UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
__________________________________
FORM
__________________________________
OR
For the fiscal year ended
OR
For the transition period from __________________ to __________________.
OR
Date of event requiring this shell company report __________________.
Commission file number
__________________________________
(Exact name of Registrant as specified in its charter) |
Port Central S.A.
(Translation of Registrant’s name into English)
Republic of
(Jurisdiction of incorporation or organization)
(Address of principal executive offices)
Facsimile:
Email:
(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.
Title of each class |
| Trading Symbol |
| Name of each exchange on which registered |
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* Not for trading, but only in connection with the registration of American Depositary Shares pursuant to the requirements of the 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.
Title of each class |
| Outstanding at December 31, 2021 |
Common shares, nominal value Ps.1.00 per share |
|
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.
Yes ☐
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.
Yes ☐
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.
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted and posted 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 and post such files).
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.
Large accelerated filer | ☐ | ☒ | |
Non-accelerated filer | ☐ | Emerging growth company |
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.
Indicate by check mark which basis of accounting the registrant has used to prepare the financial statements included in this filing:
U.S. GAAP ☐ | 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).
Yes
(APPLICABLE ONLY TO ISSUERS INVOLVED IN BANKRUPTCY PROCEEDINGS DURING THE PAST FIVE YEARS)
Indicate by check mark whether the registrant has filed all documents and reports required to be filed by Sections 12, 13 or 15(d) of the Securities Exchange Act of 1934 subsequent to the distribution of securities under a plan confirmed by a court.
Yes ☐ No ☐
TABLE OF CONTENTS
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Item 5 F | [Reserved] |
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Item 5 G | [Reserved] |
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Item 5 H | [Reserved] |
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Material Modifications to the Rights of Security Holders and Use of Proceeds |
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Purchases of Equity Securities by the Issuer and Affiliated Purchasers |
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Disclosure Regarding Foreign Jurisdictions that Prevent Inspections |
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| Table of Contents |
CERTAIN DEFINITIONS
In this annual report, except where otherwise indicated or where the context otherwise requires:
| · | “Argentine Corporate Law” refers to Law No. 19,550, as amended; |
| · | “Authorized Generators” refers to electricity generators that do not have contracts in the term market in any of its methods; |
| · | “BCRA” refers to the Argentine Central Bank. |
| · | “BYMA” refers to Bolsas y Mercados Argentinos S.A.; |
| · | “CAMMESA” refers to Compañía Administradora del Mercado Mayorista Eléctrico Sociedad Anónima. See “Item 4.B, Business Overview— The Argentine Electric Power Sector—General Overview of Legal Framework—CAMMESA;” |
| · | “CNV” refers to the Comisión Nacional de Valores, the Argentine Securities Commission; |
| · | “COD” refers to Commercial Operation Date, the day in which a generation unit is authorized by CAMMESA (in Spanish, “Habilitación Comercial”) to sell electric energy through the grid under the applicable commercial conditions; |
| · | “CTM” refers to Centrales Térmicas Mendoza S.A.; |
| · | “CVO” refers to the thermal plant Central Vuelta de Obligado; |
| · | “CVO Agreement” refers to the Agreement for Project Management and Operation, Increase of Thermal Generation Availability and Adaptation of Remuneration for Generation 2008-2011” executed on November 25, 2010 among the Secretariat of Energy and Central Puerto along with other electric power generators; |
| · | “CVOSA” refers to Central Vuelta de Obligado S.A.; |
| · | “Ecogas” refers collectively to Distribuidora de Gas Cuyana (“DGCU”) and Distribuidora de Gas del Centro (“DGCE”); |
| · | “Energía Base” refers to the regulatory framework established under Resolution SE No. 95/13, as amended, and, from February 2017 to February 2019, regulated by Resolution SEE No. 19/17, from March 2019 to January 2020, regulated by Resolution No. 1/19 of the Secretary of Renewable Resources and Electric Market of the National Ministry of Economy and since February 2020 regulated by Resolution No. 31/20 of the Secretary of Energy. See “Item 4.B, Business Overview—The Argentine Electric Power Sector;” |
| · | “Energía Plus” refers to the regulatory framework established under Resolution SE No. 1281/06, as amended. See “Item 4.B, Business Overview—The Argentine Electric Power Sector—Structure of the Industry—Energía Plus;” |
| · | “FODER” refers to Fondo para el Desarrollo de Energías Renovables (Fund for the Development of Renewable Energies). See “Item 4.B, Business Overview—The Argentine Electric Power Sector —Structure of the Industry—Renewable Energy Program” |
| · | “FONINVEMEM” or “FONI” refers to the Fondo para Inversiones Necesarias que Permitan Incrementar la Oferta de Energía Eléctrica en el Mercado Eléctrico Mayorista (the Fund for Investments Required to Increase the Electric Power Supply) and similar programs, including the CVO Agreement. See “Item 4.B, Business Overview—The Argentine Electric Power Sector—Structure of the Industry—The FONINVEMEM and Similar Programs;” |
| · | “FONINVEMEM Plants” refers to the plants José de San Martín, Manuel Belgrano and Vuelta de Obligado; |
| · | “FX Market” refers to the foreign exchange market; |
| · | “HPDA” refers Hidroeléctrica Piedra del Águila S.A., the corporation that previously owned the Piedra del Águila plant; |
| · | “IEASA” refers to Integración Energética Argentina S.A.; |
| · | “IGCE” refers to Inversora de Gas del Centro S.A.; |
| · | “IGCU” refers to Inversora de Gas Cuyana S.A.; |
| · | “La Plata Plant Sale” refers to the sale of the La Plata plant to YPF EE, effective as of January 5, 2018. For further information on the La Plata Plant Sale, see “Item 4.A. History and development of the Company—La Plata Plant Sale;” |
| · | “La Plata Plant Sale Effective Date” is January 5, 2018. For further information on the La Plata Plant Sale Effective Date, see “Item 4.A. History and development of the Company—La Plata Plant Sale;” |
| · | “LPC” refers to La Plata Cogeneración S.A., the corporation that owned the La Plata plant prior to us; |
| · | “LVFVD” refers to liquidaciones de venta con fecha de vencimientos a definir, or receivables from CAMMESA without a fixed due date. See “Item 4.B, Business Overview—FONINVEMEM and Similar Programs;” |
| · | “MATER” refers to Term Market for Renewable Energy Resolution No. 281-E/17; |
| · | “PPA” refers to Power Purchase Agreements, power capacity and energy supply agreements for a defined period of time or energy quantity; |
| · | “Resolution SRRyME No. 1/19” refers to the resolution No. 1/19 issued on March 1, 2019, by the Secretary of Renewable Resources and Electric Markey of the National Ministry of Economy by which the Secretary modified the remuneration scheme (for capacity and energy) applicable to Authorized Generators (electricity generators which do not have contracts in the term market in any of its modalities) acting in the WEM; |
| · | “Resolution 31/20” or “Res. 31/20” refers to the resolution No. 31/20 issued on February 27, 2020, by the Secretary of Energy of the National Ministry of Production Development by which the Secretary modified the remuneration scheme (for capacity and energy) applicable from February 1, 2020, to Authorized Generators (electricity generators which do not have contracts in the term market in any of its modalities) acting in the WEM; |
| · | “SADI” refers to the Argentine Interconnection System; |
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| · | “sales under contracts” refers collectively to (i) term market sales of energy under contracts with private and public sector counterparties, (ii) sales of energy sold under the Energía Plus and (iii) sales of energy under the RenovAr Program; |
| · | the “spot market” refers to energy sold by generators to the WEM and remunerated by CAMMESA pursuant to the framework in place prior to the Energía Base. See “Item 4.B, Business Overview—The Argentine Electric Power Sector—Structure of the Industry—Electricity Dispatch and Spot Market Pricing prior to Resolution SE No. 95/13;” |
| · | “YPF” refers to YPF S.A., Argentina’s state-owned oil and gas company; |
| · | “YPF EE” refers to YPF Energía Eléctrica S.A., a subsidiary of YPF; and |
| · | “WEM” refers to the Argentine Mercado Eléctrico Mayorista, the wholesale electric power market. See “Item 4.B, Business Overview—The Argentine Electric Power Sector—General Overview of Legal Framework—CAMMESA.” |
PRESENTATION OF FINANCIAL AND OTHER INFORMATION
Financial Statements
We maintain our financial books and records and publish our consolidated financial statements (as defined below) in Argentine pesos, which is our functional currency. This annual report contains our audited consolidated financial statements as of December 31, 2021 and 2020 and for each of the years ended December 31, 2021, 2020, and 2019 (our “Audited Consolidated Financial Statements”), which were approved by our board of directors (our “Board of Directors”) on April 28, 2022.
