the mega-project could not have been completed. |
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On December 10, 2021, the Attorney General’s Office closed the fourth proceeding related to the findings included in the final report of the Project special audit carried out by the Office of the Comptroller General in 2016. The process was formally closed pursuant to the applicable statute of limitation. |
As of the date of this annual report, no member of Ecopetrol’s current management team, nor the current Boards of Directors of Ecopetrol or Reficar are subject to Attorney General’s Office processes and Ecopetrol is not aware of any allegations related to acts of corruption, bribery or fraud in connection therewith.
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The Prosecutor’s Office investigations: |
The Prosecutor’s Office has been conducting the following legal proceedings in which Ecopetrol S.A. has been recognized as a victim:
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3.1 |
Between July 25 and August 2, 2017, the Prosecutor’s Office indicted the following individuals with charges, the majority of which are related to offenses against the public administration and illegal interest in the execution of agreements: (i) Orlando José Cabrales Martínez (Reficar CEO, 2009-2012); (ii) Reyes Reinoso Yánez (Reficar CEO, 2012-2016); (iii) Felipe Laverde Concha (Reficar General Counsel, 2009-March 2017); (iv) Pedro Alfonso Rosales Navarro (Ecopetrol S.A. Downstream Executive Vice President, 2008-2015); (v) Masoud Deidehban (CBI Executive Project Director); (vi) Phillip Asherman (CBI CEO) and (vii) Carlos Lloreda (Reficar’s statutory auditor from 2013-2015). The arraignment hearing began on May 30, 2018 and concluded on August 22, 2019. |
The Prosecutor’s Office made public the factual basis for such charges. On May 9, 2017, Ecopetrol’s Audit and Risk Committee retained a U.S.-based outside law firm to commence a third-party investigation into the matters set forth in the Prosecutor’s Office announcement. The results were presented in December 2017 to Ecopetrol’s Audit and Risk Committee. This investigation concluded that to date there has been no evidence of possible unlawful acts that affect Ecopetrol’s internal control over the financial reporting of the Company, on the allegations made by the Prosecutor’s Office.
The preparatory trial hearing took place between November 25, 2019 and February 2, 2024. The trial hearings are concluded and we expect a first-instance decision in 2025.
As of the date of this annual report, no member of Ecopetrol’s current management team, nor the current Boards of Directors of Ecopetrol or Reficar are subject to this process.
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3.2 |
On October 22 and 23, 2018, the Prosecutor’s Office indicted the following individuals with charges related to improper management and obtaining false public documents: Javier Genaro Gutiérrez Pemberthy (Ecopetrol S.A. CEO, 2007-2015), Reyes Reinoso Yánez (Reficar CEO, 2012-2016), Pedro Alfonso Rosales Navarro (Ecopetrol S.A. Downstream Executive Vice President, 2008-2015), and Diana Constanza Calixto Hernández (Ecopetrol S.A. Head of the Corporate Finance Unit, 2009-2014). In the arraignment hearing that took place on August 5, 2019, Ecopetrol and Reficar were recognized as victims. |
The Prosecutor’s Office made public the factual basis of the charges, which is based on the theory that the indicted directors hid necessary information from Ecopetrol’s Board of Directors before the approval of amendment No. 3 of the internal budget of the project (Control de Cambio No. 3).
The trial hearing commenced on October 28, 2024. During the hearing, defense attorneys sought the dismissal of the investigation, citing the expiration of the statute of limitations for the criminal action. However, the presiding judge denied the request. The defense attorneys subsequently filed appeals. On December 10, 2024, the Superior Court of Bogotá upheld the lower court’s decision, ordering the continuation of the oral trial.
As of the date of this annual report, the oral trial remains ongoing.
No member of the current management team of Ecopetrol, nor the current Boards of Directors of Ecopetrol or Reficar are part of the process.
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3.3 |
On March 18, 2019, the Prosecutor’s Office indicted the following individuals with charges related to entering into agreements without compliance with legal requirements: Orlando José Cabrales Martínez (Reficar CEO, 2009-2012) and Felipe Castilla (Reficar CEO, 2009). The arraignment hearing took place on January 27, 2020. |
The Prosecutor’s Office made public the factual basis of the charges, which is based on the theory that hiring FPJVC as the project manager consultant of the Project through a sole source process violated the objective selection principle.
On May 9, 2022, the judge found the indicted citizens guilty and condemned them to 64 months of prison. On August 18, 2022, the verdict was read, and the defense appealed.
On October 19, 2023, the Criminal Chamber of the Superior Court of Bogotá upheld the initial verdict. Attorneys representing the convicted parties subsequently lodged an extraordinary appeal in cassation before the Supreme Court of Justice challenging this ruling. On March 5, 2025, the Supreme Court of Justice declared the proceeding against Orlando José Cabrales Martínez—regarding the execution of a contract without compliance with legal requirements—terminated, on the grounds that the action was barred due to the defendant’s death, which extinguished the cause of action. A decision remains pending on the cassation claim filed by Felipe Castilla Canales. As of the date of this annual report, there have been no significant updates to the appeal process.
As of the date of this annual report, Ecopetrol and Reficar have no knowledge of any legal proceeding in the United States regarding the project.
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3.4 |
On April 24, 2018, the Prosecutor’s Office indicted Nicolás Isaksson, former employee of Reficar, with alleged charges for offenses against the public administration and illegal interest in the execution of certain agreements. The criminal action is currently suspended until December 2025, due to the application of a plea agreement ( principio de oportunidad ). |
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4. |
Arbitration Tribunal |
On March 8, 2016, Reficar filed a Request for Arbitration before the International Chamber of Commerce (the “ICC”), against Chicago Bridge Iron Company N.V., CBI UK Limited, and CBI Colombiana S.A. (jointly “CBI”) concerning a dispute related to the EPC contract entered into by and between Reficar and CBI for the expansion of the Cartagena refinery in Cartagena, Colombia. Reficar was the claimant in the ICC arbitration and seeked no less than USD 2 billion in damages plus lost profits.
On May 25, 2016, CBI filed its Answer to the Request for Arbitration and Counterclaim for approximately USD 106 million and COP 324,052 million. On June 27, 2016, Reficar filed its reply to CBI’s counterclaim denying and disputing the declarations and relief requested by CBI. On April 28, 2017, CBI submitted its Statement of Counterclaim increasing its claims to approximately USD 116 million and COP 387,558 million. On March 16, 2018, CBI submitted its Exhaustive Statement of Counterclaim further increasing its claims to approximately USD 129 million and COP 432,303 million (including in each case interest), and also filed its Exhaustive Statement of Defense to Reficar’s claims. On this same date, Reficar filed its Exhaustive Statement of Claim seeking, among others, USD 139 million for provisionally paid invoices under the Memorandum of Agreement(“MOA”) and Project Invoicing Procedure (“PIP”) Agreements and the EPC Contract.
On June 28, 2019, CBI submitted its Reply to the Non-Exhaustive Statement of Defense to Counterclaim increasing its claims to approximately USD 137 million and COP 503,241 million (including in each case interest, respectively). On this same date, Reficar filed its Reply to CBI’s Non-Exhaustive Statement of Defense and its Exhaustive Statement of Defense to CBI’s counterclaim, updating its claim for provisionally paid invoices under the MOA and PIP Agreements and the EPC Contract to approximately USD 137 million.
In January 2020, McDermott International Ltd, formerly McDermott International Inc. (hereinafter “McDermott”), CBI’s parent company, filed for bankruptcy and announced that it would initiate a reorganization plan pursuant to Chapter 11 of the United States Bankruptcy Law. In response to this situation, Reficar implemented actions to protect its interests and is being advised by a group of experts with whom it continued to analyze other available measures under these new circumstances.
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On January 21, 2020, Comet II B.V., the successor in interest to Chicago Bridge Iron Company N.V., commenced a bankruptcy case under Chapter 11 of the United States Code in the United States Bankruptcy Court for the Southern District of Texas. Upon the bankruptcy filing, an automatic stay of the commencement or continuation of any action or proceeding, or the enforcement of any judgment or award, against Comet II B.V. became effective, staying the arbitration against Comet II B.V. On January 23, 2020, Comet II B.V. obtained an order from the Bankruptcy Court permitting it to, in its discretion, modify the automatic stay to permit it to proceed with litigation or other contested matters. On March 14, 2020, the Bankruptcy Court entered an order confirming a plan of reorganization, and the order provides for the stay against the arbitration to end upon the earlier of the effective date of the plan and August 30, 2020.
As a consequence of the bankruptcy filing, the arbitration was stayed until July 1, 2020, as described below.
In respect of the arbitration involving Reficar, the confirmation order provided that the proper forum for adjudication of the merits of the arbitration is an International Tribunal under the arbitration rules of the International Chamber of Commerce, the arbitration claims would not be subject to estimation in the Bankruptcy Court, and the stay would not be violated if the parties discuss logistical items with the International Chamber of Commerce tribunal or each other. The order reserved all rights and arguments of the parties related to the arbitration schedule, hearing location, and arbitration logistics and recognizes that, without waiving any arguments, including but not limited to the Debtors’ objections to alternative hearing locations and long gap(s) between hearing dates. On June 30, 2020, McDermott notified the relevant parties of the occurrence of the effective date of the plan of reorganization, and thus the stay on the arbitration was lifted on July 1, 2020.
On May 6, 2020, the Superintendence of Companies ordered the liquidation of CBI Colombiana S.A., a respondent in the arbitration against CBI. On October 22, 2020, Reficar submitted a proof of claim in the liquidation proceeding to seek recognition as a creditor of CBI Colombiana S.A. for the amounts of its claims in the arbitration. On January 15, 2021, the liquidator of CBI Colombiana S.A. accepted Reficar’s petition.
On September 22, 2020, the Tribunal scheduled the commencement of the hearing in May 2021.
Between May 17, 2021, and June 16, 2021, the first two blocks of the merits hearing took place. On June 16, 2021, the Tribunal ordered the parties to submit two post-hearing briefs, the first one on October 15, 2021, and the second one on November 5, 2021. Additionally, the Tribunal scheduled the hearing for the parties to present their closing arguments on November 18 and 19, 2021.
The post-hearing briefs were submitted on October 22, 2021, and November 10, 2021, respectively and on November 18, 2021, the parties presented their closing arguments.
Later, on December 20, 2021, Reficar filed its Statement on Costs, and on February 11, 2022, CBI filed its Statement on Costs.
On June 7, 2023, Reficar was notified of the decision of the international arbitral tribunal (the “Award”) that resolved the dispute in relation to the EPC Contract. The arbitral tribunal ordered CBI to pay USD 1,008 million plus interest accruing from December 31, 2015 until paid, in favor of Reficar, as follows: (i) USD 845.4 million in damages for exceeding costs, (ii) USD 152.75 million in damages for delays, and (iii) USD 10.3 million in damages for corrections of defects.
On June 8, 2023, Chicago Bridge Iron Company N.V. (now McDermott Holdings B.V.) and CBI UK Limited filed an action to vacate the Award before the U.S. District Court for the Southern District of New York, seeking denial of its recognition and enforcement in the United States.
On August 4, 2023, Reficar replied to the request for annulment and in turn, requested its confirmation. Moreover, on September 22, 2023, the Company filed its reply memorandum concerning the request for confirmation of the Award.
On September 8, 2023, McDermott publicly announced that it would initiate financial restructuring proceedings for its subsidiaries in the United Kingdom and the Netherlands, CBI UK Limited and Chicago Bridge Iron Company N.V. respectively.
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On October 10, 2023, Chicago Bridge Iron Company N.V. and CBI UK Limited filed a petition before the Texas Bankruptcy Judge to initiate a procedure for recognition of financial restructuring processes abroad, known as Chapter 15 of the Bankruptcy Code of the United States of America. Specifically, they requested recognition of the financial restructuring processes that were announced by McDermott International on September 8, 2023. The action to vacate and the request of confirmation of the Award – which would determine the possibility of executing and therefore collecting the amounts decreed – was temporarily suspended by order of the bankruptcy judge overseeing the matter in the State of Texas.
On November 29, 2023, a hearing was held to request the lifting of the temporary suspension, however, the judge overseeing the matter in the State of Texas did not grant the request and determined that when new facts are available, Reficar may file another request to lift the provisional suspension measure.
On February 27, 2024, Reficar was notified of the decision of the Court of the United Kingdom in which it was determined that the financial restructuring plan of CBI UK Limited was approved by the Court of the United Kingdom.
With respect to the reorganization process initiated by Chicago Bridge Iron N.V. in the Netherlands on September 8, 2023. On February 25, 2024, an independent restructuring expert appointed by the Court voted on an alternative reorganization plan under which Refinería de Cartagena would receive, among others, certain shares of McDermott.
On March 21, 2024, Reficar was notified of the decision by the District Court of Amsterdam to approve the alternative financial restructuring plan of Chicago Bridge Iron Company N.V. Under the plan, which was presented by an independent expert appointed by the court, Reficar received convertible preferred shares representing 19.9% of the share capital of McDermott, holding company of a group of entities with presence in more than 54 countries which specialize in engineering services for the energy industry and low-carbon solutions, and that includes CBI N.V. These shares do not grant Reficar the right to vote, designate a member of its board of directors, nor exercise control over McDermott.
On March 22, 2024, the United States Bankruptcy Judge for the United States Bankruptcy Court for the Southern District of Texas issued (1) an order granting verified petition for (a) recognition of foreign proceedings in England, (b) recognition of foreign proceedings in the Netherlands, and (2) the order recognizing and giving full force and effect to (a) the restructuring plan and the order of the English Court sanctioning the restructuring plan, and (b) the parallel restructuring plans (the “WHOA Plans”) and the order of the Dutch Court sanctioning the WHOA Plans. The effective date and the consummation date of the restructuring was March 25, 2024. On March 31, 2024, because of the aforementioned plans, Reficar became the beneficiary of (i) USD 70 million and USD 95 million draw under two different letters of credits; and (ii) USD 9 million corresponding to the reimbursement of legal fees.
As of September 30, 2024, Reficar carried out the financial valuation of the shares for the amount of USD 234,525,440, which represents an increase in the financial assets account for Refinería de Cartagena compared to a lower value of the property, plant and equipment.
On December 9, 2024, McDermott announced that it has completed the sale of its storage business (CBI’s tank business) to a consortium of financial investors led by Mason Capital Management. Under the terms of the deal announced on October 7, 2024, McDermott would receive USD 475 million of pre-tax income and transaction expenses. Pursuant to the terms of McDermott’s credit agreement, the proceeds from the sale would be used to repay CBI’s existing tank business term loan, secure certain McDermott letters of credit in cash, and reduce an existing McDermott term loan.
On January 16, 2025, Refinería de Cartagena S.A.S. was notified of the decision issued by the Court of the Southern District of New York, by which it denied the request presented by Chicago Bridge Iron Company N.V., CBI UK Limited to vacate the arbitration award dated June 2, 2023 in relation to the EPC Contract (Engineering, Procurement, and Construction Contract) executed between Reficar and CBI for the expansion and modernization of the refinery located in the city of Cartagena, accordingly resolving the disputes between Reficar and Chicago Bridge Iron Company N.V., CBI UK Limited and CBI Colombiana S.A. Consequently, the arbitration award in question was confirmed in its entirety.
Ecopetrol continuously monitors the operations of McDermott to identify any potential changes in the fair value of the investment and/or risk premiums associated with the valuation model.
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Requirements related to VAT by the National Tax Authority of Colombia
Refinería de Cartagena and Ecopetrol S.A. received customs requirements REA 211, REA 264 and REA 289, respectively, from the National Tax Authority of Colombia (DIAN) in 2025. The National Tax Authority of Colombia (DIAN) proposed an official corrective liquidation and a penalty on certain gasoline import filings for the period of 2022 to 2024, due to the failure to pay VAT on these filings. Refinería de Cartagena and Ecopetrol consider that their fillings were prepared in accordance with current customs legislation and are preparing their response to the requirements indicated by the National Tax Authority of Colombia (DIAN).
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6. |
Shareholder Information |
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6.1 |
Shareholders’ General Assembly |
Our Shareholders General Assembly was held on March 28, 2025, and the following matters were discussed and approved, among others:
| ● | The plan for distribution of the Company’s profits, which establishes the distribution of an ordinary dividend per share of COP 214, as follows: payment of dividends to minority shareholders to be made in two equal installments on April 4, 2025 and April 29, 2025; and the payment to the majority shareholder will be made in three installments as follows: i) COP 2,200,000,000,000 on April 4, 2025, ii) COP 2,300,000,000,000 on April 29, 2025, and iii) COP 3,286,344,378,880 on June 27, 2025. |
| ● | The establishment of a special reserve of COP 16,635,492,094,077 in order to support Ecopetrol S.A.’s financial sustainability and flexibility in the execution of its strategy. |
| ● | Election of Deloitte Touche S.A.S., as the statutory auditor for the 2025 – 2029 period and assignment of their remuneration. |
| ● | Election of Board Members for the 2025 - 2029 period |
| ● | Approval of amendments to the Internal Regulations of the General Shareholder´s Meeting. |
| ● | Approval of amendments to the succession policy for the members of the Board of Directors. |
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6.2 |
Dividend Policy |
In 2018, the Board of Directors approved a dividend policy consisting of the ordinary distribution of between 40% and 60% of the adjusted net income of the Company of each fiscal year. For this purpose, the Board of Directors shall assess overall delivery against the Company’s financial targets, as well as the macroeconomic environment, projected cash requirements for delivering on our Business Plan and strategy, while maintaining appropriate financial flexibility in keeping the Company’s debt metrics in line with an investment grade rating. The policy does not preclude the distribution of extraordinary dividends above the 40% to 60% range, under exceptional circumstances and with due consideration of the above criteria. The maximum amount to be distributed is the profits available to shareholders (net income after release and appropriation for legal, fiscal and occasional reserves).
Pursuant to Colombian law, dividend distribution to our shareholders must be approved by a 78% majority of the shares represented in the corresponding General Shareholders Assembly. In the absence of this special majority, at least 50% of the net profits must be distributed.
On March 28, 2025, our shareholders at the ordinary General Shareholders Assembly approved an ordinary dividend of COP 214 per share for the fiscal year ended December 31, 2024; based on the number of outstanding shares as of December 31, 2024. The payment is expected to be made in two different installments on April 4 and April 29, 2025 to our minority shareholders. The payment to the majority shareholder will be made in three installments on April 4, April 29, and June 27, 2025.
On March 22, 2024, our shareholders at the ordinary General Shareholders Assembly approved an ordinary dividend of COP 278 per share for the fiscal year ended December 31, 2023 and an extraordinary dividend of COP 34 per share for the above mentioned fiscal year, amounting to a total of COP 312 per share; both based on the number of outstanding shares as of December 31, 2023. The payment was made in two different installments on April 3, 2024 and June 26, 2024 to our minority shareholders. The payment to the majority shareholder was made before December 31, 2024, taking into account the payment schedule of the balance of the Fuel Price Stabilization Fund (FEPC) corresponding to its 2023 accumulation.
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On March 30, 2023, our shareholders at the ordinary General Shareholder’s Assembly approved an ordinary dividend of 60% of our net income for the fiscal year ended December 31, 2022 amounting to COP 20,023,830 million, or COP 487 per share, and an extraordinary dividend of 13% of our net income for the above mentioned fiscal year, amounting to COP 4,358,369 million or COP 106 per share; both based on the number of outstanding shares as of December 31, 2022. The payment was made in three different installments on April 27, September 28 and December 21, 2023 to our minority shareholders amounting COP 2,806,020 and for the majority shareholder, the total dividend payment was offset against the accounts receivable form the FEPC for the amount of COP 21,576,179 million.
On March 30, 2022, our shareholders at the ordinary General Shareholders’ Assembly approved an ordinary dividend of 59.8% of our net income for the fiscal year ended December 31, 2021 amounting to COP 9,991,356 million, or COP 243 per share, and an extraordinary dividend of 9.1% of our net income for the abovementioned fiscal year, amounting to COP 1,521,317 million, or COP 37 per share; both based on the number of outstanding shares as of December 31, 2021. The payment was made on April 21, 2022 to our minority shareholders and no later than September 30, 2022 to the majority shareholder.
On June 17, 2022, our shareholders at an extraordinary General Shareholders’ Assembly, approved: (i) to extend the deadline for the payment of dividends to the Nation, originally approved in the General Shareholders’ Assembly of March 30, 2022, from September 30 to October 31, 2022, and (ii) to distribute the Company’s special reserve that had been approved in the General Shareholder’s Assembly held on March 30, as an extraordinary dividend of COP 168. The payment of the dividend for minority shareholders was made in a single payment on June 30, 2022, and for the majority shareholder, the total dividend payment was offset against the accounts receivable from the FEPC.
Ecopetrol S.A. S.A. is required to maintain legal reserves equal to 50% of its subscribed capital. If the legal reserves are less than 50% of subscribed capital, we intend to allocate 10% of net income to our legal reserves on an annual basis until our legal reserves meet the required level.
See section Financial Review—Liquidity and Capital Resources—Dividends .
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|
6.3 |
Market and Market Prices |
Registration and Transfer of Shares
Under Colombian law, transfers of shares must be registered on the issuer’s stock ledger. Only those holders registered on the stock ledger are considered by law as shareholders. Ecopetrol S.A.’s shares are in electronic form, other than those shares held by the Nation, which are in physical form.
Transfers of electronic shares is required to be negotiated through the Colombian Stock Exchange. In Colombia, only brokers called Sociedades Comisionistas de Bolsa are authorized to make the transfer of shares through the Colombian Stock Exchange. The transfer of shares is registered in the Centralized Security Deposit ( Depósito Centralizado de Valores ) or DECEVAL, through the relevant stockbrokers. DECEVAL records the share transfer on its systems, to make the corresponding registration in the issuer stock ledger.
Under Colombian legislation, if a transfer of shares has a value equivalent to or higher than 66,000 UVR (the UVR was COP 376.78 as of December 31, 2024) it must be made through the Colombian Stock Exchange (BVC) if the shares are registered with the BVC. Otherwise, shareholders can freely negotiate a transfer of shares.
Nevertheless, pursuant to Decree 2555 of 2010 Article 6.15.1.1.2 the following transfers are not required to be performed through the BVC:
| ● | Transfers between shareholders who are considered to be the same beneficial owner; |
| ● | Transfer of shares owned by financial institutions, under supervision of the SFC, that are in a liquidation process; |
| ● | Repurchases of shares by the issuer; |
| ● | Property delivered in lieu of payment, or payment of money or other valuable property, different than the amount owed or demanded, in exchange for the payment of the debt; |
| ● | Transfer of shares made by the Nation or the Financial Institutions Warranty Fund ( Fondo de Garantías de Instituciones Financieras ) or FOGAFIN; |
| ● | Transfer of shares issued abroad by Colombian companies, provided they take place outside Colombia; |
| ● | Transfer of shares issued by foreign companies, offered through a public offering in Colombia, provided that they take place outside Colombia; |
| ● | Transfers made by the Central Counterparty Risk Chamber, in accordance with the provisions of paragraph 2 of Article 2.13.1.1.1. of this Decree; and |
| ● | Any other transaction specifically authorized by the SFC to take place outside the BVC. |
For the purposes described above, multiple transfer transactions made within one hundred twenty (120) calendar days, between the same parties on shares of the same issuer and under similar conditions, are considered a single transfer.
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6.4 |
Description of Ecopetrol Registered Debt Securities |
Ecopetrol S.A. has issued the following classes of registered notes under an indenture (the Indenture), dated as of July 23, 2009, and amended as of June 26, 2015, between the Company and the Bank of New York Mellon, as trustee:
| 1. | 8.625% Notes due 2029 |
| 2. | 6.875% Notes due 2030 |
| 3. | 4.625% Notes due 2031 |
| 4. | 7.750% Notes due 2032 |
| 5. | 8.875% Notes due 2033 |
| 6. | 8.375% Notes due 2036 |
| 7. | 7.375% Notes due 2043 |
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| 8. | 5.875% Notes due 2045 |
| 9. | 5.875% Bonds due 2051 |
Please refer to Exhibits 4.10, 4.11, 4.12, 4.13, 4.14, 4.15, 4.16, 4.17, 4.18, 4.19, and 4.38 to this Annual Report for the information relating to these debt securities required by Item 12.A of Form 20 - F.
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6.5 |
Description of Ecopetrol ADRs |
Fees and Charges That a Holder of Our ADSs May Have to Pay, Either Directly or Indirectly
JPMorgan Chase Bank, N.A., our Depositary, may charge each person to whom ADSs are issued, including, without limitation, issuances against deposits of shares, issuances in respect of share distributions, rights and other distributions, issuances pursuant to a stock dividend or stock split declared by us or issuances pursuant to a merger, exchange of securities or any other transaction or event affecting the ADSs or Deposited Securities, and each person surrendering ADSs for withdrawal of Deposited Securities in any manner permitted by the Deposit Agreement or whose ADSs are cancelled or reduced for any other reason, USD 5.00 for each 100 ADS (or any portion thereof) issued, delivered, reduced, cancelled or surrendered, as the case may be. The Depositary may sell (by public or private sale) sufficient securities and property received in respect of a share distribution, rights and/or other distribution prior to such deposit to pay such charge.
The Depositary collects its fees for issuance and cancellation of ADSs directly from investors depositing common shares or surrendering ADSs for the purpose of withdrawal or from intermediaries acting for them. The Depositary collects fees for making distributions to investors by deducting those fees from the amounts distributed or by selling a portion of distributable property to pay the fees. The Depositary may collect its annual fee for Depositary services by deduction from cash distributions, or by directly billing investors, or by charging the book-entry system accounts of participants acting for them. The Depositary may generally refuse to provide services to any holder until the fees and expenses owing by such holder for those services or otherwise are paid.
The following additional charges may be incurred by holders of ADRs, by any party depositing or withdrawing common shares or by any party surrendering ADSs and/or to whom ADSs are issued (including, without limitation, issuance pursuant to a stock dividend or stock split declared by us or an exchange of stock regarding the ADRs or the Deposited Securities or a distribution of ADSs), whichever is applicable:
| ● | A fee of USD 0.05 or less per ADS for any cash distribution made pursuant to the Deposit Agreement; |
| ● | A fee for the distribution of securities (or the sale of securities in connection with a distribution), such fee being in an amount equal to the fee for the execution and delivery of ADSs which would have been charged as a result of the deposit of such securities (treating all such securities as if they were common shares) but which securities or the net cash proceeds from the sale thereof are instead distributed by the Depositary to those holders of ADRs entitled thereto; |
| ● | An aggregate fee of up to USD 0.05 per ADS per calendar year (or portion thereof) for services performed by the Depositary in administering the ADRs (which fee may be charged on a periodic basis during each calendar year and shall be assessed against holders of ADRs as of the record date or record dates set by the Depositary during each calendar year and shall be payable in the manner described in the next succeeding provision); |
| ● | A fee for the reimbursement of such fees, charges and expenses as are incurred by the Depositary and/or any of the Depositary’s agents (including, without limitation, the custodian and expenses incurred on behalf of holders of ADRs in connection with compliance with foreign exchange control regulations or any law or regulation relating to foreign investment) in connection with the servicing of our common shares or other Deposited Securities, the sale of securities (including, without limitation, Deposited Securities) and the delivery of Deposited Securities or otherwise in connection with the Depositary’s or its custodian’s compliance with applicable law, rule or regulation (which fees and charges shall be assessed on a proportionate basis against registered holders of ADRs as of the record date or dates set by the Depositary and shall be payable at the sole discretion of the Depositary by billing such holders of ADRs or by deducting such charge from one or more cash dividends or other cash distributions); |
| ● | Stock transfer or other taxes and other governmental charges; |
| ● | SWIFT, cable, telex and facsimile transmission and delivery charges incurred at the request of a holder of ADRs; |
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| ● | Transfer or registration fees for the registration of transfer of Deposited Securities on any applicable register in connection with the deposit or withdrawal of Deposited Securities; and |
| ● | In connection with the conversion of foreign currency into U.S. dollars, the Depositary shall deduct out of such foreign currency the fees, expenses and other charges charged by it or the Depositary’s agent (which may be a division, branch or affiliate) so appointed in connection with such conversion. The Depositary and/or the Depositary’s agent may act as principal for such conversion of foreign currency. Such charges may at any time and from time to time be changed by agreement between us and the Depositary. |
| ● | We will pay all other charges and expenses of the Depositary and any agent of the Depositary (except the custodian) pursuant to agreements from time to time between us and the Depositary. The fees described above may be amended from time to time. |
Fees and Other Direct and Indirect Payments Made by the Depositary to Us
Our Depositary has agreed to reimburse us for certain expenses we incur that are related to establishment and maintenance of the ADR program, including investor relations expenses and exchange application and listing fees. In 2022, reimbursements were made in the amount of approximately USD 1,200,000. In 2023, reimbursements were made in the amount of approximately USD 2,591,158. In 2024, reimbursements were made in the amount of approximately USD 2,705,924.38. For more information, see section Recent Developments-Temporal reduction in the conversion cost of Ecopetrol´s ADR .
Other
Please refer to Exhibit 2.1 to this annual report for the remaining information relating to our American Depository Shares required by Item 12.D of Form 20-F.
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6.6 |
Taxation |
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6.6.1 |
Colombian Tax Considerations |
The following is a general description of the Colombian tax considerations for investments in common shares in Colombia or for the purchase of ADSs, in a foreign securities market. This description is based on applicable law in effect as of the date of this annual report is issued, which may be subject to changes.
Prospective purchasers of common shares or ADSs should consult their own tax advisors for a detailed analysis of the tax consequences in Colombia, resulting from the acquisition, ownership and disposition of common shares or ADSs.
General Rules
Colombian entities and individuals who are deemed to be residents within the Colombian national territory for Colombian tax purposes are subject to Colombian income tax on their worldwide income. Foreign entities and individuals who are not deemed to be residents in Colombia, are subject to income tax in Colombia only with respect to their Colombian-source income, which is generally defined as income obtained from (i) the rendering of services inside Colombian territory, (ii) the exploitation of tangible and intangible assets in Colombia, and (iii) the sale of tangible or intangible assets that are located inside Colombian territory at the time of the sale among others. Double taxation treaties signed by Colombia, if applicable, may provide for special regulations regarding income taxation. Until 2018, foreign residents deriving income through a permanent establishment were subject to Colombian income tax on the Colombian source income attributable to their permanent establishment only. As of 2019, foreign tax residents deriving income through a permanent establishment will be subject to Colombian income tax on their global source income attributable to their permanent establishment in Colombia.
Dividends paid by Colombian companies, as well as profits distributed by branches/permanent establishments of foreign entities, are deemed as a dividend and as Colombian income. However, the applicable tax depends on an imputation system set forth in Articles 48 and 49 of the Colombian Tax Code. For more information related to the Colombian dividends tax regime, see Risk Review—Risk Factors—Risks Related to Colombia’s Political and Regional Information.
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As mentioned above, Law 1819 of 2016 created a new dividends tax that applies on all dividend distributions to Colombian individuals or to any type of non-resident shareholder, absent any specific treaty or exception, regardless that dividends are paid from taxed or untaxed profits. According to the aforementioned law, dividend payments made to foreign shareholders out of profits accrued at the corporate level as of 2017 were subject to a 5% withholding. That rate was subsequently modified by Law 1943 of 2018, which increased it to 7.5% and extended dividend taxation to intercompany dividends between Colombian resident companies (with certain exceptions).
From fiscal year 2022 onwards, a withholding tax on dividends paid applies as follows:
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(i) |
Dividends paid to non-resident shareholders: (i) a 10% dividend tax on dividends distributed from profits taxed at the corporate level (except that dividends paid to non-resident shareholders out of profits taxed at the corporate level prior to and including December 31, 2016, are not subject to this tax); or (ii) 35% withholding tax rate on dividends distributed from profits not taxed at the corporate level, plus an additional 10% dividend tax after applying the initial 35% withholding tax rate (i.e., 41.5% in 2022). |
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(ii) |
For Colombian individuals: dividend income in excess of 300 UVT are taxed at a 10% rate, in respect of profits taxed at the corporate level; and 31% withholding tax rate on dividends distributed from profits not taxed at the corporate level, plus an additional 10% dividend tax after applying the initial 35% withholding tax rate. |
From fiscal year 2023 onwards, dividend taxation will be as follows:
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(i) |
Dividends paid to non-resident shareholders: (i) a 20% dividend tax on dividends distributed from profits taxed at the corporate level (except that dividends paid to non-resident shareholders out of profits taxed at the corporate level prior to and including December 31, 2016 are not subject to this tax); or (ii) 35% withholding tax rate on dividends distributed from profits not taxed at the corporate level, plus additional 20% dividend tax after applying the initial 35% withholding tax rate. |
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(ii) |
For Colombian individuals: dividend income in excess of 1,090 UVT are taxed at progressive rates up to 39% in respect of profits taxed at the corporate level, and 35% withholding tax rate on dividends distributed from profits not taxed at the corporate level, plus an additional dividend tax (at the aforementioned progressive rates) after applying the initial 35% withholding tax rate. Additionally, resident individuals may take a marginal 19% discount on the portion of dividend income exceeding 1,090 UVT in the same taxable period. |
Relief or reduced tax rates may apply under an applicable treaty to avoid double taxation, but the application of any such rules must be analyzed on a case-by-case basis.
For Colombian tax purposes, an individual is considered a Colombian resident when he/she meets any of the following criteria:
|
(i) |
He/she remains in Colombia continuously or discontinuously for more than 183 calendar days within any given 365-consecutive-day term; |
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(ii) |
He/she is related to the Colombian Government’s foreign service or to individuals who are in the Colombian Government’s foreign service and who, by virtue of the Vienna Conventions on diplomatic and consular relations, are exempted from taxes during the time of their service; or |
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(iii) |
He/she is a Colombian national and meets one or more of the following: |
| ● | Has a spouse or permanent companion, or dependent children, who are tax residents in Colombia, or |
| ● | 50% or more of his or her total income is Colombian source income, or |
| ● | 50% or more of his or her assets are managed in Colombia, or |
| ● | 50% or more of his or her assets are deemed to be located or possessed in Colombia, or |
| ● | Has failed to provide proof of residency in another country (different from Colombia) upon previous official request by the Colombian tax office, or |
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· |
He/she has a tax residency in a country considered by the Colombian Government to be a low tax jurisdiction or a tax haven. |
Law 1739 of 2014 clarifies that Colombian nationals who otherwise falls under point (iii) above will not be deemed tax residents if meet any of the following conditions:
|
(i) |
If more than 50% of his or her annual income has its source in the jurisdiction where he or she is domiciled and whose country of domicile is not Colombia. |
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(ii) |
If more than 50% of his/her assets are located in the jurisdiction where he or she is domiciled and whose country of domicile is not Colombia. |
For purposes of Colombian taxation, an entity is deemed to be a “national” or a “Colombian entity” and, therefore, subject to taxation in Colombia on its worldwide income, if it meets any of the following criteria:
|
(i) |
It has its place of effective management, in Colombia during the corresponding year or taxable period; |
|
(ii) |
It has its main domicile in the Colombian territory; or |
|
(iii) |
It has been incorporated in Colombia, in accordance with Colombian laws. |
Pursuant to the Colombian Tax Code, a foreign company or non-resident individual has a permanent establishment in Colombia when said company or individual performs activities in Colombia through: (i) a fixed place of business (i.e., branches, factories or offices), or (ii) an individual who is not an independent agent empowered to execute agreements on behalf of the foreign company. As noted above, until 2018 permanent establishments were considered Colombian taxpayers in connection with their Colombian source income. As of fiscal year 2019, foreign residents deriving income through a Colombian permanent establishment are subject to Colombian income tax on the worldwide income attributable to the Colombian permanent establishment. A foreign company or entity will not be deemed to have a permanent establishment by the sole fact that it acts through a broker or any other independent agent provided that such persons act in the ordinary course of their business. However, if the independent agent conducts all or nearly all its activities on behalf of that company, and the commercial or financial conditions established between independent enterprises, that agent will no longer be considered an independent agent for these purposes. In addition, passive-income generating activities, such as dividends, royalties and interests, typically do not qualify as entrepreneurial and are not deemed to create permanent establishments.
Tax Treatment of a Non-Colombian Entity and a Non-Resident Individual of Colombia Who Purchases an ADS in a Foreign Securities Market
Dividends
As a general rule, dividends paid to foreign companies, foreign entities or non-resident individuals who are investing in ADSs which underlying assets are Colombian shares are treated as Colombian-source income and are thus subject to Colombian income tax.
To avoid double taxation, dividends paid by Colombian entities are not subject to income tax at the shareholder level when they are paid out of corporate profits that have been previously taxed at the corporate level. For fiscal years 2017 and 2018, a withholding tax on dividends was triggered for dividends paid to non-resident shareholders. Withholding tax rates on dividends were as follows: (i) a 5% dividend tax for dividends distributed out of profits already taxed at the company’s level; (ii) 35% withholding tax rate for dividends distributed out of profits that were not taxed at the company’s level, plus a 10% dividend tax rate after having applied and deducted the initial 35% withholding. Note that dividends paid to non-resident shareholders out of profits taxed at the corporate level until December 31, 2016, are not subject to the aforementioned 10% dividend tax or any other income tax. As of 2021, the withholding tax rates applicable to dividends paid to resident companies and non-resident shareholders (companies and individuals) are: i) a 7,5% or 10% tax on dividends, as applicable, distributed from profits taxed at the corporate level (except that dividends paid to non-resident shareholders out of profits taxed at the corporate level prior to and including December 31, 2016, are not subject to this tax); and (ii) 35% withholding tax rate on dividends distributed from profits not taxed at the corporate level, plus an additional 7.5% or 10%, as applicable, dividend tax after applying the initial 35% withholding tax rate.
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From the fiscal year 2023 and onwards, applicable tax rates on dividends paid to non-resident shareholders are as follows: (i) a 20% dividend tax on dividends distributed from profits taxed at the corporate level (except that dividends paid to non-resident shareholders out of profits taxed at the corporate level prior to and including December 31, 2016 are not subject to this tax); or (ii) 35% withholding tax rate on dividends distributed from profits not taxed at the corporate level, plus additional 20% dividend tax after applying the initial 35% withholding tax rate.
Further to the above, non-resident entities or non-resident individuals whose investment qualifies as portfolio investments (i.e., investing through a Foreign Funds Administration Account - FFAA) will be taxed upon distribution by means of a withholding tax mechanism. In this case, pursuant to Article 18-1 of the Colombian Tax Code, the applicable withholding tax rate on taxable dividends is 25%, assuming that the dividends cannot be attributed to a permanent establishment in Colombia belonging to the shareholder and were not subject to taxation at the corporate level. The abovementioned 10% or 20% dividend tax rates, as applicable, apply on the balance of dividends to be distributed to the shareholder investing through an FFAA, or on the gross amount in such cases the dividend is paid out of profits that were subject to taxation at the corporate level. These foreign shareholders subject to this withholding tax are not required to file an income tax return in Colombia.
Taxation of Capital Gains from the Sale of ADSs
Capital gains obtained from the sale of ADSs by non-Colombian entities, Colombian individuals who are non-residents in Colombia and foreign non-resident individuals, are not subject to income tax in Colombia, as such sale does not generate Colombian-source income to the extent that the ADSs are not deemed to be sourced in Colombia. If the holder of the ADSs who is a non-resident entity, a Colombian individual who is not a resident in Colombia or a foreign non-resident individual, decides to surrender the ADSs and withdraw the underlying common shares, it is arguable that such transaction does not generate a capital gain subject to income tax in Colombia. However, different interpretations may be adopted by the Colombian Tax Authorities on this matter.
Tax Treatment in Colombia of a Non-Colombian Entity and a Non-Resident Individual of Colombia Who Purchases Ecopetrol’s Shares in Colombia’s Securities Market.
Dividends
As a general rule, dividends paid to foreign companies, foreign entities, or to non-resident individuals in Colombia, who are investing in Colombian shares directly or through a FFAA, are treated as national-source income; thus, they are subject to Colombian income tax.
The dividend tax regime was modified and, as of 2022, is as follows:
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(i) |
Dividends paid to non-resident shareholders: (i) a 10% dividend tax on dividends distributed from profits taxed at the corporate level (except that dividends paid to nonresident shareholders out of profits taxed at the corporate level prior to and including December 31, 2016, are not subject to this tax); or (ii) 35% withholding tax rate on dividends distributed from profits not taxed at the corporate level, plus an additional 10% dividend tax after applying the initial 35% withholding tax rate (i.e., 41.5% in 2022). |
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(ii) |
Dividends paid to Colombian companies: (i) a 7.5% dividend tax on dividends distributed from taxed profits, or (ii) a 35% withholding tax on dividends distributed from untaxed profits, plus an additional 7.5% dividend tax on the balance of the dividend amount after the initial 35% withholding. |
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(iii) |
For Colombian resident individuals: dividend income in excess of 300 UVT is taxed at a rate of 10%, for fiscal years 2021 onwards in respect of profits taxed at the corporate level; and 35% withholding tax rate on dividends distributed from profits not taxed at the corporate level, plus an additional 10% dividend tax after applying the initial 35% withholding tax rate. |
From fiscal year 2023 onwards, dividend taxation will be as follows:
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(i) |
Dividends paid to non-resident shareholders: (i) a 20% dividend tax on dividends distributed from profits taxed at the corporate level (except that dividends paid to non-resident shareholders out of profits taxed at the corporate level prior to and including December 31, 2016 are not subject to this tax); or (ii) 35% withholding tax rate on dividends distributed from profits not taxed at the corporate level, plus additional 20% dividend tax after applying the initial 35% withholding tax rate. |
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|
(ii) |
For Colombian individuals: dividend income in excess of 1,090 UVT are taxed at progressive rates up to 39% in respect of profits taxed at the corporate level, and 35% withholding tax rate on dividends distributed from profits not taxed at the corporate level, plus an additional dividend tax (at the aforementioned progressive rates) after applying the initial 35% withholding tax rate. |
Non-resident entities or non-resident individuals whose investment qualifies as portfolio investment (i.e., investing through a FFAA), will be taxed upon distribution by means of the withholding tax mechanism. In this case withholding will apply at 25% on dividends that are distributed by the Colombian entity are not taxed at the corporate level. Pursuant to Article 18-1 of the Colombian Tax Code, assuming that the dividends cannot be attributed to a permanent establishment in Colombia belonging to the shareholder. These foreign shareholders subject to this withholding tax are not required to file an income tax return in Colombia, nevertheless those rules would not apply to foreign investments whereby the final beneficiary is a tax resident in Colombia who has control over such investments. This treatment was modified by Law 1943/2018 and Law 2010/2019. See section Financial Review—Effect of Taxes, Exchange Rate .
Variation, Inflation and the Price of Oil on our Results—Taxes—Taxes.
In addition to the above, the new dividend tax will apply at a 5% rate over dividends distributed from profits taxed at the corporate level. This treatment was modified by Law 1943 of 2018 and Law 2010 of 2019 (7.5% in 2019 and 10% from 2020 onwards). See section Financial Review—Effect of Taxes, Exchange Rate Variation, Inflation and the Price of Oil on our Results—Taxes .
Taxation of Capital Gains for the Sale of Shares
Pursuant to Article 36 - 1 of the Colombian Tax Code, capital gains derived from the sale of shares listed on the BVC and owned by the same beneficial owner, are deemed as non-taxable income in Colombia, provided that the shares sold during the same taxable year do not represent more than 10% (3% as of 2023) of the outstanding shares of the listed company. Pursuant to Section 1.6.1.13.2.19 of Regulatory Decree 1625 of 2016, sellers of shares are not required to file an income tax return for the transfer of securities that are listed in the National Registry of Securities and Issuers ( Registro Nacional de Valores y Emisores ) as long as the foreign investment is treated as a portfolio investment according to Article 3 of Decree 2080 of 2000 (currently compiled in Article 2.17.2.2.1.2 of Decree 1068 of 2015) and the abovementioned 10% (3% as of 2023) threshold is not surpassed.
If the abovementioned requirements are not met, the capital gain obtained in the sale of shares is subject to income tax or capital gains tax, under the following rules:
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(i) |
The gain or loss arising therefrom will be the difference between the sale price and the tax basis of the shares. As a general rule, the tax basis of shares is equal to the price paid for such shares (i.e., cost of acquisition). |
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(ii) |
The applicable tax rate and the withholding tax rate have to be determined on a case-by-case basis. Generally, if the shares have been owned for at least two years and qualify as fixed assets (i.e., they are not sold within their ordinary course of business), the profits from the sale will qualify as capital gains taxable at 15%; otherwise, profits will qualify as ordinary income, subject to a 33% income tax for fiscal year 2021 (2022 onwards – 35%). |
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Tax Treatment of Non-Residents Who Purchase Ecopetrol’s Shares in the BVC Market and Exchange Them for ADSs
Dividends
Payment of dividends by Colombian entities to foreign companies, foreign entities or to non-resident individuals who are investing in ADSs which underlying assets are Colombian shares or in Colombian shares directly are subject to the tax treatment described above.
Taxation on Capital Gains for the Sale of Shares
If the holder of the Colombian shares is a non-resident entity, a Colombian individual who is not a resident in Colombia or a foreign non-resident individual, and such holder decides to exchange such common shares for ADSs, it is arguable that such transaction should not generate a capital gain subject to income tax in Colombia. However, different interpretations may be adopted by the Colombian tax authorities on this matter. For instance, assuming that the exchange of securities is treated as a sale of Ecopetrol S.A.’s shares, the seller would be subject to the tax treatment described above in connection with the taxation of capital gains for the sale of shares. Absent any specific rules or regulations addressing this specific situation, a case-by-case analysis would be necessary.
Extraordinary Taxes Decreed Under Decree 175 of 2025
Decree 175 introduced tax measures intended to address the state of internal commotion declared by the National Government through Decree 062 of 2025. These measures include the introduction of two new taxes: (i) the special tax for the Catatumbo; and (ii) the reactivation of the stamp tax rate. Both taxes are temporary and will be in effect from February 22, 2025, through December 31, 2025.
Special Tax for the Catatumbo
This tax applies to: (i) the first sale of hydrocarbons and coal within or from Colombia; and (ii) the submission and acceptance of the export clearance request for hydrocarbons and coal for outside Colombia.
Decree 175 specifies that the taxable products are those classified under the following tariff classifications: 27.01 (Coal; briquettes, ovoids, and similar solid fuels manufactured from coal); 27.09 (Crude petroleum oils or oils obtained from bituminous minerals).
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Below are the main elements of this tax, based on the taxable event:
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Element |
First sale within or from the national territory |
Exports |
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Moment of accrual |
Occurs upon issuance of the invoice, or upon the first delivery if no invoice is issued. Hydrocarbons received by the ANH as royalty payments only trigger the tax at the time of export |
Occurs upon filing and acceptance of the export clearance request for shipments outside the country. If the party extracting hydrocarbon or coal is also the direct exporter, the tax only accrues upon the sale. From the first clarification, it follows that the tax may accrue twice if the extractor and the exporter are not the same entity. In that scenario, the tax is triggered (i) at the time of the first sale, and (ii) upon export. |
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Tax Base |
Sale Price |
The FOB value (in pesos) of the product. If the amount is in U.S. dollars, the exchange rate (TRM) on the date of filing and acceptance of the export clearance request shall apply. |
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Rate |
1% |
1% |
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Taxable and responsible party |
Any individual or legal entity that sells hydrocarbons. |
Any individual or legal entity that carries out definitive export operations. |
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Collection |
Must be remitted within the first five business days of each month, consolidating the previous month’s sales transactions. |
Must be paid at the time the export clearance request is filed and accepted. This rule applies to clearance requests filed and accepted on or after February 22, 2025. In the event the export clearance request contains provisional data that differs from the final data reported in the export return, the Decree 175 authorizes: (i) payment of any additional tax amount within ten business days after the final export return is filed; or (ii) a refund request if there is an overpayment. |
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Penalties |
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Non filing/non-payment: A penalty equal to 20% of the tax due.
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Late filing: A penalty of 5% of the tax due for each month or fraction thereof, not to exceed 100% of the tax liability.
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Underpayment: If corrected before a special assessment notice, a penalty of 10% of the additional tax due; if corrected after the special assessment notice, a penalty of 20%.
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Any incomplete payment of the tax triggers a penalty of 5% on the FOB value of the goods, without prejudice to the calculation and payment of the outstanding tax amount and any applicable interest. |
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Reactivation of the Stamp Tax Rate
Law 1111 of 2006 had progressively reduced the stamp tax rate to 0% as of taxable year 2010. Decree 175 reinstates a 1% stamp tax rate applicable to public or private documents that meet the following conditions:
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(i) |
Are executed or accepted within Colombia or are executed abroad but enforced in Colombian territory. |
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(ii) |
Give rise to obligations in Colombia, whereby the creation, existence, modification, or termination of obligations is recorded, including extensions or assignments, with an amount exceeding 6,000 UVT (COP 298,794,000 in 2025). |
A document is subject to stamp tax if the grantor, acceptor, or signatory is: (i) a legal entity; (ii) an individual who is a merchant and who, in the previous taxable year, obtained gross income or held gross assets exceeding 30,000 UVT (COP 1,493,970,000 in 2025).
The tax is collected through withholding at source, whereby: if a public entity is involved, that public entity acts as the withholding agent; a notary acts as the withholding agent in the case of public deeds; for other documents, the withholding agent is the contracting party, acceptor, or signatory.
For installment-based or periodic contracts, the tax base is the total amount of the periodic payments due under the contract. If the contract amount is undetermined, the stamp tax applies to each individual payment made during the contract’s term.
This is an instantaneous tax, and the withheld amount must be reported in the monthly withholding tax return.
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6.6.2 |
U.S. Federal Income Tax Consequences |
This summary describes the principal U.S. federal income tax consequences of the ownership and disposition of common shares or ADSs, but it does not purport to be a comprehensive description of all of the U.S. tax consequences that may be relevant to a decision to hold or dispose of common shares or ADSs. This summary applies only to purchasers of common shares or ADSs who will hold the common shares or ADSs as capital assets for U.S. federal income tax purposes and does not apply to special classes of holders such as dealers in securities or currencies, holders whose functional currency is not the U.S. dollar, holders of 10% or more of our shares (taking into account shares held directly or through depositary arrangements) by vote or by value, tax-exempt organizations, financial institutions, holders liable for the alternative minimum tax, securities traders who elect to account for their investment in common shares or ADSs on a mark-to-market basis, partnerships or other pass-through entities or arrangements and investors therein, insurance companies, U.S. expatriates, persons that purchase or sell common shares or ADSs as part of a wash sale for tax purposes, and persons holding common shares or ADSs in a hedging transaction or as part of a straddle, conversion or other integrated transaction for U.S. federal income tax purposes. The statements regarding U.S. tax law set forth in this summary are based on the Internal Revenue Code of 1986, as amended, the “Code,” its legislative history, existing and proposed U.S. Treasury regulations, published rulings and court decisions, all as in force on the date of this annual report, and changes to such law subsequent to the date of this annual report may affect the tax consequences described herein (possibly with retroactive effect). This summary is also based in part on the representations of the Depositary and the assumption that each obligation in the Deposit Agreement and any related agreement will be performed in accordance with its terms.
Each holder is encouraged to consult such holder’s tax advisor concerning the overall tax consequences to it, including the consequences under laws other than U.S. federal income tax laws, of an investment in common shares or ADSs. In this discussion, references to a “U.S. Holder” are to a beneficial owner of a common share or an ADS that is for U.S. federal income tax purposes (1) an individual citizen or resident of the United States, (2) a corporation, or any other entity taxable as a corporation, organized under the laws of the United States, any state thereof or the District of Columbia, (3) an estate whose income is subject to U.S. federal income tax regardless of its source, or (4) a trust if (i) a United States court can exercise primary supervision over the trust’s administration and one or more United States persons are authorized to control all substantial decisions of the trust or (ii) it has in effect a valid election under applicable U.S. Treasury regulations to be treated as a U.S. person.
For U.S. federal income tax purposes, holders of ADSs generally will be treated as owners of the common shares represented by such ADSs.
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This discussion does not address any aspect of U.S. federal taxation other than U.S. federal income taxation (such as the estate and gift tax or the Medicare tax on net investment income). Holders of common shares or ADSs should consult their own tax advisor regarding the U.S. federal, state and local and other tax consequences of owning and disposing of common shares and ADSs in their particular circumstances.
Distributions on Common Shares or ADSs
A distribution to U.S. Holders made by us of cash or property with respect to common shares or ADSs generally will be treated as a dividend for U.S. federal income tax purposes to the extent paid out of our current or accumulated earnings and profits (as determined under U.S. federal income tax principles). Distributions in excess of our current or accumulated earnings and profits, as determined for U.S. federal income tax purposes, will be treated first as a tax-free return of capital reducing such U.S. Holder’s adjusted tax basis in the common shares or ADSs. Any distribution in excess of such adjusted tax basis will be treated as capital gain and will be either long-term or short-term capital gain depending upon whether the U.S. Holder held the common shares or ADSs for more than one year. Distributions of additional common shares or ADSs to U.S. Holders that are part of a pro rata distribution to all of our shareholders generally will not be subject to U.S. federal income tax. We do not maintain calculations of our earnings and profits under U.S. federal income tax principles, and, therefore, except as described in the previous sentence, U.S. Holders should expect that any distributions generally will be reported as dividends for U.S. federal income tax purposes. As used below, the term “dividend” means a distribution that constitutes a dividend for U.S. federal income tax purposes. The amount of any distribution will include the amount of any Colombian tax withheld on the amount distributed, and the amount of a distribution paid in Colombian Pesos will be measured by reference to the exchange rate for converting Colombian Pesos into U.S. dollars in effect on the date the distribution is received by the Depositary (or by a U.S. Holder in the case of a holder of common shares) regardless of whether the payment is in fact converted into U.S. dollars. If the Depositary (or U.S. Holder in the case of a holder of common shares) does not convert such Colombian Pesos into U.S. dollars on the date it receives them, generally, any gain or loss resulting from currency exchange fluctuations during the period from the date the dividend payment is included in income to the date the payment is converted into U.S. dollars will be treated as ordinary income or loss and will not be eligible for the special tax rate applicable to qualified dividend income (as discussed below). The gain or loss generally will be income or loss from sources within the United States for foreign tax credit limitation purposes. Dividends paid by us will not be eligible for the dividends received deduction allowed to corporations under the Code.
If you are a non-corporate U.S. Holder, dividends that constitute qualified dividend income will be taxable to you at the preferential rates applicable to long-term capital gains, provided that you meet certain holding requirements. Dividends paid on the ADSs will be treated as qualified dividend income if (1) the ADSs are readily tradable on an established securities market in the United States and (2) we were not, in the year prior to the year in which the dividend was paid, and are not, in the year in which the dividend is paid, a passive foreign investment company (PFIC). The ADSs are listed on the New York Stock Exchange and will qualify as readily tradable on an established securities market in the United States, as long as they are so listed. Based on our audited financial statements and relevant market and shareholder data, we believe that we were not treated as a PFIC for U.S. federal income tax purposes with respect to our 2024 year. In addition, based on our audited financial statements and our current expectations regarding the value and nature of our assets, the sources and nature of our income, and relevant market and shareholder data, we do not anticipate becoming a PFIC for the 2025 taxable year. However, this conclusion is a factual determination that is made annually and thus may be subject to change. Based on existing guidance, it is not clear whether dividends received with respect to the common shares will be treated as qualified dividends. Holders of ADSs and common shares should consult their own tax advisers regarding the availability of the reduced dividend tax rate in the light of the considerations discussed above and their own particular circumstances.
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A U.S. Holder may be eligible, subject to a number of complex limitations and conditions and the Foreign Tax Credit Regulations (as defined below), to claim a U.S. foreign tax credit in respect of any Colombian income taxes withheld on dividends received on common shares or ADSs. For purposes of calculating the foreign tax credit, dividends paid on our common shares or ADSs will be treated as income from sources outside of the United States and will generally constitute passive category income. However, Treasury regulations that apply to taxes paid or accrued in taxable years beginning on or after December 28, 2021 (the Foreign Tax Credit Regulations) impose additional requirements for foreign taxes to be eligible for a foreign tax credit, and there can be no assurance that those requirements will be satisfied. A recent notice from the IRS provides temporary relief from the Foreign Tax Credit Regulations by allowing taxpayers to apply a modified version of the regulations for taxable years ending before the date that a notice or other guidance withdrawing or modifying the temporary relief is issued (or any later date specified in such notice or other guidance), provided that the taxpayer consistently applies such modified version of the U.S. Treasury regulations and complies with specific requirements set forth in a previous notice. Any taxes imposed by Colombia on dividends received generally will qualify as potentially creditable taxes if a U.S. Holder applies a modified version of the U.S. Treasury regulations pursuant to the notice. However, a U.S. Holder will generally be denied a foreign tax credit for foreign taxes imposed with respect to the dividends where the U.S. Holder does not meet a minimum holding period requirement. In the case of all other U.S. Holders, the application of these requirements to the Colombian tax on dividends is uncertain and we have not determined whether these requirements have been met. If the Colombian tax is not a creditable tax or a U.S. Holder does not elect to claim a credit for any foreign income taxes paid during the taxable year, such U.S. Holder may instead, at such U.S. Holder’s election, deduct such Colombian income taxes in computing U.S. taxable income, subject to generally applicable limitations and conditions. The rules relating to the eligibility and deductibility of foreign tax credits are extremely complex, and U.S. Holders are urged to consult their own independent tax advisors regarding the availability of foreign tax credits with respect to any Colombian income taxes withheld.
Sale, Exchange or Other Taxable Dispositions of Common Shares or ADSs
A U.S. Holder generally will recognize capital gain or loss upon the sale, exchange or other taxable disposition of common shares or ADSs in an amount equal to the difference between the U.S. dollar value of the amount realized on the sale, exchange or other taxable disposition of the common shares or ADSs and the U.S. Holder’s adjusted tax basis, determined in U.S. dollars, in the common shares or ADSs. Any gain or loss will be long-term capital gain or loss if the common shares or ADSs have been held for more than one year. Certain non-corporate U.S. Holders (including individuals) may be eligible for preferential rates of U.S. federal income tax in respect of long-term capital gains. The deductibility of capital losses is subject to limitations under the Code.
If you are a U.S. Holder of common shares or ADSs, the initial tax basis of your common shares or ADSs will be the U.S. dollar value of the Colombian Peso-denominated purchase price determined on the date of purchase. If the common shares or ADSs are treated as traded on an “established securities market,” a cash basis U.S. Holder, or, if it elects, an accrual basis U.S. Holder, will determine the dollar value of the cost of such common shares or ADSs by translating the amount paid at the spot rate of exchange on the settlement date of the purchase. Such an election by an accrual basis U.S. Holder must be applied consistently from year to year and cannot be revoked without the consent of the IRS. If you convert U.S. dollars to Colombian Pesos and immediately use that currency to purchase common shares or ADSs, such conversion generally will not result in taxable gain or loss to you. With respect to the sale or exchange of common shares or ADSs, the amount realized generally will be the U.S. dollar value of the payment received determined on (1) the date of receipt of payment in the case of a cash basis U.S. Holder and (2) the date of disposition in the case of an accrual basis U.S. Holder. If the common shares or ADSs are treated as traded on an “established securities market,” a cash basis taxpayer, or, if it elects, an accrual basis taxpayer, will determine the U.S. dollar value of the amount realized by translating the amount received at the spot rate of exchange on the settlement date of the sale.
Deposits and withdrawals of common shares in exchange for ADSs, and of ADSs for common shares, generally will not result in the realization of gain or loss for U.S. federal income tax purposes.
Backup Withholding and Information Reporting
In general, dividends on common shares or ADSs, and payments of the proceeds of a sale, exchange or other taxable disposition of common shares or ADSs, paid within the United States, by a U.S. payer through certain U.S.-related financial intermediaries to a U.S. Holder are subject to information reporting and may be subject to backup withholding at a current rate of 24%, unless the holder (1) establishes that it is an exempt recipient or (2) with respect to backup withholding, provides an accurate taxpayer identification number and certifies that it is a U.S. person and that no loss of exemption from backup withholding has occurred.
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Backup withholding is not an additional tax. The amount of any backup withholding tax from a payment to a U.S. Holder will be allowed as a credit against the U.S. Holder’s U.S. federal income tax liability, provided that the required information is timely furnished to the IRS. A U.S. Holder generally may obtain a refund of any amounts withheld under the backup withholding rules that exceed its U.S. federal income tax liability by timely filing a refund claim with the IRS.
U.S. Tax Considerations for Non-U.S. Holders
A holder or beneficial owner of common shares or ADSs that is not a U.S. Holder for U.S. federal income tax purposes (a “non-U.S. Holder”) generally will not be subject to U.S. federal income or withholding tax on dividends received on common shares or ADSs, unless the dividends are “effectively connected” with the non-U.S. Holder’s conduct of a trade or business within the United States. In such a case, a non-U.S. Holder generally will be taxed in the same manner as a U.S. Holder. In the case of “effectively connected” dividends received by a corporate non-U.S. Holder, the corporate non-U.S. Holder may, under certain circumstances, be subject to an additional “branch profits tax” at a 30% rate.
A non-U.S. Holder of common shares or ADSs will not be subject to U.S. federal income or withholding tax on gain realized on the sale of common shares or ADSs, unless (i) the gain is “effectively connected” with the non-U.S. Holder’s conduct of a trade or business in the United States or (ii) in the case of gain realized by an individual non-U.S. Holder, the non-U.S. Holder is present in the United States for 183 days or more in the taxable year of the sale and certain other conditions are met. In the case of “effectively connected” gains realized by a corporate non-U.S. Holder, the corporate non-U.S. Holder may, under certain circumstances, be subject to an additional “branch profits tax” at a 30% rate.
Although non-U.S. Holders generally are exempt from backup withholding and information reporting requirements, a non-U.S. Holder may be required to comply with certification and identification procedures in order to establish its exemption from information reporting and backup withholding.
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6.7 |
Exchange Controls and Limitations |
Certain foreign exchange transactions with foreign exchange control restrictions including international investments and some transactions between Colombian residents and non-Colombian residents must be conducted through the foreign exchange market. In Colombia, foreign investment transactions are subject to foreign exchange control restrictions, and the acquisition of shares registered in the National Registry of Securities and Issuers ( Registro Nacional de Valores y Emisores ). ADRs by non-residents are considered a type of portfolio investment and must be registered before the Colombian Central Bank. Therefore, any foreign currency income or expense under the ADRs must be transferred through the appropriate channels of the foreign exchange market, which means using an intermediary of the foreign exchange market or a bank account opened abroad of Colombia and registered as compensation account before the Colombian Central Bank.
Transactions conducted through intermediaries of the foreign exchange market are made at market rates freely negotiated with authorized intermediaries (local banks, financial corporations, administrators and others) or using a bank account opened abroad and registered as a compensation account (in this case, without effective conversion of the currencies into Colombian Pesos). Since September 25, 1999, the Colombian foreign exchange regime is structured under the system of free flotation of the exchange rate, whereby market forces determine the level of exchange rate from time to time.
Foreign portfolio investments must be made through authorized foreign exchange investment management companies, that will act as the administrator. Only brokerage firms, trust companies and investment management companies, subject to the inspection and supervision of the SFC, are allowed to act in the local Colombian stock market on behalf of foreign investors. Such brokerage firms, trust companies and investment management companies also act as the foreign investors’ local representatives for tax, foreign exchange purposes, remittance of information and any other purpose defined by the supervisory entity.
Non-residents are also allowed to register the acquisition of shares registered in the National Registry of Securities and Issuers, as direct investments in Colombian companies. The registration must be completed before the Colombian Central Bank, considering the method of payment of the acquisition and the formalization of the agreement in accordance to which the acquisition has been made.