We prepare our Audited Consolidated Financial Statements in Argentine pesos and in conformity with the IFRS as issued by the IASB.
In accordance with IAS 29, the restatement of the financial statements is necessary when the functional currency of an entity is the currency of a hyperinflationary economy. To define a hyperinflationary state, IAS 29 provides a series of non-exclusive guidelines that consist of (i) analyzing the behavior of the population, prices, interest rates and wages before the evolution of price indexes and the loss of the currency’s purchasing power, and (ii) as a quantitative characteristic, verifying if the three-year cumulative inflation rate approaches or exceeds 100%. Due to macroeconomic factors, the triennial inflation was above that figure in 2018 and Argentina has been considered hyperinflationary since July 1, 2018. Such conditions remained during 2019, 2020 and 2021. See “Risks Relating to Argentina—As of July 1st, 2018, the Argentine Peso qualifies as a currency of a hyperinflationary economy and we are required to restate our historical financial statements to apply inflationary adjustments, which could adversely affect our results of operations and financial condition and those of our Argentine subsidiaries”
Therefore, our Audited Consolidated Financial Statements included herein, including the figures for the previous periods (this fact not affecting the decisions taken on the financial information for such periods), and, unless otherwise stated, the financial information included elsewhere in this annual report, were restated to consider the changes in the general purchasing power of the functional currency of the Company (Argentine peso) pursuant to IAS 29 and General Resolution no. 777/2018 of the CNV. Consequently, the consolidated financial statements are stated in the current measurement unit as of December 31, 2021. The information included in our Audited Consolidated Financial Statements is not comparable to the consolidated financial statements previously published by us. For further information, see “Item 5.A. Operating Results—Factors Affecting our Results of Operations—Inflation” and Note 2.1.2 to our Audited Consolidated Financial Statements.
We remind investors that we are required to file financial statements and other periodic reports with the CNV because we are a public company in Argentina. Investors can access our historical financial statements published in Spanish on the CNV’s website at www.cnv.gob.ar. The information found on the CNV’s website is not a part of this annual report. Investors are cautioned not to place undue reliance on our financial statements not included in this annual report.
Currency and Rounding
All references herein to “pesos,” “Argentine pesos” or “Ps.” are to Argentine pesos, the legal currency of Argentina. All references to “U.S. dollars,” “dollars” or “US$” are to U.S. dollars. All references to “SEK$” are to Swedish krona. A “billion” is a thousand million.
Solely for the convenience of the reader, we have translated certain amounts included in this annual report from pesos into U.S. dollars, unless otherwise indicated, using the seller rate for U.S. dollars quoted by the Banco de la Nación Argentina for wire transfers (divisas) as of December 31, 2021, of Ps.102.72 per US$1.00. The Federal Reserve Bank of New York does not report a noon buying rate for pesos. The U.S. dollar equivalent information presented in this annual report is provided solely for the convenience of the reader and should not be construed to represent that the peso amounts have been, or could have been or could be, converted into U.S. dollars at such rates or at any other rate. See “Item 3.A. Selected Financial Data—Exchange Rates.”
Certain figures included in this annual report and in the Audited Consolidated Financial Statements contained herein have been rounded for ease of presentation. Percentage figures included in this annual report have in some cases been calculated on the basis of such figures prior to rounding. For this reason, certain percentage amounts in this annual report may vary from those obtained by performing the same calculations using the figures in this annual report and in the consolidated financial statements contained herein. Certain other amounts that appear in this annual report may not sum due to rounding.
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Market Share and Other Information
The information set forth in this annual report with respect to the market environment, market developments, growth rates and trends in the markets in which we operate is based on information published by the Argentine federal and local governments through the Instituto Nacional de Estadísiticasy Censos (the National Statistics and Census Institute, or “INDEC”), the Ministry of Interior, the Secretariat of Electric Energy, the Banco Central de la República Argentina (the “Argentine Central Bank”, or “Central Bank”) CAMMESA, the Dirección General de Estadística y Censos de la Ciudad de Buenos Aires (General Directorate of Statistics and Census of the City of Buenos Aires) and the Dirección Provincial de Estadística y Censos de la Provincia de San Luis (Provincial Directorate of Statistics and Census of the Province of San Luis), as well as on independent third-party data, statistical information and reports produced by unaffiliated entities, as well as on our own internal estimates. In addition, this annual report contains information from Vaisala, Inc. (“Vaisala - 3 Tier”), a company that develops, manufactures and markets products and services for environmental and industrial measurement.
This annual report also contains estimates that we have made based on third-party market data. Market studies are frequently based on information and assumptions that may not be exact or appropriate.
Although we have no reason to believe any of this information or these sources are inaccurate in any material respect, we have not verified the figures, market data or other information on which third parties have based their studies, nor have we confirmed that such third parties have verified the external sources on which such estimates are based. Therefore, we do not guarantee, nor do we assume responsibility for, the accuracy of the information from third-party studies presented in this annual report.
This annual report also contains estimates of market data and information derived therefrom which cannot be gathered from publications by market research institutions or any other independent sources. Such information is based on our internal estimates. In many cases there is no publicly available information on such market data, for example from industry associations, public authorities or other organizations and institutions. We believe that these internal estimates of market data and information derived therefrom are helpful in order to give investors a better understanding of the industry in which we operate as well as our position within this industry. Although we believe that our internal market observations are reliable, our estimates are not reviewed or verified by any external sources. These may deviate from estimates made by our competitors or future statistics provided by market research institutes or other independent sources. We cannot assure you that our estimates or the assumptions are accurate or correctly reflect the state and development of, or our position in, the industry.
FORWARD-LOOKING STATEMENTS
This annual report contains estimates and forward-looking statements, principally in “Item 3.D. Risk Factors,” “Item 4.B. Business Overview” and “Item 5. Operating and Financial Review and Prospects.”