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Colombian law provides that the Colombian Central Bank may regulate the foreign exchange regime at its own discretion at any time (i.e., it is allowed to temporarily limit the remittance of dividends from abroad whenever the international reserves of the Colombian Central Bank fall below an amount equal to three months of imports or those reserves are at the highest allowable level). Additionally, from time to time, the Colombian Government introduces amendments to the International Investment Statute. Hence, we cannot assure you that the Colombian Central Bank will not intervene in the future imposing restrictions to the free convertibility system currently applicable in Colombia. See section Risk Review—Risk Factors—Risks Related to Colombia’s Political and Regional Environment .
Registration of Foreign Investment Represented in Underlying Shares
Colombia’s International Investment Statute as approved by the Government and the foreign exchange regulations issued by the Colombian Central Bank, which have been amended from time to time through decrees and regulations, govern the manner in which non-Colombian resident entities and individuals can invest in Colombia and participate in the Colombian securities markets. Among other requirements, the International Investment Statute and Colombian Central Bank regulations establish the liability of registration of foreign investment transactions with the Colombian Central Bank and specify procedures to authorize and administer such foreign investment transactions. Additionally, pertinent information related to foreign investment transactions must be updated on a regular basis (on a monthly basis by the administrator with the submission of the “Statistical Report on Foreign Portfolio Equity Investments in Colombia - IPEXT”).
Under the International Investment Statute and Colombian Central Bank regulations, the failure of a foreign investor to report or register with the Colombian Central Bank foreign exchange transactions relating to investments in Colombia on a timely basis may (i) prevent the investor from obtaining remittance rights, (ii) constitute an exchange control infraction and (iii) result in economic fines.
Notwithstanding the regulations described above, foreign investors who acquire ADRs are not required to directly register this investment with Colombian authorities as such registration is made in the name of the ADR program administrator. Holders of ADRs will benefit from the registration to be obtained by the local custodian for our common shares underlying the ADRs in Colombia. Such registration allows the custodian to convert dividends and other distributions with respect to the common shares into foreign currency and remit the proceeds abroad. If investors in ADRs choose to surrender their ADRs and withdraw common shares, they must retain an administrator, who will act as a local representative for the investments and register their investments in common shares as a portfolio investment through said local representative. The local representative is the brokerage firm, trust company or investment management company that acts on behalf of the holders of the ADRs in Colombia, and the request for registration is made by them.
Colombian residents who acquire ADRs and either receive profits from this investment, surrender their ADRs or liquidate their investment in ADRs, are considered as a type of financial investment and/or in assets located abroad by resident in Colombian and in that case, may be registered with the Colombian Central Bank depending on whether the payment was performed using the foreign exchange market.
In case of obtaining its own foreign investment registration, an investor who surrenders its ADRs and sells common shares may incur expenses and/or suffer delays in the application process. Investors would only be allowed to transfer dividends abroad or transfer funds received as distributions relating to our common shares after their foreign investment registration procedure with the Colombian Central Bank has been completed. In addition, the Depositary’s foreign investment registration may also be adversely affected by future legislative changes, but its rights to transfer dividends abroad or profits arising from distributions relating to our common shares must be maintained according to Colombian law and foreign investment treaties entered into by Colombia in force at the time of the registration of the investment, except when Colombia’s international reserves fall below an amount equivalent to three months’ worth of imports. Prospective purchasers of common shares or ADSs should consult their own foreign exchange advisors.
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6.8 |
Exchange Rates |
On March 31, 2025, the Representative Market Exchange Rate was COP 4,192.57 per USD 1.00. The Federal Reserve Bank of New York does not report a noon-buying rate for Colombian Pesos. The SFC calculates the Representative Market Exchange Rate based on the weighted averages of the buy and sell foreign exchange rates quoted daily by foreign exchange rate market intermediaries including financial institutions for the purchase and sale of U.S. dollars. The SFC also calculates the Representative Market Exchange Rate for each month for purposes of preparing financial statements and converting amounts in foreign currency to Colombian Pesos.
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6.9 |
Major Shareholders |
The following table sets forth the names of our major shareholders, and the number of shares and the percentage of outstanding shares owned by them on March 31, 2025:
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Table 68 – Major Shareholders
|
|
|
As of March 31, 2025 |
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|
Shareholders |
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Number of shares |
|
% Ownership |
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Nation (1) – Ministry of Finance and Public Credit |
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36,384,788,417 |
|
88.49 |
|
Public float |
|
4,731,906,273 |
|
11.51 |
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Total |
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41,116,694,690 |
|
100.00 |
|
(1) |
Includes 1,600 shares owned by other state entities. |
All our common shares have identical voting rights.
As of February 14, 2025, the registration date of our annual general shareholders’ meeting, 3.34% or 1,374,128,640 of our common shares were held of record in the form of American Depository Shares, we had 56 registered holders, and 44,626 beneficiaries of common shares, or ADSs representing common shares, in the United States.
Changes in the Capital of the Company
There are no conditions in our bylaws governing changes in our capital stock that are more stringent than those required under Colombian law, with the exception that the Nation must hold a minimum of 80% in any stock issuance undertaken under Law 1118 of 2006.
On August 27, 2021, our Board of Directors approved the framework for the Third Round of the Program for the Issuance and Placement of Common Stock (the “Program”), in accordance with Law No. 1118 of 2006 (“Law 1118”). As provided by Law 1118, to the extent any potential public offerings of common shares are carried out under the Program, the Nation will at all times continue to maintain at least 80% of the common equity interest of Ecopetrol S.A. The Program contemplates a five-year term during which we may carry out one or more public offerings of common shares for the specific purposes set forth therein. On October 13, 2021, the SFC approved the Program. Any offerings to be undertaken pursuant to the Program remain subject to approval by the SFC and any such approvals, if and when granted, do not imply any commitment or obligation on Ecopetrol S.A. to issue common shares.
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6.10 |
Enforcement of Civil Liabilities |
We are a Colombian company. Most of our Directors and executive officers and some of the experts named in this annual report reside outside the United States. All or a substantial portion of our assets and the assets of these persons are located outside of the United States. As a result, it may not be possible for you to effect service of process within the United States upon us or these persons who are residents in Colombia or to enforce against us or these persons who are residents in Colombia judgments in U.S. courts obtained in such courts predicated upon the civil liability provisions of the U.S. federal securities laws. Colombian courts will enforce a U.S. judgment predicated on the U.S. securities laws through a judicial proceeding known under Colombian Law as “exequatur.” The Colombian Supreme Court will enforce a foreign judgment, without reconsideration of the merits only if the judgment satisfies the requirements set forth in Articles 605 through 607 of Law 1564 of 2012 (Código General del Proceso) which entered into force on January 1, 2016, pursuant to Acuerdo No. SAA1510392, of October 1, 2015, issued by the Colombian Superior Council of the Judiciary ( Consejo Superior de la Judicatura ), as follows:
| ● | A treaty or convention exists between Colombia and the country where the judgment was granted relating to the recognition and enforcement of foreign judgments or, in the absence of such treaty or convention, proper evidence is provided to the Supreme Court of Colombia to the effect that there is reciprocity in the recognition of foreign judgments of the same nature between the courts of the relevant jurisdiction and the courts of Colombia; |
| ● | The foreign judgment does not relate to “in rem rights” vested in assets located in Colombia at the time the lawsuit was filed; |
| ● | The foreign judgment does not contravene or conflict with public order Colombian laws other than judicial procedural rules; |
| ● | The foreign judgment, in accordance with the laws of the country where it was rendered, is final and binding, and is not subject to appeal; |
| ● | A duly legalized copy of the judgment (together with an official translation into Spanish if the judgment is issued in a foreign language either by the Colombian Ministry of Foreign Affairs ( Ministerio de Relaciones Exteriores de Colombia ), an officially recognized translator or by a translator appointed by a judge) has been presented to the Supreme Court of Colombia; |
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| ● | The foreign judgment does not refer to any matter upon which Colombian courts have exclusive jurisdiction; |
| ● | No proceeding is pending in Colombia with respect to the same cause of action, and no final judgment has been awarded in any proceeding in Colombia on the same subject matter and between the same parties; |
| ● | In the proceeding commenced before the foreign court that issued the judgment, the defendant was served in accordance with the laws of such jurisdiction and in a manner reasonably designated to give the defendant an opportunity to defend against the action; and |
| ● | The legal requirements pertaining to the exequatur proceedings have been observed. |
The United States and Colombia do not have a bilateral treaty providing for automatic reciprocal recognition and enforcement of judgments in civil and commercial matters. The Colombian Supreme Court has in the past accepted that reciprocity exists on a case-by-case basis, when it has been proven that either the U.S. court that has rendered the relevant judgement has enforced similar decisions by a Colombian court, or that the relevant U.S. court would enforce a foreign judgment, including a judgment issued by a Colombian court. However, such enforceability decisions are considered by Colombian courts on a case-by-case basis.
Proceedings for enforcement of a money judgment by attachment or execution against any assets or property located in Colombia are within the exclusive jurisdiction of Colombian courts, and such proceedings are conducted in Spanish. All parties affected by a foreign judgment in exequatur proceedings must be summoned to the exequatur proceedings in accordance with the rules that apply to the Colombian courts. In the course of such proceedings, both the plaintiff and the defendant are afforded the opportunity to request that evidence to be produced in connection with the requirements listed above. In addition, before the judgment is rendered, each party may file final allegations in support of such party’s position regarding the abovementioned requirements.
Assuming that a foreign judgment complies with the standards set forth in the preceding paragraphs and the absence of any condition referred to above that would render a foreign judgment not subject to recognition under Colombian law, such foreign judgment would be enforceable in Colombia in an enforcement proceeding under the laws of Colombia, provided that the Colombian Supreme Court has previously granted exequatur upon the foreign judgment.
We reserve our right to plead sovereign immunity under the United States Foreign Sovereign Immunities Act of 1976 with respect to actions brought against us under United States federal securities laws or any state securities laws.
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7. |
Corporate Governance |
Since 2004, Ecopetrol S.A. has voluntarily adopted transparency, governance and control practices to facilitate corporate governance to generate confidence among stakeholders and ensure the sustainability of its business. The corporate governance practices at Ecopetrol S.A. aim to:
| ● | Promote all stakeholders transparency, objectivity and competitiveness. |
| ● | Add value to the company and attract investors. |
| ● | Protect shareholders, investors and stakeholders’ rights. |
| ● | Encourage financial markets confidence; and |
| ● | Accomplish the highest corporate governance standards. |
Evolution of the Ecopetrol Group’s Management Model
The Ecopetrol Group’s management model, which was based on the segment management of the oil and gas business, evolved to reflect the Group’s updated composition and strategy as a diversified energy Group.
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In line with the 2040 Strategy, since 2022, the organization and management of the Ecopetrol Group’s operations has evolved into three business lines: (i) Hydrocarbons, (ii) Energies for the Transition and (iii) Transmission and Roads. For each business line, the objective and focus of Ecopetrol as head of the group were identified and the leaders responsible for its development and promotion within the group were defined. The Hydrocarbons business line, led by Ecopetrol’s Chief Operating Officer, focuses on maintaining its efficiency, competitiveness and the decarbonization of its operations, leading the management of its own business segments. The Energies for the Transition business, led by Ecopetrol’s Vice President of Energies for the Transition, concentrates on incubating and developing energy solutions businesses associated with gas, biogas, LPG, energy, hydrogen, renewables and CCUS. Finally, the Transmission and Roads business line is established at the Ecopetrol Group level, is led by ISA’s president, with a focus on maximizing value and capturing synergies with respect to mature energy transmission, road infrastructure and telecommunications businesses. See section Business Overview—Our Corporate Structure .
The evolution in the management of the Ecopetrol Group by business lines, recognizes the dual nature of Ecopetrol as an operating company and as a parent company or investor, and is based on other key elements for its management, such as organizational structure, corporate governance model and the processes needed to strategically guide the Ecopetrol Group as a diversified energy group.
Corporate Governance
During 2024, under the framework provided in the corporate governance model, decisions were made to advance towards meeting the goals set in the Ecopetrol Group’s 2040 Strategy, with a view to generating value and sustainability. The main milestones in corporate governance are highlighted below:
|
i. |
Statute reform to strengthen Corporate Governance: In 2024, amendments were made to the company’s statutes that address better corporate governance practices and regulatory clarifications, mainly regarding the rights of shareholders, and the functions of the different bodies of Ecopetrol. These reforms were aimed at continuing to consolidate Ecopetrol as an efficient company managed under the highest standards of corporate governance, seeking to provide greater clarity regarding the powers of Ecopetrol’s corporate bodies. As part of these reforms, it is required that at least 30% of the board of directors be made up of women. Additionally, it is made explicit in Ecopetrol’s social objective, including the possibility of developing activities related to conventional and alternative sources of energy in line with the global needs of the market, the 2040 strategy and Ecopetrol’s promise as a good corporate citizen. |
|
ii. |
Evolution of Ecopetrol’s Relationship Model with the companies of the Ecopetrol Group: In 2024, the Ecopetrol Group Relationship Model evolved towards a more strategic approach, incorporating group interactions for the Energies for Transition function and thereby leveraging compliance with the 2040 strategy |
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iii. |
Articulation of themes and optimization of the operation of the Business Line Committees and Executive Committee within the structure of Senior Management Committees (CADs): For Ecopetrol, the senior management committees are collegiate bodies that constitute a management tool to support the Chief Executive Officer of Ecopetrol in his task to achieve the corporate purpose and objectives of the Ecopetrol Group. Some of the senior management committees include business line committees: hydrocarbons; energies for transition; and transmission, roads and telecommunications; as well as the strategic committee, among others. |
These committees have been key to the management and diversification of the Ecopetrol Group’s businesses. As evidence of the above, 78% of the topics presented in the business line committees and in the strategic committee were related to the 4 pillars of the “Energy that transforms” strategy as follows: (i) Grow with the energy transition, (ii) Generate value trough TESG, (iii) Cutting-edge Knowledge and (iv) Competitive Returns. Additionally, since the beginning of 2024, Atlas Governance, the largest Corporate Governance portal in Latin America, was implemented as the new management system of the strategic committee and the three business line committees, optimizing the functioning of the committees and reflecting the commitment of the Company with innovation and efficiency in its management. In this way, with the implementation of Atlas, the committees have greater security, traceability and practicality in their operation.
|
iv. |
Ecopetrol continues to strengthen its practices in corporate governance: |
| ● | Ecopetrol participated in the Corporate Sustainability Assessment (CSA) which is part of the Dow Jones Sustainability Index (DJSI). |
| ● | Regarding the economic and governance dimension (G), Ecopetrol had a score of 61/100. |
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| ● | The survey on the adoption of the Code of Best Corporate Practices of Colombia (Country Code), sent to the Financial Superintendence of Colombia, reflects the situation of Ecopetrol S.A. against the recommendations established in the Country Code in relation to corporate governance practices. In 2024, Ecopetrol obtained a score of 89.1% for implementing the practices recommended by the Country Code. |
| ● | In 2024, Atlas Governance was implemented as the new management system of Ecopetrol’s Board of Directors, as well as the strategic committee and the three business line committees. As a result of the implementation and use of the system, Ecopetrol has been recognized as the winner of the Atlas Governance Awards Latam in the State category. |
Corporate Governance System
Corporate governance is the system of rules and practices that govern the decision-making process and delegation of authority between the governing bodies of the Ecopetrol Group, as well as the relationships between the companies that comprise it. Corporate Governance in Ecopetrol is more than a key element for organizational management—it is a strategy enabler that our stakeholders value and monitor continuously, as it generates trust, sustainable results over time and results in long-term value relationships.
Our model is structured based on the law, international standards, the corporate governance principles of the Organization for Economic Cooperation and Development (OECD), good corporate governance practices and the Ecopetrol Group’s strategy. Our corporate governance provides safeguards for adequate decision-making of the governing bodies of the Ecopetrol Group in terms of agility, clarity and consistency, as well as the promotion of the realization of synergies between Ecopetrol S.A. and the Ecopetrol Group companies.
By virtue of the foregoing, the scope of the role that Ecopetrol plays as head of the group is defined according to the following criteria: (i) percentage of Ecopetrol’s participation in the different companies of the group; (ii) existence or not of a control situation (direct or indirect) by Ecopetrol; and (iii) relevance of companies in the group’s strategy. Therefore, in companies in which Ecopetrol has 100% direct or indirect participation, there is a high level of influence as a parent company; while in companies in which shareholding is shared with other companies, guidelines of the parent company are adopted considering the corporate governance of the respective companies.
Within the mechanisms and instruments of articulation that the group has, several elements of corporate governance stand out, which support Ecopetrol’s role as head of the group, such as the guidelines and positions of business lines and segments, which are adopted through different corporate governance bodies, such as the boards of directors (or equivalent body) of the companies of the Ecopetrol Group. In accordance with the nominees to which Ecopetrol is entitled according to the level of shareholding.
The President of Ecopetrol has the duty to appoint the employees of Ecopetrol or Ecopetrol’s subsidiaries to the board of directors (or equivalent body) of the companies of the Group in which Ecopetrol has a participation as a shareholder. The general principles and criteria to consider in the appointment process are, among others: (i) Good name; (ii) Professional suitability; (iii) Integrity; (iv) experience in leadership and administration; and (v) commitment and professionalism. Consequently, the evaluation of the boards of directors is a corporate governance practice adopted by the Ecopetrol Group and constitutes a tool through which the boards of directors annually evaluate their management to identify the strengths in their operation, contribute to the fulfillment of the goals set in the group’s strategy and opportunities for improvement.
To leverage the business strategy, Ecopetrol has a Corporate Governance System that aims to provide a consistent, sustainable and objective framework for action to safeguard Ecopetrol’s governance as well as generate synchrony and articulation with the companies of the Ecopetrol Group. The main elements of this system are:
|
(i) |
Boards of Directors: Ecopetrol and Subsidiaries |
|
a. |
Promote best management practices in the Boards of Ecopetrol and in the other Ecopetrol Group’s companies. |
|
b. |
Ensure alignment of the strategy under the Ecopetrol Group’s management by business lines. |
|
(ii) |
Senior Management Committees |
|
a. |
Establish the structure of the Senior Management Committees (operating, monitoring and improvement mechanisms). |
|
b. |
Optimize Ecopetrol senior management time. |
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|
(iii) |
Matrix of Decisions and Attributions |
|
a. |
Define the key or more relevant decisions of the Ecopetrol Group. |
|
b. |
Establish which governing bodies are responsible for making key decisions. |
|
c. |
Define how these decisions are made. |
|
(iv) |
Relationship Model |
|
a. |
Establish the way in which the areas within the Ecopetrol Group’s scope are related to the Ecopetrol Group’s companies. |
|
b. |
Capture the Ecopetrol Group’s synergies. |
|
c. |
Manage articulation through management or administration by business lines. |
Statement of the Nation as Majority Shareholder
Ecopetrol’s majority shareholder (the Nation, represented by the Ministry of Finance and Public Credit), is unilaterally committed to protect the interests of the minority shareholders in the following topics:
| ● | Composition of Board of Directors: including in its list of candidates a Representative for the hydrocarbon producing departments where Ecopetrol operates and a Representative for the minority shareholders, who will be chosen by the 10 shareholders with the largest stock participations. Ecopetrol has adopted the practice of having a majority of independent members. The current Board of Directors is composed of nine members: six independent and three non-independent who were elected at the General Meeting of Shareholders held on March 28, 2025. |
| ● | Dividend policy: guaranteeing the right of each shareholder to receive his pro rata dividends in accordance with Colombian law. |
| ● | Issues not included in the agenda of extraordinary meetings of the General Shareholders Assembly: permitting a vote on those initiatives submitted by one or more shareholders representing at least 2% of the subscribed shares of the company. |
| ● | Asset disposal: ensuring that any asset disposal of an amount equal or higher than 15% of the stock exchange capitalization of Ecopetrol S.A. is discussed and decided by the General Shareholders’ Assembly and that the Nation will only vote affirmatively if the vote of minority shareholders is equal to or exceeds 2% of the shares subscribed by shareholders other than the Nation. |
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|
7.1 |
Bylaws |
The Bylaws of Ecopetrol S.A. are contained in Public Deed No. 5314 of December 14, 2007, issued by the Second Notary of Bogotá; amended by Public Deed No. 560 of May 23, 2011, issued by the Notary Forty-Six of Bogotá, Deed No. 666 of May 7, 2013, issued by the Notary Sixty-Five of Bogotá, Deed No. 1049 of May 19, 2015, issued by the Notary Second of Bogotá, Deed No. 0685 of May 2, 2018, issued by the Notary Twenty of Bogotá, Deed No. 888 of May 28, 2019 issued by the Notary Twenty Third of Bogotá, Deed No. 6527 issued by the Notary Twenty Nine of Bogotá of June 08, 2020, Deed No. 10976 of May 6, 2021 issued by the Notary Twenty Nine of Bogotá, Deed No. 9184 of May 11, 2022 issued by the Notary Twenty Nine of Bogotá, Deed No. 137 of February 20, 2024, issued by the Notary Six of Bogotá, Deed No. 3136 of May 21, 2024 issued by the Notary Sixty Eight of Bogotá, and Deed No. 1273 of June 18, 2024, issued by the Notary Fifty Two of Bogotá. An English translation of the amended bylaws is included as Exhibit 1.1 to this annual report.
On January 10, 2024, the General Shareholders Assembly approved an amendment to the Company’s bylaws that requires that at least 30% of the members of the Board of Directors must be women. The amendment aims to promote gender plurality and it anticipates the requirement set forth in Colombia’s National Development Plan (PND for its acronym in Spanish) according to which 30% of the board members of the boards of directors of securities issuers must be women as of 2026.
On March 22, 2024, the General Shareholders Assembly approved an amendment to the Company’s bylaws, aligned with the terms of Law 1118 of 2006, consisting of the amendment of the Company’s corporate purpose in order to include the following activities: research, development and the commercialization of conventional and alternative energy sources; the production, blending, storage, transportation and commercialization of oxygenating components and biofuels, port operations and the performance of any related, complementary or useful activities for the execution of the aforementioned activities. Moreover, the General Shareholders Assembly also approved amendments to Ecopetrol’s bylaws related to: (a) shareholders rights (b) succession policy of the Board of Directors; (c) remote attendance to the Ordinary Meetings of the General Shareholder´s Assembly; (d) remote meetings for the Board of Directors; and (e) duties of the President of the Board of Directors. These amendments are currently undergoing the process required by Colombian law to be formalized and become effective, including the review of the Financial Superintendence of Colombia, pursuant to Article 6.4.1.1.42 of Decree 2555 of 2010, among other formalities. On May 29, 2024, the amendments to the bylaws were formalized.
This summary does not purport to be complete and is qualified by reference to our bylaws, which are filed as an exhibit to this annual report. For a description of the provisions of our bylaws relating to our Board of Directors and its committees, see sections Corporate Governance—Board of Directors—Board Practices and Corporate Governance—Board of Directors—Board Committees .
General Shareholders’ Meeting
Shareholders’ meetings may be ordinary or extraordinary. Ordinary meetings will take place in our legal domicile located in Bogotá, Colombia, within the first three months following the end of each fiscal year, on the day and at the time set forth in the notice for the General Shareholders’ Meeting. The call for the General Shareholders’ Meeting is published on the Ecopetrol S.A. website and in a newspaper of national circulation, in physical or digital form, 30 calendar days prior to the date on which the meeting will take place on the Sunday previous to the meeting, must be published at Ecopetrol S.A.’s website www.ecopetrol.com.co.
The Annual General Shareholders’ Meeting provides shareholders with the opportunity to make key management decisions reserved to shareholders. At the General Shareholders’ Meeting, our Board of Directors and the external auditor are appointed. Decisions are taken regarding the company’s annual financial statements, profit distribution, audit and management reports, including our corporate governance report and sustainability report, and any other matter provided under applicable law or our corporate bylaws.
Extraordinary Shareholders’ Meetings are summoned by our Board of Directors, by our president or chief executive officer, by our external auditor, or by shareholders holding at least 5% of the outstanding shares, or when unforeseen or urgent needs of the Company require it. An Extraordinary Shareholders’ Meeting should be called no later than 15 calendar days prior to the date of the meeting. The only exception is when the Law requires a greater time between the summons and the meeting. Such notice to the Extraordinary Shareholders’ Meeting is published on the Ecopetrol S.A. website and in a newspaper of national circulation, in physical or digital form. The notice informs the agenda for the meeting to the company’s shareholders.
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For both the ordinary and extraordinary meetings, the quorum required is a plural number of shareholders representing 50% plus one of the subscribed shareholders entitled to vote. Decisions are approved with a majority of the members present. This quorum is exempted in the case of “second-call meetings,” which may take place when a meeting fails to obtain the required quorum and is called within a period between 10 business days and 30 business days from the first date, in which case decisions may be adopted by a majority of the shares present regardless of the number represented.
Decisions made at ordinary and extraordinary shareholders’ meeting must be approved by a plural number of shareholders representing the majority of the shares present. Colombian law requires higher majorities in the following cases:
| ● | The vote of at least 70% of the shares present and entitled to vote at the ordinary shareholders’ meeting is required to approve the issuance of stock not subject to preemptive rights. |
| ● | The vote of at least 78% of the shares represented entitled to vote is required to approve the distribution of the annual net profits. In the absence of this special majority, at least 50% of the net profits must be distributed. If the sum of all legal reserves (statutory, legal and optional) exceeds the amount of the outstanding capital, the Company must distribute at least 70% of the annual net profits. |
| ● | The vote of at least 80% of the shares represented is required to approve the payment of dividends in shares; and |
| ● | The vote of 100% of the outstanding and issued shares is required to replace a vacancy on the Board of Directors without applying the electoral quotient system. |
Shareholders may be represented by proxies, provided that the proxy: (i) is in writing (faxes and electronic documents are valid), (ii) specifies the name of the representative, (iii) specifies the date or time of the meeting for which the proxy is given and (iv) includes other information specified by the applicable law. Proxies granted abroad do not require legalization or an apostille.
During our ordinary annual shareholders’ meeting, our employees and Directors are only allowed to represent their own shares, unless they act as legal representatives.
Our 2024 Shareholders’ General Assembly was held on March 22, 2024 and the following matters were approved, among others:
| ● | The plan for distribution of the Company’s profits, which establishes the distribution of an ordinary dividend per share of COP 278 and an extraordinary dividend per share of COP 34, for a total dividend of COP 312 per share, as follows: payment of dividends to minority shareholders to be made in two equal installments on April 3, 2024 and June 26, 2024; and the payment to the majority shareholder will be made before December 31, 2024, taking into account the payment schedule of the balance of the debt of the Fuel Price Stabilization Fund (FEPC) accrued during 2023, which is owed by the majority shareholder to Ecopetrol. |
| ● | The establishment of a special reserve of COP 11,993,230,652,653 in order to support Ecopetrol S.A.’s financial sustainability and flexibility in the execution of its strategy. |
| ● | Election of members of the Board of Directors for the period of 2024 to 2025. |
| ● | Amendment of our bylaws. |
Our 2025 Shareholder’s General Assembly was held on March 28, 2025, and the following matters were approved, among others:
| ● | The plan for distribution of the Company’s profits, which establishes the distribution of an ordinary dividend per share of COP 214, as follows: payment of dividends to minority shareholders to be made in two equal installments on April 4, 2025 and April 29, 2025; and the payment to the majority shareholder will be made in three installments as follows: 1) COP 2,200,000,000,000 on April 4, 2025, 2) COP 2,300,000,000,000 on April 29, 2025, and 3) COP 3,286,344,378,880 on June 27, 2025. |
| ● | The establishment of a special reserve of COP 16,635,492,094,077 in order to support Ecopetrol S.A.’s financial sustainability and flexibility in the execution of its strategy. |
| ● | Election of Deloitte Touche S.A.S., as the statutory auditor for the 2025 – 2029 period and assignment of their remuneration . |
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| ● | Election of Board Members for the 2025 - 2029 period |
| ● | Approval of amendments to the Internal Regulations of the General Shareholder´s Meeting. |
| ● | Approval of amendments to the succession policy for the members of the Board of Directors. |
Preference Rights and Restrictions Attaching to Our Shares
There are only ordinary shares, and these carry no special rights or restrictions (ordinary shares). Our current shareholders do not have any type of preemptive rights. However, in the case of a future equity offering, we will review whether or not existing shareholders would be entitled to preemptive or similar rights and, if that were the case, the corporate approvals and offering documents for any such equity offering would regulate the subject matter accordingly. In connection with any future public offering of ordinary shares within the five-year Program for the Issuance and Placement of Common Stock authorized by the Superintendence of Finance of Colombia on October 13, 2021, we have determined that preemptive rights will be available to our registered holders of common shares to purchase additional common shares in Colombia, in accordance with applicable regulations.
Under Commercial Colombian law, our shareholders have the following economic privileges and voting rights:
| ● | to participate and vote on the decisions of the General Shareholders Assembly; |
| ● | to receive dividends based on the financial performance of the Company in proportion to their share ownership; |
| ● | to transfer and sell shares according to our bylaws and Colombian law; |
| ● | to inspect corporate books and records with 15 business days prior to the ordinary shareholders’ meeting where the year-end financial statements are to be approved; |
| ● | upon liquidation, to receive a proportional amount of the corporate assets after the payment of external liabilities; and |
| ● | to sell the shares, known as right of withdrawal ( derecho de retiro ), if a corporate restructuring affects the economic or voting rights of the shareholders in the terms and conditions established under Colombian law. |
Ecopetrol S.A.’s bylaws provide additional rights to our minority shareholders. These rights include:
Sale of Assets. For a ten-year period counted from the date of subscription of the declaration of the Nation dated February 16, 2018 or until the Nation loses its status as majority shareholder, the Nation guarantees that any sale of 15% or more of our assets requires the approval of the General Shareholders Assembly and that the Nation would only be allowed to vote its shares in favor of the proposal if 2% or more of our minority shareholders accept the proposal.
Candidate List . Pursuant to our bylaws and Law 1118 of 2006, the Nation will include in its candidate list for election of members of the Board of Directors one member nominated by the departments that produce hydrocarbons. In addition, pursuant to the declaration of the Nation dated February 16, 2018, the Nation will include in its candidate list for election of members of the Board of Directors one member nominated by the ten largest minority shareholders. The minority shareholders’ right to appoint a candidate loses its effect when minority shareholders, according to their share participation, name a member to our Board of Directors.
Extraordinary Shareholders Meetings. Our bylaws provide that the entity exercising permanent control over Ecopetrol S.A. must instruct the Company’s CEO or External Auditor to call an extraordinary meeting of the Company’s shareholders when so requested by a plurality of shareholders holding at least 5% of the total number of outstanding shares. Such requests shall be made in writing and must clearly indicate the purpose of the meeting.
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Investor Relations Office. Ecopetrol S.A. has an investor relations office, a specialized unit responsible for our shareholders. Pursuant to our bylaws, shareholders holding at least 5% of the total number of shares outstanding may request that the investor relations office conduct a special audit, provided that such audit does not hinder the day-to-day operations of the Company, of the following documents: the income statement; the proposal for the distribution of profits; the report of the Board of Directors as to the economic and financial status of our Company; the report from our general counsel as to the legal status of our Company; and the report from the independent auditors. Special audits cannot be made of documents that contain scientific, technological or statistical information of our Company, or agreements that give us competitive and economic advantages over our competitors, or in respect of any document related to intellectual property. Shareholders also have the right to propose good corporate governance recommendations to the office for the protection of investors.
Others. Pursuant to our bylaws, shareholders holding at least 5% of the total number of shares outstanding may propose recommendations to our Board of Directors pertaining to the management of our Company. Any shareholder may file a written petition to our Board of Directors to investigate corporate governance violations that the shareholder believes to have been committed.
Amendments to Rights and Restrictions to Shares
We have only one class of stock and it has no special rights or restrictions (ordinary shares). Our shareholders do not have any type of preemptive rights. The rights given to our shareholders by law are described in our bylaws and may only be modified through an amendment to the law.
The additional rights given to our minority shareholders in our bylaws and corporate governance code may only be modified through an amendment of those internal documents.
Limitations on the Rights to Hold Securities
There are no limitations in our bylaws or Colombian law on the rights of Colombian residents or foreign investors to own the shares of our Company, or on the right to hold or exercise voting rights with respect to those shares, except in cases of legal representation.
Restrictions on Change of Control, Mergers, Spin-offs or Transformations of the Company
Under Colombian law and our bylaws, the General Shareholders Assembly has full authority to approve any mergers, spin-offs or transformations, subject to compliance of applicable law. Corporate restructurings are subject to the requirement that the Nation must hold a minimum of 80% of our common stock in any issuance of stock pursuant to Law 1118 of 2006.
Ownership Threshold Requiring Public Disclosure
The Corporate Governance Code, Title III, Chapter 1, Section 5, states: Identification of Major Shareholders. The shareholding composition of the Company, indicating at least the twenty (20) people with the greatest number of shares, is disclosed on Ecopetrol’s website at www.ecopetrol.com.co. Colombian securities regulations set forth the obligation to disclose any material event or “ información relevante” . Any transfer of shares equal or greater than 5% of our capital stock, or any legal entity or individual acquiring a percentage of shares that would make him the beneficial owner of 5% or more of our capital stock, is a material event, and therefore, must be disclosed to the SFC. The regulation includes other criteria in order to identify when to report a material event other than the situations described in the previous sentence.
External Auditor
Pursuant to our bylaws, the external auditor will be appointed for periods of four (4) years and may be reelected consecutively for up to ten (10) years, and it may once again be hired after one (1) period away from the position. The partner assigned to the Company must be replaced after a term of five (5) years holding this position.
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7.2 |
Code of Ethics and Conduct |
Our Code of Ethics and Conduct states integrity, responsibility, respect and commitment to life, as ethical principles of the organization. Our Code of Ethics and Conduct also sets forth that we must comply with the provisions contained in the applicable national and international laws in the countries where we have operations, including the U.S. and Colombia, as well as all internal regulations that are adopted by the Company.
In our Code, we define the guidelines for the following aspects: conflict of interest; ethical conflict; prohibition of bribery, other forms of corruption and violations of the FCPA; integrity in accounting; prevention of money laundering and financing of terrorism; gifts, amenities and hospitalities; protection and use of resources; information management; security and confidentiality; prohibition of insider trading and use of inside information, environmental policy, social responsibility, respect for human rights and rejection of discrimination, antitrust and anticompetitive practices and sexual harassment in the workplace; whistleblowing channel; and examples of ethical behaviors. As part of the Ethics guidelines of Ecopetrol, facilitation payments, political contributions and donations, diversion of money from social investment activities or sponsorships towards political activities or other than the purposes established by the Company and lobbying are prohibited.
Our Code of Ethics and Conduct applies to our Board of Directors, our Chief Executive Officer, our Chief Financial Officer, principal accounting officer, persons performing similar functions, to all of the other employees of the company and its affiliates and all individuals or legal entities that have any relationship with it, including beneficiaries, shareholders, contractors, suppliers, agents, partners, customers, allies (included joint ventures) and suppliers, in addition to the personnel and companies that the contractors may engage for the execution of the agreed activities.
All our agreements with suppliers or third parties include a provision relating to compliance with applicable anti-bribery anti-corruption and general compliance regulations. These agreements also require our suppliers and third parties to accept and adopt our Code of Ethics and Conduct as well as our compliance manuals.
Our Code of Ethics and Conduct is available on our website.
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7.3 |
Board of Directors |
Board of Directors from March 2025
The Board of Directors was elected at the Ordinary Shareholders Meeting held on March 28, 2025. The current Board of Directors is composed as follows:
Non-independent members:
| ● | Lilia Tatiana Roa Avendaño |
| ● | Alberto José Merlano Alcocer |
| ● | Hildebrando Vélez Galeano |
Independent members:
| ● | Ángela María Robledo Gómez |
| ● | Mónica de Greiff Lindo |
| ● | Guillermo García Realpe |
| ● | Álvaro Torres Macías |
| ● | Ricardo Rodríguez Yee (nominated by the hydrocarbon producing departments) |
| ● | Luis Felipe Henao Cardona (nominated by the minority shareholders with largest shareholding) |
On April 5, 2025, Guillermo García Realpe was appointed as the Chairperson and Mónica de Greiff Lindo was appointed as Vice Chairperson, until a new election was held. On April 23, 2025, they were ratified.
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The information below sets forth the names and business experience of each of the directors elected at the General Shareholders Ordinary Meeting held on March 28, 2025.
Lilia Tatiana Roa Avendaño currently serves as Vice Minister of Environmental Land Management at the Ministry of Environment and Sustainable Development. She is a petroleum engineer from the Universidad Industrial de Santander , and holds a Master’s degree in Latin American Studies from Universidad Andina Simón Bolívar in Quito, Ecuador and a Ph.D. in Humanities from the University of Amsterdam. She served as Coordinator of the Energy and Climate Justice Area of Censat Agua Viva – Amigos de la Tierra , Colombia, along with other positions in this organization. She has been a consultant to the Vincent Price Art Museum, Rosa Luxemburg Foundation, Heinrich Boll Foundation, Pax Christi, Ecofondo, Transnational Institute and Colombia’s Mining and Energy Planning Unit – UPME. She is a non-independent member of Ecopetrol’s Board of Directors since March 2024.
Ms. Roa Avendaño has expertise in (i) energy transition; (ii) administration, senior management, and leadership; (iii) government and/or public policy; (iv) human resources and/or talent development; (v) health, safety and/or environment; (vi) sustainability; (vii) climate change; (viii) territorial development; (ix) water and/or wastewater matters; and (x) business strategy and/or project management. As a member of Ecopetrol’s board of directors, she is periodically trained in ethics, compliance and risk management matters.
Alberto José Merlano Alcocer, currently serves as a Management Consultant at Escala Humana with an emphasis on corporate conflict management. Moreover, he teaches postgraduate courses at the business school of Universidad de los Andes and as professor at the business and law schools of Universidad del Norte . At the latter, he is co-creator and professor of the specialization and master’s programs in negotiation and conflict resolution. He holds a bachelor’s degree in business administration from Universidad EAFIT in Medellín and a master’s degree in industrial administration from Universidad del Valle. He was Administrative Vice-President at Ecopetrol for 12 consecutive years, Manager of UT Kapital Geophysical, and General Manager of the Empresa de Acueducto de Bogotá under two different district administrations. He was also Dean of the School of Business at the Universidad del Norte , Director of the Sena business advisory program on the Atlantic Coast, National Director of Human Development at Carvajal S.A., Director of the Management Advisory Center at INCOLDA and of the master’s in business administration program at EAFIT in Cali, and served as Manager of “ Educación para la Acción ” in Cali.
Mr. Merlano Alcocer has expertise in: (i) the energy industry; (ii) administration, senior management and leadership; (iii) government affairs and/or public policy; (iv) finance; (v) human resources and/or talent development; (vi) corporate governance; (vii) health and industrial safety; (viii) business strategy and/or project management.
Hildebrando Vélez Galeano , worked as a consultant and advisor for the Administrative Department of the Environment of Cali (DAGMA) and as advisor to the Ministry of Equality and Equity. He is a chemical engineer from the Universidad Nacional, has a PhD in environmental sciences from the Universidad del Valle, and master’s degrees in philosophy from the Universidad Javeriana and sociology from the Universidad Nacional. He has served as director of Censat Agua Viva, as advisor to Universidad Nacional in the Advisory Group for Trade Unions in Occupational Health, and as a member of the Colombian Safety Council.
Mr. Vélez Galeano has expertise in: (i) the energy industry; (ii) energy transition; (iii) administration, senior management and leadership; (iv) government and/or public policy; (v) human resources and/or talent development; (vi) technology and/or innovation; (vii) health, safety and/or the environment (viii) sustainability; (ix) business strategy and/or project management.
Ángela María Robledo has served as a member of the Advisory Committee for the Development of the National Care System of the Ministry of Equality and is a member of the National Participation Committee on behalf of “ Defendamos la Paz ” in the conversations between the Colombian Government and the Ejército de Liberación Nacional. She is part of the National Government delegation in the peace negotiation in the Department of Nariño with the group “Comuneros del Sur”. She holds a bachelor’s degree in psychology and a master’s degree in political science and international relations from the Pontificia Universidad Javeriana in Bogotá. She was a member of the First and Seventh Commissions of the House of Representatives of the Republic of Colombia, Co-President of the Peace Commission, and a member of the Gender Equity Commission of such body. She has served as an Advisor to the Office of the Dean of Universidad Pedagógica Nacional, on Peace and Gender Issues, she served as Academic Dean of the School of Psychology of the Pontificia Universidad Javeriana and was a member of both, the Academic Counsil and the University Governing Counsil of such institution, where she also served as professor and researcher for its Faculty of Psychology. She has also served as Director of the Administrative Department for Social Welfare of Bogotá. She served as Social Director, Manager, and Coordinator in the fields of health, education, rural development, and the protection of young women’s and children’s rights for the Antonio Restrepo Barco Foundation. She is an independent member of Ecopetrol’s Board of Directors since March 2024.
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Ms. Robledo has expertise in: (i) administration, senior management, and leadership; (ii) government affairs and/or public policy; (iii) human resources and/or talent development; (iv) health, safety and/or environment; (v) sustainability; (vi) human development in the territories (territorial development) and (vii) business strategy and project management. As a member of Ecopetrol’s board of directors, she is periodically trained in ethics, compliance and risk management matters.
Monica de Greiff Lindo is currently a member of the boards of directors of EPS Sanitas S.A.S., Lagos de Aurea S.A.S, the Aris Mining Corporation, located in Cánada, One Young World, located in London, Fiducoldex S.A., and Corporación Historia PAR. She holds a bachelor´s degree is a Ph.D. in jurisprudence and is a specialist in law and a graduate degree in administrative law, both from Universidad del Rosario in Bogotá. She served as Ambassador to Kenya, permanent representative to the United Nations for Environment and Habitat, former CEO of the Bogotá Chamber of Commerce and of the Bogotá Energy Group, as well as a former District Secretary of Economic Development of Bogotá. She served as former presidential advisor for international affairs, Minister of Justice of Colombia, Vice Minister of Justice of Colombia, and Secretary General at the Ministry of Mines and Energy. In addition to her positions in the public sector she also served as Vice President of Legal and Public Affairs at Shell Colombia Inc. and was a member of the board of the International Chamber of Commerce of Paris, Promigas S.A., Corporación de Ferias y Exposiciones S.A ., Grupo Keralty S.A.S and Gran Colombia Gold. She is a member of Ecopetrol’s board of directors since October 24, 2022. She was a non-independent member until October 2, 2023, and as of such date she is an independent member.
Ms. de Greiff Lindo has expertise in: (i) the energy industry and energy transition; (ii) administration, senior management, and leadership; (iii) government affairs and/or public policy; (iv) business risk management; (v) human resources and talent development; (vi) legal affairs and corporate governance; (vii) health, safety and/or environment; (viii) sustainability; (ix) climate change; and (x) business strategy and project management. As a member of Ecopetrol’s board of directors, she is periodically trained in ethics, compliance and risk management matters.
Guillermo García Realpe currently serves as an advisor and consultant, specializing in matters related to environmental conservation and regional development. He holds a bachelor’s degree in law and a graduate degree in socioeconomic sciences from Pontificia Universidad Javeriana . He has served as Secretary General of the Ministry of the Interior, Senator of the Republic of Colombia, Vice President of the Senate, and member of the Third Commission of the Senate. He has also served as President and Member of the Fifth Commission of the Senate, advisor in the National Planning Department in regional development affairs, Director of planning of Nariño, Head of planning of the University of Nariño, and Departmental Secretary of Planning. He is an independent member of Ecopetrol’s board of directors since March 2024.
Mr. García Realpe has expertise in: (i) energy industry and/or energy transition; (ii) administration, senior management and leadership; (iii) governance and/or public policy matters; (iv) finance; (v) human resources; (vi) legal and/or corporate governance matters; (vii) technology; (viii) health and environment; (ix) sustainability; and (x) business strategy. As a member of Ecopetrol’s board of directors, he is periodically trained in ethics, compliance and risk management matters.
Álvaro Torres Macías currently serves as chief executive officer (CEO) of Electryon Power Inc. in Canada. He is an electrical engineer from the Universidad Industrial de Santander in Colombia. He holds a graduate degree in electrical transmission networks from the L’Institut National Polytechnique de Lorraine in Nancy, France, a Master’s degree (M.Eng. and M.Sc.) in electric power engineering and computer and systems engineering from Rensselaer Polytechnic Institute in Troy, USA, and a Ph.D. in electric power engineering from the same institution. He served as a member of the boards of directors of Empresa de Energía de Boyacá - EBSA, Transportadora de Gas Internacional - TGI, Transportadora de Energía de Centroamérica S.A. in Guatemala, Cálidda Energía S.A.C. in Perú, Contugas S.A.C. in Perú, Empresa de Energía de Cundinamarca - EEC , companies of the Grupo de Energía de Bogotá - GEB, ITANSUCA, OPAIN, the technology business incubator Innovar of COLCIENCIAS, SOFTEC, and was an alternate board member of PROMIGAS. He also served as Country Manager of Northland Power Inc. and Electryon Power Inc., both Canadian companies, Manager of Delphi Capital Partners, president of CONALVIAS, Vice President of corporate planning and shareholders portfolio of Empresa de Energía de Bogotá (currently Grupo de Energía de Bogotá - GEB), general manager of SNC Lavalin Inc., as well as senior partner, Technical Manager and General Manager of Consultoria Colombiana S.A. – CONCOL. Similarly, Mr. Torres, in his former leadership roles he has contributed with his expertise in cybersecurity and cyber defense policies and practices. Between 1980 and 2012, he was a professor at Universidad de Los Andes in the Faculty of Electrical and Electronic Engineering. He is an independent member of Ecopetrol’s board of directors since March 2024. Currently, he is the financial and accounting expert of the Board of Directors of Ecopetrol.
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Dr. Torres Macías has expertise in (i) the energy business; (ii) energy transition; (iii) administration, senior management, and leadership; (iv) finance; (v) business risk management; (vi) human resources and/or talent development; (vii) legal matters and/or corporate governance; (viii) technology and/or innovation; (ix) health, safety, and/or environment - HSE; (x) sustainability; (xi) cybersecurity; (xii) climate change; and (xiii) business strategy and project management. As a member of Ecopetrol’s board of directors, he is periodically trained in ethics, compliance and risk management matters.
Ricardo Rodríguez Yee is an Industrial Engineer from the Universidad Distrital Francisco José de Caldas, and a Ph.D. candidate at the Università degli Studi di Palermo in the Model Based Public Planning, Policy Design and Management program. He holds master’s degrees in organizational management from the Université du Québec à Chicoutimi and in Industrial Engineering from the Universidad de los Andes.
He has served as Deputy Comptroller for the Mining and Energy Sector and Vice at the office of the Comptroller General of the Republic, leading fiscal investigations into companies such as Reficar, Bioenergy, Propilco, Hidroituango and Electricaribe. Also, he served as Director of the Mining and Energy Planning Unit, contributing to the indicative planning and strategic development of the sector. He led corporate restructurings in state-owned companies such as Enertolima, Barranquilla Telecomunicaciones , Gecelca, Emsirva and Cedelca and acted as an advisor on investment and strategy to the Chief of Staff of the National Army, the General Commander of the Colombian Armed Forces, the UNDP, the FNG, the Ministry of Mines and Energy, the Office of the Inspector General, the National Federation of Departments and Ecopetrol.
Mr. Rodríguez Yee has expertise in: (i) the energy industry; (ii) energy transition; (iii) administration, senior management and leadership; (iv) government and/or public policy; (v) finance; (vi) business risk management; (vii) human resources and/or talent development; (viii) legal affairs and/or corporate governance; (ix) technology and/or innovation; (x) health and environment; (xi) sustainability; and (xii) business strategy and/or project management.
Luis Felipe Henao Cardona is currently a member of the board of directors of EPM and Director of Lambda Consultoría. He holds a degree in Law from Universidad del Rosario and is a Ph.D. candidate in Law at the University of Salamanca. He also holds specialization degrees in business law from Universidad del Rosario and Criminal Law from the University of Salamanca.
He served as Minister of Housing, Land, and Territory (2013–2016) and previously held roles as Vice Minister of Housing and Vice Minister of Participation and Equal Rights. Additionally, he was Secretary General of the Ministry of the Interior and Justice and the Ministry of Environment, Housing, and Territorial Development. He has been a columnist for El Espectador and El Tiempo and a panelist for Hora 20.
Mr. Henao Cardona has expertise in: (i) the energy industry; (ii) energy transition; (iii) administration, senior management and leadership; (iv) government affairs and public policy; (v) finance; (vi) human resources and/or talent development; (vii) legal and/or corporate governance issues; (viii) the environment; and (ix) business strategy and project management.
Board of Directors from March 2024 to March 2025
Non-independent members:
|
· |
Lilia Tatiana Roa Avendaño |
|
· |
Edwin Palma Egea |
Independent members:
|
· |
Ángela María Robledo Gómez |
|
· |
Mónica de Greiff Lindo |
|
· |
Luis Alberto Zuleta Jaramillo |
|
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Gonzalo Hernandez Jiménez (Independent since May 1 st , 2024) |
|
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Guillermo García Realpe |
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Álvaro Torres Macías (nominated by the hydrocarbon producing departments) |
|
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Juan José Echavarría Soto (nominated by the minority shareholders with largest shareholding) |
Mr. Edwin Palma Egea presented his resignation as member of Ecopetrol’s Board of Directors, effective on March 6, 2025.
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On August 30, 2024, Mr. Juan José Echavarría Soto and Mr. Luis Alberto Zuleta Jaramillo presented their resignations as independent members of the Ecopetrol’s Board of Directors, which became effective on November 9, 2024.
The information below sets forth the names and business experience of directors Gonzalo Hernández Jiménez, Edwin Palma Egea, Luis Alberto Zuleta Jaramillo and Juan José Echavarría Soto. For the business experience of directors Lilia Tatiana Roa Avendaño, Ángela María Robledo Gómez, Mónica de Greiff Lindo, Guillermo García Realpe and Álvaro Torres Macías, please refer to title “Board of Directors from March 2025” immediately above.
Gonzalo Hernández Jiménez currently holds the position of Professor at Pontificia Universidad Javeriana’s department of economics. He is also a member of the board of directors of Financiera de Desarrollo Nacional (FDN), and of the Aris Mining Corporation, located in Canada. He is an economist from the Pontificia Universidad Javeriana , with a master’s degree and Ph.D. in Economics from the University of Massachusetts, Amherst. He was a member of the boards of directors of Grupo Bicentenario S.A.S., and the Administrator of Resources of the General System of Social Security in Health (ADRES, for its acronym in Spanish). He was a member of Ecopetrol’s Board of Directors since October 24, 2022. He was a non-independent member of Ecopetrol’s Board of Directors until April 30, 2024, and as of May 1st, 2024 he was an independent member.
Mr. Hernández Jiménez has expertise in: (i) administration, senior management and leadership; (ii) financial and securities markets; (iii) human resources and/or talent development; (iv) legal affairs and/or corporate governance; (v) business strategy and project management; (vi) health, safety and/or environment; (vii) sustainability, (viii) energy industry, and (ix) government affairs and public policy As a member of Ecopetrol’s board of directors, he was periodically trained in ethics, compliance and risk management matters.
Edwin Palma Egea currently serves as Minister of Mines and Energy of Colombia and previously served as special agent for AIR-E S.A.S. and as Vice Minister of Labor Relations and Inspection at the Ministry of Labor. He holds a bachelor’s degree in law from Universidad Cooperativa de Colombia in Barrancabermeja, as well as graduate degrees in labor law and social security from the Universidad Libre de Colombia in Socorro, Santander. He also holds a graduate degree in constitutional law and a master’s degree in law with a focus on labor law, both from Universidad Externado de Colombia in Bogotá. He also completed the Specialization Course for Latin American Experts in Labor Relations at Universidad de Castilla-La Mancha, Spain. He worked for Ecopetrol for approximately two decades, served as an arbitrator in legal disputes for the Company for more than 10 years, and led the Unión Sindical Obrera (USO) as the National Board Chair from 2018 to 2021. He was a non-independent member of Ecopetrol’s Board of Directors since March 2024.
Mr. Palma Egea has expertise in: (i) administration, senior management, and leadership; (ii) governance and/or public policy; (iii) human resources and/or talent development; (iv) legal matters and/or corporate governance; and (vi) health, safety and/or environment. As a member of Ecopetrol’s board of directors, he was periodically trained in ethics, compliance and risk management matters.
Luis Alberto Zuleta Jaramillo is an economist from the Universidad de Antioquia with a Master of Sciences in Economic Development from the University of Strathclyde in the United Kingdom. He is currently an economic and financial consultant to the audit committee of Bancolombia, Banco Agromercantil of Guatemala and Banistmo of Panama, as well as an Associate Researcher for Fedesarrollo, and a university professor. He has been a member of the boards of directors of Medellín’s Metro, Carbocol, Banco Caja Social, Corporación de Ahorro y Vivienda Colmena, Compañía de Financiamiento Comercial Sufinanciamiento , Bancolombia, Suramericana, Bolsa Mercantil de Colombia, Protección S.A. and member of the governing board of Fundación Social . Mr. Zuleta has served in the following committees: financial and audit committee of the manufacturing company Grupo Crystal S.A.S. and financial committee of ICETEX. Additionally, he is a member of the board of directors of the nonprofit Fundación Pro Niñez Gabriel Herrera Rogelis . He was an independent member of the Board of Directors of Ecopetrol, Chairperson of the Board´s Audit and Risk Committee and financial and accounting expert from March 2023 to November 9, 2024.
Mr. Zuleta has expertise in: (i) energy industry and energy transition; (ii) administration, senior management and leadership; (iii) government affairs and/or public policy; (iv) financial and securities markets; (v) business risk management; (vi) human resources and talent development; (vii) legal affairs and corporate governance; (viii) technology and innovation; (ix) health, safety and environment; (x) sustainability; (xi) cybersecurity; and (xii) business strategy and project management. As a member of Ecopetrol’s board of directors, he was periodically trained in ethics, compliance and risk management matters.
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Juan José Echavarría Soto is an Administrative Engineer from the School of Mines, Universidad Nacional de Colombia , he completed a non-degree program in economics at Harvard University and holds a master’s degree in economics from Boston University and a PhD in Economics from Oxford University. He served as a member of the board of directors of Ecopetrol for four months in 2016. He has been an associate researcher at Fedesarrollo and a university professor He previously served as general manager and director of the Nation´s Central Bank ( Banco de la República ), as a Consultant of the Development Bank of Latin America (CAF), the Inter-American Development Bank (IDB), the Ministry of Commerce and Finagro, Director of the Mission for the Restructuring of Coffee in Colombia, Executive Director of Fedesarrollo, Plenipotentiary Minister of the Colombian Mission to the Organization of American States (OAS), advisor in the area of international trade at the OAS, Vice Minister of Foreign Trade of Colombia and principal negotiator of the Colombia- Chile, Colombian– Central America, Colombia – Caricom, and Colombia ‐ G3 trade agreements, and dean of the Faculty of Economics at Universidad Nacional de Bogotá .
Mr. Echavarría has served on the Boards of Directors of Isagen S.A., Banco de la República, Bolsa y Banca , and Fiduciaria Bogotá . He has been a member of the board of directors of the nonprofit Alejandro Ángel Escobar Foundation. He was an independent member of Ecopetrol’s board of directors, nominated by the minority shareholders with the second largest shareholding (after the Nation), from March 2023 to November 9, 2024, and was the Chairperson of the Board’s Corporate Governance and Sustainability Committee from November 2023 to November 2024.
Mr. Echavarría has expertise in: (i) the energy industry; (ii) the energy transition; (iii) administration, senior management, and leadership; (iv) government affairs and/or public policy; (v) financial and securities market; (vi) human resources and talent development; and (vii) legal affairs and corporate governance. As a member of Ecopetrol’s Board of Directors, he was periodically trained in ethics, compliance and risk management matters.
Board of Directors from March 2023 to March 2024
The previous Board of Directors was elected at the Ordinary Shareholders Meeting held on March 30, 2023. Such Board named Saúl Kattan Cohen as Chairperson and Mauricio Cabrera Galvis as Vice Chairperson. Hence, from January 2024 to March 22, 2024, the Board was composed as follows:
Non-independent members:
| ● | Gonzalo Hernández Jiménez |
| ● | Esteban Piedrahíta Uribe |
Independent members:
| ● | Saúl Kattan Cohen |
| ● | Mónica de Greiff Lindo |
| ● | Claudia González Sánchez |
| ● | Gabriel Mauricio Cabrera Galvis |
| ● | Luis Alberto Zuleta Jaramillo |
| ● | Sandra Ospina Arango (nominated by the hydrocarbon producing departments) |
| ● | Juan José Echavarría Soto (nominated by the minority shareholders with largest shareholding) |
The information below sets forth the names and business experience of each of the Directors elected at the General Shareholders Ordinary Meeting held on March 30, 2023. For the business experience of directors Gonzalo Hernández Jiménez, Luis Alberto Zuleta Jaramillo and Juan José Echavarría please refer to the title “Board of Directors from March 2024 to March 2025” immediately above. For the business experience of Monica de Greiff Lindo, please refer to the title “Board of Directors from March 2025” above.
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Gabriel Mauricio Cabrera Galvis works on investment banking and financial consulting activities as the Director of the firm Cabrera Bedoya, Banqueros de Inversión . He has been member of the Boards of Directors of the Asociación para la Promoción de las Artes (PROARTES), Lloreda S.A. , and Financiera de Desarrollo Nacional . He has also served as President of the Banco de Occidente and Fundación FES, Dean of the Faculty of Economics of Universidad Externado , General Director of Public Credit at the Ministry of Finance and Public Credit, Head of the Global Planning Unit of the National Planning Department, and Technical Vice President, Director of the Economics Department and researcher at Asociación Bancaria de Colombia. He has been also a former director of Clínica DIME S.A., Fabricato S.A., Grupo Energía Bogotá, Empresa de Teléfonos de Bogotá, Propal, Banco de Bogotá, ISA, Carbocol, Astorga S.A., Giros y Finanzas C.F.C., Incorbank S.A. and Ecopetrol S.A. (from 2017 to 2019). He holds a B.A. degree in Philosophy from the Pontificia Universidad Javeriana and a Master’s degree in economics from Universidad de los Andes and is a Ph.D. candidate from the London School of Economics. He had published various books on economic policies and articles on monetary exchange policy and fiscal policy. He was an independent member of Ecopetrol’s Board of Directors from October 24, 2022 to March 22, 2024, and during such period served as the Vice-Chairperson of the Board and Chairperson of its Remuneration, Nomination and Culture Committee.
Mr. Cabrera Galvis has expertise in: (i) the energy industry; (ii) administration, senior management, and leadership; (iii) government affairs and/or public policy; (iv) financial and securities markets; (v) human resources and talent development; (vi) legal and corporate governance; and (vii) business strategy and project management. As a member of Ecopetrol’s Board of Directors, he was periodically trained in ethics, compliance and risk management matters.
Saúl Kattan Cohen was the President of the firm SK Consulting Partners Corp. He has been the liquidator of the companies of Grupo Transtel and an alternate member of the Board of Directors of Tikva S.A. He has served as President of Empresa de Telecomunicaciones de Bogotá, NFCGC Investments and Blockbuster Video Colombia and was a Financial and Economic Researcher at Colombia’s central bank ( Banco de la República ). He has been a member of several Boards of Directors, including Colombia Móvil (TIGO), Empresa de Energía de Bogotá, Contact Center Americas, Colvatel, Skynet, Kokoriko and Pepe Ganga. He holds a bachelor’s degree in economics from the Universidad de los Andes in Bogotá, and he attended the Executive Management Program at the Instituto de Alta Dirección Empresarial (INALDE) in Bogotá and the Advanced Management Program at the Wharton Business School at the University of Pennsylvania. He was an independent member of Ecopetrol’s Board of Directors from October 24, 2022 to March 22, 2024, and during such period served as the Chairperson of the Board and Chairperson of its Business Committee and its Technology and Innovation Committee.
Mr. Kattan Cohen has expertise in: (i) administration, senior management and leadership; (ii) government affairs and public policy; (iii) financial and securities markets; (iv) business risk management; (v) human resources and talent development; (vi) legal matters and corporate governance; (vii) technology and innovation; (viii) cybersecurity; and (ix) business strategy and project management. As a member of Ecopetrol’s Board of Directors, he was periodically trained in ethics, compliance and risk management matters.
Esteban Piedrahíta Uribe previously held the positions of Chairperson of the Chamber of Commerce of Cali, General Director at Departamento Nacional de Planeación, Advisor to the President and then Senior Specialist at the Inter-American Development Bank, Economic Editor of Semana magazine, General Manager of Endriven Colombia/Gas Meridional S.A.S. E.S.P., member of the Advisory Council of Fundación Panthera, member of the board of directors of Cementos Argos S.A., among others. He holds a degree in Economics from Harvard University and a Master’s degree in Philosophy and History of Science from the London School of Economics and Political Science. He is currently the Dean of Icesi University and has served as member of the Boards of Directors of Grupo Argos S.A, Compañía de Seguros Bolívar S.A. and Seguros Comerciales Bolívar S.A. He has also been a member of the Board of Trustees of Fundación Sidoc and Centro Internacional de Entrenamiento e Investigaciones Médicas (CIDEIM). He was a member of the Board of Directors of Ecopetrol from April 2019 to March 22, 2024. He was an independent member and Chairperson of the Board’s Corporate Governance and Sustainability Committee until November 2023, and as of such date, he was a non-independent member of the Board.
Mr. Piedrahíta Uribe has experience in: (i) the energy industry; (ii) energy transition; (iii) administration, senior management and leadership; (iv) government affairs and public policy; (v) business strategy and project management; and (vi) legal matters and/or corporate governance. In addition to the aforementioned positions, Mr. Piedrahíta Uribe has experience in: (i) finance and securities markets, having worked as Investment Banker with Salomon Brothers in New York and Estrategias Corporativas in Bogotá; and (ii) climate change and sustainability, having served as independent member of the Investment Committee of the MGM Sustainable Energy Fund (MSEF) I and II. As for technology and innovation, Mr. Piedrahíta Uribe founded two internet companies: Laciudad.com and Zoom Media Group and participated in the Massachusetts Institute of Technology’s program “Massachusetts Institute of Digital Business Strategy: Harnessing Our Digital Future”. As a member of Ecopetrol’s Board of Directors, Mr. Piedrahíta Uribe was periodically trained in ethics, compliance, and risk management matters.
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Sandra Ospina Arango has over 31 years of experience in the energy industry. She had co-led projects and initiatives for the development and upgrading of national electricity systems; participated in formulating regulations and standards for the future development of smart grids and renewable energies, and in shared-value initiatives between the State, academia and industry, supporting innovation and regional entrepreneurship. She is an Electrical Engineer, licensed in Physical Mathematics from Universidad del Valle . She holds a graduate studies degree in Energy Transmission and Distribution and a master’s degree in Energy Generation from the aforementioned university. She has been a professor of the master’s in engineering at Universidad del Valle and has participated on projects on I+D+I (Research, Development and Innovation, for its acronym in Spanish) at Universidad del Valle . She is a Ph.D. candidate in Electrical and Electronic Engineering at the same University and has led the Smart Grid Group of the Regional Energy Integration Commission (CIER, for its acronym in Spanish) – Latin America. Throughout the past years she has served in management positions at Celsia Colombia S.A. E.S.P. and has been a member of various steering committees in the energy sector for various entities. She was an independent member of Ecopetrol’s Board of Directors from October 24, 2022 to March 22, 2024, and during such period served as the Chairperson of the Board’s HSE (Health, Safety Environment) Committee.
Ms. Ospina Arango has expertise in: (i) energy industry and energy transition; (ii) administration, senior management and leadership; (iii) government affairs and public policy; (iv) financial and securities markets; (v) business risk management; (vi) human resources and talent development; (vii) legal affairs and corporate governance; (viii) technology and innovation; (ix) health, safety and/or environment; (x) sustainability; (xi) cybersecurity; and (xii) business strategy and project management. As a member of Ecopetrol’s Board of Directors, she was periodically trained in ethics, compliance and risk management matters.
Claudia González Sánchez is a lawyer from the Universidad del Rosario with a specialization in financial legislation from the Universidad de los Andes . She served as a member of the Board of Directors of Ecopetrol from March 2018 to March 2019. She is currently the Executive President of the Asociación Colombiana de Corredores de Seguros or “ACOAS,” an association that represents insurance brokers. She served as Legal Secretary of the Presidency of the Republic, Secretary General of the Ministry of Finance and Public Credit, Secretary General of the Ministry of Mines and Energy, Secretary General of the Administrative Department of Security (DAS), National Administrative and Financial Director of the Attorney General’s Office and Deputy Director of Programming for the Central Sector of the National Planning Department (DNP).
Ms. Gonzalez has been a member of the board of directors of various companies including Gecelca, Fiduprevisora S.A., Central de Inversiones S.A. (CISA), Sociedad de Activos Especiales S.A.S. (SAE), Coljuegos, Unidad de Gestión Pensional y Parafiscales (UGPP), Urrá S.A. E.S.P. and Ecopetrol S.A. Given her professional background, she has experience in: (i) the energy industry; (ii) administration, senior management, and leadership; (iii) government affairs and/or public policy; (iv) business risk management; (v) human resources and talent development; and (vi) legal affairs and corporate governance. As a member of Ecopetrol’s Board of Directors, she was periodically trained in ethics, compliance and risk management matters.
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7.3.1 |
Board Practices |
Currently, our Board of Directors is composed of nine members and is responsible for, among other roles, establishing our general business policies. The majority of the Board of Directors must be independent, their independence is determined pursuant to the criteria set out in paragraph two, Article 44, Law 964, 2005, and they must be elected in accordance with the procedure determined in Decree 3923, 2006, or any other provisions that regulate, amend, replace or add such regulations. In addition, pursuant to our bylaws and in accordance with the procedures described therein, the slate of candidates must include, for the last two seats in the Board of Directors, the name of one individual jointly proposed by departments that produce hydrocarbons and one individual jointly proposed by the ten minority shareholders with the largest shareholding participation. According to the Colombian law and the internal regulations, the members of the Board of Directors must be elected by the General Shareholders Assembly in accordance with a proportional representation system similar to cumulative voting (through an electoral quota voting system). The number of votes required to fill each position is calculated by dividing the number of possible votes by the number of open board positions. The members of the Board of Directors may be elected without an electoral quota voting system when there is unanimity. Pursuant to our bylaws, (i) positions on our Board of Directors are appointed in a personal capacity, (ii) at least three members appointed for a specific period must be current members from the preceding period, without including candidates for seats eight and nine, (iii) with retroactive effect to 2021, Directors will be elected for a four-year institutional term, and (iv) members of the Board may be re-elected more than once for the same four-year term without exceeding a total of three terms. Our current Directors were elected at the General Shareholders Assembly held on March 28, 2025.
Our CEO is appointed by the Board of Directors and, as the Company’s general legal representative, will have at least two personal alternates. The CEO is elected and freely removed by the Board of Directors. In accordance with our bylaws, the Board of Directors must evaluate the performance of the CEO. Such results are published in Ecopetrol’s website or in an alternative media vehicle.
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The remuneration of our Directors is set exclusively by the shareholders at the General Shareholders Assembly. Currently, Directors are remunerated for attending board meetings and committee meetings. A Board meeting requires a quorum of at least five members and decisions are approved with a majority of the Directors present.
Under Colombian law, a director or executive officer must abstain from participating in any transaction that may result in a conflict of interest or that involves competing with the company, unless authorized at a General Shareholders Assembly. The general shareholders may approve or reject the participation of the director or executive officer in the transaction giving rise to the conflict of interest with the vote of the majority of the shares present at the General Shareholders Assembly. If the director or executive officer who has the conflict is a shareholder, his or her vote must be excluded. We disclose the number of conflicts of interest of our employees, executive officers and Directors in our annual reports.
Neither our bylaws nor our corporate governance code provide a retirement age for our Directors. Under our bylaws, there is no requirement for a person to have a minimum number of shares to be elected as a Director. Colombian law provides that Directors willing to sell or purchase shares in our Company need prior authorization from the entire Board of Directors. Colombian law does not impose any limitation as to the number of shares that may be acquired by a Director.
Succession policy of the Board of Directors
In 2021 Ecopetrol´s Board of Directors adopted the Board of Directors’ succession policy, with the purpose of (i) ensuring an organized replacement of its members, (ii) minimizing the possible economic and reputational impact that may arise from the change in board membership, (iii) promoting the attraction of human talent, and (iv) ensuring the long-term stability and sustainability of the Ecopetrol Group’s strategy.
On March 22, 2024, the General Shareholders Assembly approved, among others, an amendment to the Company’s bylaws consisting of that the General Shareholders Assembly must approve the succession policy for the members of the Board of Directors.
On March 28, 2025, the General Shareholders Assembly approved, among others, the succession policy for the members of the Board of Directors, since it is the corporate body responsible for approving the succession policy proposed by the Board of Directors. The succession policy maintains the purpose of ensuring an organized replacement of its members and reflects the Company’s preparedness to face any changes arising from handovers in its directorate, a characteristic valued by the Company’s shareholders. The succession policy reduces uncertainty and provides additional surety regarding the transparency and dependability of the selection process for the members of the Board of Directors.
The policy regulates the capacities, obligations, and requirements for the nomination and election of the board members in order to strengthen the transparency of the selection process and guarantee that their capacities contribute to the fulfillment of Ecopetrol’s objectives and strategic plans.
This Policy is part of the corporate rules concerning the succession of the Board of Directors.
Gender diversity
Furthermore, in 2021 Ecopetrol became part of the 30% Club, a global campaign intended to increase gender diversity on boards of directors, whereby Ecopetrol committed itself to boosting efforts to achieve 30% participation of women in senior positions at the Company within a reasonable timeframe; and also, on the boards of the other affiliates of the Ecopetrol Group by adopting a progressive plan. In 2023, the Company ratified its goal to promote an increased participation of women in the boards of directors of companies of the Ecopetrol Group.
Part of this commitment is reflected in the appointment of women on the boards of directors of the Ecopetrol Group, with a participation of 23% in 2024. In 2024, 94 of the 408 positions on the boards of directors of the Group’s companies were held by women.
As for Ecopetrol’s Board of Directors, on January 10, 2024, the General Shareholders Assembly approved an amendment to the Company’s bylaws that requires that at least 30% of the members of the Board of Directors must be women. The current Board of Directors, whose members were appointed on March 28, 2025, is comprised of three women. The amendment aims to promote gender plurality and it anticipates the requirement set forth in Colombia’s National Development Plan (PND for its acronym in Spanish) according to which 30% of the board members of the boards of directors of securities issuers must be women as of 2026.
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7.3.2 |
Board Committees |
Pursuant to our bylaws, our Board of Directors may constitute the committees it considers necessary. The Board of Directors currently has six committees (audit and risk committee, corporate governance and sustainability committee, remuneration, appointments and culture committee, business committee, HSE (health, security and environment) committee and technology and innovation committee). These committees establish guidelines, set specific actions and evaluate and submit proposals designed to improve performance in the areas under their supervision and control. The committees are solely comprised of members of the Board of Directors who are also appointed by the same members. The chairperson of each of the committees must be an independent Director. In addition to applicable regulations, the committees also have their own specific regulations that establish their purposes, duties and responsibilities.
Table 69– Composition of committees of the Board of Directors since April 23, 2025
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Audit and Risk Committee |
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Remuneration, Nomination, and Culture Committee |
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Álvaro Torres Macías
|
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Guillermo García Realpe
|
|
Ángela María Robledo Gómez |
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Mónica de Greiff Lindo |
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Mónica de Greiff Lindo |
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Lilia Tatiana Roa Avendaño |
|
Guillermo García Realpe |
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Alberto José Merlano Alcocer |
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Ricardo Rodríguez Yee |
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Luis Felipe Henao Cardona |
|
|
|
|
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Corporate Governance and Sustainability Committee |
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Business Committee |
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Luis Felipe Henao Cardona
|
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Mónica de Greiff Lindo
|
|
Ángela María Robledo Gómez |
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Guillermo García Realpe |
|
Guillermo García Realpe |
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Álvaro Torres Macias |
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Lilia Tatiana Roa Avendaño |
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Alberto José Merlano Alcocer |
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Alberto José Merlano Alcocer |
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Hildebrando Vélez Galeano |
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|
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Ricardo Rodríguez Yee |
|
|
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Luis Felipe Henao Cardona |
|
|
|
|
|
HSE Committee |
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Technology and Innovation Committee |
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Ángela María Robledo Gómez
|
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Ricardo Rodríguez Yee
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|
Mónica de Greiff Lindo |
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Ángela María Robledo Gómez |
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Álvaro Torres Macias |
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Álvaro Torres Macias |
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Lilia Tatiana Roa Avendaño |
|
Lilia Tatiana Roa Avendaño |
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Hildebrando Vélez Galeano |
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Hildebrando Vélez Galeano |
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|
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Audit and Risk Committee
Our audit and risk committee, which must be comprised of at least three members, all of them independent Directors, is our highest internal control body and provides support to our Board of Directors on risk, accounting and financial matters. It oversees our internal control over financial reporting. It also analyzes the annual hydrocarbons reserves report and provides support for our Board by analyzing topics related to financial matters, risks, control and the assessment of the Company’s internal and external auditors.
All committee members are required to be knowledgeable in accounting matters and at least one of them is required to be an expert in financial and accounting matters.
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Our Board of Directors has determined that Álvaro Torres Macías qualifies as an “audit committee financial expert” and he is independent under the definition of “independent” applicable to us under the rules of the NYSE.
The audit and risk committee approves on a case-by-case basis any engagement of our external independent auditors to provide services different than those related to auditing our financial statements. The audit and risk committee reviews that the additional services do not affect the external auditor’s independence.
Remuneration, Appointments and Culture Committee
Our remuneration, appointments and culture committee, which must be comprised of at least three members, and a majority of independent directors, provides general guidelines for the selection and remuneration of our executive officers and employees, and within the framework of the Ecopetrol Group’s strategy, oversees matters of organizational culture.
Corporate Governance and Sustainability Committee
Our corporate governance and sustainability committee, which must be comprised of at least three members, and a majority of independent directors, supports the Board of Directors in the analysis and decision making related to systems for the adoption of best practices in corporate governance for the oil and gas industry and the energy sector, which include matters related to the adoption of specific measures regarding the Ecopetrol Group’s governance. This committee also supports the analysis and provides recommendations related to the Ecopetrol Group’s sustainability agenda and TESG topics.
Business Committee
Our business committee, which must be comprised of at least five members, and a majority of independent directors, assists our Board in analyzing potential business ventures. Based on its delegation of power, the committee studies and analyzes capital expenditure policies, major investment projects, strategy, new businesses and other matters that would help us move forward in our efforts toward the consolidation of our strategy. The primary criteria used in the committee’s decision-making process are the optimization of our portfolio and the proper allocation of our resources.
HSE Committee (Health, Safety and Environment)
Our HSE committee, which must be comprised of at least three members, the majority of which must be independent, supports the management of the Board of Directors with respect to monitoring and management of risks associated with the health and safety of our employees, contractors and partners. The HSE Committee is also responsible for monitoring Ecopetrol’s environmental management strategy, which includes matters related to the adoption of specific metrics regarding, for example, decarbonization.
Technology and Innovation Committee
Our technology and innovation committee, which must be comprised of at least three members, the majority of which must be independent, supports the management of the Board of Directors with respect to technological and digital transformation, as well as the cultural change that Ecopetrol is undergoing to transform itself into a leading company in the use of technology and digital innovation in the hydrocarbons sector. The Technology and Innovation Committee also reviews TESG-related topics and is in charge of reviewing and monitoring the Ecopetrol Group’s digital strategy, as well as computer security, cybersecurity, cyber defense, privacy and data recovering strategies.
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7.4 |
Compliance with NYSE Listing Rules |
The following is a summary of the significant differences between our corporate governance practices and those required for U.S. companies under the NYSE listing standards.
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NYSE Standards |
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Our Corporate Governance Practices |
|---|---|---|
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Director Independence |
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The majority of the board of directors must be independent. §303A.01. “Controlled companies,” which would include Ecopetrol if we were a U.S. issuer, are exempt from this requirement. A controlled company is one in which more than 50% of the voting power is held by an individual, group or another company, rather than the public. §303A.00. |
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Pursuant to our bylaws, the majority of the Board of Directors must be independent. As of the date of this annual report, we have six independent Directors and three non-independent Directors. The criteria to determine the independent status of Board members is set forth in Colombian Law 964 of 2005, Article 44, Paragraph Two. |
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Executive Sessions |
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The non-management directors of each listed company must meet at regularly scheduled executive sessions without management. §303A.03. |
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A comparable rule does not exist under Colombian law. All Board members are non-management directors. Our Board of Directors’ regular scheduled executive sessions are usually with the Company’s management, but Directors may at any time request sessions without management. |
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Nominating/Corporate Governance and Sustainability Committee |
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A nominating/corporate governance and sustainability committee composed entirely of independent directors is required. The committee must have a charter specifying the purpose, duties and evaluation procedures of the committee. §303A.04. “Controlled companies” are exempt from these requirements. §303A.00. |
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Colombian law does not require the establishment of a nominating and a corporate governance and sustainability committee composed entirely of independent directors. Pursuant to our board charter, these committees shall be composed of a majority of independent Directors. Both the Remuneration, Nomination and Culture Committee and the Corporate Governance and Sustainability Committee have charters specifying their purpose and duties. |
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Remuneration Committee |
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A remuneration committee composed entirely of independent directors is required, which must evaluate and approve executive officer compensation. The committee must have a charter specifying the purpose, duties and evaluation procedures of the committee. §303A.05. “Controlled companies” are exempt from this requirement. §303A.00. |
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Colombian law does not require the establishment of a remuneration committee composed entirely of independent directors. Pursuant to our board charter, this committee shall be composed of a majority of independent Directors. The Remuneration, Nomination and Culture Committee has a charter specifying its purpose and duties. |
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Audit and Risk Committee |
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An audit committee with a minimum of three independent directors satisfying the independence and other requirements of Rule 10A-3 under the Exchange Act and the more stringent requirements under the NYSE standards is required. §§303A.06 and 303A.07. |
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According to Law 964 of 2005, Colombian companies that are authorized to issue securities by the Superintendence of Finance of Colombia must have an audit committee that satisfies the requirements of Law 964 of 2005, including its minimum number of members, independence criteria and audit related duties. Our audit and risk committee is composed entirely of independent Directors, and the committee meets the requirements of Law 964 of 2005 and Rule 10A-3 under the Exchange Act. |
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Equity Compensation Plans |
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Equity compensation plans and all material revisions thereto require shareholder approval, subject to limited exemptions. §§303A.08 and 312.03. |
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Under Colombian law, no similar right to vote on equity compensation plans and material revisions thereto is given to shareholders. We do not give our shareholders the right to vote on equity compensation plans and material revisions thereto. |
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NYSE Standards |
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Our Corporate Governance Practices |
|---|---|---|
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Listed companies must adopt and disclose corporate governance guidelines. §303A.09. |
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The Superintendence of Finance of Colombia recommends the adoption of corporate governance guidelines to all Colombian issuers. According to Superintendence of Finance Circular No. 028, 2014, the adoption of corporate governance guidelines is voluntary. Listed companies must annually publish a corporate governance survey comparing their corporate governance standards with those recommended by the Superintendence of Finance. Our corporate governance code and our survey of the adoption of Colombian practices are available on our website at http://www.ecopetrol.com.co. |
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Code of Ethics for Directors, Officers and Employees |
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Corporate governance guidelines and a code of business conduct and ethics is required, with disclosure of any waiver for directors or executive officers. The code must contain compliance standards and procedures that will facilitate the effective operation of the code. §303A.10. |
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We have adopted a code of ethics which complies with applicable U.S. and Colombian law. Our code of ethics applies to our chief executive officer, chief financial officer, principal accounting officer, persons performing similar functions and to all of the employees, members of the Board of Directors, suppliers, and contractors of Ecopetrol S.A. and its corporate group. Our code of ethics is available on our website at http://www.ecopetrol.com.co |
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7.5 |
Management |
Ecopetrol defines its organizational structure according to Law 1118 of 2006 and its bylaws. Senior management includes positions responsible for general management, policy formulation, and the adoption of plans and projects. Their main functions are: (i) defining and evaluating long-term strategy, (ii) formulating policies, directing the Ecopetrol, (iii) approving plans and projects, (iv) monitoring in senior management committees, and (v) verifying the internal control and risk system. The senior management positions mentioned within this chapter report to the Chief Executive Officer and Vice Presidents, and to the Executive Vice President of Hydrocarbons.
On April 26, 2024, we announced the following senior management changes and appointments:
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1. |
Rafael Ernesto Guzmán Ayala, former President of Hocol, was appointed acting COO as of May 11, 2024 and served in that position until his appointment as Executive Vice President of Hydrocarbons in January 2025 Alberto Enrique Consuegra Granger, who had been serving as Chief Operating Officer (COO), served until May 10, 2024. |
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2. |
Felipe Trujillo López as Vice President Commercial and Marketing. Dr. Trujillo has been in charge of this Vice-Presidency since January 20, 2024. |
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3. |
Victoria Irene Sepúlveda Ballesteros as Corporate Vice President of Human Resources. Dr. Sepúlveda has been in charge of this Vice-Presidency since January 19, 2024. |
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4. |
María Cristina Toro Restrepo as Legal Vice President effective as of May 7, 2024. |
On June 28, 2024, we announced the following senior management changes:
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1. |
Sandra Lucía Rodríguez, who served as Vice President of Sustainable Territorial Development, was appointed the Corporate Vice Presidency of Territorial Transformation and Health Safety and the Environment. |
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2. |
Jaime Pineda, who served as Vice President of Procurement and Services, was appointed the Vice Presidency of Administration and Services. |
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3. |
Germán González, who served as Vice President of Corporate Affairs and Secretary General, took on the position of Secretary General and became in charge of the Corporate Directorate of Institutional Relations and Communications. |
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4. |
As a result of the voluntary resignation to the Company by María Catalina Escobar, the former Corporate Vice President of Finance and Sustainable Value in charge, the Board appointed Javier Cárdenas, who previously served as Control and Reporting Manager, as Vice President in charge. |
On July 31, 2024, we announced the following senior management changes:
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1. |
Sandra Lucía Rodríguez as Corporate Vice President of Territorial Transformation and HSE as of August 1, 2024. Sandra has been in charge of this vice presidency since June 28, 2024. |
|
2. |
Camilo Barco Muñoz as Corporate Vice President of Finance and Sustainable Value as of August 20, 2024. |
|
3. |
Jaime Andrés García as Vice President of Procurement and Services as of September 2, 2024. |
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4. |
Alberto José Vergara Monterrosa as Corporate Director of Compliance as of August 1, 2024. Alberto was in charge of the Corporate Compliance Vice Presidency since April 2024 and the Corporate Compliance Directorate since June 6, 2024. |
On August 30, 2024, we announced Nicolás Azcuénaga Ramírez, whose former position was Corporate Vice President of Strategy and New Businesses, who held that position until September 15, 2024 by mutual agreement. As his replacement, the Board of Directors appointed Julián Lemos Valero, Mergers and Acquisitions Manager, as acting Corporate Vice President of Strategy and New Businesses, effective September 16, 2024 and until the appointment of the position is made.
On October 1, 2024, we announced Juan Carlos Hurtado Parra as Vice President of the Upstream segment, who was in charge of this department since June 15 and assumed the position permanently as of October 1.
On October 16, 2024, we announced Carlos Mauricio Avila Saldarriaga was appointed as Vice President of Subsidiaries and Assets with Partners.
On December 13, 2024, we announced the following senior management changes:
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1. |
Germán González Reyes, who was serving as Secretary General since September 29, 2023 and Acting Director of Institutional Relations and Communications since June 28, 2024, held that role until January 17, 2025. |
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2. |
Cristina Toro Restrepo, the former Corporate Legal Vice President, as Acting Secretary General, effective as of January 18, 2025, until the position was permanently filled by María Cristina Toro Restrepo on January 31, 2025. |
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3. |
Rodolfo García Paredes, former Hydrocarbons Legal Manager, as Acting Corporate Legal Vice President, effective as of January 18, 2025, until was permanently filled by María Cristina Toro Restrepo on January 31, 2025. |
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4. |
Diana Marcela Jiménez, former Regulatory Strategy Manager, as Acting Director of Institutional Relations and Communications, effective as of January 18, 2025, until the position is permanently filled. |
On January 15, 2025, we announced the following senior management changes:
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1. |
Walter Fabián Canova, who had served as Vice President of Refining and Industrial Processes, performed his duties until January 15, 2025 and terminated his employment contract by mutual agreement after working at the Company for more than seven years. |
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2. |
Felipe Trujillo López, current Vice President of Commercial and Marketing, serves as Vice President of Refining and Industrial Processes until a permanent appointment is made. |
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3. |
Julio César Herrera serves as Vice President of Commercial and Marketing in charge and until a permanent appointment is made. |
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On January 31, 2025, we announced the following senior management changes:
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1. |
María Cristina Toro Restrepo was confirmed as Corporate Legal Vice President and General Secretary. This Vice Presidency reports directly to the President. |
|
2. |
Rafael Ernesto Guzmán Ayala was appointed Executive Vice President of Hydrocarbons. He will continue to report directly to the President. |
On April 23, 2025, we announced the following senior management changes:
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1. |
Diana Marcela Jimenez Rodriguez was confirmed as Director of Institutional Relations and Communication. |
|
2. |
Julian Fernando Lemos Valero was confirmed as Corporate Vice President of Strategy and Business Development. |
|
3. |
Julio Herrera was confirmed Vice President of Commercial and Marketing. |
The following presents information concerning our executive officers and senior management as of April 23, 2025. Unless otherwise noted, the majority of these individuals are Colombian citizens.
Executive Officers
Ricardo Roa Barragán has served as the Chief Executive Officer of Ecopetrol S.A. since April 2023. Since joining Ecopetrol, he has led the Group’s energy transition, achieving significant progress in energy efficiency, in the expansion of renewable energy portfolio within the Group’s operations, as well as strengthening ISA’s energy transmission and roads businesses. Mr. Roa has also strengthened the role of the hydrocarbons business and its contribution to the national economy and to Ecopetrol’s shareholders. He has an extensive 30-year-plus professional career as CEO, General Manager and Director, with significant achievements in energy and gas companies in United States, Brazil, Peru, Guatemala, Honduras and Colombia. His vast experience includes roles as General Manager of Electrificadora de Santander, Director of Commercialization and Business Manager in Energy and Methanol of Ingenios Incauca and Providencia, President of Transportadora de Gas Internacional TGI, President of Grupo Energía Bogotá, General Manager of Controles Eléctricos de Colombia, President of Central Termoeléctrica La Luna, and General Manager of Empresa Energía Honduras. He holds a degree in mechanical engineering from Universidad Nacional de Colombia, and specialization in Engineering Management Systems from Pontificia Universidad Javeriana.
Rafael Ernesto Guzman has served as Chief Operating Officer of Ecopetrol S.A. since May 2024. Prior to this role, he was President and CEO of Hocol, Ecopetrol S. A’s upstream subsidiary since March 2019 and Technical Vice-President of Ecopetrol S.A since May 2013. Mr. Guzman has over 25 years of experience in the oil and gas industry, where he has held several positions as regional production manager. Mr. Guzman worked with ENI in managerial positions in Europe and Latin America and in BP, where he started his professional career as a Senior Reservoir Engineer for the large Cusiana field. Mr. Guzman holds a B.S. degree in Petroleum Engineering from Universidad America in Colombia (1995), a M.S. in Petroleum Engineering and a PhD in Petroleum Engineering with minor in Mathematics both from Stanford University.
Camilo Barco Muñoz , has served as Corporate Vice President of Finance and Sustainable Value since August 30, 2024. He is a Senior Executive with more than 30 years of successful experience in management positions, both in the public and private sectors. Currently, certified ESG Member of several Boards of Directors in Colombia– Jaramillo Mora Constructores JMC, Banco Agrario de Colombia BAC, FONDES, OZONO ESP and for former member of other important Boards in large companies across Latin America, including among others: Ecopetrol, Bancoldex, Telefónica, ISA Capital do Brasil, CTEEP, Red Eléctrica del Perú, Intervial Chile, INFRAMCO and Metro de Bogotá. He is a dynamic and encouraging leader with strong competencies in high performance team management, strategic planning, corporate governance, corporate finance and new business structuring and development. As an Investment Banker, he participated in the structuring and execution of an extensive number of transactions, either in advisory (MA), Structured finance and debt capital markets. Previously, as a Consultant, he accompanied the Colombian Government and a wide list of public and private companies in the execution of strategic projects aimed at sustainability and value generation. In addition, Mr.Barco served as Country Head of Investment Banking of Banco Itaú in Colombia; General Director of State-Owned Enterprises in the Ministry of Finance and Public Credit (holding entity of state companies); Managing Director Head of Investment Banking at BBVA Colombia; CFO of Grupo ISA; Manager of Financial Consulting at Deloitte; and Advisor to UNDP for the Privatization and Concessions Program in Colombia. He is a lawyer from Universidad del Rosario, Specialist in financial law from Universidad de los Andes, has carried out various executive courses in Corporate Finance, Capital Markets and International Finance at Chicago Booth School of Business and at the London School of Economics-LSE.
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Management Team
Juan Carlos Hurtado Parra has served as Vice President of Upstream since October 1, 2024. He is an electrical engineer, and has a Master in Business Administration (MBA) in international oil and gas as well as a specialization in Project Evaluation and Development. Mr. Hurtado has worked for over 27 years in the oil and gas sector, including extensive experience in executive positions within Ecopetrol and and Transportadora de Gas Internacional (TGI). Mr. Hurtado’s professional expertise includes resource management and coordination, processes and project methodologies, the development and operation of hydrocarbon production fields, and gas transport system operation and maintenance processes management, among others.
Alexander Cadena Motezuma has served as President of Cenit since May 2024. He previously served as President of Ocensa as of March 2020, President of ODL from 2018 to 2020, and Director of Strategy and New Business at Cenit from 2012 to 2016. Alexander has held multiple leadership positions in Ecopetrol, including New Business Manager for Downstream, Head of the Risk Management Unit in the Financial Vice Presidency, Gas Management Coordinator in the Business Management area, and served as Process Engineer at the Barrancabermeja Refinery. Additionally, he has been member of the boards of directors of Ocensa, ODL, ODC, Empresa de Energía de Bogotá, Bioenergy, Gases de la Guajira, Gasoriente, Surtigás, and Invercolsa, among others. A Chemical Engineer from the Universidad Industrial de Santander, Mr. Cadena boasts over 30 years of experience in the energy sector in the areas of production and transportation of hydrocarbons, natural gas, electricity, renewable energies, regulation, and competitiveness. Additionally, he holds a Master’s in Business Administration from Universidad Externado de Colombia.
Felipe Trujillo is the Acting Vice-President of Refining and Industrial Processes in charge of the Ecopetrol Group since January 2025. He has been a member of the board of directors of Ecodiesel and Ecopetrol US Trading. He is an Industrial Engineer from Pontificia Universidad Javeriana, with a Specialization in Strategic Marketing from “Colegio de Estudios Superiores de Administración - CESA” and has an MBA from “Universidad de Los Andes.” He has 26 years of experience in leadership positions in the commercial and marketing departments, including new business structuring. The last 20 years of his work experience have been in the oil and gas industry at Ecopetrol, working in various positions such as National Commercialization Manager, Petrochemicals and Industrials Manager, Downstream New Business Manager and Gas Manager and Vice-President Commercial and Marketing.
David Riaño Alarcón has served as Vice President of Energies for the Transition since August 18, 2023. He has over 28 years of experience in the energy sector, having held leadership positions in companies and entities in the energy and gas sector. His knowledge of the energy market has been attained in renowned companies including Transportadora de Gas Internacional, Empresa de Energía de Cundinamarca, Gas Natural Fenosa, Red de Energía del Perú (ISA), in trade associations such as ACOLGEN and government entities such as the Superintendence of Public Services (SSPD) and the Energy and Gas Regulatory Commission (CREG). He is an electrical engineer with a bachelor’s degree from the University of La Salle and three master’s degrees in economics from Universidad Javeriana, in industrial engineering from Universidad de los Andes, and in business administration from University of Warwick.
Julián Fernando Lemos Valero is the Corporate Vice President of Strategy and Business Development since April 23, 2025. He graduated as a Mechanical Engineer from Universidad Nacional de Colombia and completed a specialization in economic and social appraisal of projects from Universidad de los Andes. Mr. Lemos has 18 years of professional experience in the energy sector, primarily in the assessment of investment opportunities in energy, gas, petrochemicals, and biofuels. His previous positions include Business Development Manager and strategy manager at Mitsubishi Corporation, a Japanese multinational. In Ecopetrol, he has been part of the Corporate Vice Presidency of Strategy and Business Development since 2017, with responsibilities for developing the energy, gas infrastructure, and petrochemicals businesses, among others. He played a prominent role in the team that completed the purchase of ISA in August 2021 and successfully headed the Mergers and Acquisitions Management area from December 2022 to September 2024.
Sandra Lucia Rodriguez Rojas has served as Vice president of Territorial Transformation HSE since October 2023; managers for Social Prosperity, Dialogue and relations with stakeholders, Sustainability and environmental management, Territorial planning and monitoring, also Territorial Management HSE for Hydrocarbons as well as energies for transition, all report to her. Ms. Rodriguez is a lawyer from the Pontificia Universidad Javeriana (Bogotá, Colombia) who specialized in business law —at that same university— and in Administrative Law at Universidad Santo Tomás (Bogotá, Colombia). She also holds two masters’ degrees: one in Public Law and another one in Environmental Policy and Management, both from Universidad Carlos III (Madrid, Spain). Before being appointed Ms. Rodriguez served as Colombia’s Deputy Ombudsman for Environmental and Collective Rights since 2018. She was one of the founding members of the Center for Environmental Law Studies at Pontificia Universidad Javeriana (Bogotá, Colombia), conducted research in Administrative Law, Economic Law, and Environmental Regulation since 1998 and stays an Administrative Law and Environmental Law professor for the university graduate programs.
239
Jaime Andrés García Cuello was appointed as Vice President of Supply and Services in September 2024. Prior to this appointment, he was Executive Vice President of Banco Agrario. Mr. Garcia has 24 years of professional experience, having served in strategic positions in both national and multinational companies. His expertise concentrates on supply chain, operations, purchasing, finance, and shared services management, in roles such as Procurement and Supply Chain Director and Human Capital Supply Chain Vice President of ETB S.A. - E.S.P; Vice President of operations of dexFreight Corp.; Procurement, Administrative and Organizational Development Director of Grupo Empresarial Oleoflores; and Procurement Director of DIRECTV Colombia Ltd. He has also served as advisor to board of Directors in companies and has been a professor at the Universidad del Norte in purchasing and supply management, organizational development and culture, and strategic management and organizational design. He graduated as a Civil Engineer from Universidad de los Andes and has a Master’s in Business Administration from Universidad Politécnica de Madrid, Spain.
María Cristina Toro Restrepo has served as Corporate Vice-President of Legal Affairs and Secretariat since May 7, 2024. She holds a law degree from Universidad de Caldas university. She has completed specialization programs in Mining-Energy Law at Universidad Externado de Colombia and Commercial Law and Tax and Customs Legislation at Universidad de Caldas. In her 26 years of professional experience, she served as General Secretary of Medellin’s public utilities company (EPM), headed the Legal Counsel Office of the Metro of Bogotá, acted as General Secretary of the Metro of Medellín, headed the Labor Relations Management area of EPM, served as General Secretary and Legal Vice President of Grupo Energía de Bogotá, General Secretary of CHEC and Legal Director of Aguas de Manizales. Ms. Toro is a member of Women in Connection, and both the Women Corporate Directors’ Community and Leadership Advisory Board of CESA, a private business administration college in Bogota.
Alberto José Vergara Monterrosa has served as the Corporate Director of Compliance since August 1, 2024. With over 23 years of expertise in Ecopetrol, Alberto José has harnessed his knowledge to simultaneously pursue an academic career, working as a professor at the Universidad Nacional and Universidad Católica de Colombia universities. He is a lawyer from Universidad Nacional with a specialization in Procedural Law from the same university. He also realized additional specializations in business law and contract law from the Universidad Colegio Mayor de Nuestra Señora del Rosario and Commercial Law from the Universidad de los Andes University and holds a Master’s Degree in Private Law from the latter. Prior to this new role, Mr. Vergara worked as Corporate Ethics and Compliance Affairs Manager from 2023 to date and as Compliance Investigations Coordinator from 2020 to 2023 with a corporate purview for the Ecopetrol Group. He joined Ecopetrol in November 2000 and served in various roles in a number of departments, including the Internal Disciplinary Control Office (2000 – 2008), the Internal Audit Directorate (2008 – 2014), the Vice Presidency of Legal Affairs (2015), Head of the Ethics and Compliance Unit (2015), Counselor to the Vice Presidency of Compliance (2015 – 2016), and Corporate Internal Audit Management (2016 – 2020), where he served as Head of Legal Affairs. He has vast knowledge and experience in the independent assurance of management, governance, control, and risk processes within the macro processes and projects of the Upstream, Downstream, Midstream, and corporate segments of the Oil Gas industry.
Julio Herrera is the Vice President of Commercial and Marketing since April 23, 2025. He is a Certified Public Accountant from Universidad Javeriana and holds studies in Marketing and Sales from Kellogg School of Management at Northwestern University in Chicago, as well as in Finance from the Wharton School of Business at the University of Pennsylvania. With over 30 years of experience in the oil and gas industry. Throughout his career, he has excelled in leadership roles in Finance and Strategy, Planning, Business Development, Operations, Upstream, Downstream, and Midstream. From his various positions at ExxonMobil, BP, Ecopetrol and other American private energy companies, he has been a key player in complex international ventures across the Americas, the Caribbean, Europe, Africa, the Middle East, and Australia. In recent years, he has focused on Crude and Product Marketing in the Americas.
Sergio Andrés Moreno Acevedo, has served as Acting Corporate Vice President of Science, Technology, and Innovation at Ecopetrol S.A, since January 17, 2025. He holds a systems engineer degree from the Industrial University of Santander, with a specialization in technology management. He has over 25 years of experience in transformation, digital strategy, and innovation. He has held key roles in globally oriented companies, leading digital transformation initiatives. His career includes high-responsibility positions with multiple achievements in process optimization from tactical, operational, and strategic perspectives, impacting operational efficiency and service experience. He has strong skills in transformational leadership, strategic planning, adaptability, critical thinking, innovation, and problem-solving.
Victoria Irene Sepúlveda Ballesteros has served as the Corporate Vice President of Organizational Talent since January 19, 2024. She is a lawyer specializing in Commercial Law and an MBA candidate, with nearly 20 years of experience in administrative and human management roles. She has extensive expertise in human talent management and labor relations within companies and business groups in the energy sector in Colombia. Previously, she was the Human Management Manager at Chilco, the parent company in Colombia of the Lipigas Group. She has held corporate roles in business groups as Director of Subsidiaries and Resource Manager. Among her notable projects, her strategic planning stands out, addressing complex situations assertively, constantly seeking to engage with peers and superiors to find the best solutions that add value. She has experience in organizational transformation projects, project management, process management, and continuous improvement.
240
Ricardo Montes Gómez has served as Corporate Director of Internal Audit for the Ecopetrol Group since September 1, 2016. Mr. Gomez is a Public Accountant from the Universidad Externado of Colombia, holds a Master’s in Business Administration from the INALDE Business School of Universidad de la Sabana of Colombia, and completed the Certified Financial Planning certificate program of Southern Methodist University located in Dallas, USA. He has over 40 years of professional experience both locally and internationally in the Oil Gas sector, undertaking various leadership roles within Internal Audit and Financial Management, as well as serving as Chief Financial Officer (CFO) and Comptroller of public and private companies within this sector.
Diana Marcela Jimenez Rodriguez is the director of Institutional Relations and Communication since April 23, 2025. She is an electrical engineer from the Universidad de los Andes, with additional qualifications in business administration. She holds a specialization in business administration from UCUF Spain, and she has an executive master’s in business administration from EADA Business School. With over 20 years of experience, Diana has held strategic positions in the energy sector both nationally and internationally. She has served as director for the Ecopetrol Group in Gas and LPG, and Regulatory Strategy, and as vice-president for Institutional Relations, Regulation, and the Environment for the Enel Group in Colombia and Central America. Moreover, she has been business development manager (VP) for Enel Group companies in Colombia and advisor to the CREG.
None of our Directors, Executive Officers or members of senior management has any familial relationship with any other Director, Executive Officer or member of senior management.
|
7.6 |
Compensation of Directors and Management |
Based on a resolution adopted at our annual shareholders’ meeting in 2012, compensation for Directors’ attendance at meetings of the Board of Directors and/or committee meetings was set to six minimum monthly wage salaries, which totals approximately COP 8.5 million for 2025 and COP 7.8 million for 2024. See Note 31.1 to our consolidated financial statements for more details.
During 2024, the total compensation paid to our Board Directors amounted to COP 6,139 million and the remuneration paid to executive officers and senior management amounted to COP 23,186 million. The latter includes amounts paid to certain Directors, executive officers and senior management pursuant to a bonus plan under which such persons are entitled to receive variable compensation based on the Company’s results for each year. Ecopetrol has a short-term and long-term variable compensation.
The short-term variable compensation for senior management is recognized based on the annual company’s results associated with the achievement of strategic objectives and the goals of the Company´s Balanced Scorecard (“BSC”). 2024 BSC includes metrics based on four strategic pillars: (i) Grow with the Energy Transition (that weighs 25% of the BSC); (ii) Generate Value with sustainability (10%), (iii) Cutting-edge Knowledge (5%), and (iv) Competitive Returns (50%). The remaining 10% of the BSC corresponds to the most important cultural principle for Ecopetrol, “Life First”.
None of the members of our management team are eligible to receive pension and retirement benefits from us.
Implementation of the Long-Term Incentive Plan
Companies have increasingly incorporated incentive compensation plans into their compensation structures, in line with good international practices, to drive exceptional and sustainable results to meet stakeholder expectations. Long-Term Incentives Plans (ILPs for its acronym in Spanish) are designed to generate incremental value for shareholders based on the Company’s proposed objectives and goals. These plans offer senior management a compensation mechanism consistent with the achievement of those strategic objectives and align incentives for beneficiary leaders with the Company’s success in meeting these strategic objectives.
Ecopetrol’s general ILP Plan is managed through a voluntary pension fund administered by a legally authorized financial entity, as required under Colombian law. The fund receives cash contributions from Ecopetrol with the mandate of investing such cash in ordinary shares of the Company, through open market purchases in Colombia. Once the plan expires and the company confirms and provided that the goals are met, the contributions become equity for the beneficiaries, and they will be able to determine the allocation of any earned contributions according to the following options:
| ● | Keep the contributions in the portfolio that invests in Ecopetrol shares and over which Ecopetrol does not exercise investment decisions. |
| ● | Monetize the equity to invest the contributions (totally or partially) in other investment portfolios offered by the fund’s manager. |
| ● | Monetize the equity by withdrawing the cash (totally or partially) from the fund. |
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Every year, the Board of Directors approves a set of metrics and objectives that are aligned with the corporate strategy and business plan. These objectives are updated periodically and are valid for a three-year term. The metrics and objectives seek to accelerate the path of the energy transition and guarantee the country’s energy sovereignty. They are regularly monitored to ensure that the company stays on track and is making progress towards meeting its strategic goals. Currently, there are three ILP plans in effect:
(i) for the 2022-2024 period, the metrics are Operational Cash Flow – OCF (60%), Greenhouse Gas Emissions (GHG) reduction (20%) and Oil Production (20%);
(ii) for the 2023-2025 period, the metrics are related to Free Cash Flow (FCF) (50%), Reserve Replacement Ratio (RRR) (20%), New Energies (including hydrogen production and incorporation of renewables) (20%), and Greenhouse Gas Emissions (GHG) reduction (10%); and
(iii) for the 2024-2026 period, the metrics are related to Free Cash Flow - FCF (40%), Return on Average Capital Employed - ROACE (20%), Reserve Replacement Ratio - RRR (20%), and Energy Reduction Cost (20%).
Currently, the ILPs are part of the compensation scheme applicable to the CEO, Vice Presidents, equivalent positions, and other positions at Ecopetrol, according to their level of responsibility and relevant performance criteria. This compensation scheme applies to all of Ecopetrol’s subsidiaries.
|
7.7 |
Share Ownership of Directors and Executive Officers |
The following table sets forth the executive officers and directors that own shares of Ecopetrol S.A. as of January 31, 2025. Under Colombian law, all of our shareholders have the same economic privileges and voting rights.
Table 70 – Executive Officers and Directors owning Ecopetrol’s shares
|
Executive Officer |
|
Number of shares (1) |
|
% Ownership |
|
|
Edwin Palma Egea |
|
25 |
|
0.0000001 |
% |
|
Juan Carlos Hurtado Parra |
|
2,000 |
|
0.0000050 |
% |
|
Luis Felipe Rivera Garcia |
|
13,750 |
|
0.0000330 |
% |
|
7.8 |
Controls and Procedures |
Disclosure Controls and Procedures
As required by Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as of December 31, 2024, we evaluated the design and effectiveness of our financial disclosure controls and procedures under the supervision and participation of our management, including our Chief Executive Officer and Chief Financial Officer. There are inherent limitations to the effectiveness of any system of disclosure controls and procedures, including the possibility of human error and the circumvention or overriding of the controls and procedures. Accordingly, even if effective, disclosure controls and procedures can only provide reasonable assurance of achieving their control objectives.
Based upon this evaluation, our Chief Executive Officer and Chief Financial Officer concluded that as of the end of the period covered by this annual report, our disclosure controls and procedures were effective to provide reasonable assurance that the information required to be disclosed in the reports that we file and submit under the Securities Exchange Act of 1934 is recorded, summarized and reported as and when required and is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosure.
242
Management’s Annual Report on Internal Control over Financial Reporting
Our management is responsible for establishing and maintaining adequate internal control over financial reporting as defined in Rules 13a - 15(f) and 15(d) - 15(f) under the Securities Exchange Act of 1934. Our internal control over financial reporting is a process designed under the supervision of our Chief Executive Officer and Chief Financial Officer, and monitored by our board of directors, management and other personnel, in order to provide reasonable assurance regarding the reliability of financial reporting and the preparation of our financial statements for external reporting purposes in accordance with generally accepted accounting principles, and it includes those policies and procedures that: i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect transactions and dispositions of our assets; ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures are being made only in accordance with authorization of our management and directors; and iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of our assets that could have a material effect on our financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Therefore, effective control over financial reporting cannot, and does not, provide absolute assurance of achieving our control objectives. Also, projection of any evaluation of the effectiveness of the internal controls to future periods is subject to the risk that controls may become inadequate because of changes in conditions or that the degree of compliance with the policies or procedures may deteriorate.
As of the year ended December 31, 2024, our management conducted an assessment of the effectiveness of our internal control over financial reporting in accordance with the criteria established in the publication “Internal Control – Integrated Framework (2013),” issued by the Committee of the Sponsoring Organizations of the Treadway Commission, as well as the rules set by the SEC in its Final Rule “Management’s Report on Internal Control Over Financial Reporting and Certification of Disclosure in Exchange Act Periodic Reports.”
Based on the assessment performed, management concluded that our internal control over financial reporting was effective as of December 31, 2024.
The effectiveness of our internal control over financial reporting has been audited by Ernst Young Audit S.A.S., an independent registered public accounting firm, as stated in their audit report accompanying our consolidated financial statements.
Audit and Non-Audit Fees
Our consolidated financial statements for the fiscal years ended December 31, 2024 and 2023 were audited by Ernst Young Audit S.A.S. The following table sets forth the fees billed to us by Ernst Young Audit S.A.S. during the fiscal years ended December 31, 2024 and 2023.
Table 71 – Fees Billed to us by Ernst Young Audit S.A.S.
|
|
|
For the year ended December 31, |
||
|
COP Millions, excluding 19% Value Added Tax |
|
2024 |
|
2023 |
|
Audit fees |
|
24,649 |
|
23,845 |
|
Tax fees |
|
— |
|
— |
|
All other fees |
|
133 |
|
132 |
|
Total |
|
24,782 |
|
23,977 |
Audit Fees. The audit fees listed in the table above are the aggregated fees billed by Ernst Young and its affiliates. in connection with their audits of our annual consolidated financial statements (IFRS), interim consolidated financial statements (under IFRS), statutory audits of Ecopetrol S.A. and its consolidated subsidiaries and some of its associate entities (under local GAAP) and review of periodic documents filed with the SEC. In addition, these audit fees include fees related to our independent auditors’ audits of our internal controls over financial reporting.
Tax fees. Tax fees in the above table are fees billed by Ernst Young for pre-approved services related to technical compliance with tax matters of one of our subsidiaries.
243
All Other Fees. The all other fees listed in the table above are the aggregated fees billed by Ernst Young Audit S.A.S. in connection with the review of our sustainability report.
Changes in Internal Control over Financial Reporting
There were no changes made in our internal control over financial reporting for the year ended December 31, 2024 that have materially affected or are reasonably likely to materially affect our internal controls over financial reporting.
Attestation Report of the Registered Public Accounting Firm
Ernst Young Audit S.A.S.’s attestation report on our internal control over financial reporting is included in their audit report accompanying our consolidated financial statements. See Report of Independent Registered Public Accounting Firm to the consolidated financial statements.
Clawback Policy
On November 30, 2023, we approved its claw-back policy providing for the recovery of erroneously awarded incentive-based compensation “received” by current and former executive officers in connection with a financial restatement, regardless of fault or misconduct, on or after October 2, 2023. A copy of our claw-back policy is attached hereto as Exhibit No. 7.1.
Insider Trading Policy
On March 25, 2025, the
244
8. Financial Statements
Ecopetrol S.A.
Consolidated Financial Statements
As of December 31, 2024, and 2023 and for the three years in the period ended December 31, 2024
Index
|
Report of Independent Registered Public Accounting Firm
(Ernst Young Audit SAS, Auditor Firm ID
|
F-3 |
|
|
|
|
|
|
Report of Independent Registered Public Accounting Firm
(Ernst Young Audit SAS, Auditor Firm ID
|
F-8 |
|
|
|
|
|
|
F-10 |
||
|
|
|
|
|
F-11 |
||
|
|
|
|
|
F-12 |
||
|
|
|
|
|
F-13 |
||
|
|
|
|
|
F-14 |
||
|
|
|
|
|
F-15 |
||
|
|
|
|
|
F-15 |
||
|
|
|
|
|
F-18 |
||
|
|
|
|
|
F-21 |
||
|
|
|
|
|
F-41 |
||
|
|
|
|
|
F-43 |
||
|
|
|
|
|
F-45 |
||
|
|
|
|
|
F-46 |
||
|
|
|
|
|
F-47 |
||
|
|
|
|
|
F-50 |
||
|
|
|
|
|
F-61 |
||
|
|
|
|
|
F-62 |
||
|
|
|
|
|
F-64 |
||
|
|
|
|
|
F-68 |
||
|
|
|
|
|
F-70 |
||
|
|
|
|
|
F-72 |
||
F-1
|
|
|
|
|
F-73 |
||
|
|
|
|
|
F-74 |
||
|
|
|
|
|
F-80 |
||
|
|
|
|
|
F-81 |
||
|
|
|
|
|
F-84 |
||
|
|
|
|
|
F-84 |
||
|
|
|
|
|
F-88 |
||
|
|
|
|
|
F-97 |
||
|
|
|
|
|
F-99 |
||
|
|
|
|
|
F-103 |
||
|
|
|
|
|
F-104 |
||
|
|
|
|
|
F-104 |
||
|
|
|
|
|
F-105 |
||
|
|
|
|
|
F-105 |
||
|
|
|
|
|
F-113 |
||
|
|
|
|
|
F-116 |
||
|
|
|
|
|
F-118 |
||
|
|
|
|
|
Supplemental information on oil and gas producing activities (unaudited) |
F-125 |
|
|
|
|
|
|
F-130 |
||
|
|
|
|
|
Exhibit 1 – Consolidated subsidiaries, associates, and joint ventures |
F-132 |
|
|
|
|
|
|
F-138 |
||
|
|
|
|
|
Exhibit 3. Quantitative information of concession services contracts |
F-143 |
|
F-2
Report of Independent Registered Public Accounting Firm
To the Shareholders and the Board of Directors of Ecopetrol S.A.
Opinion on the Financial Statements
We have audited the accompanying consolidated statements of financial position of Ecopetrol S.A. (the Company) as of December 31, 2024 and 2023, the related consolidated statements of profit or loss, comprehensive income, changes in equity and cash flows for each of the three years in the period ended December 31, 2024, and the related notes and financial statement schedules listed in exhibits 1, 2 and 3 (collectively referred to as the “consolidated financial statements”). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company at December 31, 2024 and 2023, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2024, in conformity IFRS Accounting Standards as issued by the International Accounting Standards Board (IASB).
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the Company's internal control over financial reporting as of December 31, 2024, based on criteria established in Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework) and our report dated April 23, 2025, expressed an unqualified opinion thereon.
Basis for Opinion
These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.
F-3
Critical Audit Matters
The critical audit matters communicated below are matters arising from the current period audit of the financial statements that were communicated or required to be communicated to the audit committee and that: (1) relate to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matters below, providing separate opinions on the critical audit matters or on the accounts or disclosures to which they relate.
|
|
|
Estimation of recoverable amount of long-lived assets in the Cartagena refiner y |
|
Description of the Matter |
|
As described in notes 4.13 and 18 of the consolidated financial statements, management assesses at each reporting date, whether there is an indication that long-lived assets may be impaired. If any indication exists, or when annual impairment testing for a cash generating unit (CGU) is required, management estimates the CGU’s recoverable amount. A CGU’s recoverable amount is the higher of a CGU’s fair value less costs of disposal and its value in use. When the carrying amount of a CGU exceeds its recoverable amount, the CGU is considered impaired and is written down to its recoverable amount. A previously recognized impairment loss is reversed only if there has been a change in the assumptions used to determine the CGU’s recoverable amount since the last impairment loss was recognized. The reversal of impairment is limited so that the carrying amount of the CGU does not exceed either its recoverable amount or the carrying amount that would have been determined had no impairment loss been recognized for the CGU in prior periods. In 2024, the Company recognized a reversal of impairment loss in the Cartagena refinery CGU, of COP $1,271,120, as disclosed in note 18.2.1 of the consolidated financial statements.
Auditing management’s estimate related to the determination of the Cartagena refinery CGU recoverable amount was complex and required the involvement of specialists due to the highly judgmental nature of the assumptions used in the model. In particular, the significant assumptions were the discount rate (weighted average cost of capital) and estimated refining margins, which are affected by expectations about future market or economic conditions such as the sales prices of refined products and crude oil purchase prices.
|
F-4
|
How We Addressed the Matter in Our Audit |
|
We obtained an understanding, evaluated the design, and tested the operating effectiveness of controls over the Company’s process to determine the recoverable amount of the CGU, including controls over management’s review of the methodology used to development such estimates, the projected financial information and the significant assumptions described above.
Our audit procedures included, among others, assessing the methodology used and testing the significant assumptions described above, as well as the underlying data used by the Company, by comparing the significant assumptions used in the model with current industry and economic trends. Additionally, we assessed the reasonableness of the Company´s projections by comparing them to actual results and comparable trends in the industry and tested the clerical accuracy of such projections.
We also involved our valuation specialists to assist in the assessment of the discount rate (weighted average cost of capital), estimates of forward prices for oil and refined products, and projected financial information used in management’s estimate for the projected refining margin.
Furthermore, we evaluated the related disclosures in the consolidated financial statements. |
|
|
|
The impact of oil and gas reserves in the determination of depreciation and depletion, and assessment of impairment of long-lived assets for the Exploration and Production segment |
|
Description of the Matter |
|
As described in notes 3.1 and 3.2 of the consolidated financial statements, the oil and gas reserves estimate impacts the calculation of depreciation and depletion, and the determination of future cash flows used in the assessment of impairment of long-lived assets for the Exploration and Production segment. The depletion and depreciation of long-lived assets for the Exploration and Production segment are calculated using the units-of-production method, based on proven developed and proven undeveloped reserves. These types of reserves are estimated quantities of oil and gas that can be reasonably expected to be commercially recoverable in future years from reservoirs under existing economic and operating conditions.
The estimation of oil and gas reserves requires the assessment of assumptions such as oil and gas prices, operational and capital expenditures and production rates, among others. Because of the complexity involved in estimating oil and gas reserves, management used independent petroleum engineers (hereinafter “specialists”) to estimate the volume of oil and gas reserves.
Auditing the calculation of depreciation and depletion and the assessment of impairment of long-lived assets for the Exploration and Production segment was complex because of the use of the work of the specialists and the evaluation of management’s determination of the assumptions described above used by the specialists in estimating oil and gas reserves. |
F-5
|
How We Addressed the Matter in Our Audit |
|
We obtained an understanding, evaluated the design, and tested the operational effectiveness of the Company’s controls over its process to determine depreciation and depletion and assess impairment of long-lived assets for the Exploration and Production segment, including management’s controls over the review of the methodologies used by the specialists and the completeness and accuracy of the financial assumptions provided to the specialists for use in estimating oil and gas reserves.
Our audit procedures included, among others, obtaining the reserve reports from the specialists and evaluating the competence and objectivity of the specialists and management´s qualified persons responsible for overseeing the preparation of the reserve estimates through the consideration of their professional qualifications and experience, as well as the use of generally accepted practices and methodologies in preparing the reserve estimates. Additionally, we evaluated the completeness and accuracy of the financial assumptions described above used by the specialists in estimating oil and gas reserves by agreeing the inputs to source documentation and comparing them to historical results. We tested the mathematical accuracy of the calculation of depreciation and depletion and evaluated the methodologies used in the impairment assessment for long-lived assets for the Exploration and Production segment. We also tested the underlying data by comparing the oil and gas reserves used in the calculation of depreciation and depletion and impairment assessment to the reserve reports prepared by the specialists, among other procedures. |
|
|
|
Acquisition of the remaining interest in the Joint Operating Agreement (JOA) for the field CPO-09. |
|
Description of the Matter |
|
As described in Note 12 of the consolidated financial statements, on December 31, 2024, Ecopetrol acquired the remaining 45% interest in the field CPO-09 for COP $1,989,695. Considering that the Company previously held a 55% interest in the Joint Operating Agreement for the field CPO-09, this transaction is classified as a business combination achieved in stages in accordance with IFRS 3 – Business Combinations. Under this approach, the Company remeasures its previously held interest to its acquisition-date fair value and recognizes the resulting gain or loss, if any, in profit or loss or other comprehensive income, as appropriate. The fair value of the net assets acquired and the previously held interest was determined using the income approach and totaled COP $5,562,201, resulting in a gain on the transaction of COP $1,698,862.
Auditing the business combination achieved in stages was complex and required the involvement of specialists due to the judgmental nature of the assumptions used to determine the fair value of the assets acquired and previously held interest. The significant assumptions used to estimate the fair value of the assets included oil and gas reserves, oil and gas prices and the discount rate, among others. |
F-6
|
How We Addressed the Matter in Our Audit |
|
We obtained an understanding, evaluated the design, and tested the operational effectiveness of the Company’s controls over its process to estimate the fair value of the assets acquired, including controls over management’s review of the methodology used to develop such estimates and the financial information used by the specialists in determining the significant assumptions described above.
Our audit procedures included, among others, the review of the binding Sale and Purchase Agreement and assessment of the completeness and accuracy of the financial data used in determining the significant assumptions described above.
For the oil and gas reserve estimates used in the valuation, our audit procedures included obtaining the reserve reports from the specialists and evaluating the competence and objectivity of the specialists and management´s qualified persons responsible for overseeing the preparation of the reserve estimates through the consideration of their professional qualifications and experience, as well as the use of generally accepted practices and methodologies in preparing the reserve estimates. We evaluated the completeness and accuracy of the financial assumptions used by the specialists in estimating oil and gas reserves by agreeing the inputs to source documentation and comparing them to historical results. We also tested the underlying data by comparing the oil and gas reserves used in the valuation to the reserve reports prepared by the specialists.
We also evaluated the competence and objectivity of the internal and external specialists used by management in determining the oil and gas prices and discount rate. Additionally, we involved our valuation specialists to assist in assessing the fair value methodology used by management and the determination of the oil and gas prices and discount rate.
Furthermore, we evaluated the related disclosures in the consolidated financial statements. |
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/s/
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|
A member practice of |
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|
Ernst Young Global Limited |
We have served as the Company’s auditor since 2016.
April 23, 2025
F-7
Report of Independent Registered Public Accounting Firm
To the Shareholders and the Board of Directors of Ecopetrol S.A.
Opinion on Internal Control over Financial Reporting
We have audited Ecopetrol S.A.’s internal control over financial reporting as of December 31, 2024, based on criteria established in Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework), (the COSO criteria). In our opinion, Ecopetrol S.A. (the Company) maintained, in all material respects, effective internal control over financial reporting as of December 31, 2024, based on the COSO criteria.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated statements of financial position of the Company as of December 31, 2024 and 2023, the related consolidated statements of profit or loss, comprehensive income, changes in equity and cash flows for each of the three years in the period ended December 31, 2024, and the related notes and financial statement schedules listed in exhibits 1, 2 and 3 and our report dated April 23, 2025 expressed an unqualified opinion thereon.
Basis for Opinion
The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting included in the accompanying Management’s Annual Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects.
Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.
F-8
Definition and Limitations of Internal Control Over Financial Reporting
A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
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/s/
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A member practice of |
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Ernst Young Global Limited |
April 23, 2025
F-9
Ecopetrol S.A.
Consolidated statement of financial position
(In millions of Colombian pesos)
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|
As of December 31, |
||
|
|
|
Note |
|
2024 |
|
2023 |
|
Assets |
|
|
|
|
|
|
|
Current assets |
|
|
|
|
|
|
|
Cash and cash equivalents |
|
6 |
|
|
|
|
|
Trade and other receivables |
|
7 |
|
|
|
|
|
Inventories |
|
8 |
|
|
|
|
|
Other financial assets |
|
9 |
|
|
|
|
|
Current tax assets |
|
10 |
|
|
|
|
|
Other assets |
|
11 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Assets held for sale |
|
|
|
|
|
|
|
Total current assets |
|
|
|
|
|
|
|
Non–current assets |
|
|
|
|
|
|
|
Trade and other receivables |
|
7 |
|
|
|
|
|
Other financial assets |
|
9 |
|
|
|
|
|
Investment in associates and joint ventures |
|
13 |
|
|
|
|
|
Property, plant, and equipment |
|
14 |
|
|
|
|
|
Natural and environmental resources |
|
15 |
|
|
|
|
|
Right-of-use assets |
|
16 |
|
|
|
|
|
Intangible assets |
|
17 |
|
|
|
|
|
Non-current tax assets |
|
10 |
|
|
|
|
|
Goodwill |
|
19 |
|
|
|
|
|
Other assets |
|
11 |
|
|
|
|
|
Total non–current assets |
|
|
|
|
|
|
|
Total assets |
|
|
|
|
|
|
|
Liabilities |
|
|
|
|
|
|
|
Current liabilities |
|
|
|
|
|
|
|
Loans and borrowings |
|
20 |
|
|
|
|
|
Trade and other payables |
|
21 |
|
|
|
|
|
Provisions for employee benefits |
|
22 |
|
|
|
|
|
Current tax liabilities |
|
10 |
|
|
|
|
|
Accrued liabilities and provisions |
|
23 |
|
|
|
|
|
Other liabilities |
|
|
|
|
|
|
|
Total current liabilities |
|
|
|
|
|
|
|
Non–current liabilities |
|
|
|
|
|
|
|
Loans and borrowings |
|
20 |
|
|
|
|
|
Trade and other payables |
|
21 |
|
|
|
|
|
Provisions for employee benefits |
|
22 |
|
|
|
|
|
Non-current tax liabilities |
|
10 |
|
|
|
|
|
Accrued liabilities and provisions |
|
23 |
|
|
|
|
|
Other liabilities |
|
|
|
|
|
|
|
Total non–current liabilities |
|
|
|
|
|
|
|
Total liabilities |
|
|
|
|
|
|
|
Equity |
|
|
|
|
|
|
|
Subscribed and paid in capital |
|
24.1 |
|
|
|
|
|
Additional paid in capital |
|
24.2 |
|
|
|
|
|
Reserves |
|
24.3 |
|
|
|
|
|
Other comprehensive income |
|
24.5 |
|
|
|
|
|
Retained earnings |
|
|
|
|
|
|
|
Equity attributable to owners of parent |
|
|
|
|
|
|
|
Non–controlling interest |
|
|
|
|
|
|
|
Total equity |
|
|
|
|
|
|
|
Total liabilities and equity |
|
|
|
|
|
|
F-10
Ecopetrol S.A.
Consolidated statement of profit or loss
(In millions of Colombian pesos, except for basic and diluted earnings per share, which are expressed in Colombian pesos)
|
|
|
|
|
For the years ended December 31, |
||||
|
|
|
Note |
|
2024 |
|
2023 |
|
2022 |
|
Sales revenue |
|
25 |
|
|
|
|
|
|
|
Cost of sales |
|
26 |
|
(
|
|
(
|
|
(
|
|
Gross profit |
|
|
|
|
|
|
|
|
|
Administrative expenses |
|
27 |
|
(
|
|
(
|
|
(
|
|
Operations and project expenses |
|
27 |
|
(
|
|
(
|
|
(
|
|
Impairment recovery (loss) of non-current assets |
|
18 |
|
|
|
(
|
|
(
|
|
Other operating income (expense) |
|
28 |
|
|
|
(
|
|
(
|
|
Operating income |
|
|
|
|
|
|
|
|
|
Financial result |
|
29 |
|
|
|
|
|
|
|
Finance income |
|
|
|
|
|
|
|
|
|
Finance expenses |
|
|
|
(
|
|
(
|
|
(
|
|
Foreign exchange gain (loss) |
|
|
|
|
|
|
|
(
|
|
|
|
|
|
(
|
|
(
|
|
(
|
|
Share of profits of associates and joint ventures |
|
13 |
|
|
|
|
|
|
|
Profit before income tax expense |
|
|
|
|
|
|
|
|
|
Income tax expense |
|
10 |
|
(
|
|
(
|
|
(
|
|
Net profit for the year |
|
|
|
|
|
|
|
|
|
Net profit attributable to: |
|
|
|
|
|
|
|
|
|
Owners of parent |
|
|
|
|
|
|
|
|
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Non–controlling interest |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic and diluted earnings per share |
|
24.6 |
|
|
|
|
|
|
F-11
Ecopetrol S.A.