Our estimates and forward-looking statements are mainly based on our current beliefs, expectations and estimates of future courses of action, events and trends that affect or may affect our business and results of operations. Although we believe that these estimates and forward-looking statements are based upon reasonable assumptions, they are subject to several risks and uncertainties and are made in light of information currently available to us.
Many important factors, in addition to those discussed elsewhere in this annual report, could cause our actual results to differ substantially from those anticipated in our forward-looking statements, including, among other things:
| · | changes in general economic, financial, business, political, legal, social or other conditions in Argentina; |
| · | changes in conditions elsewhere in Latin America or in either developed or emerging markets; |
| · | changes in capital markets in general that may affect policies or attitudes toward lending to or investing in Argentina or Argentine companies, including volatility in domestic and international financial markets; |
| · | the impact of political developments and uncertainties relating to political and economic conditions in Argentina, on the demand for securities of Argentine companies; |
| · | increased inflation; |
| · | fluctuations in exchange rates, including a significant devaluation of the Argentine peso; |
| · | changes in the law, norms and regulations applicable to the Argentine electric power and energy sector, including changes to the current regulatory frameworks, changes to programs established to incentivize investments in new generation capacity and reductions in government subsidies to consumers; |
| · | our ability to develop our expansion projects and to win awards for new potential projects; |
| · | increases in financing costs or the inability to obtain additional debt or equity financing on attractive terms, which may limit our ability to fund new activities; |
| · | government intervention, including measures that result in changes to the Argentine labor market, exchange market or tax system; |
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| · | adverse legal or regulatory disputes or proceedings; |
| · | changes in the price of energy, power and other related services; |
| · | changes in the prices and supply of natural gas or liquid fuels; |
| · | changes in the amount of rainfall and accumulated water; |
| · | changes in environmental regulations, including exposure to risks associated with our business activities; |
| · | risks inherent to the demand for and sale of energy; |
| · | the operational risks related to the generation, as well as the transmission and distribution, of electric power; |
| · | ability to implement our business strategy, including the ability to complete our construction and expansion plans in a timely manner and according to our budget; |
| · | competition in the energy sector, including as a result of the construction of new generation capacity; |
| · | exposure to credit risk due to credit arrangements with CAMMESA; |
| · | our ability to retain key members of our senior management and key technical employees; |
| · | the effects of a pandemic or epidemic, such as COVID-19, and any subsequent mandatory regulatory restrictions or containment measures; |
| · | our relationship with our employees; and |
| · | other factors discussed under “Item 3.D.—Risk Factors” in this annual report. |
The words “believe,” “may,” “will,” “aim,” “estimate,” “continue,” “anticipate,” “intend,” “expect,” “forecast” and similar words are intended to identify forward-looking statements. Forward-looking statements include information concerning our possible or assumed future results of operations, business strategies, financing plans, competitive position, industry environment, potential growth opportunities, the effects of future regulation and the effects of competition. Forward-looking statements speak only as of the date they were made, and we do not undertake any obligation to update publicly or to revise any forward-looking statements after we distribute this annual report because of new information, future events or other factors, except as required by applicable law. In light of the risks and uncertainties described above, the forward-looking events and circumstances discussed in this annual report might not occur and do not constitute guarantees of future performance. Because of these uncertainties, you should not make any investment decisions based on these estimates and forward-looking statements.
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PART I
Item 1. Identity of Directors, Senior Management and Advisors
Not applicable.
Item 2. Offer Statistics and Expected Timetable
Not applicable.
Item 3. Key Information
Item 3.A [Reserved]
Item 3.B Capitalization and indebtedness
Not applicable.
Item 3.C Reasons for the offer and use of proceeds
Not applicable.
Item 3.D Risk Factors
Summary of Risk Factors
We are subject to several risks related to our business that are described under “Risk Factors” and elsewhere in this annual report. These risks could materially and adversely impact our business, results of operations, financial condition, and future prospects. Among these important risks are the following:
Risks Relating to Argentina
| · | Substantially all our revenues are generated in Argentina and thus are highly dependent on economic and political conditions in Argentina. |
| · | As of July 1, 2018, the Argentine Peso qualifies as a currency of a hyperinflationary economy and we are required to restate our historical financial statements to apply inflationary adjustments, which could adversely affect our results of operations and financial condition and those of our Argentine subsidiaries. |
| · | Significant fluctuations in the value of the peso could adversely affect the Argentine economy and, in turn, adversely affect our results of operations. |
| · | Exchange controls and restrictions on capital inflows and outflows could limit the availability of international credit and could threaten the financial system, adversely affecting the Argentine economy and, as a result, our business. |
| · | Argentina’s ability to obtain financing from international markets is limited, which could affect its capacity to implement reforms and sustain economic growth and may negatively impact our financial condition or cash flows. |
| · | The Argentine economy could be adversely affected by economic developments in other markets and by more general “contagion” effects. |
| · | We may be exposed to adverse effects arising from the ongoing conflict between Russia and Ukraine. |
| · | The Argentine banking system may be subject to instability which may affect our operations. |
| · | Failure to adequately address actual and perceived risks of institutional deterioration and corruption may adversely affect Argentina’s economy and financial condition, which in turn could adversely affect our business, financial condition, and results of operations. |
Risks Relating to the Electric Power Sector in Argentina
| · | The Argentine Government has intervened in the electric power sector in the past and is likely to continue intervening. |
| · | Changes in regulatory frameworks under which we sell our electricity may affect our financial condition and results of operations. |
| · | We have, in the recent past, been unable to collect payments, or to collect them in a timely manner, from CAMMESA and other customers in the electric power sector. |
| · | Argentina has certain energy transmission and distribution limitations that adversely affect the capacity of electric power generators to deliver all of the energy they can produce, which results in reduced sales. |
| · | Restrictions on the supply of energy could negatively affect Argentina’s economy. |
| · | We operate in a heavily regulated sector that imposes significant costs on our business, and we could be subject to fines and liabilities that could have a material adverse effect on our results of operations. |
| · | Risks arise for our business from technological change in the energy market. |
| · | Competition in the Electric Power Sector in Argentina may adversely affect our results of operations. |
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Risks Relating to Our Business
| · | Our results depend largely on the compensation established by the Secretariat of Electric Energy and received from CAMMESA. |
| · | Factors beyond our control may affect or delay the completion of the awarded projects or alter our plans for the expansion of our existing plants. |
| · | Our business may require substantial capital expenditures for ongoing maintenance requirements and the expansion of our installed generation capacity. |
| · | Covenants in our indebtedness could adversely restrict our financial and operating flexibility. |
| · | We may be unable to refinance our outstanding indebtedness, or the refinancing terms may be materially less favorable than their current terms, which would have a material adverse effect on our business, financial condition, and results of operations. |
| · | The non-renewal or early termination of the HPDA Concession Agreement would adversely affect our results of operations. |
| · | Our interests in TJSM, TMB were diluted and CVOSA will be significantly diluted. |
| · | Future changes in the rainfall amounts in the Limay River basin could adversely affect the revenues from the Piedra del Águila concession and, therefore, our financial results. |
| · | Our ability to operate wind farms profitably is highly dependent on suitable wind and associated weather conditions. |
| · | Climate change and energy transition could affect our business. |
| · | Our power plants are subject to the risk of mechanical or electrical failures due to natural disasters, catastrophic accidents or terrorist attacks, and any resulting unavailability may affect our ability to fulfill our contractual and other commitments and thus adversely affect our business and financial performance. |
| · | Our insurance policies may not fully cover damage, and we may not be able to obtain insurance against certain risks. |
| · | We may be exposed to lawsuits and or administrative proceedings that could adversely affect our financial condition and results of operations. |
| · | Energy demand is seasonal, largely due to climate conditions. |
| · | We may undertake acquisitions and investments to expand or complement our operations that could result in operating difficulties or otherwise adversely affect our financial conditions and results of operations. |
| · | If we were to acquire another energy company in the future, such acquisition could be subject to the Argentine Antitrust Authority’s approval. |
| · | We depend on senior management and other key personnel for our current and future performance. |
| · | We could be affected by material actions taken by the trade unions. |
| · | Our equipment, facilities and operations are subject to environmental, health and safety regulations. |
| · | We are subject to anticorruption, anti-bribery, anti-money laundering and other laws and regulations. |
| · | A cyberattack could adversely affect our business, balance sheet, results of operations and cash flow. |
| · | Our ability to generate electricity at our thermal generation plants partially depends on the availability of natural gas and, to a lesser extent, liquid fuel. |
| · | We may be adversely affected by changes in LIBOR reporting practices or the method in which LIBOR is determined. |
| · | An outbreak of a disease, including COVID-19, may have material adverse consequences on our operations including new projects. |
Risks Relating to our Shares and ADSs
| · | It may be difficult for you to obtain or enforce judgments against us. |
| · | Restrictions on transfers of foreign exchange and the repatriation of capital from Argentina may impair your ability to receive dividends and distributions on, and the proceeds of any sale of, shares underlying the ADSs. |
| · | We will be traded on more than one market, and this may result in price variations; in addition, investors may not be able to easily move shares for trading between such markets. |
| · | Under Argentine Corporate Law, shareholder rights may be fewer or less well defined than in other jurisdictions. |
| · | Holders of our common shares and the ADSs located in the United States may not be able to exercise preemptive or accretion rights. |
| · | Voting rights, and other rights, with respect to the ADSs are limited by the terms of the deposit agreement. |
| · | The relative volatility and illiquidity of the Argentine securities markets may substantially limit our ADS holders’ ability to sell common shares underlying the ADSs at the price and time they desire. |
| · | If there are substantial sales of our common shares or the ADSs, the price of the common shares or of the ADSs could decline. |
| · | Our shareholders may be subject to liability for certain votes of their securities. |
| · | As a foreign private issuer, we are exempt from several rules under the U.S. securities laws and are permitted to file less information with the Commission than a U.S. company. This may limit the information available to holders of our ADSs. |
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| · | As a foreign private issuer, we are not subject to certain NYSE corporate governance rules applicable to U.S. listed companies. |
| · | The market price for our common shares or ADSs could be highly volatile. |
| · | If we fail to maintain an effective system of internal control over financial reporting, we may not be able to accurately report our financial results or prevent fraud. As a result, shareholders could lose confidence in our financial and other public reporting, which would harm our business and the trading price of our common shares. |
| · | The protections afforded to minority shareholders in Argentina are different from and more limited than those in the United States and may be more difficult to enforce. |
| · | Holders of our common shares may determine not to pay any dividends. |
| · | We may be a passive foreign investment company for U.S. federal income tax purposes. |
| · | The requirements of being a public company may strain our resources and distract our management, which could make it difficult to manage our business. |
Detailed Risk Factors
You should carefully consider the risks described below, as well as the other information in this annual report. Our business, results of operations, financial condition or prospects could be materially and adversely affected if any of these risks occurs, and as a result, the market price of our common shares and ADSs could decline. The risks described below are those known to us and that we currently believe may materially affect us.
Risks Relating to Argentina
Substantially all of our revenues are generated in Argentina and thus are highly dependent on economic and political conditions in Argentina
Central Puerto is an Argentine corporation (sociedad anónima). All of our assets and operations are located in Argentina. Accordingly, our financial condition and results of operations depend to a significant extent on macroeconomic, regulatory, social and political conditions prevailing in Argentina, including but not limited to, the following: (i) international demand and prices for Argentina’s commodity exports; (ii) competitiveness and efficiency of domestic industries and services; (iii) stability and competitiveness of the Argentine peso against foreign currencies; (iv) foreign and domestic investment and financing; (v) level of foreign exchange reserves in the Central Bank of the Argentine Republic (“BCRA”) which may cause abrupt changes in currency values and exchange and capital control regulations (including, to import equipment , payment of cross border indebtedness and other necessities relevant for operations); (vi) high interest and inflation rates to corresponding wage and price controls; (vii) adverse external economic shocks; (viii) effects of the ongoing COVID-19 pandemic and results of the measures adopted by the Argentine government in response; (ix) changes in economic or fiscal policies implemented by the Argentine government; (x) labor disputes and work stoppages; (xi) the level of expenditure by the Argentine government and ability to sustain fiscal balance; (xii) the level of unemployment, political instability and social tensions, such as land-takings and claims in areas where we operate.
The Argentine economy has experienced significant volatility in recent decades, characterized by periods of low or negative growth, high levels of inflation and currency devaluation. Sustainable economic growth in Argentina is dependent on a variety of factors, including the international demand for Argentine exports, the stability and competitiveness of the peso against foreign currencies, confidence among consumers and foreign and domestic investors, a stable rate of inflation, national employment levels and the circumstances of Argentina’s regional trade partners.
Argentina has experienced repeatedly, especially in recent years, periods of high inflation. High inflation rates affect Argentina’s foreign competitiveness, social and economic inequality, negatively impacts employment, consumption and the level of economic activity and undermines the confidence in Argentina’s banking system, which could further limit the availability of and access by local companies to domestic and international credit. If the measures adopted by the Argentine government fail to correct Argentina’s structural inflationary imbalances, inflation may continue or increase and have an adverse effect on Argentina’s economy and on our business, financial condition and results of operations. Inflation can also lead to an increase in Argentina’s local currency-denominated debt and have an adverse effect on Argentina’s ability to service its debt, mainly in the medium and long term when most inflation-indexed debt matures.
Argentina’s fiscal imbalances, its dependence on foreign revenues to cover its fiscal deficit, and material rigidities that have historically limited the ability of the economy to absorb and adapt to external factors, have added to the severity of the current crisis.
In the past, some governments increased direct intervention in the Argentine economy, including the implementation of expropriation measures, price controls, exchange controls and changes in laws and regulations affecting foreign trade and investment. These measures had a material adverse effect on private sector entities, including us. It is possible that similar measures could be adopted by the current or future Argentine Government or that economic, social and political developments in Argentina, over which we have no control, could have a material adverse effect on the Argentine economy and, in turn, adversely affect our financial condition and results of operations. Uncertainty with respect to government policies may lead to additional volatility of Argentine stock market prices including companies that operate in the energy sector, given the degree of state regulation and intervention in this industry.
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As in the recent past, Argentina’s economy may be adversely affected if political and social pressures inhibit the implementation by the Argentine Government of policies designed to control inflation, generate growth and enhance consumer and investor confidence, or if policies implemented by the Argentine Government that are designed to achieve these goals are not successful. These events could materially adversely affect our financial condition and results of operations.