Consolidated statement of comprehensive income
(In millions of Colombian pesos)
|
|
|
|
|
For the years ended December 31, |
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|
|
|
Note |
|
2024 |
|
2023 |
|
2022 |
|
|
|
|
|
|
|
|
|
|
|
Net profit for the year |
|
|
|
|
|
|
|
|
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Other comprehensive income |
|
|
|
|
|
|
|
|
|
Other comprehensive income that may be reclassified to profit or loss in subsequent periods -net of taxes: |
|
|
|
|
|
|
|
|
|
Unrealized (loss) gain on hedges: |
|
|
|
|
|
|
|
|
|
Cash flow hedge for future exports |
|
|
|
(
|
|
|
|
(
|
|
Hedge of a net investment in a foreign operation |
|
|
|
(
|
|
|
|
(
|
|
Cash flow hedge with derivative instruments |
|
|
|
(
|
|
|
|
|
|
Financial instruments measured at fair value |
|
|
|
(
|
|
(
|
|
|
|
Foreign currency translation |
|
|
|
|
|
(
|
|
|
|
|
|
|
|
|
|
(
|
|
|
|
Other comprehensive income that will not to be reclassified to profit or loss in subsequent periods -net of taxes: |
|
|
|
|
|
|
|
|
|
Remeasurement gain (loss) on defined benefit plans |
|
22.1 |
|
|
|
(
|
|
(
|
|
|
|
|
|
|
|
(
|
|
(
|
|
Other comprehensive income for the year, net of tax |
|
|
|
|
|
(
|
|
|
|
Total comprehensive income for the year, net of tax |
|
|
|
|
|
|
|
|
|
Comprehensive income attributable to: |
|
|
|
|
|
|
|
|
|
Owners of parent |
|
|
|
|
|
|
|
|
|
Non–controlling interest |
|
|
|
|
|
(
|
|
|
|
|
|
|
|
|
|
|
|
|
F-12
Ecopetrol S.A.
Consolidated statement of changes in equity
(In millions of Colombian pesos)
|
|
|
|
|
Attributable to owners of parent |
|
|
|
|
||||||||||
|
|
|
|
|
Subscribed |
|
Additional |
|
|
|
Other |
|
|
|
|
|
Non- |
|
|
|
|
|
|
|
and paid- |
|
paid-in |
|
|
|
comprehensive |
|
Retained |
|
|
|
controlling |
|
Total |
|
|
|
Note |
|
in capital |
|
capital |
|
Reserves |
|
income |
|
earnings |
|
Total |
|
interest |
|
equity |
|
Balance as of January 1, 2024 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net profit |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Release of reserves |
|
24.3 |
|
|
|
|
|
(
|
|
|
|
|
|
|
|
|
|
|
|
Dividends declared |
|
24.4 |
|
|
|
|
|
|
|
|
|
(
|
|
(
|
|
(
|
|
(
|
|
Equity restitution |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(
|
|
(
|
|
Acquisition of subsidiaries |
|
24.4 |
|
|
|
|
|
|
|
|
|
(
|
|
(
|
|
(
|
|
(
|
|
Appropriation of reserves, net: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Legal |
|
24.3 |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
|
|
Fiscal and statutory reserves |
|
24.3 |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
|
|
Occasional |
|
24.3 |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
|
|
Other comprehensive income: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss on hedging instruments: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash flow hedge for future exports |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
(
|
|
(
|
|
(
|
|
Hedge of a net investment in a foreign operation |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
(
|
|
(
|
|
(
|
|
Cash flow hedge with derivative Instruments |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
(
|
|
(
|
|
(
|
|
Financial instruments measured at fair value |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
(
|
|
(
|
|
(
|
|
Foreign currency translation |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(
|
|
|
|
Remeasurement gain on defined benefit plans |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of December 31, 2024 |
|
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|
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Attributable to owners of parent |
|
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||||||||||
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Subscribed |
|
Additional |
|
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Other |
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|
Non- |
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|
|
and paid- |
|
paid-in |
|
|
|
comprehensive |
|
Retained |
|
|
|
controlling |
|
Total |
|
|
|
Note |
|
in capital |
|
capital |
|
Reserves |
|
income |
|
earnings |
|
Total |
|
interest |
|
equity |
|
Balance as of January 1, 2023 |
|
|
|
|
|
|
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|
|
|
|
|
|
|
|
|
|
Adoption of new standards |
|
|
|
|
|
|
|
|
|
|
|
(
|
|
(
|
|
|
|
(
|
|
Balance as of January 1, 2023, after adoption |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net profit |
|
|
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|
|
|
|
|
|
|
|
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|
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|
|
Release of reserves |
|
24.3 |
|
|
|
|
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(
|
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|
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|
|
|
|
|
|
|
|
Dividends declared |
|
24.4 |
|
|
|
|
|
|
|
|
|
(
|
|
(
|
|
(
|
|
(
|
|
Equity restitution |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(
|
|
(
|
|
Appropriation of reserves, net: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Legal |
|
24.3 |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
|
|
Fiscal and statutory reserves |
|
24.3 |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
|
|
Occasional |
|
24.3 |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
|
|
Other comprehensive income: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gain (loss) on hedging instruments: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash flow hedge for future exports |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(
|
|
|
|
Hedge of a net investment in a foreign operation |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash flow hedge with derivative Instruments |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Financial instruments measured at fair value |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
(
|
|
(
|
|
(
|
|
Foreign currency translation |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
(
|
|
(
|
|
(
|
|
Remeasurement loss on defined benefit plans |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
(
|
|
(
|
|
(
|
|
Balance as of December 31, 2023 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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|
Attributable to owners of parent |
|
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||||||||||
|
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Subscribed |
|
Additional |
|
|
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Other |
|
|
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|
|
Non- |
|
|
|
|
|
|
|
and paid- |
|
paid-in |
|
|
|
comprehensive |
|
Retained |
|
|
|
controlling |
|
Total |
|
|
|
Note |
|
in capital |
|
capital |
|
Reserves |
|
income |
|
earnings |
|
Total |
|
interest |
|
equity |
|
Balance as of January 1, 2022 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Adoption of new standards |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of January 1, 2022, after adoption |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net profit |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Release of reserves |
|
|
|
|
|
|
|
(
|
|
|
|
|
|
|
|
|
|
|
|
Dividends declared |
|
|
|
|
|
|
|
(
|
|
|
|
(
|
|
(
|
|
(
|
|
(
|
|
Business combination |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(
|
|
(
|
|
Equity restitution |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(
|
|
(
|
|
Appropriation of reserves, net: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Legal |
|
|
|
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
|
|
Fiscal and statutory reserves |
|
|
|
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
|
|
Occasional |
|
|
|
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
|
|
Other comprehensive income: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(Loss) gain on hedging instruments: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash flow hedge for future exports |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
(
|
|
|
|
(
|
|
Hedge of a net investment in a foreign operation |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
(
|
|
(
|
|
(
|
|
Cash flow hedge with derivative instruments |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Financial instruments measured at fair value |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(
|
|
|
|
Foreign currency translation |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Remeasurement (loss) gain on defined benefit plans |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
(
|
|
|
|
(
|
|
Balance as of December 31, 2022 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
F-13
Ecopetrol S.A.
Consolidated statement of cash flows
(In millions of Colombian pesos)
|
|
|
|
|
For the years ended December 31, |
||||
|
|
|
Note |
|
2024 |
|
2023 |
|
2022 |
|
Cash flow in operating activities: |
|
|
|
|
|
|
|
|
|
Net profit for the period |
|
|
|
|
|
|
|
|
|
Adjustments to reconcile the net profit to net cash provided by operating activities: |
|
|
|
|
|
|
|
|
|
Income tax expense |
|
10 |
|
|
|
|
|
|
|
Depreciation, depletion, and amortization |
|
14,15,16,17 |
|
|
|
|
|
|
|
(Gain) loss foreign exchange |
|
29 |
|
(
|
|
(
|
|
|
|
Finance cost of loans and borrowings |
|
29 |
|
|
|
|
|
|
|
Finance cost of post–employment benefits and abandonment costs |
|
29 |
|
|
|
|
|
|
|
Write off exploratory assets and dry wells |
|
15 |
|
|
|
|
|
|
|
Loss (gain) on disposal of non–current assets |
|
|
|
|
|
(
|
|
|
|
Profit on business combinations |
|
12 |
|
(
|
|
|
|
|
|
Profit on reversal of fields |
|
28 |
|
(
|
|
|
|
|
|
Impairment (recovery) loss of non–current assets |
|
18 |
|
(
|
|
|
|
|
|
Impairment loss of current assets |
|
28 |
|
|
|
|
|
|
|
Gain on fair value adjustment of financial assets and interest |
|
|
|
(
|
|
(
|
|
(
|
|
Loss (gain) on hedging transactions with derivatives |
|
|
|
|
|
|
|
(
|
|
Share of profit of associates and joint ventures |
|
13 |
|
(
|
|
(
|
|
(
|
|
Loss (gain) on the sale of assets held for sale |
|
|
|
|
|
|
|
(
|
|
Hedge ineffectiveness |
|
30.3 |
|
|
|
|
|
|
|
Realized loss on foreign exchange cash flow hedges |
|
25 |
|
|
|
|
|
|
|
Movements in provisions |
|
23 |
|
|
|
|
|
|
|
Net change in operational assets and liabilities: |
|
|
|
|
|
|
|
|
|
Trade and other receivables |
|
|
|
|
|
(
|
|
(
|
|
Inventories |
|
|
|
|
|
|
|
(
|
|
Trade and other payables |
|
|
|
(
|
|
|
|
|
|
Tax assets and liabilities |
|
|
|
(
|
|
(
|
|
(
|
|
Provisions for employee benefits |
|
|
|
(
|
|
(
|
|
(
|
|
Provisions and contingencies |
|
|
|
(
|
|
(
|
|
(
|
|
Other assets and liabilities |
|
|
|
(
|
|
(
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income tax paid |
|
|
|
(
|
|
(
|
|
(
|
|
Net cash provided by operating activities |
|
|
|
|
|
|
|
|
|
Cash flow in investing activities: |
|
|
|
|
|
|
|
|
|
Investment in joint ventures |
|
13 |
|
(
|
|
(
|
|
(
|
|
Acquisition of subsidiaries, net of cash acquired |
|
2.2 |
|
(
|
|
|
|
|
|
Consideration paid for the acquisition of assets |
|
12 |
|
(
|
|
|
|
|
|
Investment in property, plant, and equipment |
|
14 |
|
(
|
|
(
|
|
(
|
|
Investment in natural and environmental resources |
|
15 |
|
(
|
|
(
|
|
(
|
|
Acquisitions of intangibles |
|
17 |
|
(
|
|
(
|
|
(
|
|
Proceeds from sales of other financial assets |
|
|
|
(
|
|
|
|
|
|
Interests received |
|
29 |
|
|
|
|
|
|
|
Dividends received |
|
13.1 |
|
|
|
|
|
|
|
Proceeds from sales of assets |
|
|
|
|
|
|
|
|
|
Net cash used in investment activities |
|
|
|
(
|
|
(
|
|
(
|
|
Cash flow in financing activities: |
|
|
|
|
|
|
|
|
|
Proceeds from borrowings |
|
20.1 |
|
|
|
|
|
|
|
Repayment of borrowings |
|
20.1 |
|
(
|
|
(
|
|
(
|
|
Interest payments |
|
20.1 |
|
(
|
|
(
|
|
(
|
|
Lease payments |
|
16 |
|
(
|
|
(
|
|
(
|
|
Payment of restitution of equity to minority shareholders |
|
|
|
(
|
|
(
|
|
(
|
|
Dividends paid |
|
24.4 |
|
(
|
|
(
|
|
(
|
|
Net cash used in financing activities |
|
|
|
(
|
|
(
|
|
(
|
|
Exchange difference in cash and cash equivalents |
|
|
|
|
|
(
|
|
|
|
Net increase (decrease) in cash and cash equivalents |
|
|
|
|
|
(
|
|
|
|
Cash and cash equivalents at the beginning of the year |
|
|
|
|
|
|
|
|
|
Cash and cash equivalent at the end of the year |
|
6 |
|
|
|
|
|
|
F-14
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
1. |
Reporting entity |
Ecopetrol S.A. is a mixed economy company, with a commercial nature, formed in 1948 in Bogotá – Colombia, headquarters of the Ecopetrol Business Group (collectively called “Ecopetrol Business Group”); which is engaged in commercial and industrial activities related to the exploration, exploitation, refining, transportation, storage, distribution and marketing of hydrocarbons, their derivatives and products, as well as the electric power transmission services, design, development, construction, operation and maintenance of road and energy infrastructure projects and the provision of information technology and telecommunications services.
An
The address of the main office of Ecopetrol S.A. is Bogotá – Colombia, Carrera 13 No. 36 – 24.
2. Basis for preparation
|
2.1 |
Statement of compliance and authorization of financial statements |
The consolidated financial statements of Ecopetrol and its subsidiaries as of December 31, 2024, and 2023 and for each of the three years in the period ended December 31, 2024, have been prepared in accordance with International Financial Reporting Standards (IFRS), as issued by the International Accounting Standards Board (IASB).
Accounting policies have been applied consistently in all years presented.
These consolidated financial statements were approved and authorized for issuance by the Board of Directors of Ecopetrol on April 23, 2025.
|
2.2 |
Basis for consolidation |
The consolidated financial statements were prepared by consolidating all companies set out in Exhibits 1, which are those over which Ecopetrol S.A. exercises direct or indirect control. Control is achieved when the Ecopetrol Business Group:
| ● | has power over the investee (including rights to manage relevant activities); |
| ● | is exposed, or has the rights, to variable returns from its involvement with the investee; and |
| ● | has the ability to use its power to affect its operational returns. This instance occurs when the Ecopetrol Business Group has less than a majority of the voting rights of an investee, and it still has the power over the investee to provide it with the practical ability to direct the relevant activities of the investee unilaterally. The Ecopetrol Business Group considers all relevant facts and circumstances in assessing whether or not the Company’s voting rights in an investee are sufficient or not to give it power, including: |
|
a) |
the percentage of the Ecopetrol Business Group’s voting rights relative to the size and apportionment of the shares of other vote holders; |
|
b) |
potential voting rights held by the Ecopetrol Business Group, other vote holders or other parties; |
|
c) |
rights arising from other contractual arrangements; and |
|
d) |
any additional facts and circumstances that indicate that the Ecopetrol Business Group has, or does not have, the current ability to direct the relevant activities, at the time that decisions need to be made, including voting patterns at previous shareholders’ meetings. |
Subsidiaries are consolidated from the date on which control is obtained until the date that such control ceases.
F-15
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
All intercompany assets and liabilities, equity, income, expenses, and cash flows relating to transactions between entities of the Ecopetrol Business Group were eliminated on consolidation. Unrealized losses are also eliminated. Non–controlling interest represents the proportion of profit, other comprehensive income and net assets in subsidiaries that are not attributable to Ecopetrol shareholders.
The consolidated financial statements as of December 31, 2024, were prepared on the basis that the Ecopetrol Business Group will continue to operate as a going concern bases.
Significant changes in consolidation:
2024
Ocensa Ductos S.A.S
In July 2024, Oleoducto Central S.A. acquired
2023
Econova Technology Innovation, S.L.
On March 17, 2023, Ecopetrol S.A. concluded the establishment process of the company called Econova Technology Innovation, S.L., domiciled in Spain. Its main corporate purpose is oriented to activities related to science, technology, and innovation (CT+i). Ecopetrol S.A. is the direct owner of
2022
Ecopetrol US Trading LLC
In November 2022, the indirect subsidiary Ecopetrol US Trading LLC was incorporated. This company is domiciled in Delaware, United States of America, its main corporate purpose is the international commercialization of refined, petrochemical, crude oil, and natural gas of Ecopetrol Business Group and third parties. Ecopetrol US Trading LLC is a direct subsidiary of Ecopetrol USA Inc.
Gasoducto de Oriente S.A.
On July 12, 2022, the liquidation of the Gasoducto de Oriente S.A. took place in the Chamber of Commerce of Bogotá. It was a subsidiary of Inversiones de Gases de Colombia S.A.
Conexión Kimal Lo Aguirre
In July 2022, ISA Inversiones Chile incorporated the Joint Venture Conexión Kimal Lo Aguirre, together with Transelec and China Southern Power Grid International (CSG) as shareholders. This company will build and operate the Kimal-Lo Aguirre project in Chile awarded in 2021.
2.3 Basis of measurement
The consolidated financial statements have been prepared on a historical cost basis, except for financial assets and liabilities that are measured at fair value through profit or loss and/or changes in other comprehensive income at the end of each reporting period, as explained in the accounting policies included below.
Historical cost is generally based on the fair value of the consideration given in exchange for goods and services.
F-16
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
The fair value is the price that would be received from selling an asset or that would be paid for transferring a liability among market participants, in an orderly transaction, on the date of measurement. When estimating the fair value, the Ecopetrol Business Group uses assumptions that market participants would use for pricing an asset or liability at current market conditions, including risk assumptions, which maximize the value (highest and best use) of the asset or liability.
|
2.4 |
Functional and presentation currency |
The consolidated financial statements are presented in Colombian Pesos, which is the Ecopetrol’s functional currency. For each Ecopetrol Business Group entity, its functional currency is determined based of the main economic environment where it operates.
The statements of profit or loss, and cash flows of subsidiaries with functional currencies different from Ecopetrol’s functional currency are translated at the exchange rates on the dates of the transaction or based on the monthly average exchange rate. Assets and liabilities are translated at the closing exchange rate, and other equity items are translated at exchange rates at the time of the transaction. All resulting exchange differences are recognized in other comprehensive income. On disposal of all or significant part of a foreign operation, the cumulative translation adjustment related to the foreign operation is reclassified to profit or loss.
The consolidated financial statements are presented in Colombian pesos rounded up to the closest million unit (COP$ 000,000) except when otherwise indicated.
|
2.5 |
Foreign currency |
Transactions in foreign currencies are initially recorded by the Ecopetrol Business Group’s entities at their respective functional currency spot rates at the transactions date. Monetary items denominated in foreign currencies are translated at the functional currency spot rates prevailing at the reporting date. Differences arising on settlement, or translation, or monetary items are recognized in profit or loss, in financial results, net, except those resulting from the conversion of loans and borrowings designated as cash flow hedges or net investment in a foreign operation hedge, which are recognized in other comprehensive income within equity. When the hedged item affects the financial results, exchange differences accumulated in equity are reclassified to profit or loss as part of operating results.
Non–monetary items measured at fair value that are denominated in a foreign currency are translated using the exchange rates prevailing on the date when the fair value is determined. The gain or loss arising on translation of non–monetary items measured at fair value is treated in line with the recognition of the gain or loss on the change in fair value of the item.
|
2.6 |
Classification of assets and liabilities as current and non–current |
The Ecopetrol Business Group presents assets and liabilities in the consolidated statement of financial position based on whether assets are classified as current or non–current.
An asset or liability is classified as current when:
| ● | It is expected to be realized or intended to be sold or consumed (or expected to be settled, in the case of liabilities) in the ordinary course of business; |
| ● | Held mainly for the purpose of trading; |
| ● | Expected to be realized (or to be settled, in the case of liabilities) within twelve months after the reporting period; or |
| ● | In the case of the assets, it is cash or a cash equivalent, unless the exchange of such asset or liability is restricted or to be used to settle a liability at least twelve months after the reporting period; or |
| ● | In the case of a liability, there is no unconditional right to defer settlement of the liability until at least twelve months after the reporting period. |
Other assets and liabilities are classified as non–current.
Deferred tax assets and liabilities are classified as non–current assets and liabilities.
F-17
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
2.7 |
Earnings per share |
Basic earnings per share is calculated by dividing the profit for the year attributable to equity holders of Ecopetrol, the parent company, by the weighted average number of ordinary shares outstanding during the year. There is no potential dilution of shares.
3. Material estimates and accounting judgments
The preparation of the consolidated financial statements requires management to make judgements, estimates and assumptions that affect the reported amounts of assets, liabilities, sales revenues, costs, and commitments recognized in the financial statements and the accompanying disclosures. The Ecopetrol Business Group based its assumptions and estimates on parameters available when these consolidated financial statements were prepared. Uncertainty about these assumptions and estimates could result in outcomes that required a material adjustment to the carrying amount of assets or liabilities affected in future periods. Changes in estimates are adjusted prospectively in the period in which the estimate is revised.
In the process of applying the Ecopetrol Business Group’s accounting policies, management has made the following judgments and estimates which have the most significant impact on the amounts recognized in the consolidated financial statements:
|
3.1 |
Oil and gas reserves |
Oil and gas reserves are estimates of the amounts of hydrocarbons that can be economically and legally extracted from the Ecopetrol Business Group’s oil and gas properties.
The reserves estimation is performed annually as of December 31 in accordance with the United States Securities and Exchange Commission (SEC) definitions and rules set forth in Rule 4–10(a) of SEC Regulation S–X and the disclosure guidelines contained in the SEC final rule – Modernization of Oil and Gas Reporting.
As required by current regulations, the future estimated date on which a field will no longer produce for economic reasons, is based on actual costs and average of crude prices (calculated as the arithmetical average of prices on the first day of the past 12 months). The estimated date for end of production will affect the amounts of reserves, unless the prices have been defined by contractual agreements; therefore, if the prices and costs change from one year to the next, the proved reserves estimate also changes. Generally, our proved reserves decrease as prices go down and increase when prices go up.
Reserves estimation is an inherently complex process, and it involves professional judgments. Reserves estimation is prepared using technical and economic factors, including projections of future production rates, oil prices, engineering data and duration and amounts of future investments, and they imply a certain degree of uncertainty. These estimations reflect the regulatory and market conditions existing on the date of reporting, which could significantly differ from other conditions during the year or in future periods.
Any changes in regulatory and/or market conditions and assumptions could materially affect the reserves estimation.
Impact of oil reserves and natural gas in depreciation and depletion
Changes to estimations for proven developed reserves may affect the carrying amounts of exploration and production assets, natural resources and environment, liabilities for dismantling and depreciation and depletion. With all other variables remaining unchanged, a decrease in estimated proven reserves would increase, prospectively, depreciation, depletion, and amortization costs, while an increase in reserves would reduce depreciation and amortization expenses, as depreciation, depletion and amortization charges are calculated using the units of production method.
Information about the carrying amounts of exploration and production assets and the amounts charged to income, including depreciation and depletion, is presented in Notes 14 and 15. In addition, the movements of proved developed reserves is presented in Note 34.
|
3.2 |
Impairment (recovery) of non-current assets |
Ecopetrol Business Group Management uses its professional judgment in assessing the existence of evidence of an impairment loss or reversal, based on internal and external factors.
F-18
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
When an indicator of impairment loss or reversal of impairment of prior period impairment exists, the Ecopetrol Business Group estimates the recoverable amount of the cash generating units (CGU), which is considered the greater of fair value less costs of disposal and the value in use.
The assessments require the use of estimates and assumptions, such as, among other factors: (1) future investments, and costs; (2) useful life of assets; (3) future prices, and (4) discount rate, which is reviewed annually, and is determined as the weighted average cost of capital (WACC). Specifically, for crude oil and gas assets, the following are also included: (6) estimation of volumes and market value of oil and natural gas reserves and (7) production profiles of oil fields and future production of refined and chemical products. The recoverable amount is compared with the net book value of the asset, or of the cash-generating unit (CGU), thus determining whether the asset is impaired or if the impairment recognized in prior periods should be reversed.
A previously recognized impairment loss is reversed, only if there has been a change in the assumptions used to determine the assets or in the CGU’s recoverable amount since the last impairment loss was recognized. The reversal is limited so that the carrying amount of an asset or CGU, other than goodwill, does not exceed either its recoverable amount, or the carrying amount that would have been determined (net of amortization or depreciation) had no impairment loss been recognized for the asset or CGU in prior periods.
Future oil and refined products prices assumptions are estimated at current market conditions. For oil and gas asset, expected production volumes, which comprise proven, unproved, probable, and possible reserves are used for impairment testing because Management believes this to be the most appropriate indicator of expected future cash flows, which would also be considered by market participants. Reserves estimates are inherently imprecise and subject to uncertainty risk. Furthermore, projections about unproved volumes are based on information that is necessarily less robust than what is available for mature reservoirs.
These estimates and assumptions are subject to risk and uncertainty. Therefore, there is a possibility that changes in circumstances will impact these projections, which may also impact the recoverable amount of assets and/or CGUs, hence, may also affect the recognition of an impairment loss or the reversal of prior period impairment amounts.
|
3.3 |
Exploration and evaluation costs |
The application of the Ecopetrol Business Group’s accounting policy for exploration and evaluation costs requires judgment to determine whether future economic benefits are likely, either from future exploitation or sale, or whether activities have not reached a stage which permits a reasonable assessment of the existence of reserves. Certain exploration and evaluation costs are initially capitalized when it is expected that commercially viable reserves will result. The Ecopetrol Business Group uses its professional judgment of future events and circumstances and makes estimates to assess annually the generation of future economic benefits for extracting oil resources, as well as technical and commercial analyses to confirm its intention of continuing their development. Changes regarding available information, such as drilling success level or changes in the project’s economics, production costs, and investment levels, as well as other factors, may result in capitalized exploration drilling costs being recognized in profit or loss for the period. The expenses for dry wells, as a cost of the period, are included in operating activities in the consolidated statement of cash flows.
|
3.4 |
Determination of cash generating units (CGU) |
The allocation of assets in cash generating units requires significant judgment, as well as assessments regarding integration among assets, the existence of active markets, and similar exposure to market risk, shared infrastructure, and the way in which management monitors the operations. See Note 4.13 – Impairment of non-current assets for more information.
|
3.5 |
Abandonment and dismantling costs of fields and other facilities |
According to environmental and oil regulations, the Ecopetrol Business Group is required to bear the costs for the abandonment of oil extraction, refining plants and transportation facilities, which include the cost of plugging and abandoning wells, dismantling facilities, and environmental remediation in the affected areas.
Estimated abandonment and dismantling costs are recorded at the time of the installation of the assets and are reviewed annually.
F-19
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
The calculations for these estimations are complex and involve significant judgments by Management. The ultimate decommissioning costs are uncertain and cost estimates can vary in response to many factors, including changes to relevant legal requirements, the emergence of new restoration techniques or experience at other production sites. The expected timing, extent and amount of expenditure may also change, for example, in response to changes in internal cost projections, changes in reserve estimates, future inflation rates and discount rates. Ecopetrol Business Group considers that the abandonment and dismantling costs are reasonable, based on the experience of the Ecopetrol Business Group and market conditions; nevertheless, significant variations in external factors used for the calculation of the estimation could significantly impact the amounts recorded in the financial statements. See Note 4.14 - Provisions and contingent liabilities (asset retirement obligation).
|
3.6 |
Pension plan and other benefits |
The determination of expenses, liabilities and adjustments relating to pension plans and other defined retirement benefits makes it necessary for Management to use its judgment in the application of actuarial assumptions made in the actuarial calculation. The actuarial assumptions include estimates regarding future mortality, retirement, changes in compensation, and discount rate to reflect the time value of money, in addition to the rate of return on the plan’s assets. Due to the complexity in the valuation of these variables, as well as their long-term nature, the estimated amounts are quite sensitive to any change in these assumptions.
These assumptions are reviewed on an annual basis and may differ materially from actual results due to changes in economic and market conditions, regulatory changes, judicial rulings, higher or lower retirement rates, or longer or shorter life expectancies among employees.
|
3.7 |
Goodwill impairment |
In December of each year, the Ecopetrol Business Group performs an annual impairment test on goodwill to assess if its carrying amount may be recoverable. Goodwill is assigned to each cash generating unit (or groups of CGU).
The determination of the recoverable amount is described in Note 4.11, and its calculation requires assumptions and estimates. Ecopetrol Business Group considers that the assumptions and estimations used are reasonable and supportable based on the current market conditions and are aligned to the risk profile of the related assets. However, if different assumptions and estimations are used, they could lead to different results. Valuation models used to determine fair value are sensitive to changes in the underlying assumptions. For example, sales volumes and prices that will be paid for the purchase of raw materials are assumptions that may vary in the future. Adverse changes in any of these assumptions could lead to the recognition of goodwill impairment.
|
3.8 |
Litigation |
The Ecopetrol Business Group is subject to claims relating to regulatory and arbitration proceedings, tax assessments, and other claims arising in the normal course of business. Management evaluates these claims based on their nature, the likelihood that they materialize, and the amounts involved, to decide on the amounts recognized and/or disclosed in the financial statements.
This analysis, which may require considerable judgment, includes the assessment of current legal proceedings brought against the Ecopetrol Business Group and claims not yet initiated. A provision is recognized when the Ecopetrol Business Group has a present obligation derived from a past event, it is likely that an outflow of resources of economic benefits will be required to settle the obligation, and a reliable estimate of the amount of such obligation can be made.
|
3.9 |
Income and deferred taxes |
Calculation of the income tax provision requires interpretation of tax law in the jurisdictions where the Ecopetrol Business Group operates. Significant judgment is required to determine estimates for income tax on taxable profits and to evaluate the recoverability of deferred tax assets, which are based on the ability to generate sufficient taxable income during the periods in which such deferred taxes could be used or deduct.
To the extent that future cash flows and taxable income differ significantly from the estimates, the Ecopetrol Business Group’s ability to realize the deferred tax assets recorded could be affected.
Furthermore, changes in tax rules could impact the capacity of the Ecopetrol Business Group to obtain tax deductions in future years, as well as the recognition of new tax liabilities resulting from auditing conducted by the tax authorities.
F-20
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
Tax positions taken involve a thorough assessment by Management and are reviewed and adjusted in response to situations such as expiration in the applicability of laws, closing of tax audits, additional disclosures caused by any legal issue or a court decision relevant to a particular tax issue. The Ecopetrol Business Group records provisions based on estimated potential liabilities that could be derived from a tax audit. The amount of these provisions depends on factors such as previous experience in tax audits and different interpretations of tax legislation. The actual results may differ from the estimates recorded.
3.10 Hedge accounting
The process of identifying hedging relationships between hedged items and the underlying instruments (derivative and non–derivative, such as long–term, foreign currency–denominated debt), and their corresponding effectiveness, requires the use of judgment by Management. The Ecopetrol Business Group periodically monitors the alignment between its hedge instruments and its risk management policy.
3.11 Traffic projections for road concessions
The revenue for the services provided under the road concessions related to certain contracts, which are accounted under the financial asset model of IFRIC 12, is calculated through the present value of future revenue cash flow. This estimation is based on traffic studies made by an independent entity based on GDP projections among other variables according to the concession.
4. Accounting policies
|
4.1 |
Financial instruments |
A financial instrument is any contract that creates a financial asset for an entity and a financial liability or equity instrument for another entity. This concept includes elements such as debt instruments, shares (without control or significant influence), accounts payable, accounts receivable, financial derivatives, among others.
The classification of financial instruments depends on the nature and purpose for which the financial assets or liabilities were acquired and is determined at the time of initial recognition. Financial assets and financial liabilities are initially measured at their fair value.
Transaction costs that are directly attributable to the acquisition or issuance of financial assets and liabilities, other than those measured at fair value through profit or loss, are added to or deducted from the fair value of financial assets and liabilities on initial recognition. Transaction costs directly attributable to the acquisition of financial assets and liabilities measured at fair value through profit or loss are immediately recognized in profit or loss.
Loans and borrowings (See Note 20) and trade and other receivables (See Note 7) and financial assets (See Note 9) held to maturity are subsequently measured at amortized cost using the effective interest rate method. However, for those receivables and payables for which payment is expected to be received or made in the short term, their subsequent recognition corresponds to transaction value, considering that the effect of the value of money over time is not material due to short maturities.
Additionally, equity instruments are measured at fair value.
Measurements at fair value
Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. The fair value measurement is based on the presumption that the transaction to sell the asset or transfer the liability takes place in the principal market of the asset or liability or in the absence of a principal market in the most advantageous market.
The fair value of an asset or a liability is measured using the assumptions that market participants would use when pricing the asset or liability, supposing that the market participants act in their economic best interest.
A fair value measurement of a non-financial asset considers a market participant’s ability to generate economic benefits by using the asset for its most profitable use or by selling it to another market participant that would use the asset in its highest and best use.
F-21
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
Ecopetrol Business Group uses valuation techniques that are appropriate for the circumstances and for which the data is available and enough to measure fair value, maximizing the use of relevant observable inputs and minimizing the use of unobservable inputs.
All assets and liabilities for which fair value is measured or disclosed in the financial statements are classified within the following scale, based on the lowest level input that is significant to the fair value measurement, as follows:
| ● | Level 1: Quoted (unadjusted) market prices in active markets for identical assets or liabilities. The fair value of the Ecopetrol Business Group’s marketable securities with a quoted market price is based on Level 1 inputs. |
| ● | Level 2: Valuation techniques for which the lowest level input that is significant to the fair value measurement is directly or indirectly observed. Level 2 inputs include prices of similar assets, prices obtained through quotations made by stockbrokers, and prices that can be substantially corroborated with other observable data with the same contractual terms. |
For derivative contracts for which a quoted market price is not available, fair value estimates are generally determined using models and other valuation methods, the key inputs for which include future prices, volatility estimates, price correlation, counterparty credit risk, and market liquidity, as appropriate.
| ● | Level 3: Valuation techniques for which the lowest level input that is significant to the fair value measurement is unobservable. The Ecopetrol Business Group does not use Level–3 inputs for the measurement of financial assets and liabilities. The Ecopetrol Business Group may use Level–3 inputs for the calculation the recoverable amount of certain non–financial assets for the purpose of impairment testing. |
Effective interest rate method
The effective interest rate method is a method of calculating the amortized cost of a financial instrument and accounting of income or financial cost over the relevant period. The effective interest rate is the discount rate that exactly discounts estimated future cash receipts or payments (including all fees, transaction costs and other premiums or discounts) through the expected life of the financial instrument (or, when appropriate, at a shorter period), to the net carrying amount on initial recognition. This methodology is also applied to the instrument’s measurement related to the concession financial assets.
Impairment
The Ecopetrol Business Group evaluates if there is objective evidence that a financial asset or group of financial assets are impaired. Financial assets are evaluated for the impairment indicators at the end of each reporting period. Financial assets are considered impaired when there is objective evidence that, because of one or more events that occurred after initial recognition, the estimated future cash flows of the asset have been affected. For financial assets measured at amortized cost, the amount of the impairment loss recognized is the difference between the asset’s carrying amount and the present value of estimated future cash flows, discounted at the financial asset’s original effective interest rate.
|
4.1.1 |
Cash and cash equivalents |
Cash and cash equivalents include cash on hand, financial investments that are highly liquid, bank deposits, and special funds with original maturity dates of ninety days or less which are subject to an insignificant risk of changes in value.
Restricted cash is a monetary resource with the objective of allocating it to specific and previously determined purposes.
4.1.2 Financial assets
The classification of financial assets at initial recognition depends on the financial asset’s contractual cash flow characteristics and the Ecopetrol Group’s business model for managing them. Except for trade receivables that do not contain a significant financing component or for which the Ecopetrol Business Group has applied the practical expedient, Ecopetrol Business Group initially measures a financial asset at its fair value plus, and, in the case of a financial asset not at fair value through profit or loss, at transaction costs. Trade receivables that do not contain a significant financing component or for which the Ecopetrol Business Group has applied the practical expedient are measured at the transaction price determined under IFRS 15.
F-22
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
Ecopetrol Business Group classifies its financial assets in the following categories:
|
a) |
Financial assets measured at fair value through profit or loss |
Financial assets are held for trading and financial assets designated at the time of the initial recognition at fair value through profit or loss. Financial assets are classified as held for trading if they are acquired to be sold or repurchased in the short term. They are recognized at their fair value and losses or profits arising at the time of re–measurement are recognized in the statement of profit or loss.
|
b) |
Financial assets measured at fair value with changes in other comprehensive income |
These are equity instruments of other non–controlled and non–strategic companies not allowing for any type of control or significant influence thereon and where the Ecopetrol Business Group’s Management does not intend to negotiate with them in the short term. These financial instruments are recorded at their fair value, and unrealized gains or losses are recognized in other comprehensive income.
|
c) |
Financial assets at amortized cost |
This category is the most relevant to Ecopetrol Business Group. The Group’s financial assets at amortized cost includes trade receivables, other receivables, loans, and borrowings.
Loans and receivables are non–derivative financial assets with fixed or determinable payments that are not quoted in an active market. Loans and receivables, including trade and other receivables, are measured initially at fair value and then at amortized cost using the effective interest rate method, less impairment.
Loans to employees are initially recorded using the present value of the future cash flows, discounted at the current market rate for similar loans. If the interest rate is less than the current market rate, fair value will be less than the amount of the loan. This difference is recorded as a benefit to employees.
Ecopetrol Business Group measures financial assets at amortized cost if both of the following conditions are met:
| ● | The asset is held within a business model with the objective to hold financial assets to collect contractual cash flows. |
| ● | The contractual terms of the asset give rise on specified dates to cash flows that are solely payments of principal and interest on the principal amount outstanding. |
Financial assets at amortized cost are subsequently measured using the effective interest method and are subject to impairment analysis. Gains and losses are recognized in profit or loss when the asset is derecognized, modified, or impaired.
Derecognition of financial assets
The Ecopetrol Business Group derecognizes a financial asset only upon the expiration of the contractual rights to the cash flows of the asset or, when it has transferred its rights to receive such cash flows or has assumed the obligation to pay the cash flows received in full without material delay to a third party and (a) it has transferred substantially all the risks and benefits inherent in the ownership of the financial asset or (b) it has neither transferred nor retained substantially all the risks and benefits of the asset, but has transferred control of the asset.
When the Ecopetrol Business Group does neither transfer nor retain substantially all the risks and benefits of the asset or transfer control of the asset, the Ecopetrol Business Group continues to recognize the transferred asset, to the extent of its continuing participation, and it also recognizes the associated liability.
4.1.3 Financial liabilities
Financial liabilities correspond to the financing obtained by the Ecopetrol Business Group through bank credit facilities and bonds, accounts payables to suppliers, and creditors.
F-23
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
Bonds and bank credit facilities are initially recognized at their fair value, net of directly attributable transactions cost. After initial recognition, interest–bearing credit facilities and bonds are subsequently measured at amortized cost, using the effective interest rate method. The effective interest method amortization is included as a financial expense in the statement of profit or loss. Amortized cost is calculated by considering any discount or premium on acquisition and fees or costs that are an integral part of the effective interest rate (EIR). The EIR amortization is included as finance costs in the statement of profit or loss.
Accounts payable to suppliers and other creditors are short-term financial liabilities recognized at their transaction value upon subsequent recognition, considering that the effect of the time value of money is not significant as they have short maturities.
Derecognition of financial liabilities
A financial liability is derecognized when the obligation specified in the contract is discharged, cancelled, or expires. When an existing financial liability has been replaced by another from the same lender, under substantially different terms, or the terms of an existing liability are substantially modified, such an exchange or modification is treated as the de–recognition of the original liability and recognized as a new liability. The difference between the respective carrying amounts is recognized in the statement of profit or loss.
4.1.4 Derivative financial instruments
Financial instruments are initially recognized at fair value on the date on which a derivative contract is entered into and are subsequently remeasured at fair value. Changes in the fair value of derivatives are recognized as gains or losses in the statement of profit or loss, except for the effective portion of cash flow hedges, which is recognized in other comprehensive income and later reclassified to profit or loss when the hedge item affects profit or loss.
Changes in fair value of derivative contracts, which do not qualify or are not designated as hedges, including forward contracts for the purchase and sale of commodities under negotiation for physical delivery or receipt of the commodity are recorded in profit or loss.
Derivatives embedded in the host contract are accounted for as separate derivatives at fair value if their economic characteristics and risks are not closely related to those of the host contracts and the host contracts are not held for trading or designated at fair value through profit or loss. These embedded derivatives are measured at fair value with changes in fair value recognized in profit or loss.
4.1.5 Hedging operations
For purposes of hedge accounting, hedges are classified as:
| ● | Cash flow hedges: hedges of the exposure to variability in cash flows attributable to a particular risk associated with all, or a component of, a recognized asset or liability or a highly probable forecast transaction, and that could affect profit or loss. |
| ● | Hedges of net investments in foreign operations. |
| ● | Fair value hedges: hedges of the exposure to changes in fair value of a recognized asset or liability or an unrecognized firm commitment, or a component of any such item, that is attributable to a particular risk and that could affect profit or loss. |
At the inception of a hedge relationship, Ecopetrol Business Group formally designates and documents the hedge relationship to which it wishes to apply hedge accounting and the risk management objective and strategy for undertaking the hedge. Such hedges are expected to be highly effective in achieving offsetting changes in fair value or cash flows and are assessed on an ongoing basis to determine whether they have been highly effective throughout the financial reporting periods for which they were designated.
|
4.1.5.1 |
Cash flow hedge |
The effective portion of the gain or loss on the hedging instrument is recognized in Other Comprehensive Income (OCI) in the cash flow hedge reserve, while any ineffective portion is recognized immediately in the statement of profit or loss.
The amounts previously accumulated in OCI are recognized in profit or loss when the hedged transaction affects the statement of profit or loss. If the hedged transaction subsequently results in the recognition of a non-financial item, the amount accumulated in equity is removed from the separate component of equity and included in the initial cost or other carrying amount of the hedged asset or liability.
F-24
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
If the hedging instrument expires or is sold, terminated, or exercised without replacement or rollover, or if its designation as a hedge is revoked or when the hedge no longer meets the criteria for hedge accounting, any cumulative gain or loss previously recognized in other comprehensive income remains separately in equity until the forecast transaction occurs is recognized in the consolidated statement of profit or loss. When it is no longer expected that the initially hedged transaction will occur.
Ecopetrol Business Group designates certain loans as a hedging instrument for its exposure to exchange rate risk in future crude oil exports. Additionally, Ecopetrol Business Group enters positions with derivative financial instruments such as commodity swaps, cross currency swaps or interest rate swaps to hedge commodity price risks, exchange rate risk and interest rate risk, respectively, which may also be designated as cash flow hedges (See Note 30.3).
4.1.5.2 Hedge of net investment in a foreign operation
Hedges of a net investment in a foreign operation, including a hedge of a monetary item that is accounted for as part of the net investment, are accounted for similarly to cash flow hedges.
Gains or losses on the hedging instrument relating to the effective portion of the hedge are recognized as OCI while any gains or losses relating to the ineffective portion are recognized in the statement of profit or loss. On the disposal of a foreign operation, the cumulative value of any such gains or losses recorded in equity is transferred to the statement of profit or loss.
Ecopetrol Business Group allocates long–term loans as hedging instruments for its exposure to foreign exchange risk on its investment in subsidiaries whose functional currency is the U.S. dollar. See Note 30.4.
4.1.5.3 Fair value hedge
The gain or loss on the hedging instrument shall be recognized in profit or loss or other comprehensive income if the hedging instrument hedges an equity instrument for which an entity has elected to present changes in fair value in other comprehensive income.
The hedging gain or loss on the hedged item shall adjust the carrying amount of the hedged item (if applicable) and be recognized in profit or loss. If the hedged item is a financial asset (or a component thereof) that is measured at fair value through other comprehensive income, the hedging gain or loss on the hedged item shall be recognized in profit or loss. However, if the hedged item is an equity instrument for which an entity has elected to present changes in fair value in other comprehensive income, those amounts shall remain in other comprehensive income.
|
4.2 |
Inventories |
Inventories are recorded at the lower of cost and net realizable value.
Inventories mainly comprise crude oil, fuels and petrochemicals, and consumable inventories (spares and supplies).
The cost of crude oil includes to the production costs and the transportation costs related to the process of giving to the products the current conditions and locations.
The cost of other inventories is determined based on the weighted average cost method, which includes acquisition costs (deducting commercial discounts, rebates, and other similar items), transformation, and other costs incurred to bring inventory to their current location and condition, such as transportation costs.
Consumable inventories (spares and supplies) are recognized as inventory and then charged to expense, maintenance, or project to the extent that such items are consumed.
Ecopetrol Business Group estimates the net realizable value of inventories at the end of the period. When the circumstances that previously caused inventories to be written down below cost no longer exist, or when there is clear evidence of an increase in the net realizable value because of a change in economic circumstances, the amount of the write down is reversed. The reversal cannot be greater than the amount of the original write-down, so that the new carrying amount will always be the lower of the cost and the revised net realizable value.
F-25
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
4.3 |
Related parties |
Related parties are considered those where one of the parties can control the other, has joint control, or exercises significant influence in the financial or operational decision making of the investee or is a member of key management personnel (or close family member of key personnel). Ecopetrol Business Group has considered as related parties the associated companies, joint businesses, key management executives, the entities managing the resources for payment of post-employment benefit plans for employees and some relevant transactions entered with entities of the Colombian Government, such as the purchase of hydrocarbons and the oil stabilization fund. (See Note 31 – Related Parties).
4.3.1 Investments in associates
An associate is an entity over which the Ecopetrol Business Group has significant influence but not control. Significant influence is the power to participate in the financial and operational policy decisions of the investee, but it is not control or joint control over those policies. Generally, these entities are those in which the Ecopetrol Business Group holds an equity interest with voting rights of
Investments in associates are accounted for using the equity method. Under this method, the investment in an associate is initially recognized at cost. The carrying amount of the investment is adjusted to recognize changes in the Ecopetrol Business Group’s share of net assets of the associate since the acquisition date. Goodwill related to the associate is included in the carrying amount of the investment and it is not tested for impairment separately.
The Ecopetrol Business Group’s share of the results of operations of the associate is recognized in the consolidated statement of profit or loss. Any change is recognized in other comprehensive income of the Ecopetrol Business Group.
After application of the equity method, the Ecopetrol Business Group determines if it is necessary to recognize an impairment on its investment in its associate. The Ecopetrol Business Group determines whether there is objective evidence that the investment is impaired. If there is such evidence, the amount of the impairment is calculated as the difference between the recoverable amount and the carrying value, and then the impairment is recognized in the consolidated profit or loss statement.
When necessary, the Ecopetrol Business Group adjusts the accounting policies of associates to ensure consistency with the policies adopted by the Ecopetrol Business Group. Additionally, the equity method of these companies is measured on their most recent financial statements.
|
4.3.2 |
Joint ventures |
A joint venture is a type of joint arrangement whereby the parties that have joint control of the arrangement have rights to the net assets of the joint arrangement. Joint control exists only when decisions about the relevant activities require unanimous consent of the parties sharing such control. The accounting treatment for the recognition of joint ventures is the same as investments in associates (see Note 31).
|
4.4 |
Joint operations |
A joint operation is a type of joint arrangement whereby the parties that have joint control of the arrangement have rights to the assets and obligations for the liabilities, relating to the arrangement.
Joint operation contracts are entered into between Ecopetrol Business Group and third parties to share risk, secure capital, maximize operating efficiency, and optimize the recovery of reserves. In these joint operations, one party is designated as the operator to execute the operations and report to partners according to their participating interests. Likewise, each party takes its share of the produced hydrocarbons (crude oil or gas), according to their share in production.
When Ecopetrol Business Group participates as a non–operator partner, it recognizes the assets, liabilities, sales revenues, cost of sales, and expenses based on the operator partner’s report. When Ecopetrol Business Group is the direct operator of joint venture contract, it recognizes its percentage of assets, liabilities, sales revenues, costs, and expenses, based on the participation of each partner in the items corresponding to assets, liabilities, sales revenues, costs, and expenses.
F-26
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
When the Ecopetrol Business Group acquires or increases its participation in a joint operation in which the activity constitutes a business combination, such transaction is recognized applying the acquisition method in accordance with IFRS 3 – Business combination. The acquisition cost is the sum of the consideration transferred, which corresponds to the fair value, on the date of acquisition of the assets transferred and the liabilities incurred. Any transaction cost related to the acquisition or increased share in the joint operation that constitutes a business combination is recognized in the consolidated statement of profit or loss.
The excess of the sum of the consideration transferred and the amount paid in the operation is recognized as goodwill. If the result is in an excess value of the net assets acquired over the amount paid in the purchase transaction, the difference is recognized as income in the consolidated statement of profit or loss on the date of recognition of the transaction.
|
4.5 |
Non–current assets held for sale |
Non–current assets are classified as held for sale if their carrying values will be recovered principally through a sale transaction rather than through continued use. Non–current assets are classified as held for sale only when the sale is highly probable within one year from the classification date and the asset (or group of assets) is available for immediate sale in its present condition. These assets are measured at the lower of their carrying amount and fair value less related costs of disposal.
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4.6 |
Property, plant, and equipment |
Recognition and measurement
Property, plant, and equipment are stated at cost less accumulated depreciation and impairment losses. Tangible components related to natural and environmental resources are part of property, plant, and equipment.
The initial cost of an assets comprises its purchase price or construction cost, including import duties and non–refundable purchase taxes, any costs directly attributable to bringing the asset into operation, costs of employee benefits arising directly from the construction or acquisition, borrowing costs incurred that are attributable to the acquisition and construction of qualifying assets and the initial estimate of the costs of dismantling and abandonment of the item.
Spare parts and servicing equipment are recorded as inventories and recognized as an expense as they are used. Major spare parts and stand–by equipment that Ecopetrol Business Group expects to use during more than one period are recognized as property, plant, and equipment.
Any gain or loss arising from the disposal of a property, plant, and equipment is recognized in profit or loss of the period.
Subsequent disbursements
Subsequent disbursements correspond to all payments to be made on existing assets to increase or extend the initial expected useful life, increase productivity or productive efficiency, allow for significant reduction of operating costs, increase the level of reserves in exploration or production areas or replace a part or component of an asset that is considered critical for the operation.
The costs of repair, conservation and maintenance of a day-to-day nature are expensed as incurred. However, disbursements related to major maintenance are capitalized.
Depreciation
Property, plant, and equipment is depreciated using the straight–line method, except for those associated with exploration and production activities which are depreciated using the units–of–production method. Technical useful lives are updated annually considering factors such as: additions or improvements (due to parts replacement or critical components for the asset’s operation), technological advances, obsolescence, and other factors; the effect of this change is recognized from the period in which it was executed. Depreciation of an asset starts when it is ready to be used.
Useful lives are determined based on the period over which an asset is expected to be available for use, physical exhaustion, technical or commercial obsolescence and legal limits or restrictions over the use of the asset.
F-27
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
The estimated useful life of assets fluctuates in the following ranges:
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Plant and equipment |
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|
Pipelines, networks, and lines |
|
|
Buildings |
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|
Other |
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Lands are recognized separately from buildings and facilities, have unlimited useful lives, and they are not subjected to depreciation.
Depreciation methods and useful lives are reviewed annually and adjusted if appropriate.
Impairment
Non-current assets are subject to review for possible impairment in their recoverable value. See notes 3.2 – Impairment (recovery) of non-current assets and 4.13 – Impairment of non-curent assets.
|
4.7 |
Natural and environmental resources |
Recognition and measurement
Ecopetrol Business Group uses the successful efforts method to account for exploration and production of crude oil and gas activities, following the provisions of IFRS 6 – Exploration for the evaluation of mineral resources.
Exploration costs
Acquisition and exploration costs are recorded as exploration and evaluation assets until the determination of whether the exploration drilling is successful or not; if determined to be unsuccessful, all costs incurred are recognized as expenses in the statement of profit or loss.
Exploration costs are those incurred with the objective of identifying areas that are considered to have prospects of containing oil and gas reserves, including geological and geophysical, seismic costs, viability, and others, which are recognized as expenses when incurred. Furthermore, disbursements associated with the drilling of exploratory wells and those related to stratigraphic wells of an exploratory nature are charged as assets until it is determined if they are commercially viable; otherwise, they are expensed in the consolidated statement of profit or loss as dry wells expense. Other expenditures are recognized as expenses when incurred.
An exploration and evaluation asset will not be classified as such when the technical feasibility and commercial viability of extracting a mineral resource are demonstrable. Exploration and evaluation assets are reclassified to the natural and environmental resources account after being assessed for impairment.
All capitalized costs are subjected to technical and commercial revisions at least once a year to confirm the evaluation and exploration efforts continue the fields; otherwise, these costs are written off through to profit or loss.
Exploration costs are net of the revenues obtained from the sale of crude oil during the extensive testing period, net of cost of sales since they are considered necessary to complete the asset.
Development costs
Development costs correspond to those costs incurred to obtain access to proved reserves and to provide facilities for extracting, treating, gathering, and storing. When a project is approved for development, the corresponding capitalized acquisition and exploration costs are classified as natural and environmental resources and costs after the exploration phase are capitalized as development costs of the properties that contain such natural resources. All development costs are capitalized, including drilling costs of unsuccessful development wells.
F-28
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
Production costs
Production costs are those incurred to operate and maintain productive wells and are part of the corresponding equipment and facilities. Production activity includes extraction of oil and gas to the surface, its gathering, treatment, and processing as well as storage in the field. Production costs are expenses recorded in the consolidated statement of profit or loss as incurred unless they add oil and gas reserves, in which case they are capitalized.
Production and support equipment is recognized at cost and is part of property, plant, and equipment subject to depreciation.
Capitalized costs also include decommissioning, dismantling, retiring, and restoration costs, as well as the estimated cost of future environmental obligations. The estimation includes plugging and abandonment costs, facility dismantling and environmental recovery of areas and wells. Changes arising in new abandonment liability estimations and environmental remediation are capitalized in the carrying amount of the related asset.
Depletion
Depletion of natural and environmental resources is determined using the unit–of–production method per field, using proved developed reserves as a base, except in limited exceptional cases that require greater judgment by Management to determine a better amortization factor of future economic benefits over the useful life of the asset. Depreciation/depletion rates are reviewed annually, based on reserves reports and the impact of any changes is recognized prospectively in the financial statements.
Reserves are independently estimated by internationally recognized external consultants and approved by Ecopetrol’s Board of Directors. Proved reserves consist of the estimated quantities of crude oil and natural gas demonstrated with reasonable certainty by geological and engineering data to be recoverable in future years from known reserves under existing economic and operating conditions, which are at the prices and costs that apply for the date of the estimation.
Impairment
Assets associated to exploration, evaluation and production are subject to review for possible impairment in their carrying amount. See Notes 3.2 — Impairment (recovery) of non-current assets and 4.13 — Impairment of non–current assets .
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4.8 |
Capitalization of borrowing costs |
Borrowing costs related to the acquisition, construction or production of a qualifying asset that requires a substantial period to get ready for its intended use are capitalized as part of the cost of such asset when it is probable that future economic benefits associated with the item will flow to the Ecopetrol Business Group and costs can be measured reliably. Other borrowing costs are recognized as financial costs. Projects that have been suspended but that the Ecopetrol Business Group intends to continue to pursue their development in the future, are not considered qualifying assets for the purpose of capitalization of borrowing costs.
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4.9 |
Intangible assets |
Intangible assets with a defined useful life, are stated at cost less accumulated amortization and any impairment loss. Intangible assets are amortized under the straight–line method, over their estimated useful lives. The estimated useful lives and amortization method are revised at the end of each reporting period; any change in estimates is recognized on a prospective basis.
The disbursements related to research activities are recognized as expense as incurred.
Easements
Easements are rights obtained for the use part of land for the installation of a transmission line. This implies restrictions on the use of the land by the owner and authorizations to Ecopetrol Business Group to build, operate, or maintain the transmission lines. These intangible assets are permanent rights with an indefinite term of use. Although the transmission lines to which these easements are related have a finite useful life, the rights do not expire, and Ecopetrol Business Group may replace the transmission lines at the end of their useful life or make use of said rights for any other service related to transmission electricity and telecommunications. Easements have an indefinite useful life, so they are not amortized and are reviewed annually for impairment.
F-29
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
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4.10 |
Concessions |
Ecopetrol Business Group operates concessions under public service concession agreements, in which the grantor controls or regulates the services provided by the concessionaire, whom they are provided to, and price of the service.
Concessions that meet the above criteria are recorded according IFRIC 12 - Concession Agreements of services.
IFRIC 12, Service Concession Arrangements, establishes general guidelines for the recognition and measurement of rights and obligations related to concession agreements and applies when the granting authority controls or regulates which services the concessionaire should provide with the infrastructure, to whom the services should be provided and at what price, and controls any significant residual interest in the infrastructure at the end of the concession period.
Ecopetrol Business Group’s assets that were built to operate concessions where the grantor has no residual interest in the infrastructure and Ecopetrol Business Group has no obligation to return the assets are recognized under IFRS 16 - Leases. In these cases, the construction of the infrastructure is a service provided to the grantor, different from the operation and maintenance service. Revenue from services is measured and recorded in accordance with IFRS 15 – Revenue from Contracts with Customers and IFRS 9 – Financial Instruments, depending on the asset model.
Concessions in which the Ecopetrol Business Group does not have a contractual right to receive money or another financial asset from the grantor, but has the right to charge users in exchange for services provided, are accounted for under the intangible asset model.
Concessions assets are subject to impairment test in their recoverable value. See notes 3.2 – Impairment (recovery) of non-current assets and 4.13 – Impairment of non-current assets.
The detail of each type of concession by country is disclosed in Note 25 and Exhibit 3.
Intangible asset model
Considering IFRIC 12, concessions in which Ecopetrol Business Group does not have a contractual right to receive cash or another financial asset from the grantor but has the right to charge users in exchange for the services provided, are recognized under the intangible asset model. The costs incurred by Ecopetrol Business Group for the construction of the concession infrastructure are on a straight-line basis over the term of the concession period. Revenue from construction or improvement services is recognized according to the level of completion of the construction, based on the costs actually incurred, including at construction margin.
The operation and maintenance costs related to the concession are recognized in the statement of profit or loss once the infrastructure of the concession is ready for its use and Ecopetrol Business Group receives from the grantor the right to receive a fee for the services. Revenues are recognized based on the services provided as established in the concession agreements.
Infrastructure expansions are recognized as intangible asset when they are expected to generate future economic benefits. The renovations costs, improvements and additions are capitalized, while routine maintenance and repairs that do not extend the useful life of the assets are recognized in the profit or loss statement.
Financial asset model
Concessions in which Ecopetrol Business Group has a contractual right to receive cash or another financial asset from the grantor for the services provided under the concession agreements and the grantor has little or no power to avoid payment are recognized under financial asset model. In this model the financial asset is classified as a financial asset concession, according to IFRS 9 – Financial Instruments, and it will be represented as current and non-current concessions in the financial position of Ecopetrol Business Group. This asset accrues interest using the effective interest rate method (see Note 4.1).
Mixed model for concessions
This model is applied when the contract simultaneously includes remuneration commitments guaranteed by the grantor and remuneration commitments that depend on the level of use of the concession infrastructure.
F-30
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
4.11 Goodwill
Goodwill is initially measured at cost (being the excess of the aggregate of the consideration transferred and the amount recognized for non–controlling interest and any previous interest held over the net identifiable assets acquired and liabilities assumed). After initial recognition goodwill is measured at cost less any accumulated impairment loss, which cannot be reversed in subsequent periods according to IAS 36. Goodwill is not amortized but tested for impairment annually.
4.12 Leases
At the beginning of a contract, Ecopetrol Business Group assesses whether a contract is, or contains, a lease. This situation arises if the contract transfers the right to control the use of an identified asset for a period in exchange for a consideration. To assess whether a contract conveys the right to control an identified asset, the regulations of IFRS 16 are used.
Ecopetrol Business Group applies the guidance of IFRS 16 – Leases on concessions contracts that do not meet the criteria of the guidance of IFRIC 12.
Ecopetrol Business Group as a lessee
On the commencement date of the lease, Ecopetrol Business Group recognizes lease liabilities to make lease payments and right-of-use assets representing the right to use the underlying asset during the lease term. The interest expense on the lease liability and the depreciation expense on the right-of-use asset are recognized separately.
In subsequent recognition, Ecopetrol Business Group makes a remeasurement of the lease obligation upon the occurrence of events such as: a) changes in the lease term and b) changes in future lease payments resulting from variations in an index or in the rate used for determining the payments. The amount of the remeasurement of the obligation will be recognized as an adjustment to the asset for the right of use.
Ecopetrol Business Group as a lessor
Ecopetrol Business Group classifies as financial leases those contracts in which the terms of the lease substantially transfer to the lessees all the risks and inherent rewards to ownership of the asset. All other leases are classified as operational.
If the lease is classified as financial, an account receivable is recorded in the statement of financial position, for an amount equal to the net investment in the lease.
For leases classified as operating leases, income from payments is recognized on a straight-line basis in the profit and loss statement.
Right-of-use assets
The Ecopetrol Business Group recognizes right-of-use assets on the commencement date of the lease (that is, the date on which the underlying asset is available for use). The right-of-use assets are measured at cost, less any accumulated depreciation and impairment losses, and adjusted for any remeasurement of the lease liabilities. Right-of-use assets are amortized in a straight-line basis during the lease term. Right-of-use assets are subject to impairment assessment. The cost of right-of-use assets includes the amount of lease liabilities recognized, initial direct costs incurred, and lease payments made at or before the commencement date less any lease incentives received.
Lease liabilities
At the commencement date of the lease, the Ecopetrol Business Group recognizes lease liabilities measured at the present value of the lease payments to be made during the term of the lease. The lease payments include fixed payments (including in-substance fixed payments) less any lease incentives receivable, variable lease payments that depend on an index or a rate, and amounts expected to be paid under residual value guarantees. Variable payments that do not depend on an index or rate are recognized as expenses in the period in which an event or condition indicates that the payment will occur.
F-31
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
To calculate the present value of the lease payments, the Ecopetrol Business Group uses the incremental borrowing rate on the lease’s commencement date. After the commencement date, the amount of lease liabilities is increased to reflect the accretion of interest and reduced for the lease payments made. In addition, the carrying amount of lease liabilities is remeasured if there is a modification, a change in the lease term, a change in the lease payments or a change in the assessment of an option to purchase the underlying asset.
Current leases and low-value asset leases
The Ecopetrol Business Group elected to use the recognition exemptions for lease contracts that, at the commencement date, have a lease term of 12 months or less and do not contain a purchase option (short-term leases), and lease contracts for which the underlying asset is of low value (low-value assets).
Joint Operating Agreements (JOA)
In JOA agreements, the Ecopetrol Business Group assesses whether it controls the use of the asset. If the Ecopetrol Business Group, as the operator, controls the use of the asset, it recognizes the entire right-of-use and lease liability in the financial statements. If it is the JOA who controls, it is analyzed whether the contract meets the characteristics of a sublease, and in that case each party must recognize the right of use in proportion to their participation. Ecopetrol Business Group recognizes
4.13 Impairment of non–current assets
In order to evaluate if any non-current assets are impaired, Ecopetrol Business Group compares its carrying amount with its recoverable amount at least annually or earlier, if there is any indicator that an asset may be impaired.
For purposes of impairment testing, assets are grouped into cash generating units (CGU), provided that those assets individually considered do not generate cash inflows that, to a greater extent, are independent from those generated by other assets or CGUs. The grouping of assets in different CGUs requires the exercise of professional judgment and the consideration, among other parameters, of the business segments. In this sense, in the Exploration and Production segment, each CGU corresponds to each one of the different contractual areas commonly called “fields”; by exception, in those cases where the cash inflows generated by several fields are interdependent from each other, those fields are grouped into a single CGU. In the case of the Refining and Petrochemicals, each CGUs corresponds to each one of the refineries, petrochemical plants, and companies in this segment of the Ecopetrol Business Group, for the Transportation and logistics segment, each pipeline system is considered an independent CGU, and for the Electric power transmission and toll roads concessions segment, which also includes telecommunication business, the CGUs correspond to three groups: energy power transmission, toll roads and telecommunications; these units are distributed in identified and independent groups of assets, agreements, subsidiaries, associates, and joint ventures defined within Interconexión Eléctrica S.A. E.S.P.
The recoverable amount of an asset is the higher amount of the fair value less costs of disposal or its value in use. If the recoverable amount of an asset (or of a CGU) is lower than its net carrying amount, such amount (or that of the CGU) is reduced to its recoverable amount, recognizing an impairment loss in profit or loss.
Fair value less costs of disposal is usually higher than the value in use for the asset in the production segment due to some significant restrictions in the estimation of future cash flows, such as: a) future capital expenses that improve the CGU performance, which could result in expected increase of net cash flows, and b) items that reflect specific business risks, resulting in a higher discount rate.
Fair value less costs of disposal is determined as the sum of the future discounted cash flows adjusted to the estimated risk. The estimations of expected future cash flows used in the assessment of impairment of the assets include estimates of futures commodity prices, supply and demand estimations, and the margins of the products.
Fair value less costs of disposal, as described above, is compared to valuation multiples and quoted prices of shares in companies comparable to Ecopetrol Business Group to determine if it is reasonable. In the case of assets or CGUs that participate in the evaluation and exploration of reserves, proven, probable, and possible reserves are considered, with a risk factor associated with them.
F-32
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
When an impairment loss is recorded, future amortization expenses are calculated based on the adjusted recoverable amount. Impairment losses may be recovered only if the reversal is related to a change in estimations used after impairment loss was recognized in previous periods. These recoveries do not exceed the carrying amount of the assets net of depreciation or amortization that would have been determined if such impairment had not been recognized.
The carrying amount of non–current assets reclassified as assets held–for–sale is compared to its fair value less costs of disposal. No other provision for depreciation, depletion, or amortization is recorded if the fair value less costs of sale is lower than the carrying amount.
For the case of concessions, Ecopetrol Business Group periodically performs a qualitative impairment test on the assets related to the concession to identify events or circumstances, at the CGU level, which is the concession contract with its corresponding amendments, if any, events that indicate that the carrying amount exceeds the recoverable amount. When such events are identified, the quantitative calculation is made, and any impairment is recognized in profit or loss statement.
4.14 Provisions and contingent liabilities
Provisions are recognized when the Ecopetrol Business Group has a current obligation (legal or constructive) because of a past event, it is probable that Ecopetrol will be required to settle the obligation, and a reliable estimation can be made of the amount of the obligation. Where applicable, they are recorded at present value, using a rate reflecting the risk specific to the liability.
If the effect of the temporary value of money over time is significant, the provisions are discounted using a current market rate before taxes that reflects, when applicable, the specific risks of the liability. When the discount is recognized, the increase in the provision is recognized as a financial expense in the statement of profit and loss.
Disbursements related to environmental conservation, linked to revenue from current or future operations, are recognized as expenses or assets, as appropriate. Disbursements related to past operations, which do not contribute to obtaining current or future revenue, are recorded as expenses.
The recognition of these provisions coincides with the identification of an obligation related to environmental remediation and Ecopetrol Business Group uses all available information to determine a reasonable estimate of their respective cost.
Contingent liabilities are not recognized but are subject to disclosure in the explanatory notes when an outflow of resources is possible; including those whose amounts cannot be estimated.
In cases where the provision is expected to be reimbursed in whole or in part, for example under an insurance contract, the reimbursement is recognized as a separate asset only in cases where such reimbursement is practically certain. The amount recognized for the asset should not exceed the amount of the provision.
Asset retirement obligation
Liabilities associated with the retirement of assets are recognized when there are current obligations, either legal or constructive, related to the abandonment and dismantling of wells, facilities, pipelines, buildings, and equipment.
The obligation is usually recorded when the assets are installed or when the surface or the environment are altered at the operating sites. These liabilities are calculated using the discounted cash flow method, using a pre–tax rate reflecting current market conditions similar liabilities and considering the economic limits of the field or the useful life of the respective asset. When it is not possible to determine a reliable estimation in the period in which the obligation originates, a provision is recognized when there is enough information available to make the best estimation.
The carrying amount of the provision is reviewed and adjusted annually considering changes in the assumptions used for its estimation, using a risk-free rate adjusted by a premium that reflects the risk and the company credit rating under the current market conditions. Any change in the present value of the estimated expenditure is reflected as an adjustment to the provision and the corresponding property, plant, and equipment and natural and environmental resources. When a decrease in the asset retirement obligation related to a producing asset exceeds the carrying amount of the asset, the excess is recognized in the statement of profit or loss. The increase in the provision due to the passage of time is recognized in results for the period as a financial expense.
F-33
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
4.15 |
Income tax and other taxes |
Income tax expense is comprised of income tax payable for the period and the effect of deferred taxes in each period.
Current income taxes are recognized in income except when they relate to items recognized in other comprehensive income, in which case the corresponding tax effect is also recognized in other comprehensive income. Income tax assets and liabilities are presented separately in the consolidated statement of financial position, except where there is a right of setoff within fiscal jurisdictions and an intention to settle such balances on a net basis.
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4.15.1 |
Current income tax |
The Ecopetrol Business Group determines the provision for income tax based on the highest amount between taxable income and presumptive income (the minimum estimated amount of taxable profit on which the law expects to quantify and collect income taxes). Taxable income differs from profit before tax as reported in the consolidated statement of profit or loss, because of items of income or expense that are taxable or deductible in other periods, special taxable deductions, tax losses and income and line items measured that, according to applicable tax laws in each jurisdiction, are considered nontaxable or nondeductible.
4.15.2 Deferred income tax
Deferred tax is provided using the liability method for temporary differences between the carrying amounts of existing assets and liabilities in the consolidated financial statements and their respective tax bases. A deferred tax liability is recognized for all taxable temporary differences. A deferred tax asset is recognized for all deductible temporary differences and for all accumulated tax losses, if there is a reasonable expectation that the Ecopetrol Business Group will generate future tax profits against which they will be used.
Deferred taxes on assets and liabilities are calculated based on the tax rates that are expected to apply during the years in which temporary differences between the carrying amounts and tax bases are expected to be reversed.
The carrying amount of a deferred tax asset is subject to review at the end of each reporting period, and it is reduced to the extent it is no longer probable that the corresponding legal entity will generate enough future taxable profit to realize such deferred tax asset.
In the statement of financial position, deferred tax assets are reflected net and as an offset against deferred tax liabilities, depending on the overall tax position in a particular jurisdiction and on the same taxable entity.
Deferred taxes are not recognized when they arise in the initial recognition of an asset or liability in a transaction (except in a business combination) and at the time of the transaction, do not affect the accounting or tax profit, or in respect of the taxes on the possible future distribution of accumulated profits of subsidiaries or investments accounted for by the equity method, if at the time of the distribution it may be controlled by Ecopetrol and it is probable that the retained earnings will be reinvested by the Ecopetrol Business Group companies and, therefore, will not be distributed to the Group.
4.15.3 Other taxes
The Ecopetrol Business Group recognizes in profit or loss the costs and expenses related to other taxes than the income tax, such as the wealth tax, which is determined based on the tax equity, the industry and commerce tax on income obtained in the municipalities for performance of commercial, industrial, and service activities, and the transport tax on volumes loaded in the transport systems. Taxes are calculated in accordance with current tax regulations.
4.16 Employee benefits
Salaries and benefits for Ecopetrol Business Group’s employees are governed by the Colombian Collective Labor (Agreement 01 of 1977), and, by the Colombian Substantive Labor Code. In addition to the benefits determined by labour laws, employees are entitled to fringe benefits which are subject to the place of work, type of work, length of service, and basic salary. An annual interest of
F-34
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
Ecopetrol belonged to the special pension regime under which pension liabilities are Ecopetrol’s responsibility and not pension fund’s responsibility. However, Law 797 of January 29, 2003, and Legislative Act 001 of 2005 determined that Ecopetrol will no longer belong to the said regime and that from that point on employees would be part of the General Pension Regime. Consequently, pension obligations related to employees pensioned until July 31, 2010, are still Ecopetrol’s responsibility. Employees are entitled to such pension bonus if they worked with Ecopetrol prior to January 29, 2003, but whose labor agreement expired without renewal before that date.
All labor benefits of employees who joined Ecopetrol before 1990 are Ecopetrol’s responsibility, without the involvement of any social security entity or institution. Service cost for the employee and his/her relatives registered with Ecopetrol is determined by means of a mortality table, prepared based on facts occurring during the year.
For employees who joined Ecopetrol after the Act 50 of 1990 went in effect, Ecopetrol makes periodic contributions for severance payments, pensions, and labor risks to the respective funds.
In 2008, Ecopetrol partially settled the value corresponding to monthly pension payments from its pension liabilities, transferring such liabilities and their underlying amounts to autonomous pension funds (PAP, for its acronym in Spanish). The funds transferred, and returns on those funds, cannot be redirected, nor can they be returned to the Ecopetrol Business Group, until all of the pension obligations have been fulfilled. The settled obligation covers allowances and pension bonds payments, with health and education remaining Ecopetrol’s responsibility.
Employee benefits are divided into four groups comprised as follows:
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a) |
Short–term employee benefits and post–employment defined benefits: |
Benefits to employees in the short term mainly correspond to those which payment will be made in the term of twelve months following the closing of the period in which the employees have rendered their services. These mainly include salaries, severance payments, vacation, bonuses, and other benefits.
Post–employment benefits of defined contributions plans correspond to the periodic payments for severance, pensions, and labor risk payments that the Ecopetrol Business Group makes to the respective funds that assume these obligations in their entirety.
F-35
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
The above benefits are recognized as an expense with an associated liability after deducting any already paid amounts.
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b) |
Post–employment defined benefit plans: |
In the defined benefits plan, the Ecopetrol Business Group provides the benefits agreed to current and former employees and assumes the actuarial and investment risks.
The following benefits are classified as long–term defined benefit plans recognized in the financial statements according to the calculations of an independent actuary:
| ● | Pensions |
| ● | Pension bonds |
| ● | Pension incentives |
| ● | Health |
| ● | Educational plan |
| ● | Retroactive severances |
Liabilities recognized in the statement of financial position with respect to these benefit plans are determined based on the present value of the defined benefit obligation at the date of the statement of financial position less the fair value of plan assets.
The defined benefit obligation is calculated annually by independent actuaries using the projected credit unit method, which considers employees’ years of service and, for pensions, average or final pensionable remuneration. This obligation is discounted at its present value using interest rates of high–quality government bonds denominated in the currency in which the benefits will be paid and of a duration consistent with the plan obligations.
These actuarial calculations involve several assumptions that could differ from the events that will effectively take place in the future. Said assumptions include the determination of a discount rate, future salary increases, mortality rates and future pension increases. Because of the complexity of the calculation, the underlying assumptions and long–term nature of these plans, the obligations for defined benefits are extremely sensitive to changes in assumptions. All key assumptions are revised at the end of the reported period.
In determining the appropriate discount rate, in absence of a broad high quality bond market, Management considers interest rates corresponding to the class B TES bonds issued by the Colombian Government as its best reference, at an appropriate discount rate with maturities extrapolated in line with the term expected for each benefit plan. The mortality rate is based on the country’s rate, the latest version of which is the RV08 mortality table published in resolution 1555 of October 2010. The future salary and pension increases are linked to the country’s future inflation rates. Note 22 – Provisions for employee benefits provides further details on key assumptions used.
F-36
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
The amounts recognized in the consolidated statement of profit or loss related to employees defined benefit plans are comprised mainly by service cost and the net financial expense. Service cost includes mainly the increase in present value of the benefit obligation during the period (current service cost) and the amount resulting from a new benefit plan. Plan amendments correspond to changes in benefits and are usually recognized when all legal and regulatory approvals have been obtained and the effects have been conveyed to the employees involved. The net financial expense is calculated using the net liability for defined benefits as compared with the yield curve of the discount rate at the beginning of each year for each plan. The net defined benefit obligation or asset resulting from actuarial profits and losses, the asset ceiling effect, and the asset profitability, excluding the value of recognized in the consolidated statement of profit or loss, are recognized in other comprehensive income.
When the plan assets exceed the gross obligation, the recognized asset is limited to the lower of the surplus in the defined benefits plan and the ceiling of assets determined using a discount rate based on Colombian Government bonds.
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(a) |
Others long-term benefits |
Others long–term benefits include the five–year term bonus which also considered in the actuarial calculation. This benefit is a cash bond that accumulates annually and is paid every five years to employees. The Ecopetrol Business Group recognizes in the consolidated statement of profit or loss the service cost, the net financial cost and the adjustment to the obligation of the defined benefit plan.
|
(b) |
Termination benefits |
Termination benefits are recognized only when a detailed plan exists and there is no possibility to withdraw the offer. The Ecopetrol Business Group recognizes a liability and an expense for termination benefits at the earliest date between the date when the offer of such benefits cannot be withdrawn and the date when the restructuring costs are recognized.
4.17 Revenue from contracts with customers
The Ecopetrol Business Group’s business is based on four principal sources of revenue from customer contracts: 1) sales of crude oil and natural gas, 2) services associated with the transport of hydrocarbons, 3) sales of refined and petrochemical products, and biofuels, and 4) electric power transmission and toll roads concessions. Revenue from customer contracts is recognized when control of the goods or services are transferred to the customer at an amount that reflects the consideration that the Ecopetrol Business Group expects to receive in exchange for those goods or services (See notes 7 and 25).
Sales of crude oil and natural gas
Revenue from sales of crude oil and natural gas is recognized upon transfer of control to the buyer. This generally occurs when the product is physically transferred into a vessel, pipeline or by another delivery method, thus fulfilling the Ecopetrol Business Group’s performance obligations to its customers.
For some natural gas supply contracts with a replacement period, a distinction is made between quantities of gas consumed and not consumed to recognize the respective revenue or liability relating to quantities that will be requested in the future. Once the customer claims such natural gas, the revenue is recognized.
F-37
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
Services associated with the transport of hydrocarbons
Revenue from hydrocarbons transport services is recognized when the service is provided to the customer and there are no contractual conditions that prevent recognition of the revenue. Ecopetrol Business Group companies are principal in providing these services.
Ship/ Take-or-Pay contracts for the sale of refined products, storage and transport specify minimum quantities of products or services for which a customer will pay, even if the latter does not receive them or use them (“deficient quantities”). Although the Ecopetrol Business Group expects customers to recover all deficient quantities to which they are contractually entitled, any load revenue received related to temporary shortfalls that will be offset in a future period will be deferred and that amount recognized as revenue in the event any of the following scenarios occurs:
|
a) |
The customer exercises its right to deficient volumes or services, or |
|
b) |
The possibility is remote that the customer will exercise its right to deficient volumes or services. |
Refined and petrochemical products and biofuels
In the case of refined products and petrochemicals, such as fuel oil, asphalt, polyethylene, LPG and propane and gasoline, etc., revenue is recognized when the products are shipped and delivered by the refinery; subsequently, they are adjusted for price changes, in the case of products with regulated prices. In the case of the companies that distribute natural gas and LPG, the revenue from the services is recognized when the service is provided to the customer.
In other cases, Ecopetrol Business Group recognizes revenue when the performance obligation is satisfied, giving rise to the certain, probable, and quantifiable right to demand payment.
Under current local regulation, Ecopetrol Business Group sells regular gasoline and ACPM in Colombia at a regulated price.
In accordance with Decree 1068 of 2015, the Ministry of Mines and Energy semiannually calculates and settles Ecopetrol’s net position to be stabilized for each fuel by the Fuel Price Stabilization Fund (FEPC, for its acronym in Spanish). The net position corresponds to the sum of the spreads throughout the period, the result of which is the amount in pesos owed to the Company and charged to the resources of the FEPC. The differential corresponds to the product between the volume reported by the Company at the time of sale and the difference between the parity price and the reference price, the parity price being that which corresponds to the daily prices of motor and diesel gasoline observed during the month, expressed in pesos, referenced to the Gulf of the United States market, calculated by applying Resolution 18 0522 of 2010, and the reference price is the Producer Income defined by the Ministry of Mines and Energy for these purposes. Therefore, this differential constitutes a greater or lesser value of sales revenue and a receivable or payable account for Ecopetrol.
Electric power transmission and toll roads concessions
This group refers to 1) supplying of electricity transmission services in Latin America through the operation and maintenance of high-voltage transport networks and interconnections 2) design, construction, operation, and maintenance of road infrastructures, 3) supplying of information technology, and (4) telecommunications services.
The recognition of revenue from electric power transmission services occurs according to the performance obligations based on the conditions of the contracts that include requirements established by the electricity market regulators in the countries in which Ecopetrol Business Group operates. This is generally achieved when the performance obligations agreed with the regulatory entities are executed, considering the period and the quality of the service established in the contracts. Technology and telecommunications services revenue is also recognized according to the performance obligations defined in contracts with customers.
F-38
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
For service concession agreements, Ecopetrol Business Group measures the revenue in accordance with IFRIC 12 at the fair value of the consideration received or receivable, considering the payment defined in the contracts.
| ● | Recognize revenues and costs for project construction services in results for the period, according to the percentage completion method of the projects at the reporting date, which includes an estimated profit margin determined based on the macroeconomic characteristics and the conditions of the project, and the weighting of the estimated receivable cash flows related to the estimated cash flows of the construction. |
| ● | Recognize revenues and costs for operation and maintenance services of third-party facilities in the profit or loss statement for the period, as the service is provided, based on the performance obligations established in the contracts. |
| ● | Recognize the financial returns of concession agreements classified as financial assets in the statement of profit or loss for the period using the effective interest rate method. |
The business model developed under electric power transmission concession agreement, associated with the obligation to build, and implement the electric power transmission infrastructure and is classified under the asset according to IFRS 15 – Revenue from contracts with customers. The asset is recognized while the obligation to build and implement the infrastructure is satisfied, and revenue is recognized over the life of the project.
Significant financing component
Payments received from customers are generally short term (except for revenue of concessions). Using the practical expedient in IFRS 15, Ecopetrol Business Group does not adjust the promised amount of consideration for the effects of a significant financing component if it expects, at contract inception, that the period between the transfer of the promised good or service to the customer and the customer’s payment for that good or service to be one year or less.
Considering that revenues related to concessions generates long term accounts receivables, a financial component is applied considering the measurement of the asset as amortized cost, defining the future cash flows, and applying and discount rate, according to IFRS 9 – Financial Instruments.
Variable considerations
Upon fulfillment of the obligations set forth in agreements with customers, via delivery of the product or provision of the service, variable components of the transaction price may exist, such as the exchange rate for crude exports or international price fluctuations. In these cases, the Ecopetrol Business Group makes its best estimate of the transaction price that reflects the goods and services transferred to customers.
Agreements signed with customers do not include material variable considerations such as rebates, refunds, or discounts.
Customer advances
They correspond to contractual obligations in which the Ecopetrol Business Group receives monetary resources from customers to subsequently transfer goods and services. These advances made by customers are part of the policies and risk assessment defined by the Ecopetrol Business Group.
4.18 Costs and expenses
Costs and expenses are presented according to their function; they are detailed in the related disclosures in cost of sales, and administrative, operating, projects, and other associated expenses.
F-39
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
4.19 Finance income (expenses)
Finance income and expenses include mainly: a) borrowings costs on loans and financing, except for those that are capitalized on qualifying asset, b) gains and losses on changes in fair value of financial instruments measured at fair value through profit or loss, c) currency exchange differences of financial assets and liabilities, except for debt instruments designated as hedging instruments, d) interest expenses as a result of discounting long–term liabilities (abandonment costs and pension liabilities), e) dividends derived from equity instruments measured at fair value with changes in other comprehensive income.
4.20 Information by business segment
Ecopetrol Business Group presents the information related to its business segments in its consolidated financial statements in accordance with paragraph 4 of IFRS 8 – Operation segments.
The operations of the Ecopetrol Business Group are performed through four business segments: 1) Exploration and Production, 2) Transport and Logistics, 3) Refining and Petrochemical, and 4) Electric Power Transmission and Toll Roads Concessions.
Segments are determined based on Ecopetrol Business Group Management objectives and corporate strategic plans, considering that these businesses: (a) are engaged in different commercial activities, which generate sales revenue and incur costs and expenses; (b) the operational results are revised regularly by the Ecopetrol Business Group’s Governance that makes operational decisions to allocate resources to the various segments and assess their performance; and (c) there is differentiated financial information available. Internal transfers represent sales to inter–company segments and are recognized and presented at market prices.
|
a) |
Exploration and production : This segment includes activities related to the exploration and production of oil and gas. Revenues are derived from sales of oil and natural gas at market prices to other segments and to third parties (domestic and foreign distributors). Costs include costs incurred in production. Expenses include all exploration costs that are not capitalized. |
|
b) |
Transport and logistics : This segment includes sales revenue and costs associated with the transport and distribution of hydrocarbons and derivative products in operation. |
|
c) |
Refining and petrochemicals : This segment mainly includes activities performed at the Barrancabermeja and Cartagena refineries, where crude oil from production fields is refined or processed. Additionally, this segment includes distribution of natural gas and LPG activities performed by Invercolsa Group. Revenues are derived from the sale of products to other segments and to domestic and foreign customers and include refined and petrochemical products at market prices and some fuels at regulated price. This segment also includes industrial service sales to customers. |
|
d) |
Electric power transmission and toll roads concessions: This segment includes activities of supplying electric power transmission services, design, development, construction, operation, and maintenance of road and energy infrastructure projects. Revenues come from the supplying of these services to domestic and foreign clients (mainly Latin America). This segment also includes the supplying of information technology and telecommunications services. |
See information by segments in Note 33.
4.21 Business combinations
The Ecopetrol Business Group accounts for business combinations using the acquisition method. Identifiable assets acquired and liabilities assumed are initially measured at fair value on the acquisition date. Ecopetrol Business Group recognizes separately, at the acquisition date, the identifiable assets, and liabilities of the acquiree that meet the appropriate criteria for recognition, regardless of whether they had been previously recognized in the financial statements of the acquiree.
On the acquisition date, the acquirer will recognize separately the identifiable assets acquired, the liabilities assumed, and any non-controlling interest in the acquiree.
F-40
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
The company that acts as buyer will recognize the goodwill generated as an asset on the acquisition date, measured as the difference between (i) the sum of the consideration transferred, the amount of any non-controlling interest, and the fair values on the date of acquisition of the shareholding in the acquiree, and (ii) the net amount of the acquisition date of the identifiable assets acquired and the liabilities assumed.
The cost of an acquisition is measured as the aggregate of the consideration transferred, which is measured at acquisition date fair value, and the amount of any non-controlling interests in the acquiree. For each business combination, the Ecopetrol Business Group elects whether to measure the non-controlling interests in the acquiree at fair value or at the proportionate share of the acquiree’s identifiable net assets. Acquisition-related costs are expensed as incurred and included in administrative expenses.
The Ecopetrol Business Group determines that it has acquired a business when the acquired set of activities and assets include an input and a substantive process that together significantly contribute to the ability to create outputs. The acquired process is considered substantive if it is critical to the ability to continue producing outputs, and the inputs acquired include an organized workforce with the necessary skills, knowledge, or experience to perform that process or it significantly contributes to the ability to continue producing outputs and is considered unique or scarce or cannot be replaced without significant cost, effort, or delay in the ability to continue producing outputs.
When Ecopetrol Business Group acquires a business, it assesses the financial assets and liabilities assumed for appropriate classification and designation in accordance with the contractual terms, economic circumstances and pertinent conditions as at the acquisition date.
Goodwill is initially measured at cost (being the excess of the aggregate of the consideration transferred and the amount recognized for non-controlling interests and any previous interest held over the net identifiable assets acquired and liabilities assumed). If the fair value of the net assets acquired is in excess of the aggregate consideration transferred, the Ecopetrol Business Group re-assesses whether it has correctly identified all of the assets acquired and all of the liabilities assumed and reviews the procedures used to measure the amounts to be recognized at the acquisition date. If the reassessment still results in an excess of the fair value of net assets acquired over the aggregate consideration transferred, then the gain is recognized in profit or loss.
After initial recognition, goodwill is measured at cost less any accumulated impairment losses. For the purpose of impairment testing, goodwill acquired in a business combination is, from the acquisition date, allocated to each of Ecopetrol Business Group’s cash-generating units that are expected to benefit from the combination, irrespective of whether other assets or liabilities of the acquiree are assigned to those units.
Where goodwill has been allocated to a cash-generating unit (CGU) and part of the operation within that unit is disposed of, the goodwill associated with the disposed operation is included in the carrying amount of the operation when determining the gain or loss on disposal. Goodwill disposed in these circumstances is measured based on the relative values of the disposed operation and the portion of the cash-generating unit retained.
5. New standards and regulatory changes
5.1 New standards adopted by the Group, effective as of January 1, 2024
The IASB issued amendments to the following standards, with an effective date on January 1, 2024, or later periods:
| ● | Amendment to IAS 1 - Classifications of liabilities as current or non-current, modifies the requirement to classify a liability as current, by establishing that a liability is classified as current when it does not have the right at the end of the reporting period to defer the liquidation of the liability during, at least, the twelve months following the date of the reporting period. |
Under legacy IAS 1, a company classified a liability as current unless, among other things, it had an unconditional right to defer settlement of the liability for at least 12 months from the reporting date. The IAS 1 amendments remove the requirement that the right to defer settlement be unconditional; instead, now the right must have substance and must exist at the reporting date.
In addition, an entity is required to disclose when a liability arising from a loan agreement is classified as non-current and the entity’s right to defer settlement is contingent on compliance with future covenants within twelve months.
F-41
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
There is no relevant impact from this modification of IAS 1, neither regarding the classification of liabilities between current and non-current nor with respect to covenants.
| ● |
IAS 12 Amendment: The IASB issued the amendment in May 2023, which provides to the companies a temporary exemption from accounting of deferred taxes arising from the international tax reform of the Organization for Economic Co-operation and Development (OECD), which published the rules to ensure that large multinational companies would be subject to a minimum tax rate of
|
| ● | Amendment IAS 7 - Cash Flow Statement and IFRS 7 - Financial instruments: Disclosures. The IASB issued the amendment on disclosure requirements to improve the transparency of suppliers financing arrangements and their effects on a company’s liabilities, cash flows and liquidity risk exposure. |
| ● | Modifications to IFRS 16 - Lease Liability in a Sale and Leaseback Transaction. In September 2022, the IASB issued amendments to IFRS 16 to specify the requirements that a seller-lessee uses in measuring the lease liability arising in a sale and leaseback transaction, to ensure that the seller-lessee does not recognize any amount for profit or loss related to the right of use that it maintains. |
There is no relevant impact from these new standards adopted by the business Group.
5.2 New standards issued but not yet adopted
| ● | Amendment IAS 21 - Effects of Variations in Foreign Currency Exchange Rates. The Amendment establishes criteria that allows assessing whether a currency is interchangeable and knowing when it is not. Thus, it will be possible to determine the exchange rate to be used and the disclosures to be provided. The Amendment applies to annual periods beginning on January 1, 2025. |
| ● | Issuance of IFRS 18 Presentation and disclosure in financial statements. This new IFRS standard aims to improve the usefulness of the information presented and disclosed in financial statements and will provide investors with more transparent and comparable information on the financial performance of companies, allowing them to make better investment decisions. This new standard is effective internationally for reporting periods beginning on or after January 1, 2027, but companies can apply it early. It should be noted that IFRS 18 replaces IAS 1 - Presentation of financial statements. |
| ● | Issuance of IFRS 19 – Non-Public Interest Subsidiaries: Disclosures, this new standard allows subsidiaries to disclose reduced information, instead of disclosures in accordance with other IFRSs. Thus, the application of this standard will reduce the costs of preparing the financial statements of subsidiaries, while maintaining the usefulness of the information for users of their financial statements. |
| ● | Limited-scope amendments to IFRS 7 and IFRS 9: These amendments will improve the consistency and understanding of accounting requirements by clarifying terms and procedures, introducing detailed disclosure requirements and allowing flexible early application, which will reduce diversity in accounting practice and increase transparency and consistency of financial reporting. Amendments effective from 1 January 2026 and early application is allowed. |
| ● | Volume 11 of the annual improvements to IFRS. The document includes clarifications, simplifications, corrections and changes intended to improve the consistency of the following standards: |
|
o |
IFRS 1 – First-time adoption of International Financial Reporting Standards |
|
o |
IFRS 7 – Financial instruments: disclosures |
|
o |
IFRS 9 – Financial instruments |
|
o |
IFRS 10 – Consolidated financial statements |
|
o |
IAS 7 – Statement of cash flows |
F-42
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
| ● | Sale or Contribution of Assets between an Investor and its Associate or Joint Venture - Amendments to IFRS 10 and IAS 28. The amendments address an acknowledged inconsistency between the requirements in IFRS 10 and those in IAS 28 (2011), in dealing with the sale or contribution of assets between an investor and its associate or joint venture. |
The main consequence of the amendments is that a full gain or loss is recognized when a transaction involves a business (whether it is housed in a subsidiary or not). A partial gain or loss is recognized when a transaction involves assets that do not constitute a business, even if these assets are housed in a subsidiary.
| ● | Power Purchase Agreements – Amendments to IFRS 9 and IFRS 7. The amendment helps the companies to report the financial effects of nature-dependent electricity contracts, which are often structured as power purchase agreements (PPAs). The IASB acted swiftly in the light of the increased use of these contracts. |
Nature-dependent electricity contracts help companies to secure their electricity supply from sources such as wind and solar power. The amount of electricity generated under these contracts can vary based on uncontrollable factors such as weather conditions. Current accounting requirements may not adequately capture how these contracts affect a company ’ s performance.
To allow companies to better reflect these contracts in the financial statements, the IASB has made targeted amendments to IFRS 9 Financial Instruments and IFRS 7 Financial Instruments: Disclosures. The amendments include:
|
o |
clarifying the application of the ‘ own use ’ requirements; |
|
o |
permitting hedge accounting if these contracts are used as hedging instruments; and |
|
o |
adding new disclosure requirements to enable investors to understand the effect of these contracts on a company ’ s financial performance and cash flows. |
|
5.3 |
New standards issued by the ISSB that with effect in future periods |
The International Sustainability Standards Committee, in June 2023 issued the first international sustainability and climate standards: IFRS S1 General Requirements for the Information to be Disclosed on Sustainability related to Financial Information and IFRS S2 Weather-related Disclosures. The purpose of these standards is for entities to disclose information about their risks and opportunities related to sustainability and climate that is useful to the primary users of financial information for decision-making. An entity will apply these standards for reports for annual periods beginning on or after January 1, 2024.
In August 2023, the Ecopetrol Business Group began assessing and understanding the new corresponding regulations, identifying the information requested in the standards in its different pillars (Governance, Strategy, Risks and Metrics and Objectives) versus the information already contained in the ESG reports adopted by the Business Group in order to draw up the roadmap for its implementation.
6. Cash and cash equivalents
|
|
|
2024 |
|
2023 |
|
Banks |
|
|
|
|
|
Short–term investments |
|
|
|
|
|
Cash |
|
|
|
|
|
|
|
|
|
|
As of December 31, 2024, the balance of cash and cash equivalents (short-term investments) includes an amount of total restricted cash for $
F-43
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
The fair value of cash and cash equivalents approximates its book value due to its short-term nature (less than three months) and its high liquidity. Cash equivalents are convertible to a known amount of cash and are subject to a non-significant risk of changes in value. The effective rate of return on cash and cash equivalents as of December 31, 2024, was
The following table reflects the credit quality of banks in which Ecopetrol Business Group has deposits and check accounts, and issuers of investments included in cash and cash equivalents:
|
Rating |
|
2024 |
|
2023 |
|
AAA |
|
|
|
|
|
F1 |
|
|
|
|
|
A+ |
|
|
|
|
|
F3 |
|
|
|
|
|
A-1 |
|
|
|
|
|
P-1 |
|
|
|
|
|
F1+ |
|
|
|
|
|
A |
|
|
|
|
|
BRC1+ |
|
|
|
|
|
BBB |
|
|
|
|
|
F2 |
|
|
|
|
|
Ba1 |
|
|
|
|
|
AA |
|
|
|
|
|
A1 |
|
|
|
|
|
P AAA |
|
|
|
|
|
BB |
|
|
|
|
|
AAAmmf |
|
|
|
|
|
AAAF |
|
|
|
|
|
B |
|
|
|
|
|
BRC1 |
|
|
|
|
|
Aaa |
|
|
|
|
|
AAAm |
|
|
|
|
|
C |
|
|
|
|
|
Not available rating |
|
|
|
|
|
|
|
|
|
|
See credit risk policy in Note 30.7.
F-44
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
7. Trade and other receivables
|
|
|
2024 |
|
2023 |
|
Current |
|
|
|
|
|
Fuel Price stabilization fund (1) |
|
|
|
|
|
Concessions (2) |
|
|
|
|
|
Customers |
|
|
|
|
|
Foreign |
|
|
|
|
|
Domestic |
|
|
|
|
|
Related parties (Note 31) |
|
|
|
|
|
Accounts receivable from employees |
|
|
|
|
|
Industrial services |
|
|
|
|
|
Other |
|
|
|
|
|
|
|
|
|
|
|
Allowance for doubtful accounts (3) |
|
(
|
|
(
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Non–current |
|
|
|
|
|
Concessions (2) |
|
|
|
|
|
Accounts receivable from employees |
|
|
|
|
|
Related parties (Note 31) |
|
|
|
|
|
Customers |
|
|
|
|
|
Foreign |
|
|
|
|
|
Domestic |
|
|
|
|
|
Other (4) |
|
|
|
|
|
|
|
|
|
|
|
Allowance for doubtful accounts (3) (4) |
|
(
|
|
(
|
|
|
|
|
|
|
| (1) | Corresponds to the application of Resolution 180522 of March 29, 2010, and other regulations that modify and add it (Decree 1880 of 2014 and Decree 1068 of 2015), which establishes the procedure to recognize the subsidy for refiners and importers of motor gasoline current and ACPM, and the methodology for calculating the net position (value generated between the parity price and the regulated price, which can be positive or negative). |
The movement of the account receivable from the Fuel Price Stabilization Fund is as follows:
|
|
|
2024 |
|
2023 |
|
Opening balance |
|
|
|
|
|
Settlements for the period (Note 25) |
|
|
|
|
|
Mobilizations and others |
|
|
|
|
|
Collections (1.1) |
|
(
|
|
(
|
|
Offsetting (1.2) |
|
— |
|
(
|
|
Closing balance |
|
|
|
|
1.1
During 2024, the Ministry of Finance and Public Credit paid $
| ● |
Payments to Ecopetrol for
$
|
| ● |
Payments to Refinería de Cartagena for
$
|
F-45
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
| ● |
Payments received in 2024 include
$
|
|
1.2 |
During 2023, the Ministry of Finance and Public Credit paid $
|
| ● |
Payments to Ecopetrol for
$
|
| ● |
Payments to Reficar for
$
|
The recognition of revenue associated with the price differential is detailed in note 25.
| (2) | Includes electric power transmission and toll roads concessions. |
| (3) | Corresponds to the recognition of the Company’s client portfolio that is at risk of non-payment. The credit risk policies applied by the Company are detailed in Note 30.7. |
| (4) |
Corresponds mainly to accounts receivable from the Government of Brazil for employee benefits governed by Law 4819 of 1958 to ISA CTEEP, and crude loan agreements of the Business Group for transportation systems. The balance of these accounts receivable is
$
|
The book value of trade and other receivables approximates their fair value.
The changes in the allowance for doubtful accounts for the year ended December 31, 2024, 2023 and 2022 are as follows:
|
|
|
2024 |
|
2023 |
|
2022 |
|
Opening balance |
|
(
|
|
(
|
|
(
|
|
Additions |
|
(
|
|
(
|
|
(
|
|
Currency translation |
|
(
|
|
|
|
(
|
|
Accounts receivable write–off and uses |
|
|
|
|
|
|
|
Closing balance |
|
(
|
|
(
|
|
(
|
8 . Inventories
The inventories balance is presented net of the allowance for inventory losses.
|
|
|
2024 |
|
2023 |
|
Crude oil (1) |
|
|
|
|
|
Fuels and petrochemicals |
|
|
|
|
|
Materials for goods production |
|
|
|
|
|
|
|
|
|
|
|
(1) |
The variation is primarily due to increased export inventory, closing the year with no stock in transit and connected inventories. |
F-46
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
The following are the changes of the allowances for losses for the years ended December 31, 2024, 2023 and 2022:
|
|
|
2024 |
|
2023 |
|
2022 |
|
Opening balance |
|
(
|
|
(
|
|
(
|
|
Additions |
|
(
|
|
(
|
|
(
|
|
Foreign currency translation |
|
(
|
|
|
|
(
|
|
Other |
|
|
|
(
|
|
|
|
Closing balance |
|
(
|
|
(
|
|
(
|
Crude oil, fuel, and petrochemicals inventories are adjusted to the lower of cost and net realizable value, mainly due to fluctuations in international crude oil prices. The amount recorded for this in 2024 was $
9 . Other financial assets
|
|
|
2024 |
|
2023 |
|
Assets measured at fair value |
|
|
|
|
|
Investments in equity securities and trust funds (1) |
|
|
|
|
|
Investment Portfolio – Foreign currency |
|
|
|
|
|
Hedging instruments (2) |
|
|
|
|
|
Investment Portfolio – Local currency |
|
|
|
|
|
|
|
|
|
|
|
Assets measured at fair value through other comprehensive income |
|
|
|
|
|
Investment Portfolio – Local currency (3) |
|
|
|
|
|
Shares and other (4) |
|
|
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|
|
|
|
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|
Assets measured at amortized cost (5) |
|
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Current |
|
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Non–current |
|
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|
(1) |
They include deposits in trusts companies and restricted funds in Brazil, Peru, Chile, and Colombia. See note 9.1. |
|
(2) |
Corresponds to swap contracts to hedge commodity price risk and forwards contracts to hedge exchange rate risk mainly in Ecopetrol S.A. and Interconexión Eléctrica S.A. E.S.P. |
|
(3) |
Corresponds to National Government TES securities to meet liquidity needs at Ecopetrol S.A. |
|
(4) |
Corresponds mainly to the recognition of McDermott shares in Refinería de Cartagena S.A.S. (see note 23.4) |
|
(5) |
Includes investments with maturities greater than 90 days, in Chile and Colombia. |
The average return of the investment portfolio in Colombian pesos (local currency) and U.S. dollars (foreign currency) were
The fair value measurement is recognized against other comprehensive income (Note 24.5) or financial result (Note 29), in accordance with the business model established by the Business Group.
F-47
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
9.1 |
Restrictions |
As of December 31, 2024 and 2023, there were restricted funds for $
|
9.2 |
Maturity |
The following is the balance of other financial assets by date to maturity as of December 31, 2024, and 2023:
|
|
|
2024 |
|
2023 |
|
Up to 1 year |
|
|
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|
|
1 – 2 years |
|
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|
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2 – 5 years (1) |
|
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5 years (2) |
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(1) |
This corresponds mainly to the recognition of McDermott’s shares in Refinería de Cartagena S.A.S. (see Note 23.4). |
(2) Corresponds to TES maturities of the National Government.
|
9.3 |
Fair value |
The following is the balance of other financial assets by fair value hierarchy level as of December 31, 2024, and 2023:
|
|
|
2024 |
|
2023 |
|
Level 1 |
|
|
|
|
|
Level 2 |
|
|
|
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Level 3 (1) |
|
|
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— |
|
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|
|
|
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(1) |
Corresponds to the recognition of McDermott’s shares in Refinería de Cartagena S.A.S. (see note 23.4). These shares were accounted as an equity instrument recognized at fair value in hierarchy level 3, they are not listed on a stock exchange and the refinery is a minority investor. After analyzing the information available for the valuation update as of December 31, 2024, it is concluded that the company does not have enough information available in the market to allow an update of the financial valuation of McDermott’s results in 2024 and its projected cash flows. |
There were no transfers between hierarchy levels for the years ended December 31, 2024, and 2023.
The securities in the Ecopetrol Business Group’s portfolio are valued daily in accordance with the provisions of the Colombian Financial Superintendency. For this purpose, information provided by authorized entities is used, which collect data from active markets. In cases where market data is unavailable, other directly or indirectly observable data are used.
For investments denominated in dollars, Bloomberg is the information provider, and for those denominated in pesos, Precia is the entity authorized by the Colombian Financial Superintendency to provide this service.
Within the investment ranking process, in addition to the information used for valuation, other relevant aspects are taken into account, such as the issuer rating, investment classification, liquidity, active market, and the issuer risk analysis conducted by the Ecopetrol Business Group, which allows for the appropriate investment ranking level to be reached.
F-48
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
9.4 |
Credit rating |
The following table reflects the credit quality of the issuers of other financial assets:
|
|
|
2024 |
|
2023 |
|
BB+ (1) |
|
|
|
|
|
AA+ |
|
|
|
— |
|
F1 |
|
|
|
|
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P-1 |
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B |
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F2 |
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AAA |
|
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|
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F1+ |
|
|
|
— |
|
Baa3 |
|
|
|
|
|
F3 |
|
|
|
— |
|
BB |
|
— |
|
|
|
A-2 |
|
— |
|
|
|
A1 |
|
— |
|
|
|
BBB |
|
— |
|
|
|
Not available rating (2) |
|
|
|
|
|
|
|
|
|
|
| (1) | Corresponds to National Government TES securities in local currency. |
| (2) | Corresponds mainly to the recognition of McDermott’s shares in Refinería de Cartagena S.A.S. (see note 23.4) |
See credit risk policy in Note 30.7.
F-49
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
10. Taxes
10.1 Current and non-current tax assets and liabilities
|
|
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2024 |
|
2023 |
|
Current tax assets |
|
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|
|
|
Income tax (1) |
|
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|
|
|
VAT refund (2) |
|
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|
Other taxes (3) |
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Non-current tax assets |
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|
Deferred tax assets (4) |
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|
Income tax credits |
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Current tax liabilities |
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Income tax payable |
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|
National tax and surcharge on gasoline |
|
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|
Industry and commerce tax |
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Value added tax |
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Carbon tax |
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Other taxes |
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|
Non-current tax liabilities |
|
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|
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|
Deferred tax liabilities (5) |
|
|
|
|
|
Income tax |
|
|
|
|
|
|
|
|
|
|
|
(1) |
The variation corresponds to the balance in favor of the income tax generated in Ecopetrol for $
|
|
(2) |
The variation corresponds mainly to the balance in favor in value added tax (VAT) in Ecopetrol S.A. for $
|
|
(3) |
Includes the potential tax credit for the VAT paid on the acquisition of real productive fixed assets, in accordance with the section 258-1 of the Colombia Tax Code. Additionally, it includes advances and self-withholdings of territorial taxes. |
|
(4) |
The variation corresponds mainly to: i) the effect of the exchange rate on loans and borrowings in US dollars, the update of the actuarial calculation, variations in the items to calculate the present value of the technical costs of the abandonment provision, the acquisition of
|
|
(5) |
The variation mainly corresponds to the temporary differences related to IAS 12.41 and the deferred tax of ISA, represented by the changes related to the contractual asset CPC 47 and the deferral of income in accordance with Law 12,973/2014 in Companhia de Transmissao de Energia Eletrica Paulista (CTEEP); in AGUAPEI for the recognition of deferred tax due to the change in presumed profit regime for $
|
F-50
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
10.2 Income tax
In accordance with Law 2010/2019 and Laws 2155/2021 and 2277/2022, the tax provisions applicable in Colombia for taxable years 2022 and 2023, are the following:
The income tax rate applicable to national companies and foreign entities operating in Colombia will be
From the year 2021, the presumptive income rate was
The income tax for tax free trade zone users will be
For fiscal years 2023 and 2024, Ecopetrol Business Group has subsidiaries that are subject to
For Ecopetrol S.A. and Hocol, additional surcharge must be added to the general income tax rate of
|
percentile 30 |
|
0 |
% |
|
= to percentile 30 and to percentile 45 |
|
5 |
% |
|
= to percentile 45 and to percentile 60 |
|
10 |
% |
|
= to percentile 60 |
|
15 |
% |
The tax depreciation percentages are adjusted based on the table established in Law 1819 of 2016. On the other hand, oil investments depletion will be calculated based on the technical production units as it is recorded for accounting purposes.
Expenses for the acquisition of exploration rights, geology and geophysics, exploratory drilling, among others, are capitalizable until the technical feasibility and commercial viability of extracting the resource are determined.
Fluctuations in items expressed in foreign currency will only have tax effects at the time of disposal or payment in the case of assets, or liquidation or partial payment in the case of liabilities.
Tax losses generated as of January 1, 2017, may be offset against ordinary net income obtained in the following
Statute of limitations of tax returns
In Colombia, the income tax returns of the taxable years 2015, 2017, 2018, 2019, 2020, 2021, 2022, and 2023 and income tax for equality - CREE - of the taxable years 2016 can still be reviewed by the tax authorities. The management of Ecopetrol Business Group considers that the amounts recorded as liabilities for taxes payable are sufficient and are supported by the law to meet any claim that may be established with respect to such years.
In Colombia, as of January 1, 2017, the statute of limitations for the income tax return corresponds to three-year (3) counted from the due date to file the return or the filing date, when these have been lately filed. In the case of Ecopetrol S.A., because it is subject to compliance with transfer pricing rules, the final term is 6 years. However, Law 2010 of 2019 established that this term will be 5 years, for returns submitted after January 1, 2020.
F-51
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
For the years 2023 and 2024, in accordance with Law 2155 of 2021, the time in which the tax authorities can audit an income tax return is reduced, which goes from 5 years to between 6 to 12 months, depending on if the net income increased to 35% or 25% compared to that was declared in the immediately previous year.
Regarding those returns in which balances are presented in favor, the final term is 3 years, from the date of presentation of the request for refund or compensation.
Starting in 2020, tax returns that present tax losses can be reviewed by tax authorities within 5 years from the date of filing and/or correction.
Income tax expense
|
|
|
2024 |
|
2023 |
|
2022 |
|
Current income tax (1) |
|
|
|
|
|
|
|
Deferred income tax (2) |
|
|
|
(
|
|
|
|
Deferred income tax – rate change |
|
|
|
|
|
(
|
|
Adjustments to prior years’ current and deferred tax (3) |
|
(
|
|
|
|
|
|
Income tax expenses |
|
|
|
|
|
|
|
(1) |
The variation between 2024 and 2023 by ($
|
|
(2) |
The variation between 2024 and 2023 of $
|
|
(3) |
The balance for $ (
|
F-52
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
Reconciliation of the income tax expenses
The reconciliation between the income tax expense and the current tax applicable to the Ecopetrol Business Group is as follows:
|
|
|
2024 |
|
2023 |
|
2022 |
|
|
Net income before income tax |
|
|
|
|
|
|
|
|
Statutory rate (Colombia) |
|
|
% |
|
% |
|
% |
|
Income tax at statutory rate |
|
|
|
|
|
|
|
|
Effective tax rate reconciliation items: |
|
|
|
|
|
|
|
|
Adjustment - IAS 12.41 |
|
|
|
(
|
|
|
|
|
Non–deductible expenses |
|
|
|
|
|
|
|
|
Rate differential adjustment |
|
(
|
|
(
|
|
(
|
|
|
Non–taxable income |
|
(
|
|
(
|
|
(
|
|
|
Prior years’ taxes |
|
(
|
|
|
|
|
|
|
Foreign currency translation and exchange difference |
|
|
|
|
|
(
|
|
|
Tax discounts and tax credit |
|
(
|
|
(
|
|
(
|
|
|
Others |
|
|
|
|
|
(
|
|
|
Effect of recognition of shares of McDermott International, Ltd. |
|
(
|
|
— |
|
— |
|
|
Effect of tax reform |
|
|
|
|
|
(
|
|
|
Income tax calculated |
|
|
|
|
|
|
|
|
Effective tax rate |
|
|
% |
|
% |
|
% |
|
Current |
|
|
|
|
|
|
|
|
Deferred |
|
|
|
(
|
|
|
|
|
|
|
|
|
|
|
|
|
The effective tax rate as of December 31, 2024, is
Deferred income tax
|
|
|
2024 |
|
2023 |
|
Deferred tax assets (1) |
|
|
|
|
|
Deferred tax liabilities (2) |
|
(
|
|
(
|
|
Net deferred income tax |
|
(
|
|
(
|
| (1) |
The variation corresponds mainly to: i) the effect of the exchange rate on loans and borrowings in US dollars, the update of the actuarial calculation, variations in the items to calculate the present value of the technical costs of the abandonment provision, the acquisition of
|
F-53
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
(2) |
The variation mainly corresponds to the temporary differences related to IAS 12.41 and the deferred tax of ISA, represented by the changes related to the contractual asset CPC 47 and the deferral of income in accordance with Law 12,973/2014 in Companhia de Transmissao de Energia Eletrica Paulista (CTEEP); in AGUAPEI for the recognition of deferred tax due to the change in presumed profit regime for $
|
The financial projections of the Ecopetrol Business Group suggest that, in the future, sufficient profits will be generated to ensure the recoverability of the active deferred tax asset.
The detail of deferred tax assets and liabilities is as follows:
|
|
|
2024 |
|
2023 |
|
Deferred tax assets (liabilities) |
|
|
|
|
|
Loans and borrowings (1) |
|
|
|
|
|
Loss carry forwards (2) |
|
|
|
|
|
Provisions (3) |
|
|
|
|
|
Other assets (4) |
|
|
|
|
|
Employee benefits (5) |
|
|
|
|
|
Accounts payable |
|
|
|
(
|
|
Goodwill |
|
(
|
|
(
|
|
Intangibles |
|
(
|
|
(
|
|
Other |
|
(
|
|
(
|
|
Other liabilities |
|
(
|
|
(
|
|
Accounts receivable |
|
(
|
|
(
|
|
Property plant and equipment and Natural and environmental resources (6) |
|
(
|
|
(
|
|
|
|
(
|
|
(
|
|
(1) |
The variation corresponds mainly to the effect of exchange difference of loans and borrowings, considering the revaluation of the Colombian peso against the US dollar. |
|
(2) |
In 2024, a deferred tax asset for tax losses carryforwards was recognized for $
|
|
- |
Tax losses that do not expire: Ecopetrol USA for $
|
|
- |
Tax losses that expire in
|
|
- |
Tax losses that expire in
|
|
- |
Tax losses expiring in 2025 of Ruta de la Araucanía for $
|
|
(3) |
Corresponds to non-deductible accounting provisions, mainly by uploading (economic limit of the oil field, market rate, discount rate) the asset retirement obligation (ARO) provision. |
|
(4) |
The variation corresponds mainly to the effect of the uploading and increase of the financial asset due to UF readjustment in Maipó (Chile) in 2022. |
|
(5) |
Corresponds to update of the actuarial calculations for health, pensions and bonds, education, and other long-term benefits to employee. |
|
(6) |
For tax purposes, natural and environmental resources, and property, plant, and equipment have a useful life and a depreciation and amortization methodology different from those determined under international accounting standards, mainly in Ecopetrol and ISA Group. |
F-54
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
The Ecopetrol Business Group offsets tax assets and liabilities only if it has a legally enforceable right to offset current tax assets and liabilities, and to the extent that they relate to income taxes required by the same tax jurisdiction and by the same tax authority.
The movements of deferred income tax for the years as of December 31, 2024, 2023 and 2022 are as follows:
|
|
|
2024 |
|
2023 |
|
2022 |
|
Opening balance |
|
(
|
|
(
|
|
(
|
|
Deferred tax recognized in profit or loss |
|
(
|
|
|
|
(
|
|
Increase due to business combination |
|
|
|
— |
|
|
|
Deferred tax recognized in other comprehensive income (a) |
|
|
|
(
|
|
|
|
Other |
|
|
|
|
|
(
|
|
Foreign currency translation |
|
|
|
|
|
(
|
|
Closing balance |
|
(
|
|
(
|
|
(
|
(a) The following is the detail of the income tax recorded in other comprehensive income:
|
December 31. 2024 |
|
Pre–tax |
|
Deferred tax |
|
After tax |
|
Actuarial valuation gains (losses) (Note 22.1) |
|
(
|
|
|
|
(
|
|
Cash flow hedging for future crude oil exports (Note 30.3) |
|
|
|
(
|
|
|
|
Hedge of a net investment in a foreign operation (Note 30.4) |
|
|
|
(
|
|
|
|
Hedge with derivative instruments |
|
|
|
(
|
|
|
|
Valuation of financial instruments |
|
|
|
(
|
|
|
|
|
|
|
|
(
|
|
|
|
December 31. 2023 |
|
Pre–tax |
|
Deferred tax |
|
After tax |
|
Actuarial valuation gains (losses) (Note 22.1) |
|
|
|
(
|
|
|
|
Cash flow hedging for future crude oil exports (Note 30.3) |
|
(
|
|
|
|
(
|
|
Hedge of a net investment in a foreign operation (Note 30.4) |
|
(
|
|
|
|
(
|
|
Hedge with derivative instruments |
|
(
|
|
|
|
(
|
|
|
|
(
|
|
|
|
(
|
|
December 31. 2022 |
|
Pre-tax |
|
Deferred tax |
|
After tax |
|
Actuarial valuation gains (losses) (Note 22.1) |
|
|
|
(
|
|
|
|
Cash flow hedging for future crude oil exports (Note 30.3) |
|
|
|
(
|
|
|
|
Hedge of a net investment in a foreign operation (Note 30.4) |
|
|
|
(
|
|
|
|
Hedge with derivative instruments |
|
(
|
|
(
|
|
(
|
|
|
|
|
|
(
|
|
|
Deferred tax assets not recognized
Deferred tax assets related to tax loss carryforwards incurred by the subsidiaries of ISA Group: Ruta del Bosque (Chile) for $
If Ecopetrol Business Group had been able to recognize the unrecognized deferred tax asset, the profit for the year ended December 31, 2024, would have increased by $
F-55
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
With respect to the additional income surtax, deferred tax assets corresponding to the estimated surcharge for the years 2026 and following are not recognized because there is no certainty about the proportion of the deferred that will be recovered in each of these years.
Deferred tax liabilities (assets) not recognized in subsidiaries
As of December 31, 2024, in connection with paragraph 39 of IAS 12 deferred tax liabilities are not recognized on the difference between the accounting and tax bases associated with investments in subsidiaries, joint ventures of Ecopetrol S.A. (Base: $-
Dividends received in the year 2024 were untaxed. The Company expects this same treatment for the dividends it receives in 2024.
Additionally, in connection with paragraph 44 of IAS 12 deferred tax assets are not recognized on the difference between the accounting and tax bases associated with investments in subsidiaries, joint ventures of Ecopetrol S.A. (Base:
Tax: $
Minimum Tax Rate (Colombia Tax Law)
In accordance with numeral 2 of paragraph 6 of article 240 of the Tax Code, taxpayers who are tax residents in Colombia whose financial statements are subject to consolidation must calculate the adjusted tax rate in a consolidated manner.
For the taxable year 2024, according to the calculation made by Ecopetrol, the minimum tax rate of the companies with tax residence in Colombia of the Ecopetrol Group is greater than
|
|
|
2024 |
|
|
Adjusted tax |
|
|
|
|
Net income tax of Colombia Business Group companies |
|
|
|
|
(+) Tax discounts or tax credits |
|
|
|
|
(-) Income tax on passive income from controlled entities abroad |
|
(
|
|
|
Total Tax Adjusted |
|
|
|
|
|
|
|
|
|
Adjusted profit |
|
|
|
|
Profit before income tax expense of Colombia Business Group companies |
|
|
|
|
(+)Permanent differences enshrined in law and that increase net income |
|
|
|
|
(-) Income that does not constitute income or occasional profit, which affects accounting or financial profit |
|
(
|
|
|
(-)Share of profits of associates and joint ventures of the respective taxable year of Colombia Business Group companies |
|
(
|
|
|
(-) Net value of income from occasional gains that affect accounting or financial profit |
|
(
|
|
|
(-) Exempt income due to the application of treaties to avoid double taxation |
|
(
|
|
|
(-) Offsetting of tax losses or excesses of presumptive income taken in the taxable year and that did not affect the accounting profit of the period |
|
(
|
|
|
Total Adjusted Profit |
|
|
|
|
|
|
|
|
|
Adjusted tax rate |
|
|
% |
|
|
|
|
|
|
Income tax to add |
|
— |
|
|
|
|
|
|
F-56
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
Pillar II
The Ecopetrol Group has a presence in the jurisdictions of Argentina, Bahamas, Brazil, Bolivia, Cayman Island, Chile, Colombia, Spain, United States, Mexico, Panama, Peru, United Kingdom, Singapore, and Switzerland. The Ecopetrol Group reviewed its corporate structure in order to determine possible impacts of the introduction of the Pillar model rules, as well as to determine the progress of each jurisdiction in implementing this international standard.
The ongoing assessment is based on the most recent tax returns and country-by-country report for the year 2023, as well as the most up-to-date financial information for the year 2024.
From the analysis executed on the implementation of Pillar II, the Company observes that: i) Spain has implemented an IIR that will begin to apply as of January 1, 2025; ii) Brazil, Switzerland, Singapore, and Spain have implemented a QDMTT that will begin to apply as of January 1, 2025, and in Bermuda said QDMTT will begin in 2026; and iii) the United Kingdom will implement the UTPR as of January 1, 2025. It has already implemented the IIR and the QDMTT in fiscal year 2024.
For the above reasons, in the jurisdictions where the Ecopetrol Business Group is present, the tools associated with Pillar II have not been implemented, which would allow, in a certain jurisdiction, access to the tax from other jurisdictions whose Effective Tax Rate is less than 15%.
Currently, the Ecopetrol Business Group is unable to provide information on potential exposure to Pillar II income taxes, considering that in the jurisdictions in which Ecopetrol operates, although countries such as Spain and Switzerland have adopted Pillar II in their domestic legislation, there are still delays in the implementation of the payment rules as of December 31, 2024. The Business Group will continue monitoring the implementation of BEPS 2.0 in jurisdictions that already have progress. Additionally, the Company will work in 2025 on the assessment and calculation of the global minimum tax rate.
Notwithstanding, based on the mandatory temporary exception contemplated in the Amendment to IAS12, Ecopetrol Business Group does not recognize deferred tax assets or liabilities associated with the Pillar II income taxes, in its consolidated financial statement for taxable year 2024.
Uncertain tax positions - IFRIC 23
Ecopetrol Business Group’s strategy is to avoid making aggressive tax decisions that may cause questioning of its tax returns, by tax authorities.
Regarding uncertain tax positions where it has been determined that there may be a possible controversy with the tax authority that could result in an income tax increase, a success threshold has been established by IFRIC 23, which has been calculated based on current regulations and tax opinion provided by our tax advisors.
In accordance with the aforementioned interpretation, the Ecopetrol Business Group considers that uncertain tax positions included in its determination of income tax will not affect the results if it is probable that the position will be accepted by the tax authorities. Notwithstanding, the Ecopetrol Business Group will continue to monitor new tax regulations and ruling issued by the tax authority and other entities.
F-57
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
10.3. Other taxes
Dividend taxes
Starting on the profits generated from the year 2017, the tax on dividends applies to resident natural persons, national companies, and foreign entities.
Law 1943 of 2018 established that, as of January 1, 2019, dividends and participations paid or credited to the account from profit distributions that have been considered as income that does not constitute income or occasional profit between Colombian companies, are subject to a withholding for dividend tax at a rate of
The non-taxed dividends that the Ecopetrol Business Group will receive will not be subject to withholding at source by express provision of the regulation, which states that dividends distributed within business groups duly registered with the Chamber of Commerce, to decentralized entities or Colombian Holding Companies, they will not be subject to withholding at source for this concept.
Transfer prices
In Colombia, income taxpayers who enter into operations with economic associates or related parties from abroad and located in free zones, or with residents located in countries considered non-cooperative jurisdictions with low or no taxation, are required to determine for income tax purposes, their ordinary and extraordinary revenue, their costs and deductions, assets and liabilities, considering for these operations the prices and profit margins that would have been used in comparable operations with or between those not economically related.
Ecopetrol Business Group submitted in 2024 the transfer pricing information for 2023 corresponding to the informative return, the supporting documentation, the country-by-country report, and the master file, in accordance with current tax regulations.
For the taxable year 2024, the transactions with economic related parties abroad, as well as the business conditions under which such operations were made and the general structure, did not vary significantly with respect to the previous year. For this reason, it is possible to infer that said transactions were recognized in accordance with the arm’s length principle. It is estimated that no adjustments related to the transfer pricing analysis of the year 2024 will be required, which imply changes in the income provision of the same year.
Value Added Tax
The VAT already paid by the user of the free zone is excluded from the basis to settle the VAT on imports of goods from the free zone. Article 491 of the Tax Code expressly prohibits the possibility to consider the VAT paid on the acquisition of fixed assets as deductible tax. In addition,
F-58
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
Additionally, the list of goods and services excluded from VAT enshrined in articles 424, 426, and 476 of the Tax Code was modified, and article 437 of the Tax Code was added, regarding guidelines on compliance with formal duties regarding to VAT on the part of service providers from abroad and it was indicated that VAT withholding may be up to
Tax procedures
In terms of procedure, there are modifications: (i) withholding that, despite being ineffective, will be enforceable, (ii) electronic notification of administrative acts, (iii) payment of glosses in the statement of objections to avoid default interest, (iv) elimination of the extension of the finality to additional three years for offsetting of tax losses, and (v) the term of the finality will be 5 years, compared to the years in which there is an obligation to comply with the transfer pricing regime.
In addition, an audit benefit was included for taxable years 2020 and 2021. By virtue of this benefit, the private settlement of income taxpayers and complementary taxpayers who increase their net income tax by at least a percentage a minimum of 30%, related to the net income tax of the immediately preceding year, will become final within six months after the date of presentation if a notification to correct or special requirement has been notified, or provisional settlement and, considering that the declaration must be presented in a timely manner and the payment must be made within the established deadlines.
If the increase in the net income tax is at least 20% over the net income tax of the immediately preceding year, shall be considered for twelve (12) months, after the date the presentation if not notified of a deadline for correction or special requirement, or a special deadline or provisional settlement, provided that the return is filed timely, and the payment is made within the established deadlines.
The above benefit does not apply to: (i) taxpayers who enjoy tax benefits due to their location in a specific geographical area; (ii) when it is shown that declared withholdings are non-existent; (iii) when the net income tax is less than 71 UVT . The term set forth in this regulation does not extend to declarations of withholding or sales tax, which will be governed by the general regulations.
F-59
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
Law 2155 of September 14, 2021 - Colombia
In general terms, this reform increased the general income tax rate to
Works for Taxes Mechanism: The assumptions under which the “works for taxes” can be accessed are expanded, including those territories that, not being ZOMAC, are in some of these situations: (i) They have high rates of poverty, (ii) totally or partially lack infrastructure for the provision of residential public services, (iii) are in non-interconnected areas and (iv) are in Orange Development Areas (ADN acronyms in Spanish).
This mechanism will also be applicable to those projects declared of national importance that are strategic for the economic and/or social reactivation of the Nation, even if they are not located in the previous territories (subject to the approval of the Ministry of Finance and Public Credit in Colombia).
Tax reform Law 2277 of December 13, 2022
The most relevant aspects of this reform in the Business Group’s taxes.
Non-deductibility of royalties: The deductibility of oil royalties paid to the Colombian Government for the exploitation of non-renewable resources is restricted, regardless of the denomination of the payment.
On November 16, 2023, the Constitutional Court in Colombia issued ruling C-489 in which it determined that royalties are a deductible cost of income tax.
In December 2023, the Ministry of Mines and Energy and the Ministry of Finance and Public Credit requested the Constitutional Court to review the ruling issued, alleging a fiscal impact and its nullity. Given that the National Government has not filed the corresponding request, the Constitutional Court has not issued any consideration. If the Court decides to modulate the effects of the judgment issued in November 2023, the effects must be reflected in 2024.