As of July 1, 2018, the Argentine Peso qualifies as a currency of a hyperinflationary economy and we are required to restate our historical financial statements to apply inflationary adjustments, which could adversely affect our results of operations and financial condition and those of our Argentine subsidiaries.
Pursuant to the International Accounting Standard 29, Financial Reporting in Hyperinflationary Economies (“IAS 29”), the financial statements of entities whose functional currency is that of a hyperinflationary economy must be adjusted for the effects of changes in a general price index. IAS 29 does not prescribe when hyperinflation arises and the International Accounting Standards Board (“IASB”) does not identify specific hyperinflationary jurisdictions. However, IAS 29 provides a series of non-exclusive guidelines that consist of (i) analyzing the behavior of the population, prices, interest rates and wages before the evolution of price indexes and the loss of the currency’s purchasing power, and (ii) as a quantitative characteristic, verifying if the three-year cumulative inflation rate approaches or exceeds 100%. In June 2018, the International Practices Task Force of the Centre for Quality (“IPTF”), which monitors countries experiencing high inflation, categorized Argentina as a country with projected three-year cumulative inflation rate greater than 100%. In addition, certain qualitative macroeconomic factors provided under the International Accounting Standard 29, Financial Reporting in Hyperinflationary Economies (“IAS 29”) were also identified. Therefore, Argentine companies using IFRS, such as us, are required to apply IAS 29 to their financial statements for periods ending on and after July 1, 2018. As a result, our Audited Consolidated Financial Statements included in this annual report, including the figures for the previous periods (this fact not affecting the decisions taken on the financial information for such periods), and, unless otherwise stated, the financial information included elsewhere in this annual report, were restated to consider the changes in the general purchasing power of the functional currency of the Company (Argentine peso) pursuant to IAS 29 and General Resolution No. 777/2018 of the CNV.
Significant fluctuations in the value of the peso could adversely affect the Argentine economy and, in turn, adversely affect our results of operations
The depreciation of the peso has had, and may continue to have a negative impact on the ability of certain Argentine businesses to service their foreign currency-denominated debt, lead to inflation, significantly reduce real wages and jeopardize the stability of businesses, such as ours, whose success depends on domestic market demand and adversely affect the Argentine Government’s ability to honor its foreign debt obligations. In 2021, the peso depreciated approximately 22,07%, and 11.81% from December 30, 2021 through April 26, 2022. On April 26, 2022, the exchange rate was Ps. 114.85 to US$1.00, as quoted by the Banco de la Nación Argentina for wire transfers (divisas).
The main effects of the devaluation of the Argentine peso on our net results, expressed in pesos, are related to (i) exchange rate differences as a result of our exposure to the dollar, (due to the fact that our functional currency is the Argentine peso); (ii) higher revenues generated by the sale of energy priced in U.S. dollars, and (iii) higher costs generated by expense items priced in U.S. dollars such as financial obligations and certain maintenance contracts among other costs. In addition, the majority of our debt is denominated in currencies other than the peso; consequently, a devaluation of the peso against such currencies will increase the amount of pesos we need to cover our debt service obligations.
If the peso depreciates further, all the negative effects on the Argentine economy related to such depreciation could recur, with adverse consequences to our business, financial condition and results of operations. In addition, a further depreciation of the Argentine Peso against the U.S. dollar may also have an adverse impact on our capital expenditure program and increase the Argentine Peso amount of our trade liabilities and financial debt denominated in U.S. dollars. As of December 31, 2021, 100% of our financial liabilities were denominated in U.S. dollars.
The Company remains highly exposed to risks associated with the fluctuation of the Argentine Peso, therefore, a devaluation of the Argentine Peso could have a material adverse effect on our financial condition and results of operations.
Exchange controls and restrictions on capital inflows and outflows could limit the availability of international credit and could threaten the financial system, adversely affecting the Argentine economy and, as a result, our business
The Argentine government and the BCRA have implemented certain measures that control and restrict the ability of companies and individuals to access to the foreign exchange market to purchase foreign currency and to transfer it abroad. Those measures include, among others: (i) restricting access to the Argentine foreign exchange market for the purchase or transfer of foreign currency abroad for any purpose, including the payment of dividends to non-residents stakeholders; (ii) restrictions on the acquisition of any foreign currency to be held as cash in Argentina; (iii) requiring exporters to repatriate and settle in pesos, in the local exchange market, all or a portion of the proceeds of their exports of goods and services; (iv) limitations on the transfer of securities into and from Argentina; (v) establishing certain mandatory refinancing’s; and (vi) the implementation of taxes on certain transactions involving the acquisition of foreign currency.
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The exchange controls introduced gave rise to an unofficial U.S. dollar trading market. As of the date of this annual report, the peso/U.S. dollar exchange rate in such market substantially differs from the official peso/U.S. dollar exchange rate. The Argentine government could maintain a single official exchange rate or create multiple exchange rates for different types of transactions, substantially modifying the applicable exchange rate at which we acquire currency to service our outstanding foreign currency denominated liabilities.
There can be no assurance that the BCRA or other government agencies will not increase or relax such controls or restrictions, make modifications to these regulations, impose further mandatory refinancing plans related to our indebtedness payable in foreign currency, establish more severe restrictions on currency exchange, or maintain the current foreign exchange regime or create multiple exchange rates for different types of transactions, substantially modifying the applicable exchange rate at which we acquire currency to service our outstanding liabilities denominated in currencies other than the peso, all of which could affect our ability to comply with our financial obligations when due, raise capital, refinance our debt at maturity, obtain financing, execute our capital expenditure plans, and/or undermine our ability to pay dividends to foreign shareholders. Consequently, these exchange controls and restrictions could materially adversely affect the Argentine economy and/or our business, financial condition, and results of operations. See “Exchange Controls.”
Argentina’s ability to obtain financing from international markets is limited, which could affect its capacity to implement reforms and sustain economic growth, and may negatively impact our financial condition or cash flows
During recent years the Argentine Republic has experienced financial distress, leading to an increase in the incurrence of public debt.
During 2020 the Argentine government engaged in negotiations with Argentina´s creditors to restore the sustainability of its public external debt. In August 2020, the Argentine government restructured approximately U.S.$66.5 billion of its foreign currency global bonds issued under foreign laws exchanging such bonds for new bonds. Moreover, Argentina reached an agreement with the Paris Club members under the Paris Club 2014 Settlement Agreement to extend the maturity of its obligations until March 2022. In addition, the Argentine government-initiated negotiations with the International Monetary Fund (“IMF”) in order to renegotiate the principal maturities of the U.S.$ 44.1 billion disbursed between 2018 and 2019 under a Stand-By Agreement, originally planned for the years 2021, 2022 and 2023. On March 22, 2022, the Argentine government reached an agreement with the Paris Club for a new extension of the understanding reached in June 2021 (the “Paris Club Agreement”).