Free zone rate:
The rate of taxable income and complementary taxes applicable to offshore free zones; industrial users of special permanent free zones for port services, industrial users of special permanent free zones, whose main corporate purpose is the refining of petroleum-derived fuels or refining of industrial biofuels; industrial users of services that provide the logistics services of numeral 1 of article 3 of Law 1004 of 2005 and operator users, will be
Minimum tax rate:
A minimum tax rate is established for income taxpayers, which will be calculated from the adjusted financial profit, which may not be less than
A minimum tax rate of
This minimum taxation does not apply in several cases, including foreign legal entities without residence in the country; Special Economic and Social Zones, during the period that their income tax rate is
F-60
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
Taxation of non-resident entities with significant economic presence in Colombia: Non-residents that sell goods and/or provide certain digital services (listed in the standard) to people located in Colombia, could have a significant economic presence in the country and would be subject to a withholding tax of 10%, or they could choose to file an income tax return and apply a 3% rate on gross income.
Significant economic presence would exist when the non-resident (also considering its related parties):
| ● | Obtains gross income greater than 31,300 UVT for transactions with people located in Colombia. |
| ● | Has a systematic and deliberate interaction with the Colombian market. The above is presumed to happen if an interaction or marketing deployment is maintained with 300,000 or more users located in Colombia, or if there is the possibility of viewing prices in Colombian pesos (COP) or allowing payment in this currency. |
Discount for investments made in research, technological development, or innovation:
Investments in projects qualified by the National Council of Tax Benefits in Science and Technology in Innovation will have the right to discount
Tax benefits and incentives limits:
For income taxpayers, other than natural persons and illiquid successions, the value of income that does not constitute income for tax purposes or occasional gain, special deductions, exempt income, and tax discounts may not exceed the
Industry and commerce tax deduction:
The industry and commerce tax paid will be
Dividend tax:
Dividends and shares paid to national companies will be subject to the rate of ten percent (
The income tax rate applicable to dividends and shares paid to permanent establishments in Colombia of foreign companies will be
Concurrent benefits: The prohibition of taking concurrent tax benefits is extended to exempt income, revenue that does not constitute income for tax purposes or occasional gain, and the reduction of the income tax rate.
11. Other assets
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2024 |
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2023 |
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Current |
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Partners in joint operations |
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Prepaid expenses |
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Advanced payments to contractors and suppliers |
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Trust funds |
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Related parties (Note 31) |
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Other assets |
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Non–current |
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Abandonment and pension funds |
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Trust funds |
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Employee benefits |
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Advanced payments and deposits |
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Judicial deposits and attachments |
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Other assets |
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F-61
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
12. Business combination
CPO-09 Partnership Agreement
On December 29, 2024, Ecopetrol signed a binding sale and purchase agreement (SPA) with Repsol Colombia Oil Gas Limited (“Repsol”) to acquire a
Block CPO-09 is in Colombia, in the department of Meta, covering the municipalities of Villavicencio, Acacías, Guamal, Castilla La Nueva, San Martín, Lejanías, El Dorado, El Castillo and Granada. Within the block is the Acacías production area, a key asset in the operation of the Orinoquía region. It also has an ongoing exploratory activity, with key prospects such as Lorito, Lorito Este, Tinamú and Tejón, among others, which confirm its high potential. In addition, its infrastructure has the capacity to expand to support new discoveries and optimize its future development.
For accounting purposes, this transaction is configured as a step acquisition. The fair value of the assets acquired and liabilities assumed, including the previously held interest, was determined using the income approach applying the discounted cash flow methodology. The fair values of property, plant and equipment, natural resources and the environment have been determined, in compliance with the clauses of the agreement and the guidelines defined in IFRS 3 – Business Combinations.
Identifiable assets acquired and liabilities assumed
The amounts recognized for acquired and existing assets and assumed liabilities at the acquisition date are summarized below:
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Fair value |
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Assets |
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Cash and cash equivalents |
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Inventories |
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Trade and other receivables |
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Property, plant, and equipment |
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Natural and environmental resources |
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Total Assets |
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Liabilities |
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Trade and other payables |
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Retirement obligation |
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Total Liabilities |
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Fair value of identifiable net assets |
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|
The fair value of property, plant, and equipment reflects the value of the proven reserves of the acquired interest, while the fair value of the natural and environmental resources includes the risk-adjusted value of the asset’s probable and possible reserves and the residual value of the exploratory assets.
The trade and other receivables correspond to the contractual amounts of the cash call agreed between both companies in favor of Ecopetrol, intended to offset outstanding obligations at the closing of the partnership agreement. Trade and other payables, cash and cash equivalents, and inventories reflect the acquired economic right over
The retirement obligation has been valued at fair value, reflecting the obligations to dismantle the acquired interest. Its valuation incorporates a discount, considering its long-term execution.
The deferred tax liability mainly comprises temporary differences arising between the tax bases of property, plant, and equipment , natural and environmental resources, and intangible assets measured at fair value.
F-62
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
The effect on operating results as of December 31, 2024, is as follows:
|
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As of December, |
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2024 |
|
Fair value of net assets acquired and existing |
|
|
|
Book value of net assets |
|
(
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|
Consideration for the acquisition of assets (1) |
|
(
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|
(=) Net income from business combination |
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|
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|
Recognized in: |
|
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|
Profit before tax on business combinations (Note 28) |
|
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|
(-) Deferred tax expense |
|
(
|
|
(=)Net profit from acquisition after deferred tax |
|
|
(1)
As of December 31, 2024, $
The gain of $
The positive financial impact of the transaction is the result of i) the exercise of the right of preference by Ecopetrol, within the framework of the Joint Operating Agreement (JOA), which allowed it to access the negotiation with more updated and precise information and ii) the improved performance of reserves in the Akacías field was reflected in the update of the valuation cash flows.
As part of the acquisition process of the
F-63
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
13. Investments in associates and joint ventures
13.1 Composition and movements
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2024 |
|
2023 |
|
Joint ventures |
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Interligação Elétrica do Madeira S.A. |
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Transmissora Aliança de Energia Elétrica S.A. |
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Equion Energía Limited |
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Interligação Elétrica Paraguaçu S.A. |
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Interligação Elétrica Ivaí S.A. |
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Interligação Elétrica Garanhuns S.A. |
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Interligação Elétrica Aimorés S.A. |
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Conexión Kimal Lo Aguirre S.A. |
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Ecodiesel Colombia S.A. |
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Consorcio Eléctrico Yapay S.A. |
|
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— |
|
PA Energía para la paz |
|
|
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— |
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Transnexa S.A. E.M.A. |
|
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Interconexión Eléctrica Colombia Panamá S.A. |
|
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Derivex S.A. |
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Parques de Rio |
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Interconexión Eléctrica Colombia Panamá S.A.S E.S.P. |
|
|
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Less impairment: |
|
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Equion Energía Limited |
|
(
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|
(
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|
Transnexa S.A. E.M.A. |
|
(
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(
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|
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Associates |
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Gases del Caribe S.A. E.S.P. |
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ATP Tower Holdings |
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Gas Natural del Oriente S.A. E.S.P. |
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Gases de la Guajira S.A. E.S.P. |
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Extrucol S.A. |
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E2 Energía Eficiente S.A. E.S.P. |
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Serviport S.A. |
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Sociedad Portuaria Olefinas y Derivados S.A. |
|
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Less impairment: Serviport S.A. |
|
(
|
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(
|
|
|
|
|
|
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|
|
|
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|
F-64
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
The following is the movement of investments in associates and joint ventures:
For the year ended December 31, 2024:
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Joint |
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Associates |
|
ventures |
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Total |
|
Opening balance |
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Capital contributions |
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Effects of equity method through: |
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Profit or loss |
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Other comprehensive income |
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(
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(
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Dividends declared (1) |
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(
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(
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(
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Impairment recovery (Note 18) |
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Closing balance |
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(1) |
During 2024, dividends of $
|
For the year ended December 31, 2023:
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Joint |
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Associates |
|
ventures |
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Total |
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Opening balance |
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Capital contributions |
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|
Effects of equity method through: |
|
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Profit or loss |
|
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Other comprehensive income |
|
(
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(
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(
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|
Dividends declared (1) |
|
(
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(
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(
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Impairment (Note 18) |
|
|
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(
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|
(
|
|
Closing balance |
|
|
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|
|
| (1) |
During 2023, Ecopetrol Business Group received dividends of
$
|
F-65
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
For the year ended December 31, 2022:
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Joint |
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Associates |
|
ventures |
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Total |
|
Opening balance |
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|
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Capital contributions |
|
— |
|
|
|
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|
Effects of equity method through: |
|
|
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|
|
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Profit or loss |
|
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|
|
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|
Other comprehensive income |
|
|
|
|
|
|
|
Dividends declared (1) |
|
(
|
|
(
|
|
(
|
|
Impairment (Note 18) |
|
— |
|
(
|
|
(
|
|
Closing balance |
|
|
|
|
|
|
| (1) |
During 2022, Ecopetrol Business Group received dividends of
$
|
13.2 Additional information about associates and joint ventures
The following is the detail of assets, liabilities, and results of the main investments in associates and joint ventures, as of December 31, 2024, and 2023:
|
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2024 |
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2023 |
||||||||
|
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Interligação |
|
Transmissora |
|
Equion |
|
Interligação |
|
Transmissora |
|
Equion |
|
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|
Elétrica do |
|
Aliança de |
|
Energía |
|
Elétrica do |
|
Aliança de |
|
Energía |
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Madeira |
|
Energia Elétrica |
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Limited |
|
Madeira |
|
Energia Elétrica |
|
Limited |
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Statement of financial position |
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Current assets |
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Non–current assets |
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Total assets |
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Current liabilities |
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Non–current liabilities |
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Total liabilities |
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Equity |
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Other complementary information |
|
|
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Cash and cash equivalents |
|
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|
|
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|
|
|
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|
F-66
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
|
|
2024 |
|
2023 |
||||||||
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|
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Interligação |
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Transmissora |
|
Equion |
|
Interligação |
|
Transmissora |
|
Equion |
|
|
|
Elétrica do |
|
Aliança de |
|
Energía |
|
Elétrica do |
|
Aliança de |
|
Energía |
|
|
|
Madeira |
|
Energia Elétrica |
|
Limited |
|
Madeira |
|
Energia Elétrica |
|
Limited |
|
Statement of profit or loss |
|
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|
|
|
|
|
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|
|
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|
Sales revenue |
|
|
|
|
|
|
|
|
|
|
|
|
|
Costs |
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
Other operating expenses, net |
|
|
|
(
|
|
(
|
|
— |
|
(
|
|
(
|
|
Financial (expenses) income |
|
(
|
|
|
|
|
|
(
|
|
|
|
|
|
Income tax |
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
Financial year results |
|
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|
|
|
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|
|
|
|
|
|
Other comprehensive results |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
Other complementary information |
|
|
|
|
|
|
|
|
|
|
|
|
|
Depreciation and amortization |
|
|
|
|
|
— |
|
|
|
|
|
|
This is a reconciliation of equity of the significant investments and the carrying amount of investments as of December 31:
|
|
|
2024 |
|
2023 |
|
||||||||
|
|
|
Interligação |
|
Transmissora |
|
Equion |
|
Interligação |
|
Transmissora |
|
Equion |
|
|
|
|
Elétrica do |
|
Aliança de |
|
Energía |
|
Elétrica do |
|
Aliança de |
|
Energía |
|
|
|
|
Madeira |
|
Energia Elétrica |
|
Limited |
|
Madeira |
|
Energia Elétrica |
|
Limited |
|
|
Equity of the joint venture |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
% of Ecopetrol’s ownership |
|
|
% |
|
% |
|
% |
|
% |
|
% |
|
% |
|
Ecopetrol’s ownership |
|
|
|
|
|
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|
|
|
|
|
|
|
|
Additional value of the investment |
|
— |
|
|
|
|
|
— |
|
|
|
|
|
|
Impairment |
|
— |
|
— |
|
(
|
|
— |
|
— |
|
(
|
|
|
Unrealized gain |
|
— |
|
— |
|
(
|
|
— |
|
— |
|
(
|
|
|
Carrying amount of the investment |
|
|
|
|
|
|
|
|
|
|
|
|
|
The information on assets, liabilities, and profit of the other associated companies and joint ventures is found in exhibit 1.
F-67
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
14. Property, plant, and equipment
|
|
|
Plant |
|
Pipelines, |
|
|
|
|
|
|
|
|
|
|
|
|
|
and |
|
networks, |
|
Work in |
|
|
|
|
|
|
|
|
|
|
|
equipment |
|
and lines |
|
progress |
|
Buildings |
|
Lands |
|
Other |
|
Total |
|
Cost |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of December 31, 2023 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Additions/capitalizations (1) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
CPO-09 asset acquisition |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Abandonment cost update (Note 23) |
|
(
|
|
|
|
|
|
|
|
|
|
|
|
(
|
|
Capitalized financial interests (2) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Exchange differences capitalized |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Disposals |
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
Fair value adjustment in business combination |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Field reversal |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Foreign currency translation |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Reclassifications/transfers (3) |
|
(
|
|
|
|
(
|
|
|
|
|
|
(
|
|
(
|
|
Balance as of December 31, 2024 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accumulated depreciation and impairment losses |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of December 31, 2023 |
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
Depreciation expense |
|
(
|
|
(
|
|
|
|
(
|
|
|
|
(
|
|
(
|
|
Recovery (loss) impairment (Note 18) |
|
|
|
|
|
(
|
|
|
|
|
|
|
|
|
|
Disposals |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Foreign currency translation |
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
Reclassifications/transfers |
|
(
|
|
|
|
|
|
(
|
|
(
|
|
|
|
|
|
Balance as of December 31, 2024 |
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of December 31, 2023 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of December 31, 2024 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) |
Mainly includes: i) Ecopetrol S.A. projects in progress associated with the Akacías, Caño Sur, Rubiales, Castilla, Chichimene, Cupiagua fields and the Barrancabermeja Refinery ii) Interconexión eléctricas S.A. E.S.P projects in progress: UPME 09-2016 Copey–Cuestecitas, 500 kV and Copey–Fundación, 220 kV, UPME 04-2019 La Loma - Sogamoso 500 kV Transmission Line, Connection of the Alpha and Beta wind farms to the Nueva Cuestecitas substation, Copey - Cuestecitas 500kV Second Circuit Project, Connection of the Windpeshi wind farm to the Cuestecitas 200kV substation and asset optimization plan. |
|
(2) |
Financial interest is capitalized based on the weighted average rate of borrowing costs. |
|
(3) |
Corresponds mainly to i) recognition of McDermott’s shares in Refinería de Cartagena S.A.S. (see Note 23.4) and ii) additions and transfers in transmission lines of Interconexión eléctricas S.A. E.S.P due to the entry into operation of the projects. |
F-68
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
|
|
Plant |
|
Pipelines, |
|
|
|
|
|
|
|
|
|
|
|
|
|
and |
|
networks, |
|
Work in |
|
|
|
|
|
|
|
|
|
|
|
equipment |
|
and lines |
|
progress |
|
Buildings |
|
Lands |
|
Other |
|
Total |
|
Cost |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of December 31, 2022 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Additions/capitalizations (1) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Abandonment cost update (Note 23) |
|
|
|
|
|
|
|
(
|
|
|
|
(
|
|
|
|
Capitalized financial interests (2) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Exchange differences capitalized |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Disposals |
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
Foreign currency translation |
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
Reclassifications/transfers |
|
(
|
|
|
|
(
|
|
|
|
|
|
|
|
(
|
|
Balance as of December 31, 2023 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accumulated depreciation and impairment losses |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of December 31, 2022 |
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
Depreciation expense |
|
(
|
|
(
|
|
|
|
(
|
|
|
|
(
|
|
(
|
|
Recovery (loss) impairment (Note 18) |
|
|
|
(
|
|
(
|
|
|
|
(
|
|
|
|
|
|
Disposals |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Foreign currency translation |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Reclassifications/transfers |
|
|
|
(
|
|
|
|
(
|
|
|
|
(
|
|
(
|
|
Balance as of December 31, 2023 |
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of December 31, 2022 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of December 31, 2023 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) |
Mainly includes: i) Ecopetrol S.A. ongoing projects associated with the Caño Sur, Castilla, Chichimene, Cusiana and Rubiales fields and Barrancabermeja Refinery, ii) Interconexión Eléctrica S.A. E.S.P projects in progress: UPME 09-2016 Copey–Cuestecitas, 500 kV, Copey–Fundación, 220 kV, UPME 04-2019 Transmission line La Loma - Sogamoso 500 kV, Connection of the Alpha and Beta wind farms to the Nueva Cuestecitas substation, Copey Second Circuit Project - Cuestecitas 500kV and asset optimization plan. |
|
(2) |
Financial interest is capitalized based on the weighted average rate of borrowing costs. |
F-69
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
15. Natural and environmental resources
|
|
|
|
|
Asset |
|
Exploration |
|
|
|
|
|
Oil |
|
retirement |
|
and |
|
|
|
|
|
investments |
|
cost |
|
evaluation |
|
Total |
|
Cost |
|
|
|
|
|
|
|
|
|
Balance as of December 31, 2023 |
|
|
|
|
|
|
|
|
|
Additions/capitalizations (1) |
|
|
|
|
|
|
|
|
|
CPO-09 asset acquisition |
|
|
|
— |
|
|
|
|
|
Abandonment cost update (Note 23) |
|
— |
|
(
|
|
(
|
|
(
|
|
Disposals |
|
(
|
|
— |
|
— |
|
(
|
|
Write off exploratory assets and dry wells (2) |
|
— |
|
— |
|
(
|
|
(
|
|
Capitalized financial interests (3) |
|
|
|
— |
|
|
|
|
|
Exchange differences capitalized |
|
|
|
— |
|
|
|
|
|
Fair value adjustment in business combination |
|
|
|
— |
|
|
|
|
|
Field reversal |
|
|
|
|
|
— |
|
|
|
Foreign currency translation |
|
|
|
|
|
|
|
|
|
Transfers/reclassifications |
|
|
|
|
|
(
|
|
(
|
|
Balance as of December 31, 2024 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accumulated depletion and impairment losses |
|
|
|
|
|
|
|
|
|
Balance as of December 31, 2023 |
|
(
|
|
(
|
|
(
|
|
(
|
|
Depletion expense |
|
(
|
|
(
|
|
— |
|
(
|
|
Loss of impairment (Note 18) |
|
(
|
|
— |
|
(
|
|
(
|
|
Disposals |
|
|
|
— |
|
— |
|
|
|
Foreign currency translation |
|
(
|
|
(
|
|
— |
|
(
|
|
Transfers/reclassifications |
|
(
|
|
(
|
|
|
|
|
|
Balance as of December 31, 2024 |
|
(
|
|
(
|
|
(
|
|
(
|
|
Net balance as of December 31, 2023 |
|
|
|
|
|
|
|
|
|
Net balance as of December 31, 2024 |
|
|
|
|
|
|
|
|
|
(1) |
Includes mainly: a) Ecopetrol Permian for investments made in the drilling of wells and construction of facilities executed in Midland/Delaware, b) Ecopetrol S.A. mainly Caño Sur, Rubiales, Floreña and Castilla fields and c) Hocol S.A. mainly for the execution of the Llanos, Guarrojo, Perdices, Cor 9, VIM8, SN-18, Upar, Malacate, Guajira, Ocelote, Rancho Hermoso, and SSJN1 projects. |
|
(2) |
Includes: a) Ecopetrol S.A. mainly the Orca1, Arantes1, Machin1, and Morito1 wells b) Hocol S.A mainly the Milonga, Yoda A, Arbolito Norte, Sabanales, Toritos, and Saltador wells and exploration and seismic expenses mainly in Llanos, VIM8, Perdices, Cor-9, SN-18, SSJN1, Upar, YD SN-1, SN-15, RC-7, c) Ecopetrol Brasil Pau Brasil well. |
|
(3) |
Financial interest is capitalized based on the weighted average rate of borrowing costs. |
F-70
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
|
|
|
|
|
|
Exploration |
|
|
|
|
|
Oil |
|
Asset retirement |
|
and |
|
|
|
|
|
investments |
|
cost |
|
evaluation |
|
Total |
|
Cost |
|
|
|
|
|
|
|
|
|
Balance as of December 31, 2022 |
|
|
|
|
|
|
|
|
|
Additions/capitalizations (1) |
|
|
|
|
|
|
|
|
|
Abandonment cost update (Note 23) |
|
|
|
|
|
(
|
|
|
|
Disposals |
|
(
|
|
|
|
|
|
(
|
|
Write off exploratory assets and dry wells (2) |
|
|
|
|
|
(
|
|
(
|
|
Capitalized financial interests (3) |
|
|
|
|
|
|
|
|
|
Exchange differences capitalized |
|
|
|
|
|
|
|
|
|
Foreign currency translation |
|
(
|
|
(
|
|
(
|
|
(
|
|
Transfers/reclassifications |
|
|
|
(
|
|
(
|
|
(
|
|
Balance as of December 31, 2023 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accumulated depletion and impairment losses |
|
|
|
|
|
|
|
|
|
Balance as of December 31, 2022 |
|
(
|
|
(
|
|
(
|
|
(
|
|
Depletion expense |
|
(
|
|
(
|
|
|
|
(
|
|
Loss of impairment (Note 18) |
|
(
|
|
|
|
(
|
|
(
|
|
Disposals |
|
|
|
|
|
|
|
|
|
Foreign currency translation |
|
|
|
|
|
|
|
|
|
Transfers/reclassifications |
|
|
|
|
|
|
|
|
|
Balance as of December 31, 2023 |
|
(
|
|
(
|
|
(
|
|
(
|
|
Net balance as of December 31, 2022 |
|
|
|
|
|
|
|
|
|
Net balance as of December 31, 2023 |
|
|
|
|
|
|
|
|
|
(1) |
Mainly includes a) Ecopetrol Permian for investments made in the drilling of wells and construction of facilities in RODEO, b) Ecopetrol S.A. mainly Caño Sur, Castilla, Chichimene, Floreña, and Rubiales fields, c) Hocol S.A. mainly to the execution of projects in Ocelote, Llanos 87 (Koala, Picabuey, Zorzal), Llanos 123 (Saltador and Toritos), SSNN, VIM 8, SN-18, and d) Ecopetrol America mainly on Gunflint, Dalmatian, and K2. |
|
(2) |
Mainly includes: a) Ecopetrol S.A. mainly Cupiagua XD45, Cusiana Subthrust, Cusiana Profundo, Turupe, La Luna, Kale and Kinacú, b) Hocol S.A. mainly in Sabanales wells, the failure of wells LLa-87.2 A3, (Koala), LLan-87-3-a3 (Picabuey), LLan- 124 (Cucarachero), Merecumbé, Bullerengue, Yd-SN1 pozo Yoda B, and exploratory expenses in LLan-104- SSJN1, VIM8. |
|
(3) |
Financial interest is capitalized based on the weighted average rate of borrowing costs. |
F-71
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
Accounting for suspended exploratory wells
The following table shows the classification by age, from the completion date, of the exploratory wells that are suspended as of December 31, 2024, 2023 and 2022:
|
|
|
2024 |
|
2023 |
|
2022 |
|
Between 1 and 3 years (a) |
|
|
|
— |
|
|
|
More than 5 years (b) |
|
|
|
— |
|
|
|
Total suspended exploratory Wells |
|
|
|
— |
|
|
|
Number of projects exceeding 1 year |
|
|
|
|
|
|
|
Projects under 1 year of suspended (c) |
|
|
|
|
|
|
|
a) |
For 2024, the suspended exploratory wells mainly correspond to Ecopetrol: Gibraltar, Hocol: Pollera Norte 1, which were under evaluation. For 2022, the balance mainly corresponds to Hocol: Bullerengue South West-1 and Merecumbe 1, which were under evaluation. |
|
b) |
For 2022, it mainly corresponds to i) Ecopetrol S.A.: Orca 1, Purple Angel, and Gordon. |
|
c) |
For 2024, it mainly corresponds to Ecopetrol: Atalayas, Hocol: Toritos Sur 2. For 2023, it corresponds mainly to 1) Ecopetrol: Kale and Gibraltar, 2) Hocol: SSJN1 BO5, Pollera Norte A3 and YDSN-1 Yoda A. For 2022, the balance corresponds to Ecopetrol: Magallanes. For 2022, the balance corresponds to Hocol: Merecumbe 1 -SSJN1. |
16. Right-of-use assets
The following is the movement of right-of-use assets for the years ended December 31, 2024 and 2023:
|
|
|
|
|
Lands and |
|
Plant and |
|
|
|
Right-of-use |
|
Lease |
|
|
|
Pipelines |
|
buildings |
|
equipment |
|
Vehicles |
|
assets |
|
liabilities |
|
Balance as of December 31, 2023 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Additions |
|
|
|
|
|
|
|
|
|
|
|
|
|
Amortization of the period |
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
— |
|
Remeasurements (1) |
|
|
|
|
|
|
|
(
|
|
|
|
|
|
Impairment loss (Note 18) |
|
— |
|
(
|
|
(
|
|
(
|
|
(
|
|
— |
|
Disposals |
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
Effect of loss of control in subsidiaries |
|
— |
|
— |
|
(
|
|
— |
|
(
|
|
— |
|
Finance cost |
|
— |
|
— |
|
— |
|
— |
|
— |
|
|
|
Repayment of borrowings (capital) |
|
— |
|
— |
|
— |
|
— |
|
— |
|
(
|
|
Payment of interests |
|
— |
|
— |
|
— |
|
— |
|
— |
|
(
|
|
Transfers |
|
— |
|
(
|
|
|
|
(
|
|
(
|
|
|
|
Exchange difference |
|
|
|
(
|
|
|
|
|
|
|
|
|
|
Balance as of December 31, 2024 |
|
|
|
|
|
|
|
|
|
|
|
|
(1) Corresponds mainly to updating rates and conditions in lease contracts.
F-72
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
|
|
|
|
Lands and |
|
Plant and |
|
|
|
Right-of-use |
|
Lease |
|
|
|
Pipelines |
|
buildings |
|
equipment |
|
Vehicles |
|
assets |
|
liabilities |
|
Balance as of December 31, 2022 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Additions |
|
(
|
|
|
|
|
|
|
|
|
|
|
|
Amortization of the period |
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
|
|
Remeasurements (1) |
|
(
|
|
|
|
|
|
|
|
|
|
|
|
Impairment loss (Note 18) |
|
|
|
(
|
|
(
|
|
(
|
|
(
|
|
|
|
Disposals |
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
Finance cost |
|
— |
|
— |
|
— |
|
— |
|
— |
|
|
|
Repayment of borrowings (capital) |
|
— |
|
— |
|
— |
|
— |
|
— |
|
(
|
|
Payment of interests |
|
— |
|
— |
|
— |
|
— |
|
— |
|
(
|
|
Transfers |
|
|
|
|
|
|
|
(
|
|
(
|
|
(
|
|
Exchange difference |
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
Balance as of December 31, 2023 |
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) |
Corresponds mainly to updating rates and conditions in lease contracts. |
17. Intangible assets
The following is the movement of intangibles and their amortization and impairment for the years ended December 31, 2024, and 2023:
|
|
|
Licensees |
|
|
|
|
|
|
|
|
|
|
|
and |
|
Other |
|
Concessions |
|
Easements |
|
|
|
|
|
software |
|
intangibles |
|
and rights |
|
(1) |
|
Total |
|
Cost |
|
|
|
|
|
|
|
|
|
|
|
Balance as of December 31, 2023 |
|
|
|
|
|
|
|
|
|
|
|
Acquisitions |
|
|
|
|
|
|
|
|
|
|
|
Disposals |
|
(
|
|
|
|
(
|
|
(
|
|
(
|
|
Foreign currency translation |
|
|
|
(
|
|
|
|
|
|
|
|
Transfers/reclassifications |
|
|
|
|
|
|
|
|
|
|
|
Balance as of December 31, 2024 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accumulated amortization and impairment losses |
|
|
|
|
|
|
|
|
|
|
|
Balance as of December 31, 2023 |
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
Amortization |
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
Impairment (loss) recovery |
|
(
|
|
(
|
|
(
|
|
|
|
(
|
|
Disposals |
|
|
|
(
|
|
|
|
|
|
|
|
Foreign currency translation |
|
(
|
|
|
|
(
|
|
(
|
|
(
|
|
Transfers/reclassifications |
|
(
|
|
|
|
|
|
(
|
|
(
|
|
Balance as of December 31, 2024 |
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net balance as of December 31, 2023 |
|
|
|
|
|
|
|
|
|
|
|
Net balance as of December 31, 2024 |
|
|
|
|
|
|
|
|
|
|
| (1) | Easements are acquired rights for the passage of its operating assets, mainly electric power transmission lines. These assets are acquired in perpetuity, so they do not have a specific term or contractual limit established and the right is maintained over time. |
F-73
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
|
|
Licensees |
|
|
|
|
|
|
|
|
|
|
|
and |
|
Other |
|
Concessions |
|
Easements |
|
|
|
|
|
software |
|
intangibles |
|
and rights |
|
(1) |
|
Total |
|
Cost |
|
|
|
|
|
|
|
|
|
|
|
Balance as of December 31, 2022 |
|
|
|
|
|
|
|
|
|
|
|
Acquisitions |
|
|
|
|
|
|
|
|
|
|
|
Disposals |
|
(
|
|
(
|
|
|
|
(
|
|
(
|
|
Foreign currency translation |
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
Transfers/reclassifications |
|
|
|
(
|
|
(
|
|
|
|
(
|
|
Balance as of December 31, 2023 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accumulated amortization and impairment losses |
|
|
|
|
|
|
|
|
|
|
|
Balance as of December 31, 2022 |
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
Amortization |
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
Losses for impairment |
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
Disposals |
|
|
|
|
|
|
|
|
|
|
|
Foreign currency translation |
|
|
|
|
|
|
|
|
|
|
|
Transfers/reclassifications |
|
|
|
|
|
|
|
(
|
|
(
|
|
Balance as of December 31, 2023 |
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net balance as of December 31, 2022 |
|
|
|
|
|
|
|
|
|
|
|
Net balance as of December 31, 2023 |
|
|
|
|
|
|
|
|
|
|
| (1) | Easements are acquired rights for the passage of its operating assets, mainly electric power transmission lines. These assets are acquired in perpetuity, so they do not have a specific term or contractual limit established and the right is maintained over time. |
18. Impairment of non-current assets
As mentioned in Note 4.13, each year the Ecopetrol Business Group assesses whether there is an indication that an asset or cash–generating unit may be impaired or if impairment losses recognized in previous periods should be reversed.
The impairment of non-current assets includes property, plant, and equipment, natural resources, investments in companies, goodwill, and other non–current assets. Ecopetrol Business Group is exposed to future risks derived mainly from variations in (a) the estimate of future oil prices, (b) the refining margins and profitability, (c) the cost profile, (d) the investments and maintenance expenses, (e) the amounts of recoverable reserves, and (f) the market and country risk assessments reflected in the discount rate, (g) changes in national and foreign regulations, among others.
Any changes in the above estimates used to calculate the recoverable amount of a non–current assets can have a material impact on the recognition impairment losses or reversals in profit or loss statement. Highly sensitive significant estimates affecting each business segments, among others include (a) in the exploration and production segment, variations of hydrocarbon prices, (b) in the refining segment, changes in finished products and crude oil prices, the discount rate, refining margins, (c) in the transport and logistics segment, transported volumes and exchange rate, and (d) in electric power transmission and toll roads concessions, internal and external factors that affect the recoverable value of the assets versus the book value of the assets, such as currency devaluation, network capacity, modest economic growth, among others.
F-74
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
Based on the impairment tests conducted by the Ecopetrol Business Group, the following are the impairments or reversals for the years ended on December 31, 2024, 2023 and 2022:
|
Impairment (loss) reversal by segment |
|
2024 |
|
2023 |
|
2022 |
|
Exploration and Production |
|
(
|
|
(
|
|
(
|
|
Refining and Petrochemicals |
|
|
|
|
|
|
|
Transport and Logistics |
|
|
|
(
|
|
(
|
|
Electric power transmission and toll roads concessions |
|
(
|
|
(
|
|
(
|
|
|
|
|
|
(
|
|
(
|
|
|
|
|
|
|
|
|
|
Recognized in: |
|
|
|
|
|
|
|
Property, plant, and equipment (Note 14) |
|
|
|
|
|
|
|
Natural resources (Note 15) |
|
(
|
|
(
|
|
(
|
|
Investment in joint ventures and associates (Note 13) |
|
|
|
(
|
|
(
|
|
Right of use assets (Note 16) |
|
(
|
|
(
|
|
(
|
|
Other non-current assets |
|
(
|
|
(
|
|
(
|
|
|
|
|
|
(
|
|
(
|
18.1 Exploration and production
The impairment (loss) reversal of assets of the Exploration and Production segment for the years ended December 31 of 2024, 2023 and 2022 is the following:
|
|
|
2024 |
|
2023 |
|
2022 |
|
Oilfields |
|
(
|
|
(
|
|
(
|
|
Investment in joint ventures |
|
|
|
(
|
|
(
|
|
|
|
(
|
|
(
|
|
(
|
|
18.1.1 |
Oilfields |
In 2024, a net impairment expense of $
In 2023, an impairment loss was recognized, considering CAPEX variables, OPEX effects and prices mainly in the cash-generating units (CGU) Casabe, Llanito, Suria, and Tibú; and a recovery mainly in the Piedemonte unit, which was the subject of unification of Floreña, Cupiagua and Cusiana assets during 2023, considering that these fields share facilities with each other, possess synergies, and jointly manage the surface fluids across the three large infrastructures. Likewise, impairment losses were recognized in Hocol S.A. in the Cicuco, Toldado, La Hocha, Espinal, and Chenche CGUs and a recovery in Upía CGU. In the CGUs abroad, an impairment loss was recognized in K2 CGU of Ecopetrol America.
In 2022, an impairment loss was recognized, mainly the Cusiana, Llanito, Sur, Cicuco-Boquete, and Upia fields (mainly associated with a decrease in reserve volumes) and a recovery in Tibú, Oripaya, and Arrayán (mainly associated with the better projection of market prices and higher volumes of reserves).
F-75
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
The following is the breakdown of oilfields impairment losses or reversals for the years ended December 31, 2024, 2023 and 2022:
2024
|
|
|
Carrying |
|
Recoverable |
|
Impairment |
|
Cash generating units |
|
amount |
|
amount |
|
reversal (loss) |
|
Oil fields in Colombia |
|
|
|
|
|
|
|
Reversal |
|
|
|
|
|
|
|
Loss |
|
|
|
|
|
(
|
|
|
|
|
|
|
|
(
|
2023
|
|
|
Carrying |
|
Recoverable |
|
Impairment |
|
Cash generating units |
|
amount |
|
amount |
|
reversal (loss) |
|
Oil fields in Colombia |
|
|
|
|
|
|
|
Reversal |
|
|
|
|
|
|
|
Loss |
|
|
|
|
|
(
|
|
|
|
|
|
|
|
(
|
2022
|
|
|
Carrying |
|
Recoverable |
|
Impairment |
|
Cash generating units |
|
amount |
|
amount |
|
reversal (loss) |
|
Oil fields in Colombia |
|
|
|
|
|
|
|
Reversal |
|
|
|
|
|
|
|
Loss |
|
|
|
|
|
(
|
|
|
|
|
|
|
|
(
|
The assumptions used to determine the recoverable amount include the following:
| ● | The fair value less costs of disposal of the Exploration and Production segment assets was determined based on cash flows after tax derived from the business plans approved by Ecopetrol Business Group’s Management, which are developed based on long–term macroeconomic policies and fundamental assumptions of supply and demand. The fair value hierarchy is 3. |
| ● | Balance of oil and gas reserves, in addition to proven reserves, probable and possible reserves were also considered (See Note 34), adjusted by different risk factors. |
| ● |
The discount rate in real terms was determined as the weighted average cost of capital (WACC) and corresponds to a differential rate depending on the projected tax surcharge for each year, as follows:
|
| ● |
|
F-76
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
| ● | The projection of international crude oil prices is carried out by an independent agency specialized in Oil Gas, which has been considering the current scenarios of the OPEC (Organization of Petroleum Exporting Countries) oil quota agreements and the balance between supply and demand in the short and long term for the industry. |
18.1.2 Investments in joint ventures
Investments in joint ventures in the Exploration and Production segment are recorded using the equity method of accounting. Ecopetrol Business group evaluates if there is any objective evidence that indicate that the fair value of such investments has impaired in the period, especially those for which goodwill has been recorded.
As a result, Ecopetrol Business Group recognized a recovery (loss) of impairment on the carrying value as of December 31, as follows:
|
|
|
2024 |
|
2023 |
|
2022 |
|
Equion Energía Limited |
|
|
|
(
|
|
(
|
|
|
|
|
|
(
|
|
(
|
In 2024, an impairment recovery was recognized on the investment in Equion, which adjusts the book value of the assets evaluated to their current fair value.
In 2023, an impairment loss was recognized on the investment in Equion, mainly due to the update of its non-current assets in the model.
In 2022, an impairment loss was recognized on the investment in Equion, mainly due to the increase in the discount rate, as well as the sale of the Alto Magdalena Pipeline (OAM) at a lower value than expected.
18.2 Refining and Petrochemical
Ecopetrol Business Group recognized a reversal (loss) of impairment on the carrying value as of December 31, as follows:
|
|
|
2024 |
|
2023 |
|
2022 |
|
Refinería de Cartagena S.A.S. |
|
|
|
|
|
|
|
Invercolsa S.A. |
|
— |
|
(
|
|
(
|
|
|
|
|
|
|
|
|
The following is the Cash Generating Units impairment or reversals in the refining and petrochemical segment for the years ended December 31, 2024, 2023 and 2022:
2024
|
|
|
Carrying |
|
Recoverable |
|
Impairment |
|
Cash–generating units |
|
amount |
|
amount |
|
reversal (loss) |
|
Refinería de Cartagena S.A.S. |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2023
|
|
|
Carrying |
|
Recoverable |
|
Impairment |
|
Cash–generating units |
|
amount |
|
amount |
|
reversal (loss) |
|
Refinería de Cartagena S.A.S. |
|
|
|
|
|
|
|
Invercolsa S.A. |
|
|
|
|
|
(
|
|
|
|
|
|
|
|
|
F-77
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
2022
|
|
|
Carrying |
|
Recoverable |
|
Impairment |
|
Cash–generating units |
|
amount |
|
amount |
|
reversal (loss) |
|
Refinería de Cartagena S.A.S. |
|
|
|
|
|
|
|
Invercolsa S.A. |
|
|
|
|
|
(
|
|
|
|
|
|
|
|
|
The grouping of assets to determine the CGUs is consistent with prior periods.
|
18.2.1 |
Refinería de Cartagena S.A.S. |
The recoverable amount of the Refinería de Cartagena was calculated based on its fair value less costs of disposal, which is higher than its value in continued use. The fair value less costs of disposal of the Refinería de Cartagena was determined based on cash flows after taxes that are derived from business plans approved by the Ecopetrol Business Group’s Management, which are developed based on market prices provided by a third-party expert, which considers long–term macroeconomic variables and fundamental supply and demand assumptions for crude oil and refined products. The fair value hierarchy is 3.
The operating assets considered in this valuation are those that make up the refinery and that as a whole are considered a Cash Generating Unit (CGU), and have not changed with respect to 2023.
The estimates derived from the valuation of the impairment of the assets of Refinería de Cartagena S.A.S. were carried out based on: i) exogenous and market variables that are outside the control of the Administration, such as the prices that define the income (refined products) and costs of the refinery (raw materials) and the macroeconomic variables that impact the discount rate of their cash flows for the purpose of asset valuation, and ii) the operational and corporate variables subject to the Company’s management, such as the efficiency of the plants, its operational availability and the corresponding management of costs and expenses. The assumptions used in the model to determine recoverable values include:
| ● | Volumes: They correspond to the volumetric balances determined based on prices, availability of crude oil, local market demand, refinery utilization factor and particular characteristics of the system. |
| ● | Prices: The set of prices used to estimate the flow of sales income and the cost of raw materials are provided by the specialist IHS Market, a third party specialized in price projections. Long-term price forecasts are based on many assumptions and are therefore subject to change over time. Factors that affect forecasts, such as gross domestic product, changes in regulation, technology, and consumer preferences, are examples of assumptions that can have a major impact on a long-term forecast. |
| ● | OPEX: For the short and medium term projection, the OPEX per barrel included in the budget 2025, 2026 and 2027 is considered. For the purposes of the long-term projection, from 2028 to the evaluation limit, the OPEX per barrel, taking into consideration the current contracts and costs of the refinery and the latest study carried out by the specialist Solomon (a third party expert in global refinery benchmarking), adjusting the energy costs with the information included in the contracts of gas supply. |
| ● | CAPEX: Includes maintenance CAPEX (capitalizable), defined as the investments in major maintenance required to maintain the Refinery at its current operating level and optimal production level and operational continuity investments, also in according to the study of comparable entities by Solomon. The maintenance CAPEX is estimated in the 2025-2027 budget year. Starting in 2028, this indicator is estimated based on the same methodology used for OPEX. |
| ● | Capex SosTECnibilidad: Reficar’s investment plan, aligned with the Ecopetrol Business Group strategy, includes investments focused on the implementation of new technologies. These technologies aim to adjust the current operation of the refinery in line with the country’s fuel demands and to enter new markets such as petrochemicals. |
It is relevant to mention that the refining business is highly sensitive to the volatility of margins and the macroeconomic variables implicit in the determination of the discount rate, therefore, any change in these assumptions generates significant variations in the amount of impairment or recovery calculated.
F-78
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
In 2024, there is a recovery of impairment of $
During 2023 there is a recovery of $
In 2022, there is a reversal of impairment of $
18.2.2 Refinería de Barrancabermeja
As of December 31, 2024, 2023, and 2022, qualitative assessment of the assets associated with the refining segment were executed, including the Barrancabermeja Refinery Modernization Project. As a result, there are
18.3 Transport and Logistics
The recoverable amount of these assets was determined based on its fair value with costs of disposal, which corresponds to discounted cash flows based on the hydrocarbon production curves and refined products transport curves. The fair value hierarchy is 3.
The assumptions used in the model to determine the recoverable value included: i) the tariffs regulated by the Ministry of Mines and Energy and the Energy and Gas Regulation Commission - CREG and National Infrastructure Agency (ANI), ii) the actual discount rate used in the valuation was
In 2024, there was an impairment reversal of $
In 2023, for the volumetric projection exercise until 2040, there is a decrease in the North, South and Yaguará-Tenay CGUs compared to 2022. This means that by 2024, an impairment loss of $
For 2022, the volumetric projection up to 2040 shows a decrease in crude oil exploratory prospects in the southern and northern fields of Colombia because of contractual uncertainties and socio-environmental viability, which represented an impairment loss for the CGUs by 2022 of Cenit Transporte y Logística S.A.S. in the South, North, and Yaguará-Tenay for $
F-79
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
18.4 Energy transmission and roads
According to the impairment test, as of December 31, 2024, 2023 and 2022, ISA and its companies considered that there are no operational or economic issues indicating that the net book value of its non-current non-financial assets cannot be recovered, except for the facts evidenced in the period, which were recognized and assessed in accordance with the applicable accounting standard.
|
Cash–generating units |
|
2024 |
|
2023 |
|
2022 |
|
Non-current asset held for sale |
|
(
|
|
(
|
|
— |
|
Property, plant and, equipment |
|
(
|
|
(
|
|
(
|
|
Intangibles |
|
|
|
(
|
|
(
|
|
|
|
(
|
|
(
|
|
(
|
The recoverable value was determined using the discounted free cash flow methodology, based on the projection of revenues, OPEX and CAPEX, and operating taxes.
In 2024, ISA Bolivia recognized an impairment in the concession assets due to the update of the business plan, which reflects the operating margins and the increase in country risk of $
As of December 31, 2023, the impairment loss was allocated to non-current assets held for sale and subsequently to property, plant, and equipment and intangible assets based on their book values. An impairment of non-current assets in the electric power transmission and toll roads concessions segment of $
As of December 31, 2022, an impairment loss of $
19. Goodwill
|
|
|
2024 |
|
2023 |
|
Interconexión Eléctrica S.A. E.S.P. (1) |
|
|
|
|
|
Oleoducto Central S.A.S. |
|
|
|
|
|
Hocol Petroleum Ltd. |
|
|
|
|
|
Invercolsa S.A. |
|
|
|
|
|
Andean Chemical Ltd |
|
|
|
|
|
Esenttia S.A. |
|
|
|
|
|
|
|
|
|
|
|
Less impairment Hocol Petroleum Ltd. |
|
(
|
|
(
|
|
|
|
|
|
|
(1) The variations correspond to the effect of currency translation applied on the goodwill in origin currency.
F-80
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
20. Loans and borrowings
|
20.1 |
Composition of loans and borrowings |
|
|
|
Weighted average effective |
|
|
|
|
||
|
|
|
interest rate as of December 31 |
|
2024 |
|
2023 |
||
|
|
|
2024 |
|
2023 |
|
|
|
|
|
Local currency (1) |
|
|
|
|
|
|
|
|
|
Bonds |
|
|
% |
|
% |
|
|
|
|
Commercial and syndicated loan |
|
|
% |
|
% |
|
|
|
|
Lease liabilities |
|
|
% |
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Foreign currency (1) |
|
|
|
|
|
|
|
|
|
Bonds |
|
|
% |
|
% |
|
|
|
|
Commercial and syndicated loans |
|
|
% |
|
% |
|
|
|
|
Loans from related parties (Note 31) |
|
|
% |
|
% |
|
|
|
|
Lease liabilities |
|
|
% |
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current |
|
|
|
|
|
|
|
|
|
Non–current |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) |
During 2024, Ecopetrol S.A. implemented a set of strategic financing operations to optimize its debt structure, reduce costs, and strengthen the Company’s liquidity. The main transactions include: |
|
a) |
Contracting of a local loan with banks of Grupo Aval for COP $
|
|
b) |
Renegotiation of the local loan contracted with Bancolombia for COP $
|
|
c) |
Issuance of External Public Debt Bonds in the international capital market on January 9, 2024, for USD$
|
|
d) |
Issuance of External Public Debt Bonds in the international capital market on October 21, 2024, for USD$
|
|
e) |
Refinancing of the Committed Line by contracting an external credit for USD$
|
|
f) |
Contracting of an external loan with the Sumitomo Mitsui Banking Corporation for USD$
|
The increase in foreign currency debt is mainly due to the rise in the exchange rate, from $
During 2024, loans and borrowings for $
As a result of the Business Group’s strategy, related to the comprehensive management of maturities, during 2024 capital payments were made for $
F-81
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
20.2 Fair value of loans
The fair value of loans and borrowings is $
20.3 Maturity of loans and borrowings
The following are the maturities of loans and borrowing as of December 31, 2024:
|
|
|
Up to 1 |
|
|
|
|
|
|
|
|
|
|
|
year |
|
1 – 5 years |
|
5-10 years |
|
10 years |
|
Total |
|
Local currency |
|
|
|
|
|
|
|
|
|
|
|
Bonds |
|
|
|
|
|
|
|
|
|
|
|
Commercial and syndicated loan |
|
|
|
|
|
|
|
|
|
|
|
Lease liabilities |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Foreign currency |
|
|
|
|
|
|
|
|
|
|
|
Bonds |
|
|
|
|
|
|
|
|
|
|
|
Commercial and syndicated loans |
|
|
|
|
|
|
|
|
|
|
|
Lease liabilities |
|
|
|
|
|
|
|
|
|
|
|
Loans from related parties |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The following are the maturities of loans and borrowing as of December 31, 2023:
|
|
|
Up to 1 |
|
|
|
|
|
|
|
|
|
|
|
year |
|
1 – 5 years |
|
5–10 years |
|
10 years |
|
Total |
|
Local currency |
|
|
|
|
|
|
|
|
|
|
|
Bonds |
|
|
|
|
|
|
|
|
|
|
|
Commercial and syndicated loan |
|
|
|
|
|
|
|
|
|
|
|
Lease liabilities |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Foreign currency |
|
|
|
|
|
|
|
|
|
|
|
Bonds |
|
|
|
|
|
|
|
|
|
|
|
Commercial and syndicated loans |
|
|
|
|
|
|
|
|
|
|
|
Loans from related parties |
|
|
|
— |
|
— |
|
— |
|
|
|
Lease liabilities |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
F-82
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
20.4 Breakdown by type of interest rate and currency
The following is the breakdown of loans and borrowing by type of interest rate as of December 31, 2024, and 2023:
|
|
|
2024 |
|
2023 |
|
Local currency |
|
|
|
|
|
Fixed rate |
|
|
|
|
|
Floating rate |
|
|
|
|
|
|
|
|
|
|
|
Foreign currency |
|
|
|
|
|
Fixed rate |
|
|
|
|
|
Floating rate |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
20.5 Loans designated as hedging instrument
As of December 31, 2024, Ecopetrol Business Group designated USD$
20.6 Guarantees and covenants
As of December 31, 2024, the estimated value of the current guarantees granted by ISA and its companies, within the framework of the definition in paragraph 14 of IFRS 7, used to support growth in its different business units and to ensure commercial, operational, and strategic viability amounts to $
ISA and its companies have commitments (covenants) related to the delivery of periodic financial information and the fulfillment of the obligations originated in the credit contracts with the financial entities, the Ministry of Public Works of Chile, the bondholders, the rating agencies risks, auditors, and municipalities, among others.
Ecopetrol USA and its companies have commitments (covenants) related to the delivery of periodic financial information and compliance with the obligations arising from a volumetric prepayment agreement with a third party.
During the reporting period, Ecopetrol Business Group has complied with its payment obligations, guarantees and commitments acquired with its bondholders and local and/or international financing entities.
F-83
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
21 . Trade and other payables
|
|
|
2024 |
|
2023 |
|
Current |
|
|
|
|
|
Suppliers |
|
|
|
|
|
Dividends payable (1) |
|
|
|
|
|
Withholding tax |
|
|
|
|
|
Partners’ advances |
|
|
|
|
|
Insurance and reinsurance |
|
|
|
|
|
Deposits received from third parties |
|
|
|
|
|
Related parties (Note 31) |
|
|
|
|
|
Hedging operations |
|
|
|
— |
|
Agreements in transport contracts |
|
|
|
|
|
Various creditors |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Non - current |
|
|
|
|
|
Suppliers |
|
|
|
|
|
Deposits received from third parties |
|
— |
|
|
|
Various creditors |
|
|
|
|
|
|
|
|
|
|
|
(1) |
Corresponds to dividends payable from Interconexión Eléctrica S.A. for $
|
The carrying amount of trade accounts and other accounts payable approximates their fair value due to their short–term nature.
22. Provisions for employees’ benefits
|
|
|
2024 |
|
2023 |
|
Post–employment benefits |
|
|
|
|
|
Healthcare |
|
|
|
|
|
Pension |
|
|
|
|
|
Education |
|
|
|
|
|
Bonds |
|
|
|
|
|
Other plans |
|
|
|
|
|
Termination benefits – Voluntary retirement plan |
|
|
|
|
|
|
|
|
|
|
|
Social benefits and salaries |
|
|
|
|
|
Other employee benefits |
|
|
|
|
|
|
|
|
|
|
|
Current |
|
|
|
|
|
Non–current |
|
|
|
|
|
|
|
|
|
|
F-84
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
22.1 Post–employment benefits liability (asset)
The following table shows the movement in liabilities and assets, net of post-employment benefits and termination benefits, as of December 31:
|
|
|
Pension and bonds |
|
Other |
|
Total |
||||||
|
|
|
2024 |
|
2023 |
|
2024 |
|
2023 |
|
2024 |
|
2023 |
|
Liabilities for employee benefits |
|
|
|
|
|
|
|
|
|
|
|
|
|
Opening balance |
|
|
|
|
|
|
|
|
|
|
|
|
|
Current service cost |
|
|
|
|
|
|
|
|
|
|
|
|
|
Past service cost |
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest expense |
|
|
|
|
|
|
|
|
|
|
|
|
|
Actuarial (gains) losses |
|
(
|
|
|
|
(
|
|
|
|
(
|
|
|
|
Benefits paid |
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
Foreign currency translation |
|
(
|
|
(
|
|
|
|
(
|
|
(
|
|
(
|
|
Closing balance |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Plan assets |
|
|
|
|
|
|
|
|
|
|
|
|
|
Opening balance |
|
|
|
|
|
|
|
|
|
|
|
|
|
Return on assets |
|
|
|
|
|
|
|
|
|
|
|
|
|
Contributions to funds |
|
|
|
|
|
|
|
|
|
|
|
|
|
Benefits paid |
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
Actuarial gains |
|
|
|
|
|
|
|
|
|
|
|
|
|
Closing balance |
|
|
|
|
|
|
|
|
|
|
|
|
|
Net post–employment benefits liability |
|
|
|
|
|
|
|
|
|
|
|
|
The following table shows the movement in profit and loss and in other comprehensive income as of December 31, 2024, 2023 and 2022:
|
|
|
2024 |
|
2023 |
|
2022 |
|
Recognized in profit or loss |
|
|
|
|
|
|
|
Interest expense |
|
|
|
|
|
|
|
Current service cost |
|
|
|
|
|
|
|
Past service cost |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Recognized in other comprehensive income |
|
|
|
|
|
|
|
Pension and pension bonds |
|
|
|
(
|
|
|
|
Healthcare |
|
|
|
(
|
|
(
|
|
Other |
|
|
|
(
|
|
|
|
|
|
|
|
(
|
|
(
|
|
Deferred tax |
|
(
|
|
|
|
|
|
|
|
|
|
(
|
|
(
|
22.2 Plan assets
Plan assets are resources held by pension trusts for payment of pension obligations. Payments for health and education post–employment benefits are Ecopetrol’s responsibility. The destination of trust resources and its yields cannot be changed or returned to the Ecopetrol Business Group until all pension obligations have been fulfilled.
F-85
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
The following is the composition of the plan assets of pension and pension bonds by type of investment as of December 31, 2024, and 2023:
|
|
|
2024 |
|
2023 |
|
Other local currency |
|
|
|
|
|
Bonds of private entities |
|
|
|
|
|
Other foreign currency |
|
|
|
|
|
Bonds issued by the national government |
|
|
|
|
|
Variable yield |
|
|
|
|
|
Other public bonds |
|
— |
|
|
|
Bonds of foreign entities |
|
|
|
|
|
|
|
|
|
|
The
The following table reflects the credit ratings of the issuers and counterparties in assets held by the autonomous pension funds:
|
|
|
2024 |
|
2023 |
|
|
|
|
|
|
|
AAA |
|
|
|
|
|
Nation |
|
|
|
|
|
AA+ |
|
|
|
|
|
AA |
|
|
|
|
|
F1+ |
|
|
|
|
|
BRC1+ |
|
|
|
|
|
BB+ |
|
|
|
|
|
BBB- |
|
|
|
|
|
BBB+ |
|
|
|
|
|
BAA2 |
|
|
|
|
|
AA- |
|
|
|
|
|
BAA1 |
|
|
|
|
|
A+ |
|
|
|
|
|
A |
|
|
|
|
|
Other ratings |
|
|
|
|
|
Rating not available |
|
|
|
|
|
|
|
|
|
|
F-86
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
22.3 Actuarial assumptions
The following are the actuarial assumptions used in determining the present value of defined employee benefit obligations used for the actuarial calculations as of December 31, 2024, and 2023:
|
2024 |
|
Pension |
|
Bonds |
|
Health |
|
Education |
|
Others |
|
|
Discount rate |
|
|
% |
|
% |
|
% |
|
% |
|
% |
|
Salary growth rate |
|
|
% |
N/A |
|
|
% |
N/A |
|
|
% |
|
Expected inflation rate |
|
|
% |
|
% |
|
% |
|
% |
|
% |
|
Pension growth rate |
|
|
% |
N/A |
|
N/A |
|
N/A |
|
N/A |
|
|
Cost trend |
|
|
|
|
|
|
|
|
|
|
|
|
Short–term rate |
|
N/A |
|
N/A |
|
|
% |
|
% |
N/A |
|
|
Long–term rate |
|
N/A |
|
N/A |
|
|
% |
|
% |
N/A |
|
|
2023 |
|
Pension |
|
Bonds |
|
Health |
|
Education |
|
Others |
|
|
Discount rate |
|
|
% |
|
% |
|
% |
|
% |
|
% |
|
Salary growth rate |
|
|
% |
N/A |
|
|
% |
N/A |
|
|
% |
|
Expected inflation rate |
|
|
% |
|
% |
|
% |
|
% |
|
% |
|
Pension growth rate |
|
|
% |
N/A |
|
N/A |
|
N/A |
|
N/A |
|
|
Cost trend |
|
|
|
|
|
|
|
|
|
|
|
|
Short–term rate |
|
N/A |
|
N/A |
|
|
% |
|
% |
N/A |
|
|
Long–term rate |
|
N/A |
|
N/A |
|
|
% |
|
% |
N/A |
|
N/A: Not applicable for this benefit.
The cost trend is the projected increase for the initial year, which includes the expected inflation rate.
22.4 Maturity of benefit obligation
The cash flows required for payment of post–employment obligations of Ecopetrol are the following:
|
Period |
|
Pension and bonds |
|
Other benefits |
|
Total |
|
2025 |
|
|
|
|
|
|
|
2026 |
|
|
|
|
|
|
|
2027 |
|
|
|
|
|
|
|
2028 |
|
|
|
|
|
|
|
2029 |
|
|
|
|
|
|
|
2030yss |
|
|
|
|
|
|
F-87
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
22.5 Sensitivity analysis
The following sensitivity analysis shows the effect of such possible changes on the obligation for defined benefits, while keeping the other assumptions constant, as of December 31, 2024:
|
|
|
Pension |
|
Bonds |
|
Health |
|
Education |
|
Other |
|
Discount rate |
|
|
|
|
|
|
|
|
|
|
|
–50 basis points |
|
|
|
|
|
|
|
|
|
|
|
+50 basis points |
|
|
|
|
|
|
|
|
|
|
|
Inflation rate |
|
|
|
|
|
|
|
|
|
|
|
–50 basis points |
|
|
|
|
|
N/A |
|
N/A |
|
|
|
+50 basis points |
|
|
|
|
|
N/A |
|
N/A |
|
|
|
Salary growth rate |
|
|
|
|
|
|
|
|
|
|
|
–50 basis points |
|
N/A |
|
N/A |
|
N/A |
|
N/A |
|
|
|
+50 basis points |
|
N/A |
|
N/A |
|
N/A |
|
N/A |
|
|
|
Cost trend |
|
|
|
|
|
|
|
|
|
|
|
–50 basis points |
|
N/A |
|
N/A |
|
|
|
|
|
N/A |
|
+50 basis points |
|
N/A |
|
N/A |
|
|
|
|
|
N/A |
N/A: Not applicable for this benefit.
23. Accrued liabilities and provisions
|
|
|
Asset |
|
|
|
Environmental |
|
|
|
|
|
retirement |
|
|
|
contingencies and |
|
|
|
|
|
obligation |
|
Litigation |
|
others |
|
Total |
|
Balance as of December 31, 2023 |
|
|
|
|
|
|
|
|
|
Abandonment costs update |
|
(
|
|
— |
|
— |
|
(
|
|
Additions (recoveries) (1) |
|
|
|
(
|
|
|
|
|
|
Uses |
|
(
|
|
(
|
|
(
|
|
(
|
|
Financial costs and interest |
|
|
|
|
|
|
|
|
|
Fair value adjustment in business combination |
|
|
|
— |
|
— |
|
|
|
Reversal of fields (2) |
|
|
|
— |
|
— |
|
|
|
Foreign currency translation |
|
|
|
|
|
|
|
|
|
Transfers |
|
(
|
|
(
|
|
|
|
|
|
Balance as of December 31, 2024 |
|
|
|
|
|
|
|
|
|
Current |
|
|
|
|
|
|
|
|
|
Non-current |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) |
It mainly includes the recognition of provisions related to potential obligations, provision forced environmental at Ecopetrol S.A., among others. |
|
(2) |
Corresponds to the abandonment provision associated with the assets delivered to Ecopetrol S.A. of the La Cañada and La Hocha fields. |
F-88
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
|
|
Asset |
|
|
|
Environmental |
|
|
|
|
|
retirement |
|
|
|
contingencies and |
|
|
|
|
|
obligation |
|
Litigation |
|
others |
|
Total |
|
Balance as of December 31, 2022 |
|
|
|
|
|
|
|
|
|
Abandonment costs update (1) |
|
|
|
— |
|
— |
|
|
|
Additions (2) |
|
|
|
|
|
|
|
|
|
Uses (3) |
|
(
|
|
(
|
|
(
|
|
(
|
|
Financial costs and interest (3) |
|
|
|
|
|
|
|
|
|
Foreign currency translation |
|
(
|
|
(
|
|
(
|
|
(
|
|
Transfers |
|
— |
|
(
|
|
|
|
|
|
Balance as of December 31, 2023 |
|
|
|
|
|
|
|
|
|
Current |
|
|
|
|
|
|
|
|
|
Non-current |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) |
Main variations in the abandonment cost are due to 1) an increase in activity in Rubiales and Caño Sur, 2) an increase in operating costs in Cira-Infantas fields, and 3) upgrades in the equipment and tariff increases. |
|
(2) |
It mainly includes the recognition of provisions related to potential obligations, provision forced environmental at Ecopetrol S.A., among others. |
|
(3) |
It mainly includes uses and interest expenses originating from rulings against the claims of Ecopetrol S.A. related to public works contributions. The recognition applied Law 2277 of 2022 with which a benefit was obtained by reducing interest payable to the tax authority by 50% |
|
|
|
Asset |
|
|
|
Environmental |
|
|
|
|
|
retirement |
|
|
|
contingencies and |
|
|
|
|
|
obligation |
|
Litigation |
|
others |
|
Total |
|
Balance as of December 31, 2021 |
|
|
|
|
|
|
|
|
|
Abandonment costs update |
|
(
|
|
— |
|
— |
|
(
|
|
Additions |
|
|
|
|
|
|
|
|
|
Uses |
|
(
|
|
(
|
|
(
|
|
(
|
|
Financial costs |
|
|
|
|
|
|
|
|
|
Foreign currency translation |
|
|
|
|
|
|
|
|
|
Reversal of provision for sale of assets (1) |
|
(
|
|
— |
|
— |
|
(
|
|
Transfers |
|
|
|
(
|
|
|
|
|
|
Balance as of December 31, 2022 |
|
|
|
|
|
|
|
|
|
Current |
|
|
|
|
|
|
|
|
|
Non-current |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) |
Corresponding to the abandonment provision associated with the assets related to the participation of Ecopetrol S.A. in Asociación Casanare, Estero, Garcero, Orocué and Corocora (CEGOC), which were sold to Perenco Oil and Gas Colombia. This trade closed on August 26, 2022. |
F-89
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
23.1 Asset retirement obligation
The estimated liability for asset retirement obligation costs corresponds to the future obligation that the Ecopetrol Business Group to restore environmental conditions to a level similar to that existing before the start of projects or activities, as described in Note 4.14. As these relate to long–term obligations, this liability is estimated by projecting the expected future payments and discounting at present value with a rate indexed to the Ecopetrol Business Group’s financial obligations, considering the temporariness and risks of this obligation. The discount rates used in the estimate of the obligation as of December 31, 2024, were Exploration and Production
23.2 Litigations
The following table details the main litigations recognized in the statement of financial position as of December 31, whose loss expectations are probable and could imply an outflow of resources:
|
|
|
2024 |
|
2023 |
|
ISA Energía Brasil. Civil contingency: Nullity of merger of EPTE by CTEEP, issued by Joana D Arc Tensol Rodrigues Pereira. It corresponds to a declaratory action in which minority shareholders claim the nullity of the merger of the Paulista Electric Power Transmission Company (EPTE) by the company or, jointly and severally, the declaration of their right to withdraw and the determination of the payment of the redemption value of their shares. In 2023, the process was classified as a contingent liability. |
|
|
|
— |
|
CTEEP Regulatory Contingency: Billing Eletrobras – RBNI Corresponds to the collection action filed by Eletrobras against ISA CTEEP requesting the return of the value charged in excess by the company as part of the payment of the compensation resulting from the extension of Concession Contract No. 059/2001 under Law No. 12,783/201, relating to NI facilities (new investments) that had been transferred to the company by Eletrobras. |
|
|
|
|
|
Unfavorable first instance ruling for Ecopetrol in the process of direct fixing for the damages associated with the hydrocarbon spill that occurred in Guaduas, Vereda Raizal and Cajón, in the property called “La Floresta” in May 2004. |
|
|
|
|
|
Administrative processes of a sanctioning type issued by PRONATEL and OSIPTEL Internexa Peru: Procedure for failure to pay contributions during the years 2011 to 2022 or the provision of the Dark Optical Fiber service. |
|
|
|
|
|
Transelca. Regulatory contingency: Unavailability of service. Compensation for energy not supplied. In June 2020, a shot occurred in the Bay of Line BL2 Sabanalarga-Fundación, at the Sabanalarga substation, 220 kV; the substation went out of operation, as well as other assets operated by Transelca and other third parties, leaving a large region of the Atlantic Coast without electricity service. In accordance with the provisions of Resolution GREC 011 of 2009, numeral 3.8.3, this event may cause the company to pay compensation for energy not supplied. |
|
|
|
|
|
Ecopetrol S.A. as responsible for the damages caused by export activities in influence of the municipalities of Cicuco, Talaigua Nuevo and Mompox. |
|
|
|
|
23.3 Environmental contingencies and others
These correspond to contingencies for environmental incidents and obligations related to environmental compensation and mandatory investment of
F-90
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
The Colombian Government, through the Ministry of Environment and Sustainable Development, issued Decrees 2099 and 075 in December 2016 and January 2017, through which it modifies the Single Regulatory Decree of the environment and sustainable development sector, Decree 1076 of 2015, in relation to the mandatory investment for the use of water taken directly from natural sources. The main changes established by these decrees were in relation to the areas of implementation, investment lines and the basis for liquidation of obligations. Likewise, June 30, 2017, was defined as the maximum date to modify the Investment Plans that are in execution.