On January 28, 2022, the Argentine government and the IMF announced that they had reached an understanding on key policies as part of their ongoing discussions involving an IMF-supported program. Later, on March 3, 2022, the IMF and the Argentine government announced that the agreement is based on what is known as the IMF's Extended Fund Facility, which includes 10 reviews to be carried out quarterly for two and a half years and disbursements for an amount equivalent to US$44 billion, including a disbursement of US$9.6 billion immediately available to Argentina upon approval of the agreement by the IMF executive board (the “EFF Agreement”). The EFF Agreement was approved by the Argentine Congress through Law No. 27,668 on March 17, 2022 (enacted by Decree No. 130/22) and by the executive board of the IMF on its meeting held on March 25, 2022.
We cannot assure that the EFF Agreement and the Paris Club Agreement will not affect Argentina´s ability to implement reforms and public policies and boost economic growth. Consequently, there can be no assurance that the implementation of the revenue and expenditure policies of the EFF Agreement regarding the reduction of untargeted energy subsidies would not have material adverse effect on our financial condition and results of operations. Also, we cannot predict the impact of the outcome of such reforms on Argentina’s (and indirectly our) ability to access the international capital markets. Moreover, the long-term impact of these measures and any future measures taken by the current administration on the Argentine economy remains uncertain.
In addition, the Argentine Republic’s future tax revenue and fiscal results may be insufficient to meet its debt service obligations and the Argentine Republic may have to rely in part on additional financing from domestic and international capital markets, the IMF and other potential creditors, in order to meet future debt service obligations. In the future, the Argentine Republic may not be able or willing to access international or domestic capital markets, which could have a material adverse effect on the Argentine Republic’s ability to make payments on its outstanding public debt, and in turn, could materially adversely affect our financial condition and results of operations.
In spite of the restructuring of the Argentine public debt carried out in 2020, the international markets continued showing signs of doubts as to whether Argentina’s debt is sustainable and, therefore, country risk indicators remain high. Without renewed access to the financial market the Argentine government may not have the financial resources to implement reforms and boost growth, which could have a significant adverse effect on the country’s economy and, consequently, on our activities. Likewise, Argentina’s inability to obtain credit in international markets could have a direct impact on the Company’s ability to access those markets to finance its operations and its growth, including the financing of capital investments, which would negatively affect our financial condition, results of operations and cash flows. In addition, we cannot predict the outcome of any future restructuring of Argentine sovereign debt. Any new event of default by the Argentine government could negatively affect their valuation and repayment terms, as well as have a material adverse effect on the Argentine economy and, consequently, our business and results of operations.
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The Argentine economy could be adversely affected by economic developments in other markets and by more general “contagion” effects
Financial and securities markets in Argentina and the Argentine economy are influenced by the effects of global or regional financial crisis and market conditions in other markets worldwide. Weak, flat or negative economic growth of any of Argentina’s major trading partners, such as Brazil (Argentina’s main trading partner), China or the United States, could have a material adverse effect on Argentina’s trade balance and adversely affect Argentina’s economic growth. The economic performance of other trading partners such as Chile, Spain and Canada may also affect Argentina’s trade balance.
Global economic instability such as uncertainty about global trade policies, the deterioration of economic conditions in Brazil and of the economies of other major trading partners of Argentina, such as China or the United States, the withdrawal of the United Kingdom from the European Union (“Brexit”), geopolitical tensions between the United States and a number of foreign countries, the conflict between Russia and Ukraine, decisions by the Organization of Petroleum Exporting Countries (OPEC) and other non-OPEC oil-producing nations with respect to oil production that affect oil prices, idiosyncratic, political and social discords, terrorist attacks, sovereign debt downgrades, a pandemic disease, including the result of the ongoing COVID-19 pandemic, could impact the Argentine economy and jeopardize Argentina’s ability to stabilize its economy, among others.
These developments, or the perception that any of them could occur, may have a material adverse effect on global economic conditions and the stability of global financial markets. Any of these factors could depress economic activity and restrict our access to suppliers and have a material adverse effect on our business, financial condition, and results of operations.
The Argentine economy may be affected by “contagion” effects. International investors’ reactions to events occurring in one developing country sometimes appear to follow a “contagion” effect, in which an entire region or investment class is disfavored by international investors.
Consequently, there can be no assurance that the Argentine economy and securities markets will not be adversely impacted by events affecting developed economies, emerging markets, or any of Argentina’s major trading partners, which could in turn adversely affect our business, financial condition, and results of operations, and the market value of our ADSs. Furthermore, a significant devaluation of the currencies of our trading partners or trade competitors may adversely affect the competitiveness of Argentina and consequently, adversely affect Argentina’s economy and our financial condition and results of operations.
We may be exposed to adverse effects arising from the ongoing conflict between Russia and Ukraine
Russia’s military incursion into Ukraine has led to, and could continue to give a rise to an escalation of armed action, regional instability and result in heightened economic sanctions by the United States, the European Union, and other countries against Russia. Although the severity and duration of the ongoing military action is highly unpredictable, its effects could be substantial, and any continuation of the conflict could adversely affect global and regional economic conditions.
As of the date of this annual report, the ongoing conflict has led to a significant increase in commodity prices and international crude oil and gas prices, which has resulted in higher fuel prices and – consequently – in a sharper rise in inflation around the world. Moreover, economic sanctions imposed against Russia may lead to shortage of raw materials and commodities, which could in turn contribute to the increase in inflation worldwide and to interruption to the supply chain in general, and particularly in the energy sector. Such difficulties may consequently derive in constraints to supply the local market. Consequently, this could adversely affect our business, financial condition, or results of operations.
Due to the uncertainties inherent to the scale and duration of these events and its direct and indirect effects, it is not reasonably possible to estimate the impact this armed conflict will have on the world’s economy and its financial markets, on Argentina’s economy and, consequently, our business, financial condition and results of operations. Any such disruptions caused by Russian military action or resulting sanctions may magnify the impact of other risks described in this annual report.
The Argentine banking system may be subject to instability which may affect our operations
In recent years, the Argentine financial system grew significantly with a marked increase in loans and private deposits, showing a recovery of credit activity. Although the financial system’s deposits continue to grow in nominal terms, they are mostly short-term deposits and the sources of medium and long-term funding for financial institutions are currently limited.
Financial institutions are particularly subject to significant regulation from multiple regulatory authorities, all of whom may, among other things, establish limits on commissions and impose sanctions on the financial institutions. The lack of a stable regulatory framework, or changes to such regulatory framework by the government, could impose significant limitations on the activities of the financial institutions and could induce uncertainty with respect to the financial system stability.
The persistence of the current economic crisis or the instability of one or more of the larger banks, public or private, could have a material adverse effect on the prospects for economic growth and political stability in Argentina, resulting in a loss of consumer confidence, lower disposable income and fewer financing alternatives for consumers. These conditions could also have a material adverse effect on the Argentine banking system, and therefore, on our business, financial condition and results of operations.
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Failure to adequately address actual and perceived risks of institutional deterioration and corruption may adversely affect Argentina’s economy and financial condition, which in turn could adversely affect our business, financial condition and results of operations
A lack of a solid institutional framework and corruption have been identified as, and continue to be, a significant problem for Argentina. Recognizing that the failure to address these issues could increase the risk of political instability, distort decision-making processes and adversely affect Argentina’s international reputation and ability to attract foreign investment, the prior administration had adopted several measures aimed at strengthening Argentina’s institutions and reducing corruption. These measures included the reduction of criminal sentences in exchange for cooperation with the government in corruption investigations, increased access to public information, the seizing of assets from corrupt officials, and establishing a corporate criminal liability regime for corruption offenses aimed at promoting anticorruption compliance, among others. The current Argentine Government’s ability to implement them or promote further transparency and integrity measures is uncertain in a highly polarized political context. Argentina’s political environment has historically influenced, and continues to influence, the performance of the country’s economy. Political crises have affected and continue to affect the confidence of investors and the general public, which have historically resulted in economic deceleration and heightened volatility in the securities with underlying Argentine risk. The recent economic instability in Argentina has contributed to a decline in market confidence in the Argentine economy as well as to a deteriorating political environment.
In addition, various ongoing investigations into allegations of money laundering and corruption being conducted by the Office of the Argentine Federal Prosecutor, have negatively impacted the Argentine economy and political environment. Certain government officials of previous administrations as well as high ranked officers of companies holding government contracts or concessions have faced or are currently facing allegations of corruption and money laundering as a result of these investigations. These individuals are alleged to have accepted or paid, as applicable, bribes by means of kickbacks on contracts granted by the government to several infrastructure, energy and construction companies. We have no control over and cannot predict for how long the corruption investigations will continue nor whether such investigations or allegations (or any other future investigations or allegations) will lead to further political and economic instability. In addition, we cannot predict the outcome of any such allegations nor their effect on the different sectors of the Argentine economy. See also “—We are subject to anticorruption, anti-bribery, anti-money laundering and other laws and regulations.”
Risks Relating to the Electric Power Sector in Argentina
The Argentine Government has intervened in the electric power sector in the past, and is likely to continue intervening
Historically, the Argentine government has played an active role in the electric power industry through the ownership and management of state-owned companies engaged in the generation, transmission and distribution of electric power. Moreover, the Argentine government made a number of material changes to the regulatory framework applicable to the electric power sector since the Argentine economic crisis of 2001 , including adopting Law No. 25,561 (the “Public Emergency Law”), which have had significant adverse effects on electric power generation, distribution and transmission companies and included the freezing of distribution margins, the revocation of adjustment and inflation indexation mechanisms for tariffs, a limitation on the ability of electric power distribution companies to pass on to the consumer increases in costs due to regulatory charges and the introduction of a new price-setting mechanism in the WEM, all of which had a significant impact on electric power generators and caused substantial price differences within the market.
Any significant increase in energy prices to consumers (whether through a tariff increase or through a cut in consumer subsidies) could result in a decline in demand for the energy that we generate. Any material adverse effect on electric power demand, in turn, could lead electric power generation companies, like us, to record lower revenues and results of operations than currently anticipated.
It is possible that certain measures may be adopted by the Argentine Government that could have a material adverse effect on our business and results of operations, or that the Argentine Government may adopt emergency legislation similar to the Public Emergency Law or other similar resolutions in the future that could have a direct impact on the regulatory framework of the electric power industry and indirectly adversely affect the electric power generation industry, and therefore, our business, financial condition and results of operations.
Changes in regulatory frameworks under which we sell our electricity may affect our financial condition and results of operations
We cannot assure what further changes the Argentine Government may make to the regulatory frameworks under which we sell power availability or electricity, nor that these changes will not negatively impact our results of operations. Moreover, we cannot assure under what kind of regulatory framework we will be able to sell our generation capacity and electricity in the future. Any further changes in the current applicable laws and regulations, or adverse judicial or administrative interpretations of such laws and regulations, may adversely affect our results of operations. In addition, some of the measures proposed by the Argentine government may also generate political and social opposition, which may in turn prevent the Argentine government from adopting such measures as proposed.
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The factors mentioned above for both our operation of power generation and the projects under construction/development, may also lead to an impairment of property, plant and equipment and intangible assets, related to a reduction in the assessed value-in-use of certain assets that may exceed their previously recorded book value.
We have, in the recent past, been unable to collect payments, or to collect them in a timely manner, from CAMMESA and other customers in the electric power sector
A substantial amount of our total revenues comes from our sales to CAMMESA. In addition, we receive significant cash flows from CAMMESA in connection with the FONINVEMEM and similar programs. Payments to us by CAMMESA, depend upon payments that CAMMESA in turn receives from other WEM agents such as electric power distributors as well as subsidies from the Argentine government to certain users, which in turn requires additional funding to CAMMESA from the government to pay to generators.
In recent years, due to regulatory conditions and long periods of frozen tariffs in Argentina’s electric power sector that affected the profitability and economic viability of power utilities, certain WEM agents defaulted on their payments to CAMMESA, which adversely affected CAMMESA’s ability to meet its payment obligations with electric power generators, including us. As a consequence of delays in payments that CAMMESA received from other WEM agents, we also saw delays in , receiving payments from CAMMESA more than 90 days of month-end, rather than the required 42 days after the date of billing. Such payment delays resulted in higher working capital requirements that we would typically finance with our own financing sources.
As of the date of this annual report, CAMMESA is facing difficulties to make payments to generators both in respect of energy dispatched and generation capacity availability on a timely basis or in full, which in turn may substantially and adversely affect our financial position and the results of our operations.
Argentina has certain energy transmission and distribution limitations that adversely affect the capacity of electric power generators to deliver all of the energy they can to produce, which results in reduced sales
The energy that generators can deliver to the transmission system for the further delivery to the distribution system at all times depends on the capacity of the transmission and distribution systems that connects them to it. In the past, the transmission and distribution system operated at near full capacity and both transmission and distributors were not able to guarantee an increased supply of electric power to their customers. In the past years, the increase in demand for electric power resulted in blackouts in Buenos Aires and other cities around Argentina, which resulted in excess capacity for generators. As a result, the amount of hydroelectric energy and thermal energy generated was larger than what the transmission and distribution systems are capable of transmitting or distributing. Any transmission or distribution limitation for generators could reduce the energy sold, which could adversely affect our financial condition
Restrictions on the supply of energy could negatively affect Argentina’s economy .
Demand for natural gas and electricity has increased substantially, driven by a recovery in economic conditions and price constraints, which has prompted the government to adopt a series of measures that have resulted in industry shortages and/or costs increase. In particular, Argentina has been importing gas in order to compensate the shortage in local production. In order to pay for those imports the Argentine government has frequently used the Argentine Central Bank reserves due to absence of incoming currencies from investment. Argentina’s foreign exchange reserves are particularly limited and, therefore, Argentina’s ability to deal with significant increases in international oil and gas prices remains limited. If the Argentine government is unable to pay for the gas import in order to produce electricity, business and industries may be affected.
Moreover, the Argentine government has taken a number of measures aimed at alleviating the short-term impact of supply restrictions on residential and industrial users such as importing natural gas from Bolivia, importing liquefied natural gas transported to Argentina in vessels. If these measures prove to be insufficient, or if the investment that is required to increase natural gas production and energy generation over the medium-and long-term fails to materialize on a timely basis, economic activity in Argentina could be curtailed which may have a significant adverse effect on our business.
Continued disruptions in the supply of energy could cause a significant adverse impact on the electric power generation industry, and therefore, our business, financial condition and results of operations.