From the Company’s Environmental Management, with the regional environmental departments and allies in the territory, Ecopetrol executes more than
The resources allocated to environmental compensation and the mandatory investment of no less than
23.4 Contingencies
Refinería de Cartagena S.A.S.
Arbitration tribunal:
On March 8, 2016, Reficar filed a request for arbitration with the International Chamber of Commerce (the “ICC”) against Chicago Bridge Iron Company NV, CBI UK Limited and CBI Colombiana SA (jointly, “CBI”), concerning a dispute related to the engineering, procurement, and construction agreements entered into by and between Reficar and CBI for the expansion of the Refinería de Cartagena, Colombia. Reficar was the Claimant in the ICC arbitration and seeked no less than USD$
On May 25, 2016, CBI filed its Answer to the Request for Arbitration and the preliminary version of its counterclaim against Reficar, for approximately USD
On April 28, 2017, Reficar filed its non-detailed claim, and, on the same date, CBI submitted its Statement of Counterclaim increasing its claims to approximately USD$
On June 28, 2019, Chicago Bridge Iron Company filed a response to Reficar’s non-detailed defense of the counterclaim, updating the value of its claim to approximately USD $
On this same date, Reficar filed its Reply to CBI’s Non-Exhaustive Statement of Defense and its Exhaustive Statement of Defense to CBI’s counterclaim, updating its claim for provisionally paid invoices under the MOA and PIP Agreements and the EPC Contract to approximately USD$
In January 2020, McDermott International Inc. (now McDemott International Ltd and hereinafter “McDermott”) – CBI parent company – commenced a bankruptcy case under title 11 of the United States Code in the United States Bankruptcy Court for the Southern District of Texas. Faced with this situation, Refinería de Cartagena took actions to protect its interests and had a group of experts with whom it will continue to evaluate other measures it may adopt in this new circumstance.
F-91
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
As a consequence of the initiation of the reorganization process, the arbitration was suspended until July 1, 2020, as described below.
On January 21, 2020, Comet II BV, the successor in interest to Chicago Bridge Iron Company N.V., commenced a bankruptcy proceeding under title 11 of the Bankruptcy Code of the United States before the Bankruptcy Court for the Southern District of Texas. Before the beginning of the insolvency process of Comet II BV, an automatic suspension of the initiation or continuation of any action, process or execution of judgment or award against Comet II BV became effective, which suspended the arbitration.
On March 14, 2020, the Bankruptcy Court entered an order confirming a plan of reorganization, and the order provided for the stay against the arbitration to end upon the earlier of the effective date of the plan or August 30, 2020, whichever would occur first. On June 30, 2020, McDermott notified the occurrence of the effective date of the reorganization plan, thus the suspension of arbitration was lifted on July 1, 2020.
On May 6, 2020, the Superintendence of Companies of Colombia ordered the judicial liquidation of CBI Colombiana S.A., one of the defendants in the CBI arbitration. On October 22, 2020, Reficar requested its recognition as a creditor of CBI Colombiana S.A., up to the maximum amount of its claims in the arbitration. On January 15, 2021, the liquidator of CBI Colombiana S.A. accepted Reficar’s request.
On September 22, 2020, the tribunal scheduled the start of the hearings for May 2021.
Between May 17 and June 16, 2021, the first two blocks of the hearing were held, in which the evidence in the arbitration against CBI was presented. On June 16, 2021, the tribunal ordered the submission of post-hearing briefs on October 15 and November 5, 2021. Likewise, the tribunal summoned the parties to a hearing on closing arguments for November 18, and 19, 2021.
On August 16, 2021, the parties requested the tribunal to modify the procedural calendar, consisting of slightly altering the dates of presentation of the post-hearing briefs. On August 26, 2021, the tribunal granted the request of the parties, so the post-hearing briefs were presented on October 22 and November 10, 2021, respectively. The closing arguments hearing was held in a single session on November 18, 2021, and the session scheduled for November 19, 2021, was cancelled.
Subsequently, on December 20, 2021, Refinería de Cartagena presented its memorial for costs in arbitration against CBI. On February 11, 2022, CBI presented its memorial for costs.
On September 7, 2023, Refinería de Cartagena S.A.S. was notified of the decision of the International Arbitration Court that resolved the claim filed against. The Arbitration Court ordered CBI to pay approximately $
On August 4, 2023, Refinería de Cartagena answered to the annulment request and, in addition, and likewise requested the confirmation of the award Moreover, On January 10, 2025, the Southern District Court of New York confirmed the Arbitration Award and denied the request for annulment filed by Chicago Bridge Iron Company N.V. and CBI UK Limited.
On September 8, 2023, McDermott reported that it will initiate financial restructuring procedures for its subsidiaries in the United Kingdom and the Netherlands, CBI UK Limited and Chicago Bridge Iron Company N.V. respectively, considering the arbitral issued award against them and in favor of Refinería de Cartagena. The Company advised by a global team of lawyers and experts, became an active part of the business reorganization processes in said countries to defend its own interests.
Subsequently, on October 10, 2023, CBI UK Limited and Chicago Bridge Iron Company N.V. requested before the Texas Bankruptcy Judge the initiation of a procedure for recognition of financial restructuring processes abroad, known as Chapter 15 of the Bankruptcy Code of the United States of America. Specifically, they requested recognition of the financial restructuring processes that were announced by McDermott on September 8, 2023.
F-92
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
Based on the above, the process of annulment and recognition of the Arbitration Award - which determines the possibility of executing it and therefore collecting the decreed sums – was temporarily suspended by order of the Bankruptcy Judge. In this regard, it should be noted that the judge only issued an order suspending proceedings in the United States of America and which intended to execute assets of CBI UK Limited and Chicago Bridge Iron Company N.V. located in the United States. go against the assets of the Convicted parties.
On February 27, 2024, Refinería de Cartagena was notified of the decision of the United Kingdom Court in which it was determined that the financial restructuring plan of CBI UK Limited was approved by said court.
Regarding the reorganization process initiated by Chicago Bridge Iron Company (now McDermott Holdings N.V.) in the Netherlands on September 8, 2023. On February 16, 2024, an independent restructuring expert appointed by the Court submitted to a vote an alternative reorganization plan under which Refinería de Cartagena would receive, among others, an equity stake in the McDermott. On March 21, 2024, Cartagena Refinery was notified of the decision of the Netherlands Court approving the alternative financial restructuring plan of Chicago Bridge Iron Company N.V.
Given the sanction of the plan, Refinería de Cartagena was the beneficiary of (i) USD$
The Series B Preferred Shares have priority over the common shares and are on equal terms with respect to dividends and payments in the event of liquidation with the Series A Preferred Shares. They are entitled to cumulative quarterly dividends.
The holder of the Series B Preferred Shares may also require that all of the Series B Preferred Shares be converted at any time on or after June 30, 2028, into common shares representing up to
The Series B Preferred Shares are subject to mandatory redemption requirements in the event of liquidation or change of control of the Company and other similar events.
As of September 30, 2024, Refinería de Cartagena performed the valuation of McDermott’s shares considering an income approach, projecting discounted cash flows at present value and aspects such as risk premiums, information available from McDermott, the absence of significant influence and control by Refinería de Cartagena and restructuring scenarios over time. As a result of the fair value valuation, the accounting record was made as a financial instrument for USD$
On December 9, 2024, McDermott announced that it has completed the sale of its storage business (CBI’s tank business) to a consortium of financial investors led by Mason Capital Management. Under the terms of the agreement announced on October 7, 2024, McDermott will receive $
Ecopetrol S.A. continuously monitors the operations of McDermott International Ltd. to identify and measure any potential changes in the fair value of the investment and/or risk premiums associated with the valuation model.
Investigations of control entities – Reficar
Refinería de Cartagena is a wholly owned subsidiary of Ecopetrol, and since Ecopetrol is majority owned by the Government of Colombia, both companies manage public resources. In this context and in accordance with Colombian regulations, the employees of Ecopetrol and Refinería de Cartagena are considered public servants and, as such, may be held responsible for the negligent use or management of public resources.
F-93
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
Consequently, the employees of Ecopetrol and Refinería de Cartagena, in general, are subject to the control and supervision of the control entities.
Currently, derived from the Expansion and Modernization Project of the Refinería de Cartagena (hereinafter, the “Project”), the processes described below are underway:
1. Office of the Comptroller General (Contraloría General de la República – CGR):
|
- |
PRF-80011-2018-33300 |
Through Order No. 1328 of August 24
th
, 2021, the CGR closed the preliminary investigation UCC-IP-005-2019 and opened a new fiscal responsibility process. In this,
In this process,
The CGR made a special visit to the refinery facilities between February 20 and 24, 2023, which focused on two main points related to: (i) unidentified expenses, for $
On March 1, 2023, through Auto No. 0335, the CGR decreed the preparation of a technical report by the CGR team that participated in the visit.
On April 14, 2023, the officials assigned by the CGR presented the technical report in which, based on the information provided and the explanations provided by the Refinería de Cartagena, it was concluded that in all records the destination of the associated expense was identified to each of the third parties.
On April 19, 2023, by Order No. 0665, it was ordered to incorporate the technical report into the process and make it available to the procedural subjects. It is expected that, based on the conclusions of the report, the CGR will make the decision to charge or archive the process.
On October 2, 2024, by means of Order No. 1762, the ordinary fiscal responsibility process was ordered to be archived, considering that the facts investigated did not constitute damage to public property.
Procedurally, the file had to be sent, within 3 business days following notification by status, to the Fiscal and Sanctioning Chamber of the CGR, in consultation status.
On October 31, 2024, by Order ORD-801119-257-2024, the Decision Chamber of the Fiscal and Sanctioning Chamber of the CGR ordered the total archiving of the proceedings carried out related to this process, confirming, in consultation status, Order No. 1762 of October 2, 2024, issued by the Intersectoral Delegate Comptroller’s Office No. 15 of the Special Investigations Unit Against Corruption of the CGR.
2. Prosecutor’s Office (Fiscalía General de la Nación - FGN)
Proceeding 1 – 110016000101201600023 - MOA - PIP and EPC
This process is being carried out against some ex-members of the Board of Directors and ex-employees of Refinería de Cartagena, workers of the Chicago Bridge and Iron Company (CBI) and the Statutory Auditor of Refinería de Cartagena between 2013 and 2015, for crimes of undue interest in the execution of contracts, embezzlement by appropriation in favor of third parties, illicit enrichment of individuals in favor of third parties and ideological falsehood in a public document.
F-94
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
On May 31, 2018, the hearing for the formulation of accusations was held; however, on this date the jurisdiction of the judge in the case was challenged. For this reason, it was only possible to start the hearing on November 29, 2018. On August 22, 2019, the hearing for the formulation of accusations ended and Refinería de Cartagena and Ecopetrol were officially recognized as victims.
On November 25, 2019, the trial preparatory hearing was installed and is currently taking place.
On February 2, 2024, the hearing was held to read the decision of the Criminal Chamber of the Superior Court of the Judicial District of Bogota, which resolved the appeals filed against the decision issued on July 26, 2021 by the 31st Criminal Circuit Court, in which it ruled by admitting and denying the evidentiary requests submitted by the parties in the preparatory hearing.
With this, the preparatory hearing of the trial was concluded; to date, the oral trial hearings are being held. The oral trial hearing resumed in February. The defendants’ defense is currently presenting evidence.
As of December 31, 2024, there were no changes to the process.
Proceeding 2 - 110016000101201800132 Business line
This process is being carried out against ex-members of the Board of Directors and a ex-president of Refinería de Cartagena, for the crimes of aggravated unfair administration, and obtaining a false public document. In this process, Refinería de Cartagena and Ecopetrol S.A. were officially recognized as victims.
On November 18, 2019, the preparatory hearing for the trial was held and has been resumed on several occasions. As of December 31, 2023, there have been no changes in the process.
On April 19, 2024, the 34th Criminal Circuit Court declared the annulment of the order that ordered the evidence for trial and issued a new order, which was appealed by the defendants and after the transfers were revoked, the appeal was granted before the Superior Court of Bogota, Criminal Chamber.
On July 5, 2024, the Criminal Chamber of the Superior Court of Bogota resolved the appeals filed by the defendants, confirming the first instance decision that denied the exclusion of evidence from the Prosecutor’s Office.
On October 28, 2024, at the beginning of the oral trial hearing, the defendants requested the foreclosure of the investigation, when the prescription of the criminal action. The 34th Criminal Circuit Judge denied the request; the defendants filed appeals.
On December 10, 2024, the Superior Court of Bogota held a hearing to read the decision on the appeals filed by the defendants, in which it confirmed in its entirety the decision of the 34th Court and ordered the case to be returned to the Court of Knowledge so that the oral trial hearing could continue.
Proceeding 3 – 110016000101201800134 – Subscription of contract PMC - Foster Wheeler
This process is being carried out against two ex-employees of Refinería de Cartagena who acted as ex-president on property and ex-president in charge, for the crime of entering into a contract without legal requirements. In this process, Refinería de Cartagena and Ecopetrol S.A. were officially recognized as victims.
On August 18, 2022, a sentence was handed down imposing the minimum penalty for the crime charged, equivalent to 64 months in prison and a fine of (66.66) SMLMV. On August 25, 2023, the defenders of the defendants supported the appeal briefs, and the parties were notified to rule.
On October 19, 2023, the Criminal Chamber of the Superior Court of Bogota confirmed the first instance ruling.
Against this ruling, the attorneys of the convicted persons filed an extraordinary appeal for cassation before the Supreme Court of Justice.
F-95
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
On February 23, 2024, the Superior Court of the Judicial District of Bogota granted the appeal and referred the case to the Criminal Chamber of the Supreme Court of Justice.
On February 26, 2024, the Court acknowledged receipt of the file, the distribution was made in April and the decision to admit or reject the claims is awaited.
As of December 31, 2024, there were no changes in the process.
Proceeding 4 - 110016000000201702546 – Principle of opportunity
This process is being executed against a ex-employee of the Refinería de Cartagena, for charges related to crimes against the public administration, and illegal interest in the execution of contracts.
On December 5, 2024, by Resolution No. 549, one year was set as the term for the extension of the suspension of the exercise of criminal action.
23.5 Detail of contingent liabilities
The following is a summary of the main contingent liabilities that have not been recognized in the statement of financial position as, according to the evaluations made by internal and external advisors of the Ecopetrol Business Group, the expectation of loss is not probable as of December 31:
|
|
|
2024 |
|
2023 |
||||
|
|
|
Number of |
|
|
|
Number of |
|
|
|
Type of process |
|
processes |
|
Proceedings |
|
processes |
|
Proceedings |
|
Constitutional |
|
|
|
|
|
|
|
|
|
Ordinary administrative |
|
|
|
|
|
|
|
|
|
Labor |
|
|
|
|
|
|
|
|
|
Civil |
|
|
|
|
|
|
|
|
|
Arbitration |
|
|
|
|
|
|
|
|
|
Penal |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
23.6 Details of contingent assets
The following is a breakdown of the Ecopetrol Business Group’s principal contingent assets, where the associated contingent gain is likely, but not certain:
|
|
|
2024 |
|
2023 |
||||
|
|
|
Number of |
|
|
|
Number of |
|
|
|
Type of process |
|
processes |
|
Proceedings |
|
processes |
|
Proceedings |
|
Ordinary administrative |
|
|
|
|
|
|
|
|
|
Arbitration |
|
|
|
— |
|
|
|
|
|
Civil |
|
|
|
|
|
|
|
|
|
Penal |
|
|
|
|
|
|
|
|
|
Labor |
|
|
|
|
|
|
|
|
|
Constitutional |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
F-96
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
24. Equity
|
24.1 |
Subscribed and paid–in capital |
Ecopetrol’s authorized capital amounts to $
24.2 Additional paid–in capital
Additional paid–in capital mainly corresponds to: (i) share premium from the Ecopetrol Business Group’s capitalization in 2007, for $
24.3 Equity reserves
The following is the composition of the Ecopetrol Business Group’s reserves as of December 31, 2024, and 2023:
|
|
|
2024 |
|
2023 |
|
Legal reserve |
|
|
|
|
|
Fiscal and statutory reserves |
|
|
|
|
|
Occasional reserves |
|
|
|
|
|
|
|
|
|
|
The General Shareholders’ Meeting of Ecopetrol S.A., held on March 22, 2024, approved the 2023 profit distribution project and the establishment of a reserve for $
The movement of equity reserves is the following for the years ended December 31, 2024, and 2023:
|
|
|
2024 |
|
2023 |
|
Opening balance |
|
|
|
|
|
Release of reserves |
|
(
|
|
(
|
|
Allocation to reserves |
|
|
|
|
|
Closing balance |
|
|
|
|
24.4 Retained earnings and dividends
Ecopetrol Business Group distributes dividends based on its financial statements prepared under International Financial Reporting Standards accepted in Colombia (NCIF, as its acronym in Spanish).
The Ordinary General Assembly of Shareholders of Ecopetrol S.A., held on March 22, 2024, approved the profit distribution project for fiscal year 2023 and defined the distribution of dividends in the amount of $
The payment of dividends to minority shareholders was made in
F-97
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
Dividends were paid as follows:
|
|
|
2024 |
|
2023 |
|
2022 |
|
Ecopetrol S.A. |
|
|
|
|
|
|
|
Interconexión Eléctrica S.A. ESP |
|
|
|
|
|
|
|
Oleoducto Central S.A. - Ocensa |
|
|
|
|
|
|
|
Oleoducto de los Llanos Orientales S.A. - ODL |
|
|
|
|
|
|
|
Invercolsa S.A. |
|
|
|
|
|
|
|
Oleoducto de Colombia S.A. - ODC |
|
|
|
|
|
|
|
Total |
|
|
|
|
|
|
| (1) |
Of the total amount paid to the majority shareholder Ecopetrol S.A.,
$
|
In July 2024, Oleoducto Central S.A. acquired
24.5 Other comprehensive income attributable to owners of parent
The following is the composition of the other comprehensive income attributable to the shareholders of the parent, Ecopetrol, net of tax:
|
|
|
2024 |
|
2023 |
|
2022 |
|
Foreign currency translation |
|
|
|
|
|
|
|
Hedge of a net investment in a foreign operation |
|
(
|
|
(
|
|
(
|
|
Actuarial gain on defined benefit plans |
|
(
|
|
(
|
|
(
|
|
Cash flow hedges for future exports |
|
(
|
|
|
|
(
|
|
Cash flow hedge with derivative instruments |
|
|
|
|
|
|
|
Others |
|
(
|
|
|
|
|
|
|
|
|
|
|
|
|
24.6 Earnings per share
|
|
|
2024 |
|
2023 |
|
2022 |
|||
|
Profit attributable to Ecopetrol’s shareholders |
|
|
|
|
|
|
|
|
|
|
Weighted average number of outstanding shares |
|
|
|
|
|
|
|
|
|
|
Net basic earnings per share (Colombian pesos) |
|
COP $ |
|
|
COP $ |
|
|
COP $ |
|
F-98
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
25 . Revenue from contracts with customers
|
|
|
2024 |
|
2023 |
|
2022 |
|
National sales |
|
|
|
|
|
|
|
Mid–distillates (1) |
|
|
|
|
|
|
|
Gasoline and turbo fuels (1) |
|
|
|
|
|
|
|
Natural gas |
|
|
|
|
|
|
|
Services |
|
|
|
|
|
|
|
Electric power transmission services (2) |
|
|
|
|
|
|
|
Plastic and rubber |
|
|
|
|
|
|
|
LPG and propane |
|
|
|
|
|
|
|
Asphalts |
|
|
|
|
|
|
|
Fuel gas service |
|
|
|
|
|
|
|
Crude oil |
|
|
|
|
|
|
|
Roads and Construction Services (2) |
|
|
|
|
|
|
|
Aromatics |
|
|
|
|
|
|
|
Polyethylene |
|
|
|
|
|
|
|
Fuel oil |
|
|
|
|
|
|
|
Other income gas contracts |
|
— |
|
|
|
|
|
Other products |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Foreign sales |
|
|
|
|
|
|
|
Crude oil |
|
|
|
|
|
|
|
Electric power transmission services (2) |
|
|
|
|
|
|
|
Roads and Construction Services (2) |
|
|
|
|
|
|
|
Fuel oil |
|
|
|
|
|
|
|
Diesel |
|
|
|
|
|
|
|
Plastic and rubber |
|
|
|
|
|
|
|
LPG and propane |
|
|
|
|
|
|
|
Natural gas |
|
|
|
|
|
|
|
Gasoline and turbo fuels |
|
|
|
|
|
|
|
Cash flow hedges (3) |
|
(
|
|
(
|
|
(
|
|
Other products |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| (1) |
Includes the corresponding value to the application of Decree 180522 of March 29, 2010, and other standards that modify and add (Decree 1880 of 2014 and Decree 1068 of 2015), which establishes the procedure to recognize the subsidy for refiners and importers of ordinary motor gasoline and ACPM, and the methodology for calculating the net position, which can be positive or negative. As of December 31, 2024, the value recognized by price differential corresponds to
$
|
| (2) | Corresponds to the revenue related to the electric power transmission contracts and toll roads concessions of Interconexión Eléctrica S.A. E.S.P. |
| (3) |
Includes the result of hedging for future exports (Note 30.3) for $(
|
F-99
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
Sales by geographic areas
|
|
|
2024 |
|
% |
|
2023 |
|
% |
|
2022 |
|
% |
|
|
Colombia |
|
|
|
|
% |
|
|
|
% |
|
|
|
% |
|
Asia |
|
|
|
|
% |
|
|
|
% |
|
|
|
% |
|
United States |
|
|
|
|
% |
|
|
|
% |
|
|
|
% |
|
South America and others |
|
|
|
|
% |
|
|
|
% |
|
|
|
% |
|
Central America and the Caribbean |
|
|
|
|
% |
|
|
|
% |
|
|
|
% |
|
Europe |
|
|
|
|
% |
|
|
|
% |
|
|
|
% |
|
|
|
|
|
|
% |
|
|
|
% |
|
|
|
% |
Concentration of customers
During 2024, Organización Terpel S.A. represented
Revenues from concession contracts
ISA, through its companies, promotes development in several countries through concessions acquired for the supplying of public energy transport services, services associated with the Management of Real Time Systems in Colombia and public road transport, through concessionaires in Chile and Colombia.
The ISA concessions contain the obligation to carry out major works and at the end of the concession to deliver the asset to the grantors in optimal conditions. These major maintenance works are accounted for i) at the moment in which the works are executed and ii) when the value of the outflow of resources is known.
The current contracts signed by the ISA, except the contracts from Peru and Bolivia, have guaranteed cash flows.
ISA meets its obligations under the concession contracts and provides the contracted services with the use of infrastructure assets determined in each concession contract. Upon the expiration of each concession, ISA can present a bid for its renewal.
The main concessions are the following:
Concessions in Colombia
Inteia S.A.S (before Sistemas Inteligentes en Red)
Through a business collaboration agreement entered into with UNE EPM Telecomunicaciones S.A. and Consorcio ITS, executes the addendum number 5 of the Inter-administrative Agreement 5400000003 of 2006 with the Municipality of Medellín to “provide under the concession modality, the necessary technological infrastructure, the services for its modernization and optimization of the management of the administrative services of the Secretaría de Transporte y Tránsito of Medellín, through a complete solution of technology, information, communications and operation of the information and communications technology (ICT’s)”. As payment for such services, Intelligent Network Systems receives a portion of the penalty fees collected through the photodetection system within the municipality.
This contract is within the scope of IFRIC 12 under the intangible model, considering the following aspect: The Municipality of Medellín, as the grantor of the concession, controls the services provided by the concessionaire, including the corresponding infrastructure. The value of fines and the method of imposing them are defined at the national level. The Municipality of Medellín controls, through ownership of the right of use, any significant residual interest in the infrastructure at the end of its useful life, as established in the agreement. Upon termination of this agreement, all goods, equipment, technology, and software use licenses will be reverted to the Municipality.
F-100
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
Ruta Costera
In accordance with Law 1508 of 2012 which regulates public-private partnerships, the National Infrastructure Agency (“ANI”), by means of Resolution No. 862 of July 2, 2014, awarded Public Tender No. VJ-VE-IP-LP-0011-2013 and, on September 10, 2014, executed Concession Contract No. 004 of 2014 with Concesion Costera Cartagena-Barranquilla, an indirect subsidiary of ISA. The contracted services consist of executing “the final studies and designs, environmental management, property, social management, construction, rehabilitation, improvement, operation, and maintenance of the corridor Cartagena-Barranquilla Project and Circunvalar de la Prosperidad”.
This contract is within the scope of IFRIC 12 under the financial asset model for investment in construction (construction services). As compensation, the concessionaire receives: revenues from commercial exploitation, including toll collections, and payments from ANI, to the extent applicable. If the concessionaire does not achieve the expected revenue from toll collection, the grantor (ANI) will pay the concessionaire a collection differential in years 8, 13 and 18. Such collection differential has been contractually defined as the present value of toll collections for any given reference month. This revenue arrangement represents an unconditional contractual right to receive a specific and determinable amount of cash or other financial assets for the construction services provided.
As of December 31, 2024, the concession is in the operation and maintenance stage of all
In addition to the concession contract, Unit Price Fixing Acts have been signed with the ANI, for the development of the following projects on the road:
| ● | Construction of the Crespo Linear Park. |
| ● | Operation and Maintenance Activities of the Crespo Linear Park. |
| ● | Design, dismantling, construction, and maintenance of solar lighting at UF4. |
| ● | Construction of the elevated intersection “Puente Caracolí” |
Concessions in Brazil
As concessionaires for power transmission services in Brazil, the Company has the obligation to build and operate the transmission infrastructure, while the grantor retains ownership rights to the concession assets. Upon expiration of the concession, concession assets are to be transferred back to the grantor who must pay any pending compensation to the concessionaire.
The concession contracts of ISA CTEEP and TAESA were analyzed and classified in accordance with IFRS 15 - Revenue from contracts with customers within the contractual asset model as of January 1, 2018.
The value of the contractual asset of the electric power transmission concessions is equal to the present value of future cash flows, which are determined at the beginning of any given concession or renewal. Such future cash flows are revaluated periodically, in previously determined tariff review periods.
Cash flows are defined based on payments received by concessionaires for supplying power transmission services to end-users. Such payments are known as Receita Anual Permitida or “RAP” and serve to compensate the cost of investments made in the transmission infrastructure. Any investment costs that are not fully compensated through the receipt of RAPs trigger the right to receive payment from the grantor. This flow of future collections is updated for inflation (IPCA/IGPM) and paid at a discount rate at the beginning of each project.
During the construction stage, the concessionaire has the right to receive consideration in accordance with progress made on construction of the network and the performance of its obligations, and not only in accordance with the time used for construction. Revenue is equivalent to the value of construction expenses plus a construction margin, as a result of the application of the pronouncement of the CVM (Brazilian Securities and Exchange Commission) on the accounting treatment for contract assets (CVM Official Communication 4/2020)
F-101
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
Revenues from these concession assets generate taxes under the Social Integration Program and the Contribution for the Financing of Social Security (Cofins) program. These may be registered as deferred taxes (non-current liabilities).
Concessions in Chile
Road concession contracts for the supply of road infrastructure in Chile, may be remunerated in one or two ways: variable revenues, which may account for traffic risk (the variation of projected demand) or fixed revenue, that is, a guaranteed total amount subject to a revenue distribution mechanism or calculated at the present value of future cash flows. In the latter cases, the total revenue is guaranteed at present value. Additionally, in some concession contracts other concepts are included, such as the minimum guaranteed revenue and subsidies (both in construction and in operation stages); both correspond to payments from the State, subject to specific compliance of conditions by the concessionaire.
The model applied to concessions in Chile will depend on whether revenue is guaranteed or not (whether it is subject to traffic risk or not) and whether it is enough to pay for the investment. On one hand, if the concession contract considers traffic risk, it is recognized according to IFRIC 12 as an intangible asset. This asset is amortized over the life of the concession operation. On the other hand, if the contract establishes income and compensation guarantee mechanisms, it is recognized as a financial asset. This asset is extinguished through payments received from road users, through the collection of tolls, or directly through payments from the Ministry of Public Works. Currently, ISA has road concessions in Chile applying the financial asset model.
Concessions in Peru
Due to their terms and conditions, as well as the rights and obligations of concessionaires, the concession contracts of ISA REP, ISA Perú, and Consorcio Transmantaro are recognized as intangible assets. The intangible asset model applies when the services provided by the concessionaire are paid by end-users or when the grantor does not unconditionally guarantee the collection of revenues. These contracts grant the concessionaire the right to charge end-users for the energy transmission service, but do not establish an unconditional right to receive cash.
In November 2020, through a corporate reorganization process (merger by absorption), ISA Perú acquired the companies Etenorte S.R.L. (220 KV Carhuaquero - SE Chiclayo Oeste lines and 138 KV Huallanca - SE Chimbote 1 and SE Chimbote 2 lines) and Eteselva S.R.L. (SE Aguaytia - SE Tingo María - SE Paramonga Nueva 220 lines), which have an unlimited useful life.
All the concession contracts for the supply of power transmission services in Peru contain similar terms and conditions.
Concessions in Bolivia
Similar to concession contracts in Peru, concessions to provide public energy services in Bolivia do not guarantee the unconditional receipt of cash by the concessionaire. In these concession contracts, we assume the credit risk associated with the collection of amounts invoiced and may not be able to recover the entire value of the investment made. Additionally, the Bolivian State is not obliged to guarantee shortages, either due to the non-existence of demand or due to non-payment by any of the market agents; therefore, the grantor has no obligation to pay for the construction services received and, in this sense, the model that adjusts to the contractual conditions by IFRIC 12 is the intangible asset model, framed by IFRIC 12.
The balances of assets and income from concessions accounted for under IFRIC 12 are disclosed in Exhibit 3. Quantitative information on service concession contracts.
Committed investments
ISA and its companies have committed investments of $
F-102
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
The committed investments pending of execution for 2025-2030 period are distributed as follows:
| ● |
Projects awarded for $
|
| ● |
Reinforcement and improvements for the existing network of ISA Brasil and subsidiaries for
$
|
| ● |
Capital contributions of
$
|
| ● |
Projection of investments related to the maintenance and optimization plan of existing assets for
$
|
The value of committed investments pending execution may vary, among other things, due to adjustments in the scope of the projects, equipment and material prices, and variations in macroeconomic estimates, such as exchange rates and price indexes.
26. Cost of sales
|
|
|
2024 |
|
2023 |
|
2022 |
|
Variable costs |
|
|
|
|
|
|
|
Imported products (1) |
|
|
|
|
|
|
|
Purchases of crude |
|
|
|
|
|
|
|
Purchases of hydrocarbons – ANH (2) |
|
|
|
|
|
|
|
Depreciation amortization and depletion |
|
|
|
|
|
|
|
Electric energy |
|
|
|
|
|
|
|
Gas royalties in cash |
|
|
|
|
|
|
|
Taxes and economic rights |
|
|
|
|
|
|
|
Process materials |
|
|
|
|
|
|
|
Purchases of other products and natural gas |
|
|
|
|
|
|
|
Hydrocarbon transport services |
|
|
|
|
|
|
|
Services contracted in associations |
|
|
|
|
|
|
|
Others (3) |
|
|
|
|
|
(
|
|
|
|
|
|
|
|
|
|
Fixed costs |
|
|
|
|
|
|
|
Depreciation and amortization |
|
|
|
|
|
|
|
Maintenance |
|
|
|
|
|
|
|
Labor costs |
|
|
|
|
|
|
|
Construction services |
|
|
|
|
|
|
|
Services contracted |
|
|
|
|
|
|
|
Services contracted in associations |
|
|
|
|
|
|
|
Taxes and contributions |
|
|
|
|
|
|
|
Materials and operating supplies |
|
|
|
|
|
|
|
Hydrocarbon transport services |
|
|
|
|
|
|
|
General costs |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) |
Imported products correspond mainly to mid-distillates, gasolines and thinner, the variation occurs due to lower requirements due to greater operations in Barrancabermeja Refinery. |
|
(2) |
Corresponds to purchases of crude oil by Ecopetrol Business Group from the National Hydrocarbons Agency derived from national production. |
|
(3) |
Corresponds to i) result of the process of use and valuation of core inventories, ii) measurement at net realizable value, and iii) other capitalizable charges to projects. |
F-103
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
27. Administrative, operative, and project expenses
|
|
|
2024 |
|
2023 |
|
2022 |
|
Administrative expenses |
|
|
|
|
|
|
|
Labor expenses |
|
|
|
|
|
|
|
General expenses |
|
|
|
|
|
|
|
Taxes |
|
|
|
|
|
|
|
Depreciation and amortization |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operations and project expenses |
|
|
|
|
|
|
|
Exploration costs (1) |
|
|
|
|
|
|
|
Commissions fees freights and services |
|
|
|
|
|
|
|
Taxes |
|
|
|
|
|
|
|
Labor expenses |
|
|
|
|
|
|
|
Fee for regulatory entities |
|
|
|
|
|
|
|
Maintenance |
|
|
|
|
|
|
|
Depreciation and amortization |
|
|
|
|
|
|
|
Others |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| (1) | As of December 31, 2024, exploration expenses mainly include: i) the disposals of the Orca1, Arantes1, Machin1, and Morito1 wells and seismic work and studies at Ecopetrol S.A., ii) at Hocol S.A. the disposals of the Milonga, Yoda A, Arbolito Norte, Sabanales, Toritos, and Saltador wells and exploration and seismic expenses mainly at Llanos, VIM8, Perdices, Cor-9, SN-18, SSJN1, Upar, YD SN-1, SN-15, RC-7, and iii) the Pau Brasil well and exploration and seismic expenses at Ecopetrol Brasil . |
28. Other operating income (expenses)
|
|
|
2024 |
|
2023 |
|
2022 |
|
Expense for legal provisions |
|
(
|
|
(
|
|
(
|
|
(Loss) gain on sale of assets |
|
(
|
|
|
|
(
|
|
Impairment loss of current assets (1) |
|
(
|
|
(
|
|
(
|
|
Profit in business combinations and field reversal (2) |
|
|
|
|
|
|
|
Other income |
|
|
|
|
|
|
|
|
|
|
|
(
|
|
(
|
|
(1) |
Corresponds mainly to the impairment of
|
|
(2) |
Includes the profit from: a) the acquisition of Repsol’s
|
F-104
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
29. Financial result
|
|
|
2024 |
|
2023 |
|
2022 |
|
Finance income |
|
|
|
|
|
|
|
Yields and interests |
|
|
|
|
|
|
|
Results from financial assets |
|
|
|
|
|
|
|
Gain on derivatives valuation |
|
|
|
|
|
|
|
Other financial income |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Finance expenses |
|
|
|
|
|
|
|
Interest (1) |
|
(
|
|
(
|
|
(
|
|
Financial cost of other liabilities (2) |
|
(
|
|
(
|
|
(
|
|
Results from financial assets |
|
(
|
|
(
|
|
(
|
|
Other financial expenses |
|
(
|
|
(
|
|
(
|
|
|
|
(
|
|
(
|
|
(
|
|
Foreign exchange gain |
|
|
|
|
|
|
|
Gain (loss) from exchange difference |
|
|
|
|
|
(
|
|
|
|
|
|
|
|
(
|
|
Financial result |
|
(
|
|
(
|
|
(
|
|
(1) |
As of December 31, 2024, interests on natural and environmental resources and property, plant, and equipment were capitalized for $
|
|
(2) |
Includes the financial expense for the update of the liability for cost of retirement obligation and the net interest on post-employment benefits and other long-term employee benefits. |
30 . Risk management
30.1 Exchange rate risk
The Ecopetrol Business Group operates mainly in Colombia and makes sales in the local and international markets, for that reason, it is exposed to exchange rate risk.
As of December 31, 2024, the Colombian peso depreciated
The balance of financial assets and liabilities denominated in foreign currency for the years ended December 31, is presented in the following table:
|
(in USD$Million) |
|
2024 |
|
2023 |
|
Cash and cash equivalents |
|
|
|
|
|
Other financial assets |
|
|
|
|
|
Trade receivables and payables, net |
|
(
|
|
(
|
|
Loans and borrowings |
|
(
|
|
(
|
|
Other assets and liabilities, net |
|
|
|
|
|
Net liability position |
|
(
|
|
(
|
Of the total net position, USD$(
F-105
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
30.2 |
Sensitivity analysis for exchange rate risk |
The following is the effect of a change of
|
Scenario / Variation in |
|
Effect on income |
|
Effect in other |
|
the exchange rates |
|
before taxes +/– |
|
comprehensive income +/– |
|
|
|
|
|
|
|
|
|
|
|
|
30.3 Cash flow hedge for future exports
To express in the consolidated financial statements, the effect of the existing natural hedge between exports and indebtedness, understanding that the exchange rate risk materializes when exports are made, On September 30, 2015, the Board of Directors made the first designation of Ecopetrol’s debt as a hedging instrument for its future income from crude oil exports.
The following is the movement of this non-derivative hedging instrument:
|
(US$Million) |
|
2024 |
|
2023 |
|
Hedging instrument at the beginning of the period |
|
|
|
|
|
Reassignment of hedging instruments |
|
|
|
|
|
Realization of exports |
|
(
|
|
(
|
|
Designation of new coverage |
|
|
|
|
|
Hedging instrument at the end of the period |
|
|
|
|
The following is the movement in other comprehensive income for the years ended December 31, 2024, 2023 and 2022:
|
|
|
2024 |
|
2023 |
|
2022 |
|
Opening balance |
|
|
|
(
|
|
(
|
|
Exchange difference |
|
(
|
|
|
|
(
|
|
Reclassification to profit or loss (Note 25) |
|
|
|
|
|
|
|
Ineffectiveness |
|
|
|
|
|
|
|
Deferred income tax (Note 10) |
|
|
|
(
|
|
|
|
Closing balance |
|
(
|
|
|
|
(
|
The expected reclassification of the cumulative exchange difference from other comprehensive income to the profit or loss is as follows:
|
Year |
|
Before taxes |
|
Taxes |
|
After taxes |
|
2025 |
|
(
|
|
|
|
(
|
|
2026 |
|
(
|
|
|
|
(
|
|
2027 |
|
(
|
|
|
|
(
|
|
2028 |
|
(
|
|
|
|
(
|
|
2029 |
|
(
|
|
|
|
(
|
|
2030 |
|
(
|
|
|
|
(
|
|
2031 |
|
(
|
|
|
|
(
|
|
2032 |
|
(
|
|
|
|
(
|
|
2033 |
|
(
|
|
|
|
(
|
|
|
|
(
|
|
|
|
(
|
F-106
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
30.4 Hedge of a net investment in a foreign operation
The Board of Directors approved the application of net investment hedge accounting from June 8, 2016. The measure is intended to reduce the volatility of non–operating income due to exchange rate variations. The net investment hedge will be applied on a portion of the Ecopetrol Business Group’s investments in foreign operations, in this case on investments in subsidiaries which have the U.S. dollar as their functional currency, using a portion of the Ecopetrol Business Group’s U.S. dollar denominated debt as the hedging instrument.
As of December 31, 2024, the total hedged balance is USD$
The following is the movement in other comprehensive income attributable to owners of parent:
|
|
|
2024 |
|
2023 |
|
2022 |
|
Opening balance |
|
|
|
|
|
|
|
Exchange difference |
|
|
|
(
|
|
|
|
Deferred income tax (Note 10) |
|
(
|
|
|
|
(
|
|
Closing balance |
|
|
|
|
|
|
30.5 Hedging with financial derivatives to mitigate exchange rate and interest rate risk
The ISA Group and Oleoducto Central S.A. have hedges with derivative financial instruments – CCS (Cross Currency Swaps) and nondelivery forward to hedge exchange rates. These hedges are recognized as cash flow hedges.
|
Company |
|
Derivative instrument |
|
2024 |
|
2023 |
|
Intervial Chile (1) |
|
Cross currency swap |
|
|
|
|
|
Oleoducto Central S.A. |
|
Non-delivery forward |
|
— |
|
|
|
(1) |
As of December 2024, it corresponds to a cross-currency swap ISA Intervial, which belongs to the toll roads segment in Chile. This derivative contract was signed in May 2021 with Itaú Corpbanca, to exchange the flows of debt contracted in Chilean pesos to Unidades de Fomento (UF). |
30.6 Commodity price risk
The price risk of raw materials is associated with Ecopetrol Business Group’s operations, both exports and imports of crude oil, natural gas, and refined products. To mitigate this risk, the Group has implemented hedges to partially protect the results from price fluctuations, considering that part of the financial exposure under contracts for the purchase of crude oil and refined products depends on the international oil prices.
The risk of such exposure is partially hedged in a natural way, as an integrated Business Group (with operations in the exploration and production, transportation and logistics and refining segments) and carries out both crude exports at international market prices and sales of refined products at prices correlated with international prices.
F-107
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
Ecopetrol Business Group has a policy for the execution of (strategic and tactical) hedges and implemented processes, procedures, and controls for their management:
| ● | The main purpose of the strategic hedging program is to protect the separate and consolidated financial statements against the volatility of market variables in each period, protect income and thus cash flow. Hedging plan has been executed to protect the cash and cash equivalents against low price scenarios below the budget base price, in this sense, put options were purchased. As of December 31, 2024, there was no balance of these financial instruments on the balance sheet. |
| ● | On the other hand, tactical hedges allow capturing value in trading operations and Asset Backed Trading (ABT), mitigating the market risk of specific operations. In the trading activity, the commitments in spot and forward physical contracts imply an exposure to commodity price risk, particularly the risk associated with the volatility of the price of crude oil and refined products. Although said exposure is part of the natural risk of the production, refining and marketing activity carried out by the Business group, sometimes marketing, to maximize value capture, can concentrate risk exposure in terms of term and/or or indicator that differs from the Company’s natural price risk profile. |
As of the date of this report, the Ecopetrol Business Group recognized a total net liability position in swaps of $
|
30.7 |
Credit risk |
Credit risk is the risk that the Ecopetrol Business Group may suffer financial losses because of default of: (a) payments by its clients for the sale of crude oil, gas, products, or services; (b) financial institutions in which it keeps investments, or (c) by counterparties with which it has contracted financial instruments.
Credit risk related to customers
In the selling process of crude oil, gas, refined products and petrochemicals, transport services, energy transmission, roads and telecommunications, the Ecopetrol Business Group may be exposed to credit risk if customers fail to fulfill their payment obligations. The Ecopetrol Business Group’s risk management strategy has designed mechanisms and procedures that aim to minimize such events, thus safeguarding the Ecopetrol Business Group’s cash flow.
The Ecopetrol Business Group performs a continuous analysis of the financial strength of its counterparties, by classifying them according to their risk level and financial guarantees in the event of a default of payments. Similarly, the Ecopetrol Business Group continuously monitors national and international market conditions for early alerts of major changes that may have an impact on the timely payment of obligations from customers.
For the receivables that are considered exposed to credit risk (Note 7), Ecopetrol Business Group make individual analysis of each customer’s situation to determine the value of impairment to recognize in financial statements. The Ecopetrol Business Group performs administrative and legal actions required to recover amounts past due and charges interest from customers that fail to comply with payment policies.
An aging analysis of the accounts receivable portfolio in arrears, but not impaired, as of December 31, 2024, and 2023 is as follows:
|
|
|
2024 |
|
2023 |
|
Less than 3 months overdue |
|
|
|
|
|
Between 3 and 6 months overdue |
|
|
|
|
|
More than 6 months overdue |
|
|
|
|
|
|
|
|
|
|
F-108
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
Credit risk in financial assets
Following the promulgation of Decree 1525 of 2008, which provides general rules on investments for public entities, Ecopetrol’s management established guidelines for its investment portfolios. These guidelines determine that investments in Ecopetrol’s U.S. dollar portfolios are generally limited to investments of cash excess in fixed–income securities issued by entities rated A or higher in the long term and A1/P1/F1 or higher in the short term (international scale) by Standard Poor’s Ratings Services, Moody’s Investors Service or Fitch Ratings.
In addition, Ecopetrol Business Group may also invest in securities issued or guaranteed by the United States of America or Colombia governments, without regard to the ratings assigned to such securities. In Ecopetrol’s Colombian Peso portfolio, it must invest the cash excess in fixed–income securities of issuers rated AAA in the long term, and F1+/BRC1+ in the short term (local scale) by Fitch Ratings Colombia or BRC Standard Poor’s. Likewise, the Company may also invest in securities issued or guaranteed by the National Government of Colombia without qualification restrictions.
To diversify the risk in the Colombian Peso portfolio, Ecopetrol Business Group does not invest more than
The credit rating of issuers and counterparties in transactions involving financial instruments is disclosed in Note 6 – Cash and cash equivalents, Note 9 – Other financial assets, and Note 22.2 – Plan assets.
|
30.8 |
Interest rate risk |
Interest rate risk arises from Ecopetrol’s exposure to changes in interest rates because the Ecopetrol Business Group has investments in fixed and floating–rate instruments and has issued floating rate debt linked to SOFT, DTF, and CPI interest rates. Thus, interest rate volatility may affect the fair value and cash flows of the Ecopetrol Business Group’s investments and the financial expense of floating rate loans and financing.
As of December 31, 2024,
Ecopetrol Business Group controls the exposure to interest rate risk by establishing limits to the portfolio duration, Value at Risk – VAR and tracking error.
Autonomous equities linked to Ecopetrol Business Group’s pension obligations are also exposed to changes in interest rate, as they include fixed and floating rate instruments that are recognized according to the mark to market. Colombian regulation for pension funds, as stipulated in the Decree 941 of 2002 and Decree 1861 of 2012, indicates that they must follow the same regime as the regular obligatory pension funds in their moderate portfolio.
The following table provides information about the sensitivity of the Ecopetrol Business Group’s results and other comprehensive income for the next 12 months to variations in interest rate of 100 basis points:
|
|
|
|
|
|
|
Effect on Other |
|
|
|
Effect on profit or loss (+/–) |
|
Comprehensive Income (+/–) |
||
|
|
|
Financial |
|
Financial |
|
|
|
|
|
Assets * |
|
Liabilities |
|
Plan Assets |
|
+100 basis points |
|
(
|
|
(
|
|
|
|
–100 basis points |
|
|
|
(
|
|
(
|
|
(*) |
This sensitivity was executed for portfolios of Ecopetrol S.A. and Black Gold Re. These are the most relevant of the Ecopetrol Business Group. |
A sensitivity analysis of discount rates on pension plan assets and liabilities is disclosed in Note 22 – Provisions for employees’ benefits.
F-109
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
30.9 Liquidity risk
The ability to access credit and capital markets to obtain resources for the investment plan execution for Ecopetrol Business Group may be limited due to adverse changes in market conditions. A global financial crisis could worsen risk perception in emerging markets.
Events that could affect the political and regional environment of Colombia may make it difficult for our subsidiaries to access the capital markets. These conditions, together with potential significant losses in the financial services sector and changes in credit risk assessments, may make it difficult to obtain resources on favorable terms. As a result, the Ecopetrol Business Group may be forced to review the conditions of the investment plan, or access financial markets under unfavorable terms, thereby negatively affecting the Ecopetrol Business Group’s results of operations and financial results.
Liquidity risk is managed in accordance with the Ecopetrol Business Group’s policies aimed at ensuring that enough cash flows to comply with the Ecopetrol Business Group’s financial commitments within the established dates and with no additional costs. The main method for the measurement and monitoring of liquidity is cash flow forecasting.
The following is a summary of the maturity of financial liabilities as of December 31, 2024. The amounts disclosed in the table are the contractual undiscounted cash flows. The payments in foreign currency were restated taking a constant exchange rate of COP$
|
|
|
Up to 1 year |
|
1–5 years |
|
5–10 years |
|
10 years |
|
Total |
|
Loans (payment of principal and interest) |
|
|
|
|
|
|
|
|
|
|
|
Trade and other payables |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
30.10 Risk and opportunities related to climate (Unaudited)
The Ecopetrol Business Group carries out two types of analysis for climate-related risks and opportunities. The first seeks to adapt the business strategy to the energy transition and the other focuses on climate scenarios to identify the level of risk.
|
● |
Physical risks: They are related to the exposure and vulnerability of the Ecopetrol Business Group to the impacts of climate change and climate variability, which could affect operational continuity and increase the exposure of assets to possible damage and loss. Physical risks are classified as acute and chronic. |
|
o |
Acute risks are those caused by extreme weather events, the frequency and intensity of which have been increasing due to the gradual rise in global temperature. In Colombia, they are mainly reflected in the occurrence of the climate variability phenomenon “El Niño” and its opposite phase “La Niña”. These conditions could result in, among others, water shortages, heat waves, floods and fires. |
For the fourth quarter, the phenomenon of “La Niña” continues to be monitored, and the Ecopetrol Business Group has an action plan in place in case the phenomenon materializes.
F-110
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
o |
Chronic risks, arising from a sustained medium- and long-term change in climate conditions, which for the Ecopetrol Business Group can be reflected in rising sea levels, thermal overload and droughts beyond 2050. |
The physical risk analysis considered the following climate change scenarios from the Intergovernmental Panel on Climate Change (IPCC), with a horizon up to 2100, inclusive: (i) Aligned with the objective of the Paris Agreement (SSP 1 / RCP 2.6), (ii) Peak emissions in 2040 (SSP2 / RCP4.5), and (iii) ‘Business as Usual’ (SSP5 / RCP8.5). Under these scenarios, seven (7) chronic (drought and thermal stress) and acute (precipitation, coastal and river flooding, fires and winds) threats were evaluated at 95 points associated with the main assets of the Ecopetrol Business Group. The results of the analysis must provide an additional local-scale analysis, prioritizing the assets with the greatest exposure and vulnerability.
|
● |
Transition risk: They are related to the challenges that the Ecopetrol Business Group has identified to transition towards a low-carbon, sustainable and competitive operation. Ecopetrol carried out a prioritization of transition risks to establish their financial impact, identifying the following: |
|
o |
Regulatory risk, associated with regulatory changes that may directly affect the Company in the short and medium term. Among the regulatory changes, the following can be highlighted: (i) new information requirements associated with mitigation and adaptation for the application or modification of current and future licenses, (ii) greater demands associated with the regulations for the detection and repair of leaks, flaring and gas venting, (iii) Limitations on the use of compensation to meet decarbonization goals, (iv) new requirements for the validation and verification of reduction projects and their registration in the National Registry of Greenhouse Gas Emission Reductions (RENARE), (v) launching of the National Program of Tradable Emissions Quotas (PNCTE), similar to an Emissions Trading System, in which emission rights would be assigned. This program is currently in the design and development phase of the regulatory framework and is scheduled to come into effect in 2025 with full implementation in 2030. At the international level, the SEC (Securities Exchange Commission) rule on disclosure of climate-related information is under review, which may be adopted by the Colombian Financial Superintendence and modify current circulars. |
During 2023, the National Environmental Licensing Authority (ANLA) incorporated into applications for environmental licenses, license modifications or minor changes in production and exploration, requirements associated with the quantification of GHG emissions, mitigation actions, vulnerability and climate risk analysis, and adaptation actions, within the framework of the Comprehensive Business Climate Change Management Plan (PIGCCe). The report on compliance with these requirements must be presented in the Environmental Compliance Reports (ICAs). As of December 31, 2024, no modification requests were submitted. The document associated with the PIGCCe is available for public consultation.
|
o |
Legal risk, associated with the negative reactions and lawsuits against the climate action of the company. |
|
o |
Risk of assets trapped in the traditional business of hydrocarbon production, transportation, and refining, considering factors such as fuel demand prospects and asset profit horizons. |
|
o |
Market risk, related to the change in preferences in the use of low-carbon products in the long term, which implies a risk for Ecopetrol Business Group of not being able to meet market demand and of not advancing effectively in the development of these products. |
|
o |
Reputational risk, associated with the impossibility of responding in a timely way to the expectations and demand of investors and other interest groups to establish ambitious objectives regarding climate change, which would affect the image of Ecopetrol Business Group. |
|
o |
Technological risk, associated with the negative effects on the profitability of the business if there is no preparation and capacity to adapt to new technologies because of the transition process. |
F-111
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
The transition risk analysis considered the market and regulatory risks with the highest probability of materialization and were evaluated under the three scenarios of the International Energy Agency’s (IEA) World Energy Outlook 2022: (i) Net Zero Emissions (NZE), (ii) Announced Pledges Scenario (APS), and (iii) Stated Policies Scenario (STEPS). In market risk, as a first approach, the impact on the value of the assets of the Upstream segment and their resilience to different expectations of hydrocarbon demand were analyzed. In the APS and STEPS scenarios, the oil business shows resilience to volatility. However, this exercise cannot be considered absolute, since the IEA scenarios do not consider the dynamics of local energy demand, especially in the natural gas market. Regarding regulatory risk, the regulatory evolution related to the energy transition and climate change involves regulatory changes that may directly affect the Ecopetrol Business Group in the short and medium term. The Ecopetrol Business Group is committed to making a significant contribution to national and sectoral goals, which in the future may be reflected in potential mandatory requirements. Faced with this risk, the Ecopetrol Business Group evaluated two routes: i) quantification of the impact on costs associated with a potential change in carbon prices and ii) quantification of the financial repercussions derived from higher abatement costs, due to limitations in the use of offsets, to analyze the effects on cash flow and potential capital allocation needs to enable the entry of new abatement opportunities to achieve decarbonization goals.
Additionally, in regulatory terms, the Ministry of Environment and Sustainable Development of Colombia has launched a public consultation on the draft decree that will regulate the National Program of Tradable Greenhouse Gas Emission Quotas (PNCTE), an economic instrument established as one of the means of implementing Colombia’s Nationally Determined Contribution (NDC). This future regulation could have an impact on the decarbonization goals of the Ecopetrol Business Group.
To manage the risks identified, Ecopetrol Business Group defined the strategic risk as “Inadequate response to challenges associated with climate change, water, and biodiversity”, which includes treatment actions, Key Risk Indicators (KRI) and controls to effectively manage the causes and mitigate the materialization of the risk. This definition as a corporate risk allows the Ecopetrol Business Group to define actions to advance towards decarbonization and the fulfillment of medium and long-term goals and adaptation to climate variability and normal weather conditions in the country, to mitigate the effects associated with water availability and security in the regions, energy security, among others.
| ● | Climate-related opportunities: these arise from the analysis of climate-related risks, the review of energy transition scenarios, the implementation of the decarbonization plan and the alignment with the 2040 “Energy that Transforms” strategy. In the process of identifying and assessing opportunities, Ecopetrol Business Group monitors and evaluates the energy market and the business environment by defining energy transition scenarios that guide the long-term strategic analysis of the Ecopetrol Business Group (2040). Opportunities related to the diversification of traditional business, diversification into sustainable businesses, energy efficiency, and renewable energy have been identified. |
| o | Diversification of traditional business: Ecopetrol Group has identified opportunities to make its hydrocarbon business more resilient, taking advantage of the gas outlook, the need for logistics and transportation for other types of fuels and energy, and the growing demand for more sustainable petrochemical products. |
| o | Diversification into sustainable businesses: Considering that the demand for solutions and services in this line will increase in the coming decades, the Group defines, within its pillar of “Growing with the energy transition”, the potential for generating EBITDA in the following business lines: Transmission, roads, and telecommunications (through ISA) and Energies for the transition (natural gas, hydrogen, Carbon Capture, Use and Storage, mainly). |
| o | Energy efficiency: Ecopetrol, being one of the largest consumers of energy in Colombia and representing a tenth of the country’s consumption, is committed to the Energy Transition. This forces the Company to be an example of how to optimize consumption as a key lever to face climate change. |
| o |
Renewable energy:
This is one of the Group’s strategic levers. The Business Group seeks to have an installed capacity of
|
During 2024, progress was made in reviewing the long-term strategy, to analyze other opportunities associated with the energy transition.
F-112
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
30.11 Capital management
The main objective of the capital management of the Ecopetrol Business Group is to ensure a financial structure that optimizes the cost of capital, maximizes the rate of return to its shareholders and allows access to financial markets at a competitive cost to cover financial needs.
The following is the leverage ratio as of December 31:
|
|
|
2024 |
|
2023 |
|
|
Loans and borrowings (Note 20) |
|
|
|
|
|
|
Cash and cash equivalents (Note 6) |
|
(
|
|
(
|
|
|
Other financial assets (Note 9) |
|
(
|
|
(
|
|
|
Net financial debt |
|
|
|
|
|
|
Equity (Note 24) |
|
|
|
|
|
|
Leverage (1) |
|
|
% |
|
% |
| (1) | Net financial debt / (Net financial debt + Equity) |
31. Related parties
Balances with associates and joint ventures as of December 31, 2024, and 2023 are as follows:
|
|
|
|
|
Accounts |
|
|
|
|
|
|
|
|
|
Accounts |
|
receivable |
|
Other |
|
Accounts |
|
|
|
|
|
receivable |
|
– Loans |
|
assets |
|
payable |
|
Loans |
|
Joint Ventures |
|
|
|
|
|
|
|
|
|
|
|
Equion Energía Limited |
|
|
|
|
|
|
|
|
|
|
|
Ecodiesel Colombia S.A. |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica do Madeira S.A. |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Garanhuns S.A. |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Paraguaçu S.A. |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Aimorés S.A. |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Ivaí S.A. |
|
|
|
|
|
|
|
|
|
|
|
Transmissora Aliança de Energia Elétrica S.A. |
|
|
|
|
|
|
|
|
|
|
|
Consorcio Eléctrico Yapay |
|
|
|
|
|
|
|
|
|
|
|
Conexión Kimal Lo Aguirre S.A. |
|
|
|
|
|
|
|
|
|
|
|
Associates |
|
|
|
|
|
|
|
|
|
|
|
Gases del Caribe S.A. E.S.P. |
|
|
|
|
|
|
|
|
|
|
|
Extrucol S.A. |
|
|
|
|
|
|
|
|
|
|
|
E2 Energía Eficiente S.A. E.S.P. |
|
|
|
|
|
|
|
|
|
|
|
Balance as of December 31, 2024 |
|
|
|
|
|
|
|
|
|
|
|
Current |
|
|
|
|
|
|
|
|
|
|
|
Non–current |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(Note 7) |
|
(Note 7) |
|
(Note 11) |
|
(Note 21) |
|
(Note 20) |
F-113
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
|
|
|
|
Accounts |
|
|
|
|
|
|
|
|
|
|
|
Accounts |
|
receivable |
|
Other |
|
Accounts |
|
|
|
Other |
|
|
|
receivable |
|
– Loans |
|
assets |
|
payable |
|
Loans |
|
liabilities |
|
Joint Ventures |
|
|
|
|
|
|
|
|
|
|
|
|
|
Equion Energía Limited |
|
|
|
|
|
|
|
|
|
|
|
|
|
Ecodiesel Colombia S.A. |
|
|
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica do Madeira S.A. |
|
|
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Garanhuns S.A. |
|
|
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Paraguaçu S.A. |
|
|
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Aimorés S.A. |
|
|
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Ivaí S.A. |
|
|
|
|
|
|
|
|
|
|
|
|
|
Transmissora Aliança de Energia Elétrica S.A. |
|
|
|
|
|
|
|
|
|
|
|
|
|
Conexión Kimal Lo Aguirre S.A. |
|
|
|
|
|
|
|
|
|
|
|
|
|
Associates |
|
|
|
|
|
|
|
|
|
|
|
|
|
Gas Natural del Oriente S.A. E.S.P. |
|
|
|
|
|
|
|
|
|
|
|
|
|
Extrucol S.A. |
|
|
|
|
|
|
|
|
|
|
|
|
|
E2 Energía Eficiente S.A. E.S.P. |
|
|
|
|
|
|
|
|
|
|
|
|
|
Internexa Brasil Operadora de Telecomunicaciones |
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of December 31, 2023 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Current |
|
|
|
|
|
|
|
|
|
|
|
|
|
Non–current |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(Note 7) |
|
(Note 7) |
|
(Note 11) |
|
(Note 21) |
|
(Note 20) |
|
|
Loans:
|
(1) |
|
The main transactions with related parties as of December 31 are detailed as follows:
|
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2024 |
|
2023 |
|
2022 |
||||||
|
|
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Sales and |
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Purchases |
|
Sales and |
|
Purchases |
|
Sales and |
|
Purchases |
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|
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services |
|
and others |
|
services |
|
and others |
|
services |
|
and others |
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Joint Ventures |
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Equion Energy Limited |
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Ecodiesel Colombia S.A. |
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Associates |
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Gases del Caribe S.A. E.S.P. |
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Gas Natural del Oriente S.A. E.S.P. |
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Extrucol S.A. |
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E2 Energía Eficiente S.A. E.S.P. |
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F-114
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
31.1 Directors and key management personnel
In accordance with the approval given by the shareholders’ meeting in 2012, which was recorded in Minute No. 026, the directors’ fees for attending the meetings of the Board of Directors and / or the committees increase from four to six legal monthly minimum legal monthly salaries in force.
On the other hand, in the General Shareholders’ Meeting of 2018, the amendment of the Corporate Bylaws that appears in Minute No. 036 was approved, by virtue of which, the fourth paragraph of article 23 was eliminated that made the differentiation between the fees for face-to-face and non-face-to-face meetings. The members of the Board of Directors do not have any kind of variable remuneration. The amount paid in 2024 for fees to members of the Board of Directors amounted to $
The total compensation paid to Executive Officers and Senior Managers as of December 31, 2024, amounted to $
As of December 31, 2024, Germán González, one of the key directors of management, owned shares of Ecopetrol S.A., which are equivalent to
31.2 Post–employment benefit plans
The administration and management of resources for payment of Ecopetrol’s pension obligations are managed by autonomous pension funds (PAPs, by its acronym in Spanish) which serve as guarantee and payment sources. In 2008, Ecopetrol S.A. received the authorization to partially commute the value corresponding to monthly payments, bonds, and quotas, transferring said obligations and the money that support them to autonomous patrimonies of a pension nature, in accordance with the requirements of Decree 1833 of 2016.
Since 2016, the entities that manage the resources are: Fiduciaria Bancolombia, Fiduciaria de Occidente, and Consorcio Ecopetrol PACC (formed by Fiduciaria La Previsora, Fiduciaria Bancoldex, Fiduagraria, and Fiduciaria Central). These fiduciaries will manage the pension resources for a period of five years (2016-2021) and as compensation they receive remuneration with fixed and variable components, the latter being settled on the gross returns of the portfolios and charged to the managed resources.
Starting in 2023, and after a rigorous selection and asset allocation process, the new administrators of the Pension Liabilities until December 2028 are: BBVA Asset Management, Fiduciaria Bogotá, Fiduciaria BBVA and the Ecopetrol PACC 2022 Consortium made up of Fiduciaria La Previsora, Fiduciaria Bancoldex, Fiduagraria, and Fiduciaria Central.
F-115
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
31.3 |
Government related parties |
The Colombian Government controls Ecopetrol S.A. with a stock ownership of
(a) Purchase of oil from the National Hydrocarbons Agency – ANH
The ANH, an entity which operates under the rules of the Ministry of Mines and Energy, has as objective to manage the oil and gas reserves and resources owned by the Colombian Nation.
In accordance with the nature of the purchase and sale contract business, Ecopetrol purchases the crude oil from ANH that it receives from some producers in Colombia at prices set in accordance with an established formula, which reflects the sales prices, with adjustment to the quality of API gravity, sulfur content, transportation rates, to export ports or to the Barrancabermeja and/or Cartagena refineries.
The purchase value of oil and gas from ANH is detailed in Note 26 - Cost of sales.
(b) Refined Price Stabilization Fund
The sale prices of regular gasoline and diesel are regulated by the National Government. In that way, there are differentials between the volume reported by the companies at the time of sale and the difference between the parity price and the reference price, the parity price being the one that corresponds to the daily prices of motor gasoline and diesel observed during the month. This differential can be for or against the producers. The value of this differential is detailed in Note 25 - Revenue from contracts with customers and in Note 7 - Trade and other receivables.
(c) National Tax and Customs Direction
Ecopetrol Business Group, just like any other company in Colombia, has tax obligations that it must comply with and does not have any other kind of association or commercial relationship with the National Tax and Customs Direction of Colombia.
(d) Comptroller General of the Republic
Ecopetrol Business Group, just like any other state entity in Colombia, is obliged to comply with the requirements set out by the Comptroller General of the Republic and make an annual payment to this entity on account of a maintenance fee. Ecopetrol Business Group does not have any other kind of association or commercial relationship with this entity.
32. Joint operations
The Ecopetrol Business Group carries out exploration and production operations through Exploration and Production (EP) Contracts, Technical Evaluation (TEA) Contracts and Agreements signed with the National Hydrocarbons Agency or ANH, as well as through Partnership Contracts and other types of contracts.
F-116
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
The main joint operations in 2024 are as follows:
32.1 Contracts in which Ecopetrol Business Group is not the operator
|
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% |
|
Geographic area of |
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Partners |
|
Contract |
|
Type |
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Participation |
|
operations |
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|
|
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|
SierraCol Energy Arauca, LLC |
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Frontera Energy Colombia Corp |
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Union Temporal Ismocol Joshi Parko |
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According amendment number 5 |
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Parex Resources Colombia LTD |
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Anadarko Colombia Company (OXY) |
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Petrobras |
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Shell EP Offshore ventures Limited |
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Interoil Colombia |
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Geopark Colombia SAS |
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Lewis Energy Colombia |
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Quarter North Energy |
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Murphy Exploration and Production Company – USA |
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|
OXY (Anadarko) - K2 |
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HESS |
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Shell |
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Occidental Midland Basin, LLC |
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(Oxy) |
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Occidental Midland Basin, LLC (Oxy) |
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Pemex Exploration y Production |
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PC Carigali Mexico Operation SA |
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F-117
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
32.2 Contracts in which Ecopetrol Business Group is the operator
|
|
|
|
|
|
|
% |
|
Geographic area of |
|
Partners |
|
Contract |
|
Type |
|
Participation |
|
operations |
|
|
|
|
|
|
|
|
|
|
|
ExxonMobil Exploration Colombia |
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CPVEN EP Corp Sucursal Colombia |
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Repsol Exploration Colombia S.A. |
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Emerald Energy PLC Suc. Colombia |
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Parex Resourses Colombia Ltd. |
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SierraCol Energy Arauca, LLC |
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Total Colombie |
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Repsol Colombia Oil Gas |
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Emerald Energy |
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Frontera Energy |
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Perenco Oil and Gas |
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CNOOC Internantional |
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Lewis Energy Colombia |
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Perenco Oil and Gas |
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Cedco |
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|
** Fields in abandonment process.
The Group acquires investment commitments at the moment of receiving the exploration and/or exploitation rights of a determined area by the competent authority. As of December 31, 2024, investment commitments with the ANH reach USD $
Ecopetrol Permian LLC has commitments related to the five-year business plan in the Permian Basin under the Rodeo Midland Basin LLC formation agreement, which may be modified annually by contract members, and Ecopetrol América LLC commitments derived from the joint operations in the Gulf of Mexico through authorizations for expenditures (AFEs) for projects of both a capital nature and operating expenses.
33. Information by segments
A description of the Ecopetrol Business Group’s business segments is in Note 4.20 - Information by business segment.
The following segment information is reported based on the information used by the Board of Directors as the top body to make strategic and operational decisions of these business segments. The performance of the segments is based primarily on an analysis of income, costs, expenses, and results for the period generated by each segment which are regularly monitored.
The information disclosed in each segment is presented net of transactions between the Ecopetrol Business Group companies.
F-118
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
33.1 Statement of profit or loss
Below are the consolidated statements of profit or loss by segment for the years ended December 31, 2024, 2023 and 2022:
|
|
|
For the year ended on December 31, 2024 |
||||||||||
|
|
|
|
|
|
|
|
|
Electric |
|
|
|
|
|
|
|
|
|
|
|
|
|
power |
|
|
|
|
|
|
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|
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|
|
|
|
transmission |
|
|
|
|
|
|
|
Exploration |
|
|
|
Transport |
|
and toll |
|
|
|
|
|
|
|
and |
|
Refining and |
|
and |
|
roads |
|
|
|
|
|
|
|
Production |
|
Petrochemicals |
|
Logistics |
|
concessions |
|
Eliminations |
|
Total |
|
Third–party sales |
|
|
|
|
|
|
|
|
|
— |
|
|
|
Inter–segment sales |
|
|
|
|
|
|
|
|
|
(
|
|
— |
|
Revenue from contracts with customers |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
Variable cost |
|
(
|
|
(
|
|
(
|
|
— |
|
|
|
(
|
|
Fixed cost |
|
(
|
|
(
|
|
(
|
|
(
|
|
|
|
(
|
|
Cost of sales |
|
(
|
|
(
|
|
(
|
|
(
|
|
|
|
(
|
|
Gross profit |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Administrative expenses |
|
(
|
|
(
|
|
(
|
|
(
|
|
|
|
(
|
|
Operation and project expenses |
|
(
|
|
(
|
|
(
|
|
— |
|
|
|
(
|
|
Impairment (loss) reversal of non–current assets |
|
(
|
|
|
|
|
|
(
|
|
— |
|
|
|
Other operating (expenses) income net |
|
|
|
|
|
(
|
|
(
|
|
(
|
|
|
|
Operating income |
|
|
|
|
|
|
|
|
|
|
|
|
|
Financial result net |
|
|
|
|
|
|
|
|
|
|
|
|
|
Financial income |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
Financial expenses |
|
(
|
|
(
|
|
(
|
|
(
|
|
|
|
(
|
|
Foreign exchange (loss) gain net |
|
(
|
|
(
|
|
|
|
(
|
|
— |
|
|
|
|
|
(
|
|
(
|
|
|
|
(
|
|
(
|
|
(
|
|
Share of profits of associates and joint ventures |
|
|
|
|
|
— |
|
|
|
— |
|
|
|
Income before tax |
|
|
|
(
|
|
|
|
|
|
|
|
|
|
Income tax |
|
(
|
|
(
|
|
(
|
|
(
|
|
— |
|
(
|
|
Net profit (loss) for the period |
|
|
|
(
|
|
|
|
|
|
|
|
|
|
Profit (loss) attributable to: |
|
|
|
|
|
|
|
|
|
|
|
|
|
Group owners of parent |
|
|
|
(
|
|
|
|
|
|
|
|
|
|
Non–controlling interest |
|
(
|
|
|
|
|
|
|
|
— |
|
|
|
|
|
|
|
(
|
|
|
|
|
|
|
|
|
|
Supplementary information |
|
|
|
|
|
|
|
|
|
|
|
|
|
Depreciation, depletion and amortization |
|
|
|
|
|
|
|
|
|
— |
|
|
F-119
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
|
|
For the year ended on December 31, 2023 |
||||||||||
|
|
|
|
|
|
|
|
|
Electric |
|
|
|
|
|
|
|
|
|
|
|
|
|
power |
|
|
|
|
|
|
|
|
|
|
|
|
|
transmission |
|
|
|
|
|
|
|
|
|
|
|
|
|
and toll |
|
|
|
|
|
|
|
Exploration |
|
Refining and |
|
Transport and |
|
roads |
|
|
|
|
|
|
|
and Production |
|
Petrochemicals |
|
Logistics |
|
concessions |
|
Eliminations |
|
Total |
|
Third–party sales |
|
|
|
|
|
|
|
|
|
— |
|
|
|
Inter–segment sales |
|
|
|
|
|
|
|
|
|
(
|
|
— |
|
Revenue from contracts with customers |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
Variable cost |
|
(
|
|
(
|
|
(
|
|
— |
|
|
|
(
|
|
Fixed cost |
|
(
|
|
(
|
|
(
|
|
(
|
|
|
|
(
|
|
Cost of sales |
|
(
|
|
(
|
|
(
|
|
(
|
|
|
|
(
|
|
Gross profit |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Administrative expenses |
|
(
|
|
(
|
|
(
|
|
(
|
|
|
|
(
|
|
Operation and project expenses |
|
(
|
|
(
|
|
(
|
|
— |
|
|
|
(
|
|
Impairment (loss) reversal of non–current assets |
|
(
|
|
|
|
(
|
|
(
|
|
— |
|
(
|
|
Other operating (expenses) income net |
|
(
|
|
(
|
|
|
|
(
|
|
(
|
|
(
|
|
Operating income |
|
|
|
|
|
|
|
|
|
|
|
|
|
Financial result net |
|
|
|
|
|
|
|
|
|
|
|
|
|
Financial income |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
Financial expenses |
|
(
|
|
(
|
|
(
|
|
(
|
|
|
|
(
|
|
Foreign exchange gain (loss) net |
|
|
|
|
|
(
|
|
|
|
— |
|
|
|
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
Share of profits of associates and joint ventures |
|
|
|
|
|
— |
|
|
|
(
|
|
|
|
Income before tax |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
Income tax |
|
(
|
|
|
|
(
|
|
(
|
|
— |
|
(
|
|
Net profit (loss) for the period |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
Profit (loss) attributable to: |
|
|
|
|
|
|
|
|
|
|
|
|
|
Group owners of parent |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
Non–controlling interest |
|
(
|
|
|
|
|
|
|
|
— |
|
|
|
|
|
|
|
|
|
|
|
|
|
(
|
|
|
|
Supplementary information |
|
|
|
|
|
|
|
|
|
|
|
|
|
Depreciation, depletion and amortization |
|
|
|
|
|
|
|
|
|
— |
|
|
F-120
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
|
|
For the year ended on December 31, 2022 |
||||||||||
|
|
|
|
|
|
|
|
|
Electric |
|
|
|
|
|
|
|
|
|
|
|
|
|
power |
|
|
|
|
|
|
|
|
|
|
|
|
|
transmission |
|
|
|
|
|
|
|
|
|
|
|
|
|
and toll |
|
|
|
|
|
|
|
Exploration and |
|
Refining and |
|
Transport |
|
roads |
|
|
|
|
|
|
|
Production |
|
Petrochemicals |
|
and Logistics |
|
concessions |
|
Eliminations |
|
Total |
|
Third–party sales |
|
|
|
|
|
|
|
|
|
— |
|
|
|
Inter–segment sales |
|
|
|
|
|
|
|
|
|
(
|
|
— |
|
Revenue from contracts with customers |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
Variable cost |
|
(
|
|
(
|
|
(
|
|
— |
|
|
|
(
|
|
Fixed cost |
|
(
|
|
(
|
|
(
|
|
(
|
|
|
|
(
|
|
Cost of sales |
|
(
|
|
(
|
|
(
|
|
(
|
|
|
|
(
|
|
Gross profit |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Administrative expenses |
|
(
|
|
(
|
|
(
|
|
(
|
|
|
|
(
|
|
Operation and project expenses |
|
(
|
|
(
|
|
(
|
|
— |
|
|
|
(
|
|
Impairment loss (reversal) of non–current assets |
|
(
|
|
|
|
(
|
|
(
|
|
— |
|
(
|
|
Other operating expenses net |
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
Operating income |
|
|
|
|
|
|
|
|
|
|
|
|
|
Financial result net |
|
|
|
|
|
|
|
|
|
|
|
|
|
Financial income |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
Financial expenses |
|
(
|
|
(
|
|
(
|
|
(
|
|
|
|
(
|
|
Foreign exchange gain (loss) net |
|
(
|
|
(
|
|
|
|
|
|
— |
|
(
|
|
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
Share of profits of associates and joint ventures |
|
|
|
|
|
— |
|
|
|
|
|
|
|
Income before tax |
|
|
|
|
|
|
|
|
|
|
|
|
|
Income tax |
|
(
|
|
(
|
|
(
|
|
(
|
|
— |
|
(
|
|
Net profit (loss) for the period |
|
|
|
|
|
|
|
|
|
|
|
|
|
Profit (loss) attributable to: |
|
|
|
|
|
|
|
|
|
|
|
|
|
Group owners of parent |
|
|
|
|
|
|
|
|
|
|
|
|
|
Non–controlling interest |
|
(
|
|
|
|
|
|
|
|
— |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Supplementary information |
|
|
|
|
|
|
|
|
|
|
|
|
|
Depreciation depletion and amortization |
|
|
|
|
|
|
|
|
|
— |
|
|
F-121
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
33.2 Sales by product
The sales by product for each segment are detailed below for the years ended December 31, 2024, 2023 and 2022:
|
|
|
For the year ended on December 31, 2024 |
||||||||||
|
|
|
|
|
|
|
|
|
Electric power |
|
|
|
|
|
|
|
|
|
|
|
|
|
transmission |
|
|
|
|
|
|
|
|
|
|
|
|
|
and toll |
|
|
|
|
|
|
|
Exploration and |
|
Refining and |
|
Transport and |
|
roads |
|
|
|
|
|
|
|
Production |
|
Petrochemicals |
|
Logistics |
|
concessions |
|
Eliminations |
|
Total |
|
Local sales |
|
|
|
|
|
|
|
|
|
|
|
|
|
Mid-distillates |
|
— |
|
|
|
— |
|
— |
|
(
|
|
|
|
Gasoline and turbo fuels |
|
— |
|
|
|
— |
|
— |
|
(
|
|
|
|
Roads and construction services |
|
— |
|
— |
|
— |
|
|
|
— |
|
|
|
Gas natural |
|
|
|
— |
|
— |
|
— |
|
(
|
|
|
|
Services |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
Fuel gas service |
|
— |
|
|
|
— |
|
— |
|
(
|
|
|
|
LPG and propane |
|
|
|
|
|
— |
|
— |
|
(
|
|
|
|
Asphalts |
|
|
|
|
|
— |
|
— |
|
— |
|
|
|
Plastic and rubber |
|
— |
|
|
|
— |
|
— |
|
— |
|
|
|
Crude oil |
|
|
|
— |
|
— |
|
— |
|
(
|
|
|
|
Electric power transmission services |
|
— |
|
— |
|
— |
|
|
|
— |
|
|
|
Polyethylene |
|
— |
|
|
|
— |
|
— |
|
|
|
|
|
Aromatics |
|
— |
|
|
|
— |
|
— |
|
— |
|
|
|
Fuel oil |
|
|
|
|
|
— |
|
— |
|
— |
|
|
|
Other products |
|
|
|
|
|
|
|
— |
|
(
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Foreign sales |
|
|
|
|
|
|
|
|
|
|
|
|
|
Crude oil |
|
|
|
|
|
— |
|
— |
|
(
|
|
|
|
Electric power transmission services |
|
— |
|
— |
|
— |
|
|
|
— |
|
|
|
Roads and Construction Services |
|
— |
|
— |
|
— |
|
|
|
— |
|
|
|
Diesel |
|
— |
|
|
|
— |
|
— |
|
— |
|
|
|
Fuel oil |
|
— |
|
|
|
— |
|
— |
|
— |
|
|
|
Plastic and rubber |
|
— |
|
|
|
— |
|
— |
|
— |
|
|
|
LPG and propane |
|
|
|
— |
|
— |
|
— |
|
— |
|
|
|
Gasoline and turbo fuels |
|
|
|
— |
|
— |
|
— |
|
— |
|
|
|
Natural gas |
|
— |
|
|
|
— |
|
— |
|
(
|
|
|
|
Cash flow hedging |
|
(
|
|
— |
|
— |
|
— |
|
— |
|
(
|
|
Other products |
|
|
|
|
|
— |
|
|
|
(
|
|
|
|
|
|
|
|
|
|
— |
|
|
|
(
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(
|
|
|
F-122
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
|
|
For the year ended on December 31, 2023 |
||||||||||
|
|
|
|
|
|
|
|
|
Electric power |
|
|
|
|
|
|
|
|
|
|
|
|
|
transmission |
|
|
|
|
|
|
|
|
|
|
|
|
|
and toll |
|
|
|
|
|
|
|
Exploration and |
|
Refining and |
|
Transport and |
|
roads |
|
|
|
|
|
|
|
Production |
|
Petrochemicals |
|
Logistics |
|
concessions |
|
Eliminations |
|
Total |
|
Local sales |
|
|
|
|
|
|
|
|
|
|
|
|
|
Mid-distillates |
|
— |
|
|
|
— |
|
— |
|
(
|
|
|
|
Gasoline and turbo fuels |
|
— |
|
|
|
— |
|
— |
|
(
|
|
|
|
Natural gas |
|
|
|
— |
|
— |
|
— |
|
(
|
|
|
|
Services |
|
(
|
|
|
|
|
|
|
|
(
|
|
|
|
Electric power transmission services |
|
— |
|
— |
|
— |
|
|
|
— |
|
|
|
Plastic and rubber |
|
— |
|
|
|
— |
|
— |
|
— |
|
|
|
Fuel gas service |
|
— |
|
|
|
— |
|
— |
|
(
|
|
|
|
Asphalts |
|
|
|
|
|
— |
|
— |
|
— |
|
|
|
LPG and propane |
|
|
|
|
|
— |
|
— |
|
(
|
|
|
|
Roads and construction services |
|
— |
|
— |
|
— |
|
|
|
— |
|
|
|
Polyethylene |
|
— |
|
|
|
— |
|
— |
|
|
|
|
|
Aromatics |
|
— |
|
|
|
— |
|
— |
|
— |
|
|
|
Crude oil |
|
|
|
(
|
|
— |
|
— |
|
(
|
|
|
|
Fuel oil |
|
|
|
|
|
— |
|
— |
|
— |
|
|
|
Other income gas contracts |
|
|
|
— |
|
— |
|
— |
|
— |
|
|
|
Other products |
|
|
|
|
|
— |
|
— |
|
(
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Foreign sales |
|
|
|
|
|
|
|
|
|
|
|
|
|
Crude oil |
|
|
|
|
|
— |
|
— |
|
— |
|
|
|
Electric power transmission services |
|
— |
|
— |
|
— |
|
|
|
— |
|
|
|
Roads and Construction Services |
|
— |
|
— |
|
— |
|
|
|
— |
|
|
|
Diesel |
|
— |
|
|
|
— |
|
— |
|
— |
|
|
|
Fuel oil |
|
(
|
|
|
|
— |
|
— |
|
(
|
|
|
|
Plastic and rubber |
|
— |
|
|
|
— |
|
— |
|
— |
|
|
|
LPG and propane |
|
|
|
— |
|
— |
|
— |
|
— |
|
|
|
Gasoline and turbo fuels |
|
— |
|
|
|
— |
|
— |
|
— |
|
|
|
Natural gas |
|
|
|
— |
|
— |
|
— |
|
— |
|
|
|
Cash flow hedging |
|
(
|
|
(
|
|
— |
|
— |
|
— |
|
(
|
|
Other products |
|
|
|
|
|
— |
|
|
|
(
|
|
|
|
|
|
|
|
|
|
— |
|
|
|
(
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(
|
|
|
F-123
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
|
|
For the year ended on December 31, 2022 |
||||||||||
|
|
|
|
|
|
|
|
|
Electric power |
|
|
|
|
|
|
|
|
|
|
|
|
|
transmission |
|
|
|
|
|
|
|
|
|
|
|
|
|
and toll |
|
|
|
|
|
|
|
Exploration and |
|
Refining and |
|
Transport |
|
roads |
|
|
|
|
|
|
|
Production |
|
Petrochemicals |
|
and Logistics |
|
concessions |
|
Eliminations |
|
Total |
|
Local sales |
|
|
|
|
|
|
|
|
|
|
|
|
|
Mid-distillates |
|
— |
|
|
|
— |
|
— |
|
(
|
|
|
|
Gasoline and turbo fuels |
|
— |
|
|
|
— |
|
— |
|
(
|
|
|
|
Natural gas |
|
|
|
— |
|
— |
|
— |
|
(
|
|
|
|
Services |
|
|
|
|
|
|
|
|
|
(
|
|
|
|
Electric power transmission services |
|
— |
|
— |
|
— |
|
|
|
— |
|
|
|
Plastic and rubber |
|
— |
|
|
|
— |
|
— |
|
— |
|
|
|
LPG and propane |
|
|
|
|
|
— |
|
— |
|
(
|
|
|
|
Asphalts |
|
|
|
|
|
— |
|
— |
|
— |
|
|
|
Fuel gas service |
|
— |
|
|
|
— |
|
— |
|
(
|
|
|
|
Crude oil |
|
|
|
|
|
— |
|
— |
|
(
|
|
|
|
Roads and Construction services |
|
— |
|
— |
|
— |
|
|
|
— |
|
|
|
Aromatics |
|
— |
|
|
|
— |
|
— |
|
— |
|
|
|
Polyethylene |
|
— |
|
|
|
— |
|
— |
|
— |
|
|
|
Fuel oil |
|
|
|
|
|
— |
|
— |
|
— |
|
|
|
Other income gas contracts |
|
|
|
— |
|
— |
|
— |
|
— |
|
|
|
Other products |
|
|
|
|
|
— |
|
— |
|
(
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Foreign sales |
|
|
|
|
|
|
|
|
|
|
|
|
|
Crude oil |
|
|
|
|
|
— |
|
— |
|
(
|
|
|
|
Electric power transmission services |
|
— |
|
— |
|
— |
|
|
|
— |
|
|
|
Roads and Construction Services |
|
— |
|
— |
|
— |
|
|
|
— |
|
|
|
Fuel oil |
|
— |
|
|
|
— |
|
— |
|
— |
|
|
|
Diesel |
|
— |
|
|
|
— |
|
— |
|
— |
|
|
|
Plastic and rubber |
|
— |
|
|
|
— |
|
— |
|
— |
|
|
|
LPG and propane |
|
|
|
— |
|
— |
|
— |
|
— |
|
|
|
Natural gas |
|
|
|
— |
|
— |
|
— |
|
— |
|
|
|
Gasoline and turbo fuels |
|
— |
|
|
|
— |
|
— |
|
— |
|
|
|
Other products |
|
|
|
|
|
— |
|
|
|
(
|
|
|
|
Cash flow hedging |
|
(
|
|
(
|
|
— |
|
— |
|
— |
|
(
|
|
|
|
|
|
|
|
— |
|
|
|
(
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(
|
|
|
F-124
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
33.3 Capital expenditures by segments
The following are the investments amounts made by each segment for the years ended December 31, 2024, 2023 and 2022:
|
|
|
|
|
|
|
|
|
Electric |
|
|
|
|
|
|
|
|
|
|
|
power |
|
|
|
|
|
|
|
|
|
|
|
transmission |
|
|
|
|
|
Exploration |
|
Refining and |
|
Transport and |
|
and toll roads |
|
|
|
2024 |
|
and Production |
|
Petrochemicals |
|
Logistics |
|
concessions |
|
Total |
|
Property, plant, and equipment |
|
|
|
|
|
|
|
|
|
|
|
Natural and environmental resources |
|
|
|
— |
|
— |
|
— |
|
|
|
Intangibles |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Electric |
|
|
|
|
|
|
|
|
|
|
|
power |
|
|
|
|
|
|
|
|
|
|
|
transmission |
|
|
|
|
|
Exploration |
|
Refining and |
|
Transport and |
|
and toll roads |
|
|
|
2023 |
|
and Production |
|
Petrochemicals |
|
Logistics |
|
concessions |
|
Total |
|
Property, plant, and equipment |
|
|
|
|
|
|
|
|
|
|
|
Natural and environmental resources |
|
|
|
— |
|
— |
|
— |
|
|
|
Intangibles |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Electric |
|
|
|
|
|
|
|
|
|
|
|
power |
|
|
|
|
|
|
|
|
|
|
|
transmission |
|
|
|
|
|
Exploration |
|
Refining and |
|
Transport and |
|
and toll roads |
|
|
|
2022 |
|
and Production |
|
Petrochemicals |
|
Logistics |
|
concessions |
|
Total |
|
Property, plant, and equipment |
|
|
|
|
|
|
|
|
|
|
|
Natural and environmental resources |
|
|
|
— |
|
— |
|
— |
|
|
|
Intangibles |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
34. Supplemental information on oil and gas producing activities (unaudited)
The information in this note is referred to as “unaudited” as a means of clarifying that it is not covered by the audit opinion of the independent registered public accounting firm that has audited and reported on the “Consolidated Financial Statements.”
In accordance with the requirements of the United States Securities and Exchange Commission (SEC), Rule 4–10(a) of Regulation S–X, Release 33–8879, Accounting Standards Codification 932 and the ASU– 2010–03 “Oil and Gas reserve Estimation and Disclosures” rule, this section provides supplemental information on oil and gas exploration and producing activities of the Ecopetrol Business Group. The information included in sections (1) to (3) provides historical cost information pertaining to costs incurred in exploration, property acquisitions and development, capitalized costs, and results of operations. The information included in sections (4) and (5) presents information on Ecopetrol’s estimated net proved reserve quantities, standardized measure of estimated discounted future net cash flows related to proven reserves and changes in estimated discounted future net cash flows.
The following information corresponds to Ecopetrol’s oil and gas producing activities as of December 31, 2024, 2023 and 2022, and includes information related to the Ecopetrol Business Group’s consolidated subsidiaries.
Under the SEC final rule optional disclosure of possible and probable reserves is allowed but, the Ecopetrol Business Group opted not to do so. Ecopetrol estimated its reserves without considering non–traditional resources.
F-125
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
34.1 Capitalized costs relating to oil and gas exploration and production activities
|
|
|
2024 |
|
2023 |
|
2022 |
|
Natural and environmental properties |
|
|
|
|
|
|
|
Wells, equipment, and facilities – property, plant, and equipment |
|
|
|
|
|
|
|
Exploration and production projects |
|
|
|
|
|
|
|
Accumulated depreciation, depletion, and amortization |
|
(
|
|
(
|
|
(
|
|
Net capitalized cost |
|
|
|
|
|
|
It includes information of the Exploration and Production segment subsidiaries.
In accordance with IAS 37, costs capitalized to natural and environmental properties include provisions for asset retirement obligations of $
34.2 Costs incurred in oil and gas exploration and developed activities
Costs incurred are summarized below and include both amounts expensed and capitalized in the corresponding period.
|
|
|
2024 |
|
2023 |
|
2022 |
|
Acquisition of proved properties (1) |
|
|
|
|
|
|
|
Acquisition of unproved properties (2) |
|
|
|
|
|
|
|
Exploration costs |
|
|
|
|
|
|
|
Development costs |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) |
|
|
(2) |
|
F-126
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
34.3 Results of operations for oil and gas exploration and production activities
The Ecopetrol Business Group’s results of operations from oil and gas exploration and production activities for the years ended December 31, 2024, 2023 and 2022 are as follows:
|
|
|
2024 |
|
2023 |
|
2022 |
|
Net revenues |
|
|
|
|
|
|
|
Sales |
|
|
|
|
|
|
|
Transfers |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Production costs (1) |
|
|
|
|
|
|
|
Depreciation, depletion, and amortization (2) |
|
|
|
|
|
|
|
Other production costs (3) |
|
|
|
|
|
|
|
Exploration expenses (4) |
|
|
|
|
|
|
|
Other expenses (5) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income before income tax expense |
|
|
|
|
|
|
|
Income tax expense |
|
(
|
|
(
|
|
(
|
|
Results of operations for exploration and production activities |
|
|
|
|
|
|
|
(1) |
Production costs are lifting costs incurred to operate and maintain productive wells and related equipment and facilities including costs such as operating labor, materials, supplies, and fuel consumed in operations and the costs of operating natural gas liquids plants. In addition, they include expenses related to the asset retirement obligations that were recognized during 2024, 2023 and 2022 of $
|
|
(2) |
In accordance with IAS 37, the expense related to asset retirement obligations that were recognized during 2024, 2023 and 2022 in depreciation, depletion, and amortization, were
|
|
(3) |
Includes transportation costs and naphtha that are not part of the Ecopetrol Business Group’s lifting cost. |
|
(4) |
Exploration expenses include the costs of geological and geophysical activities, as well as the non–productive exploratory wells. |
|
(5) |
Corresponds to administration, marketing expenses, and impairment. |
During 2024, 2023, and 2022, the Ecopetrol Business Group transferred approximately
The intercompany transfers were realized at market prices.
34.4 Reserve information
The Ecopetrol Business Group follows international standards for estimating, classifying, and reporting reserves framed under SEC definitions. Corporate Reserve Management of Ecopetrol Business Group, Upstream Management and the Vice-Presidency of Development and Production, present the reserves balance to the Board of Directors, which approved it in February 2025.
The reserves were estimated at a level of
F-127
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
The following information relates to the net proven reserves owned by the Ecopetrol Business Group in 2024, 2023 and 2022, and corresponds to the official reserves statements prepared by the Ecopetrol Business Group:
|
|
|
2024 |
|
2023 |
|
2022 |
||||||||||||
|
|
|
Oil |
|
Gas |
|
Total |
|
Oil |
|
Gas |
|
Total |
|
Oil |
|
Gas |
|
Total |
|
|
|
(Mbls) |
|
(Gpc) |
|
(Mbe) |
|
(Mbls) |
|
(Gpc) |
|
(Mbe) |
|
(Mbls) |
|
(Gpc) |
|
(Mbe) |
|
Proved reserves: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Opening balance |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Revisions of previous estimates (1) |
|
|
|
(
|
|
|
|
|
|
(
|
|
|
|
|
|
(
|
|
|
|
Improved recovery |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Purchases |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Extensions and discoveries |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Sales |
|
(
|
|
(
|
|
(
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Production |
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
(
|
|
Closing balance |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Proved developed reserves: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Opening balance |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Closing balance |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Proved undeveloped reserves: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Opening balance |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Closing balance |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Some values were rounded for presentation purposes.
Mbls = Million barrels
Gpc: Giga cubic feet
Mbe = Million barrels of oil equivalent
|
(1) |
|
For additional information about the changes in Proved Reserves and the process for estimating reserves, see section 3.1 – Oil and Gas Reserves.
F-128
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
34.5 Standardized measure of discounted future net cash flows relating to proven oil and gas quantities and changes therein
The standardized measure of discounted future net cash flows related to the above proved crude oil and natural gas reserves is calculated in accordance with the requirements of ASU 2010–03. Estimated future cash inflows from production under SEC requirements are computed by applying unweighted arithmetic average of the first day–of–the–month for oil and gas price to year–end quantities of estimated net proved reserves, with cost factors based on those at the end of each year, currently enacted tax rates and a 10% annual discount factor. In our view, the information so calculated does not provide a reliable measure of future cash flows from proved reserves, nor does it permit a realistic comparison to be made of one entity with another because the assumptions used cannot reflect the varying circumstances within each entity. In addition, a substantial but unknown proportion of future real cash flows from oil and gas production activities is expected to derive from reserves which have already been discovered, but which cannot yet be regarded as proved.
|
|
|
2024 |
|
2023 |
|
2022 |
|
Future cash inflows |
|
|
|
|
|
|
|
Future costs |
|
|
|
|
|
|
|
Production (1) |
|
(
|
|
(
|
|
(
|
|
Development |
|
(
|
|
(
|
|
(
|
|
Income taxes |
|
(
|
|
(
|
|
(
|
|
Future net cash flow |
|
|
|
|
|
|
|
10% discount factor |
|
(
|
|
(
|
|
(
|
|
Standardized measure of discounted net cash flows |
|
|
|
|
|
|
|
(1) |
|
The following are the principal sources of change in the standardized measure of discounted net cash flows in 2024, 2023 and 2022:
|
|
|
2024 |
|
2023 |
|
2022 |
|
Net change in sales and transfer prices and in production cost (lifting) related to future production |
|
|
|
(
|
|
|
|
Changes in estimated future development costs |
|
(
|
|
(
|
|
(
|
|
Sales and transfer of oil and gas produced net of production costs |
|
(
|
|
(
|
|
(
|
|
Net change due to extensions, discoveries, and improved recovery |
|
|
|
|
|
|
|
Net change due to purchase and sales of minerals in place |
|
|
|
|
|
|
|
Net change due to revisions in quantity estimates |
|
|
|
|
|
|
|
Previously estimated development costs incurred during the period |
|
|
|
|
|
|
|
Accretion of discount |
|
|
|
|
|
|
|
Timing and other |
|
|
|
(
|
|
(
|
|
Net change in income taxes |
|
(
|
|
|
|
(
|
|
Aggregate change in the standardized measure of discounted future net cash flows for the year |
|
|
|
(
|
|
|
F-129
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
35. Subsequent and relevant events
● Decision adopted by the Southern District Court of New York related to an arbitration award issued in favor of Refinería de Cartagena S.A.S.
On January 16, 2025, Ecopetrol reported that the Southern District Court of New York denied the request filed by Chicago Bridge Iron Company N.V., CBI UK Limited to annul the arbitration award dated June 2, 2023. With this judicial ruling and with the decision of the Netherlands Court on March 21, 2024, regarding the approval of the alternative financial restructuring plan of Chicago Bridge Iron Company N.V., Refinería de Cartagena manages to consolidate the defense of its interests and those of the Nation, marking the end of a long legal process.
● Ecopetrol and OXY agree to extend the development plan in the Midland area of the Permian basin
On February 3, 2025, Ecopetrol S.A. reported that its subsidiary Ecopetrol Permian LLC and Occidental Petroleum Corp reached an agreement for the extension of the development plan of Rodeo Midland Basin LLC, in the Permian basin, in Texas, United States, within the contract signed since July 2019.
● Application of Decree 0175 of February 14, 2025 – State of Internal Unrest
The National Government, protected by the state of internal unrest decreed in the Catatumbo Region, issued Decree No. 0175 on February 14, 2025, which includes the following tax measures:
|
1. |
Special tax for Catatumbo: this tax taxes, with a rate of
|
|
2. |
Stamp tax: The stamp tax rate has been updated to
|
|
3. |
The decree will be in force between February 22 and December 31, 2025. |
| ● | Requirements related to VAT by the National Tax Authority of Colombia |
Refinería de Cartagena and Ecopetrol S.A. received customs requirements REA 211, REA 264 and REA 289, respectively, from the National Tax Authority of Colombia (DIAN) in 2025. The National Tax Authority of Colombia (DIAN) proposed an official corrective liquidation and a penalty on certain gasoline import filings for the period of 2022 to 2024, due to the failure to pay VAT on these filings. Refinería de Cartagena and Ecopetrol consider that their fillings were prepared in accordance with current customs legislation and are preparing their response to the requirements indicated by the National Tax Authority of Colombia (DIAN).
| ● | Fuel Price stabilization fund |
On March 28, 2025, the Ministry of Finance and Public Credit paid $
F-130
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
| ● | Shareholders’ General Assembly in Ecopetrol S.A. |
The Ecopetrol Shareholders General Assembly was held on March 28, 2025, and the following matters were discussed and approved, among others:
|
o |
The plan for distribution of the Company’s profits, which establishes the distribution of an ordinary dividend per share of COP
|
|
o |
The establishment of a special reserve of COP $
|
|
o |
Election of Deloitte Touche S.A.S., as the statutory auditor for the 2025 – 2029 period and assignment of its remuneration. |
|
o |
Election of Board Members for the 2025 - 2029 period. |
|
o |
Approval of amendments to the Internal Regulations of the General Shareholder´s Meeting. |
|
o |
Approval of amendments to the succession policy for the members of the Board of Directors. |
| ● | Temporal reduction in the conversion cost of Ecopetrol´s ADR |
On January 15, 2025, Ecopetrol reached an agreement with JPMorgan Chase Bank N.A., the depositary bank of its American Depositary Receipts (ADR) program, to reduce
| ● | Investment framework agreement with AES Colombia CIA SCA E.S.P. |
On April 14, 2025, Ecopetrol S.A. signed an investment framework agreement with AES Colombia CIA SCA E.S.P. to build
| ● | Gato do Mato project in Brazil |
Regarding the Gato do Mato project in Brazil, operated by Shell and associated with Total Energies, the project has made steady progress. In 2025 Ecopetrol Óleo e Gás do Brasil Ltda, a subsidiary of the Ecopetrol Group S.A., has already approved the Final Investment Decision (FID). The project completed the basic engineering “Front End Engineering Design” (FEED) for the subsea and floating production facilities, with the expectation of incorporating reserves during 2025.
The declaration of commerciality has already been filed, but the Development Plan is still awaiting approval from the ANP (National Agency of Petroleum, Natural Gas and Biofuels).
F-131
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
Exhibit 1 – Consolidated subsidiaries, associates, and joint ventures
|
|
|
|
|
Ownership |
|
|
|
|
|
Geographic |
|
|
|
Profit |
|
|
|
|
|
|
|
Functional |
|
interest |
|
|
|
Country/ |
|
area of |
|
|
|
(loss) of |
|
Total |
|
Total |
|
Company |
|
currency |
|
Ecopetrol |
|
Activity |
|
Domicile |
|
operations |
|
Equity |
|
the year |
|
assets |
|
liabilities |
|
Subsidiaries |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Refinería de Cartagena S.A.S. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
Cenit transporte y logística de hidrocarburos S.A.S. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Ecopetrol Global Energy S.L.U. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Oleoducto Central S.A.S - Ocensa |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Ocensa Ductos S.A.S. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Hocol Petroleum Limited. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Ecopetrol América LLC. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
Hocol S.A. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Esenttia S.A. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Ecopetrol Capital AG |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Oleoducto de Colombia S. A. – ODC |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Black Gold Re Ltd. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Andean Chemicals Ltd. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
Oleoducto de los Llanos Orientales S. A. - ODL |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interconexión Eléctrica S.A. E.S.P |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
F-132
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
|
|
|
|
Ownership |
|
|
|
|
|
Geographic |
|
|
|
Profit |
|
|
|
|
|
|
|
Functional |
|
interest |
|
|
|
Country/ |
|
area of |
|
|
|
(loss) of |
|
Total |
|
Total |
|
Company |
|
currency |
|
Ecopetrol |
|
Activity |
|
Domicile |
|
operations |
|
Equity |
|
the year |
|
assets |
|
liabilities |
|
Inversiones de Gases de Colombia S.A. Invercolsa S.A. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Alcanos de Colombia S.A. E.S.P. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Metrogas de Colombia S.A E.S.P. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gases del Oriente S.A. E.S.P. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Promotora de Gases del Sur S.A. E.S.P. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Combustibles Líquidos de Colombia S.A E.S.P. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
F-133
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
|
|
|
|
Ownership |
|
|
|
|
|
Geographic |
|
|
|
Profit |
|
|
|
|
|
|
|
Functional |
|
interest |
|
|
|
Country/ |
|
area of |
|
|
|
(loss) of |
|
Total |
|
Total |
|
Company |
|
currency |
|
Ecopetrol |
|
Activity |
|
Domicile |
|
operations |
|
Equity |
|
the year |
|
assets |
|
liabilities |
|
Ecopetrol USA Inc. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Ecopetrol Permian LLC. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Ecopetrol Oleo é Gas do Brazil Ltda. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
Esenttia Masterbatch Ltda. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Ecopetrol del Perú S. A. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ECP Hidrocarburos de México S.A. de C.V. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
Ecopetrol Costa Afuera S.A.S. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Esenttia Resinas del Peru SAC |
|
|
|
|
% |
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
Esenttia Resinas de México |
|
|
|
|
% |
|
|
|
|
|
|
(
|
|
(
|
|
|
|
|
|
Kalixpan Servicios Técnicos S de RL De CV. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
Ecopetrol US Trading LLC |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Econova Technology innovation S.L. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
Ecopetrol Singapore PTE. LTD |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Ecopetrol Trading Asia PTE. LTD |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
F-134
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
|
|
|
|
Ownership |
|
|
|
|
|
Geographic |
|
|
|
|
|
|
|
|
|
|
|
Functional |
|
interest |
|
|
|
Country/ |
|
area of |
|
|
|
Profit (loss) of |
|
|
|
Total |
|
Company |
|
currency |
|
Ecopetrol |
|
Activity |
|
Domicile |
|
operations |
|
Equity |
|
the year |
|
Total assets |
|
liabilities |
|
Associates |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Serviport S.A. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
Sociedad Portuaria Olefinas y Derivados S.A. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
Joint Ventures |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Equion Energía Limited |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Ecodiesel Colombia S.A. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
F-135
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
|
|
|
|
Ownership |
|
|
|
|
|
Geographic |
|
|
|
Profit |
|
|
|
|
|
|
|
Functional |
|
interest |
|
|
|
Country/ |
|
area of |
|
|
|
(loss) of |
|
|
|
|
|
Company |
|
currency |
|
ISA |
|
Activity |
|
Domicile |
|
operations |
|
Equity |
|
the year |
|
Assets |
|
Liabilities |
|
Subsidiaries Interconexión Eléctrica S.A. ESP |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Consorcio Transmantaro |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interligação Eléctrica Evrecy |
|
|
|
|
% |
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
Fundo de Investimento Assis |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
— |
|
Fundo de Investimento Barra Bonita Renda Fixa Referenciado |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
— |
|
Fundo de Investimento Referenciado di Bandeirantes |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
— |
|
Fundo de Investimento Xavantes Referenciado di |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
— |
|
Interconexiones Viales |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Aguapeí |
|
|
|
|
% |
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
Interligação Elétrica Biguaçu |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica De Minas Gerais |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Itapura |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Itaquerê |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Itaúnes |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Norte E Nordeste |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Pinheiros |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Riacho Grande |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Serra Do Japi |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Sul |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Tibagi |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Internexa |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
F-136
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
|
|
|
|
Ownership |
|
|
|
|
|
Geographic |
|
|
|
Profit |
|
|
|
|
|
|
|
|
|
interest |
|
|
|
Country/ |
|
area of |
|
|
|
(loss) of |
|
|
|
|
|
Company |
|
Functional currency |
|
ISA |
|
Activity |
|
Domicile |
|
operations |
|
Equity |
|
the year |
|
Assets |
|
Liabilities |
|
Subsidiaries Interconexión Eléctrica S.A. ESP |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica JAGUAR 6 S.A. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica JAGUAR 8 S.A. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica JAGUAR 9 S.A. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Internexa Participações |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
— |
|
Internexa Peru |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ISA Bolivia |
|
|
|
|
% |
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
ISA Capital Do Brazil |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ISA CTEEP |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ISA Interchile |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ISA Intercolombia |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ISA Intervial Chile |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ISA Intervial Colombia |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
— |
|
ISA Inversiones Chile |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ISA Inversiones Chile Vías SpA |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ISA Inversiones Costera Chile |
|
|
|
|
% |
|
|
|
|
|
|
(
|
|
|
|
|
|
|
|
ISA Inversiones Tolten |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ISA Investimentos E Participações |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ISA Peru |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ISA REP |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ISA Transelca |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Linear Systems RE |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Proyectos de Infraestructura del Perú |
|
|
|
|
% |
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
Ruta Costera |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Ruta de La Araucanía |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Ruta de Los Ríos |
|
|
|
|
% |
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
Ruta del Bosque |
|
|
|
|
% |
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
Ruta del Loa |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Ruta del Maipo |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Ruta del Este Sociedad Concesionaria S.A. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Sistemas Inteligentes en Red |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
XM |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interconexiones del Norte S.A. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
Ruta ORBITAL SUR Sociedad Concesionaria S.A. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Joint ventures Interconexión Eléctrica S.A. ESP |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica do Madeira |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Garanhuns |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Paraguaçu |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Aimorés |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Ivaí |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Transmissora Aliança de Energia Elétrica |
|
|
|
|
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interconexión Eléctrica Colombia Panamá-Panamá |
|
|
|
|
% |
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
Interconexión Eléctrica Colombia Panamá Colombia |
|
|
|
|
% |
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
Transnexa (1) |
|
|
|
|
% |
|
|
|
|
|
|
— |
|
— |
|
— |
|
— |
|
Derivex |
|
|
|
|
% |
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
Parques del Río |
|
|
|
|
% |
|
|
|
|
|
|
|
|
(
|
|
|
|
— |
|
Conexión Kimal Lo Aguirre S.A. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
Consorcio Eléctrico Yapay S.A. |
|
|
|
|
% |
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
PA Energía para la paz |
|
|
|
|
% |
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
Associates Interconexión Eléctrica S.A. ESP |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ATP Tower Holdings |
|
|
|
|
% |
|
|
|
|
|
|
|
|
(
|
|
|
|
|
|
(1) |
Transnexa is in the liquidation process and its investment has been impaired in its entirety. |
F-137
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
Exhibit 2 – Conditions of the most significant debt
|
|
|
|
|
|
|
|
|
|
|
|
|
Outstanding |
|
Outstanding |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
balance |
|
balance |
|
Interest |
|
Amortization |
|
Payment of |
|
Type of debt |
|
Company |
|
Issue date |
|
Maturity date |
|
Currency |
|
Disbursement |
|
Dec 31, 2024 |
|
Dec 31, 2023 |
|
rate |
|
plan |
|
interest |
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— |
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Bonds, |
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— |
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domestic |
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currency |
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|
F-138
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
|
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Outstanding |
|
Outstanding |
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Type of |
|
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|
Issue |
|
Maturity |
|
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|
balance |
|
balance |
|
Interest |
|
Amortization |
|
Payment of |
|
debt |
|
Company |
|
date |
|
date |
|
Currency |
|
Disbursement |
|
Dec 31, 2024 |
|
Dec 31, 2023 |
|
rate |
|
plan |
|
interest |
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— |
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— |
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Bonds, |
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foreign |
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— |
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currency |
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— |
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|
F-139
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
|
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|
|
|
|
|
|
|
|
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|
Outstanding |
|
Outstanding |
|
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|
Issue |
|
Maturity |
|
|
|
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|
balance |
|
balance |
|
Interest |
|
Amortization |
|
Payment of |
|
Type of debt |
|
Company |
|
date |
|
date |
|
Currency |
|
Disbursement |
|
Dec 31, 2024 |
|
Dec 31, 2023 |
|
rate |
|
plan |
|
interest |
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Bonds, foreign |
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currency |
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— |
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— |
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— |
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— |
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— |
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— |
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— |
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— |
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International |
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commercial |
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— |
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loans |
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— |
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|
F-140
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
|
|
|
|
|
|
|
|
|
|
|
|
Outstanding |
|
Outstanding |
|
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|
Issue |
|
Maturity |
|
|
|
|
|
balance |
|
balance |
|
Interest |
|
Amortization |
|
Payment of |
|
Type of debt |
|
Company |
|
date |
|
date |
|
Currency |
|
Disbursement |
|
Dec 31, 2024 |
|
Dec 31, 2023 |
|
rate |
|
plan |
|
interest |
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International |
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commercial |
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loans |
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— |
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— |
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— |
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— |
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International |
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commercial |
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loans |
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— |
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|
F-141
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
|
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|
Outstanding |
|
Outstanding |
|
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|
balance |
|
balance |
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|
Issue |
|
Maturity |
|
|
|
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|
Dec 31, |
|
Dec 31, |
|
Interest |
|
Amortization |
|
Payment of |
|
Type of debt |
|
Company |
|
date |
|
date |
|
Currency |
|
Disbursement |
|
2024 |
|
2023 |
|
rate |
|
plan |
|
interest |
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— |
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— |
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Domestic |
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commercial |
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loans |
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— |
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— |
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— |
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— |
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— |
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|
F-142
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
Exhibit 3. Quantitative information of concession services contracts
|
|
|
|
|
|
|
|
|
Tender at |
|
Maintenance |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
the end of |
|
obligation for |
|
Concession |
|
Revenue |
||||
|
|
|
|
|
|
|
|
|
the |
|
service condition |
|
Asset |
|
From Concession |
||||
|
Business line |
|
Concession |
|
Country |
|
Maturity date |
|
contract |
|
Y/N |
|
2024 |
|
2023 |
|
2024 |
|
2023 |
|
Intangible asset |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||
|
|
|
Consorcio Transmantaro |
|
Peru |
|
Sep-53 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
Energy transmission |
|
ISA REP |
|
Peru |
|
Sep-32 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
ISA Perú |
|
Peru |
|
Apr-33 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
Total Peru |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||
|
|
|
ISA Bolivia |
|
Bolivia |
|
Jan-39 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
Energy transmission |
|
Inteia S.A.S. |
|
Colombia |
|
Dec-25 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
Total concessions, asset intangible |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||
|
Contractual Asset |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||
|
|
|
ISA Energía Brasil |
|
Brazil |
|
Sep-52 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Aguapeí |
|
Brazil |
|
Aug-47 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Itaquerê |
|
Brazil |
|
Aug-47 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Itaúnes |
|
Brazil |
|
Feb-47 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Biguaçu |
|
Brazil |
|
Sep-48 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Norte e Nordeste |
|
Brazil |
|
Mar-38 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Jaguar 9 |
|
Brazil |
|
Oct-38 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Serra Do Japi |
|
Brazil |
|
Nov-39 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
Energy transmission |
|
Interligação Elétrica de Minas Gerais |
|
Brazil |
|
Mar-50 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Tibagi |
|
Brazil |
|
Aug-47 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Jaguar 6 |
|
Brazil |
|
Aug-47 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Evrecy Participações |
|
Brazil |
|
Mar-50 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Sul |
|
Brazil |
|
Oct-38 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Itapura |
|
Brazil |
|
Sep-48 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Jaguar 8 |
|
Brazil |
|
Aug-47 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Riacho Grande |
|
Brazil |
|
Mar-51 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Pinheiros |
|
Brazil |
|
Oct-38 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
Total concession, Contractual asset |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||
F-143
Ecopetrol S.A.
Notes to the consolidated financial statements
(Figures expressed in millions of Colombian pesos, unless otherwise stated)
|
|
|
|
|
|
|
|
|
Tender at |
|
Maintenance |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
the end of |
|
obligation for |
|
Concession |
|
Revenue |
||||
|
|
|
|
|
|
|
|
|
the |
|
service condition |
|
Asset |
|
From Concession |
||||
|
Business line |
|
Concession |
|
Country |
|
Maturity date |
|
contract |
|
Y/N |
|
2024 |
|
2023 |
|
2024 |
|
2023 |
|
Financial Asset |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||
|
|
|
ISA Energía Brasil |
|
Brazil |
|
Dec-42 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Aguapeí |
|
Brazil |
|
Aug-47 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Biguaçu |
|
Brazil |
|
Sep-48 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Serra Do Japi |
|
Brazil |
|
Nov-39 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Itaquerê |
|
Brazil |
|
Aug-47 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Jaguar 9 |
|
Brazil |
|
Oct-38 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Pinheiros |
|
Brazil |
|
Oct-38 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Jaguar 6 |
|
Brazil |
|
Aug-47 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
Energy Transmission |
|
Evrecy Participações |
|
Brazil |
|
Mar-50 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Sul |
|
Brazil |
|
Oct-38 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Itapura |
|
Brazil |
|
Sep-48 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica de Minas Gerais |
|
Brazil |
|
Mar-50 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Norte e Nordeste |
|
Brazil |
|
Mar-38 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Jaguar 8 |
|
Brazil |
|
Aug-47 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Itaúnas S. A. |
|
Brazil |
|
Sep-48 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Interligação Elétrica Tibagi |
|
Brazil |
|
Aug-47 |
|
Y |
|
Y |
|
|
|
(
|
|
|
|
|
|
Total Brazil |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||
|
|
|
Ruta del Maipo |
|
Chile |
|
Apr-35 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Ruta del Loa |
|
Chile |
|
Apr-49 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
Roads |
|
Ruta de la Araucanía |
|
Chile |
|
Oct-26 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Ruta de los Ríos |
|
Chile |
|
Mar-26 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
|
|
Ruta del Bosque |
|
Chile |
|
Feb-23 |
|
Y |
|
Y |
|
— |
|
— |
|
— |
|
|
|
|
|
Ruta orbital |
|
Chile |
|
Jun-70 |
|
Y |
|
Y |
|
|
|
— |
|
|
|
— |
|
Total Chile |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||
|
Roads |
|
Ruta Costera |
|
Colombia |
|
Feb-42 |
|
Y |
|
Y |
|
|
|
|
|
|
|
|
|
Total Colombia |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Roads |
|
Ruta del Este |
|
Panama |
|
Nov-42 |
|
Y |
|
Y |
|
|
|
— |
|
|
|
— |
|
Total Panama |
|
|
|
|
|
|
|
|
|
|
|
|
|
— |
|
|
|
— |
|
Total concessions, financial assets |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||
|
Total concessions |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
F-144
|
9. |
Signature Page |
SIGNATURES
The registrant hereby certifies that it meets all of the requirements for filing on Form 20-F and that it has duly caused and authorized the undersigned to sign this annual report on its behalf.
|
|
Ecopetrol S.A. |
|
|
|
|
|
|
|
By: |
/s/ Ricardo Roa Barragán |
|
|
Name: |
Ricardo Roa Barragán |
|
|
Title: |
Chief Executive Officer |
|
|
|
|
|
|
|
|
|
|
By: |
/s/ Alfonso Camilo Barco Muñoz |
|
|
Name: |
Alfonso Camilo Barco Muñoz |
|
|
Title: |
Chief Financial Officer |
|
|
|
|
|
Dated: April 23, 2025 |
|
|
245
|
Exhibit
|
|
Description |
|
4.11 |
|
|
|
4.12 |
|
|
|
4.13 |
|
|
|
4.14 |
|
|
|
4.15 |
|
|
|
4.16 |
|
|
|
4.17 |
|
|
|
4.18 |
|
|
|
4.19 |
|
|
|
4.20 |
|
|
|
4.21 |
|
|
|
4.22 |
|
|
|
4.23 |
|
|
|
4.24 |
|
|
|
4.25 |
|
247
|
Exhibit
|
|
Description |
|
4.26 |
|
|
|
4.27 |
|
|
|
4.28 |
|
|
|
4.29 |
|
|
|
4.30 |
|
|
|
4.31 |
|
|
|
4.32 |
|
|
|
4.33 |
|
|
|
4.34 |
|
|
|
4.35 |
|
|
|
4.36 |
|
|
|
4.37 |
|
|
|
4.38 |
|
|
|
7.1 |
|
|
|
7.2 |
|
|
|
8.1 |
|
|
|
12.1 |
|
|
|
12.2 |
|
|
|
13.1 |
|
|
|
23.1 |
|
|
|
23.2 |
|
|
|
23.3 |
|
|
|
23.4 |
|
|
|
99.1 |
|
|
|
99.2 |
|
|
|
99.3 |
|
|
|
101.INS |
|
XBRL Instance Document |
|
101.SCH |
|
XBRL Taxonomy Extension Schema Document |
|
101.CAL |
|
XBRL Taxonomy Extension Calculation Linkbase Document |
|
101.DEF |
|
XBRL Taxonomy Extension Definition Linkbase Document |
|
101.LAB |
|
XBRL Taxonomy Extension Labels Linkbase Document |
|
101.PRE |
|
XBRL Taxonomy Extension Presentation Linkbase Document |
248
11. Cross-reference to Form 20-F
|
|
|
|
Sections |
|
Item 1. |
Identity of Directors, Senior Management and Advisers |
|
N/A |
|
|
A. Directors and Senior Management |
|
N/A |
|
|
B. Advisers |
|
N/A |
|
|
C. Auditors |
|
N/A |
|
Item 2. |
Offer Statistics and Expected Timetable |
|
N/A |
|
|
A. Offer Statistics |
|
N/A |
|
|
B. Method and Expected Timetable |
|
N/A |
|
Item 3. |
Key Information |
|
N/A |
|
|
A. Reserved |
|
N/A |
|
|
B. Capitalization and Indebtedness |
|
N/A |
|
|
C. Reasons for the Offer and Use of Proceeds |
|
N/A |
|
|
D. Risk Factors |
|
5.2 |
|
Item 4. |
Information on the Company |
|
Note 1 to the consolidated financial statements - 3.4 Our Business |
|
|
A.History and Development of the Company |
|
2.1; 3.1; Note 1 to the consolidated financial statements |
|
|
B. Business Overview |
|
2; 3.4 – 3.14; 4.6, Note 1 and Supplemental information on Oil and Gas producing activities (unaudited by EY) to the consolidated financial statements |
|
|
C. Organizational Structure |
|
3.2 |
|
|
D. Property, Plants and Equipment |
|
3.4 – 3.8; 4.7.2; 4.11; Notes 13, 14, 15 and 16 to the consolidated financial statements |
|
Item 4A. |
Unresolved Staff Comments |
|
None |
|
Item 5. |
Operating and Financial Review and Prospects |
|
|
|
|
A. Operating Results |
|
3.4 – 3.8; 4; 6.2 |
|
|
B. Liquidity and Capital Resources |
|
2.1; 4.7; Consolidated statements of cash flow and Notes 6, 9, 19, and 28 to the consolidated financial statements |
|
|
C. Research and development, Patents and Licenses, etc. |
|
3.9; Note 16 to the consolidated financial statements |
|
|
D. Trend Information |
|
4.12 |
|
|
E. Critical Accounting Estimates |
|
4.5; Note 3 to the consolidated financial statements |
|
Item 6. |
Directors, Senior Management and Employees |
|
|
|
|
A. Directors and Senior Management |
|
7.3; 7.5 |
|
|
B. Compensation |
|
7.6; Notes 4, 21 and 30 to the consolidated financial statements |
|
|
C. Board Practices |
|
7.3 |
|
|
D. Employees |
|
3.14 |
|
|
E. Share Ownership |
|
7.7 |
|
|
F. Disclosure of a registrant’s action to recover erroneously awarded compensationF |
|
N/A |
|
Item 7. |
Major Shareholders and Related Party Transactions |
|
|
|
|
A. Major Shareholders |
|
6.9; 7.7 |
|
|
B. Related Party Transactions |
|
3.12; Note 30 to the consolidated financial statements |
|
|
C. Interests of Experts and Counsel |
|
N/A |
|
Item 8. |
Financial Information |
|
|
|
|
A. Consolidated Statements and Other Financial Information |
|
4; 6.2; 6.3; 8 |
|
|
B. Significant Changes |
|
4; 7.8; Note 33 and 34 to the consolidated financial statements |
|
Item 9. |
The Offer and Listing |
|
|
|
|
A. Offer and Listing Details |
|
6.4, 6.5 |
|
|
B. Plan of Distribution |
|
N/A |
|
|
C. Markets |
|
6.3 |
|
|
D. Selling Shareholders |
|
N/A |
249
|
|
E. Dilution |
|
N/A |
|
|
F. Expenses of the Issue |
|
N/A |
|
Item 10. |
Additional Information |
|
|
|
|
A. Share Capital |
|
N/A |
|
|
B. Memorandum and Articles of Association |
|
7.1 |
|
|
C. Material Contracts |
|
3,12; 4.9; Exhibits 4.1 – 4.9, 4.20 and 4.28 |
|
|
D. Exchange Controls |
|
5.3.4; 6.7 |
|
|
E. Taxation |
|
4.3.1; 6.6; Note 10 to the consolidated financial statements |
|
|
F. Dividends and Paying Agents |
|
N/A |
|
|
G. Statements by Experts |
|
N/A |
|
|
H. Documents On Display |
|
1.1 |
|
|
I. Subsidiary Information |
|
N/A |
|
|
J. Annual Report to Security Holders |
|
N/A |
|
Item 11. |
Quantitative and Qualitative Disclosures About Market Risk |
|
4.1; 5.2.1; 5.2.4; 5.3.4; Note 29 to the consolidated financial statements |
|
Item 12. |
Description of Securities Other than Equity Securities |
|
|
|
|
A. Debt Securities |
|
6.4; Exhibits 4.12–4.28 |
|
|
B. Warrants and Rights |
|
N/A |
|
|
C. Other Securities |
|
N/A |
|
|
D. American Depositary Shares |
|
5.2.4; 6.5; Exhibit 2.1 – 2.2 |
|
Item 13. |
Defaults, Dividend Arrearages and Delinquencies |
|
None |
|
Item 14. |
Material Modifications to the Rights of Security Holders and Use of Proceeds |
|
None |
|
Item 15. |
Controls and Procedures |
|
7.8 |
|
Item 16. |
Reserved |
|
|
|
Item 16A. |
Audit Committee Financial Expert |
|
7.3.2 |
|
Item 16B. |
Code of Ethics |
|
7.2; 7.4 |
|
Item 16C. |
Principal Accountant Fees and Services |
|
7.8 |
|
Item 16D. |
Exemptions from the Listing Standards for Audit Committees |
|
N/A |
|
Item 16E. |
Purchases of Equity Securities by the Issuer and Affiliated Purchases |
|
N/A |
|
Item 16F. |
Changes in Registrant’s Certifying Accountant |
|
7.8 |
|
Item 16G. |
Corporate Governance |
|
7 |
|
Item 16H. |
Mine Safety Disclosure |
|
N/A |
|
Item 16I. |
Disclosure Regarding Foreign Jurisdictions that Prevent Inspections |
|
N/A |
|
Item 17. |
Financial Statements |
|
8 |
|
Item 18. |
Financial Statements |
|
8 |
|
Item 19. |
Exhibits |
|
10 |
250