We operate in a heavily regulated sector that imposes significant costs on our business, and we could be subject to fines and liabilities that could have a material adverse effect on our results of operations
We are subject to a wide range of federal, provincial and municipal regulations and supervision, including laws and regulations pertaining to tariffs, labor, social security, public health, consumer protection, the environment and competition. Furthermore, Argentina has 23 provinces and one autonomous city (the City of Buenos Aires), each of which, under the Argentine National Constitution, has power to enact legislation concerning taxes, environmental matters and the use of public space. Within each province, municipal governments can also have powers to regulate such matters. Although the generation of electric power is considered an activity of general interest (actividad de interés general) subject to federal legislation, since our facilities are located throughout various provinces, we are also subject to provincial and municipal legislation. Future developments in the provinces and municipalities concerning taxes (including sales, security and health and general services taxes), environmental matters, the use of public space or other matters could have a material adverse effect on our business, results of operations and financial condition. Compliance with existing or future legislation and regulations could require us to make material expenditures and divert funds away from planned investments in a manner that could have a material adverse effect on our business, results of operations and financial condition.
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In addition, our failure to comply with existing regulations and legislation, or reinterpretations of existing regulations and new legislation or regulations, such as those relating to fuel and other storage facilities, volatile materials, cyber security, emissions or air quality, hazardous and solid waste transportation and disposal and other environmental matters, or changes in the nature of the energy regulatory process may subject us to fines and penalties and have a significant adverse impact on our financial results.
Risks arise for our business from technological change in the energy market
The energy market is subject to far-reaching technological change, both on the generation side and on the demand side. For example, with respect to energy generation, the development of energy storage devices (battery storage in the megawatt range) or facilities for the temporary storage of power through conversion to gas (so-called “power-to-gas-technology”), the increase in energy supply due to new technological applications such as fracking or the digitalization of generation and distribution networks should be mentioned.
New technologies to increase energy efficiency and improve heat insulation, for the direct generation of power at the consumer level, or that improve refeeding (for example, by using power storage for renewable generation) may, on the demand side, lead to structural market changes in favor of energy sources with low or zero carbon dioxide emissions or in favor of decentralized power generation, (for instance, via small-scale power plants within or close to residential areas or industrial facilities.)
If our business is unable to react to changes caused by new technological developments and the associated changes in market structure, our equity, financial or other position, or our results, operation and business, could be materially and adversely affected.
Competition in the Electric Power Sector in Argentina may adversely affect our results of operations
The power generation markets in which we operate are characterized by numerous strong and capable participants, many of which may have extensive and diversified developmental or operating experience (including both domestic and international) and financial resources similar to or significantly greater than ours. See “Item 4.B. Business Overview—Competition.” An increase in competition could cause reductions in prices and increase acquisition prices for fuel, raw materials and existing assets and therefore, adversely affect our results of operations and financial condition.
From time to time, we also compete with other generation companies for the megawatt of capacity that are allocated through public auction processes.
We and our competitors are connected to the same electrical grid that has limited capacity for transportation, which, under certain circumstances, may reach its capacity limits. Therefore, new generators may connect, or existing generators may increase, their outputs and dispatch more electric power to the same grid that would prevent us from delivering our energy to our customers. In addition, the Argentine Government (or any other entity on its behalf) might not make the necessary investments to increase the system’s capacity, which, in case there is an increase of energy output, would allow us and existing and new generators to efficiently dispatch our energy to the grid and to our customers. As a result, an increase in competition could affect our ability to deliver our product to our customers, which would adversely affect our business, results of operations and financial condition.
Risks Relating to Our Business
Our results depend largely on the compensation established by the Secretariat of Electric Energy and received from CAMMESA
Since the enactment of Resolution SE No. 95/13, issued by the former Secretariat of Electric Energy, as amended, our compensation has depended largely on the compensation determined by energy output and availability. Furthermore, on February 27, 2020, the Secretary of Energy of the National Ministry of Production Development issued Resolution 31/20 which determined the remuneration scheme applicable from February 1, 2020, for Authorized Generators in the WEM, establishing Energía Base prices in Argentine pesos. On April 8, 2020, the Secretary of Energy instructed CAMMESA to postpone until further notice the application of the mechanism for updating the prices of energy and capacity provided for in Annex VI of Resolution 31/20. Since the settlement of the transaction due on March 2020, CAMMESA has not applied the aforementioned mechanism, which has caused a material adverse effect on our business and results of operations. We cannot assure you that further reductions of these tariffs will not occur in the future. See “Item 4.B. Business Overview—The Argentine Electric Power Sector—Remuneration Scheme—The Current Remuneration Scheme.”
Except for sales under contracts, revenues from energy production are calculated and paid by CAMMESA pursuant to a fixed and variable price system arising from the Resolution 440/21 (which amended Resolution 31/20), amended by Resolution No. 238/22, and set in Argentine pesos. See “Item 5.A. Operating Results—Factors Affecting Our Results of Operations—Our Revenues—The Energía Base” and “Item 3.D. Risk Factors—Risks Relating to the Electric Power Sector in Argentina—We have, in the recent past, been unable to collect payments, or to collect them in a timely manner, from CAMMESA and other customers in the electric power sector”.
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As a result of this system, our revenues are highly dependent on actions taken by regulatory authorities. The continued suspension of price update mechanisms, lack of regulated tariffs increases by the Argentine Government and/or delays to implement such increases in a timely manner could have a material adverse effect on our revenues and, as a result, our results of operations.
Factors beyond our control may affect or delay the completion of the awarded projects or alter our plans for the expansion of our existing plants
With regards to projects currently under development or new potential projects, several factors may affect, delay or cancel the completion of such projects currently under development or new projects: a) sustained or prolonged COVID-19 outbreak, a resurgence or the emergence of a new strain of coronavirus for which current vaccines may be less effective and their respective effects, b) the economic recession in Argentina, c) the decrease in demand of electric energy, d) the lack of available financing, and e) the reduction in the prices of electric energy for power units under Energía Base, among others.
Delays in construction or commencement of operations of expanded capacity in our existing power plants or our new power plants could lead to an increase in our financial needs and cause our financial returns on new investments to be lower than expected, which could materially adversely affect our financial condition and results of operations. Furthermore, delays in the commencement of operation of our gas turbines has negatively affected its estimated recoverability. See “Item 5.A. Operating Results—Critical Accounting Policies—Impairment of Property, Plant and Equipment”.
Factors that may impact our ability to commence operations at our existing power plants, expand their power capacity or build new power plants include: (i) the failure of contractors to complete or commission the facilities or auxiliary facilities by the agreed-upon date or within budget; (ii) the unexpected delays of third parties such as gas or electric power distributors in providing or agreeing to project milestones in the construction or development of necessary infrastructure linked to our generation business; (iii) the delays or failure by our turbine suppliers in providing fully operational turbines in a timely manner; (iv) difficulty or delays in obtaining the necessary financing in terms satisfactory to us or at all; (v) delays in obtaining regulatory approvals, including environmental permits; (vi) court rulings against governmental approvals already granted, such as environmental permits; (vii) shortages or increases in the price of equipment reflected through change orders, materials or labor; (viii) opposition by local and/or international political, environmental and ethnic groups; (ix) strikes; (x) adverse changes in the political and regulatory environment in Argentina; (xi) unforeseen engineering, environmental and geological problems; (xii) adverse weather conditions, natural disasters, accidents or other unforeseen events, and (xiii) the COVID-19 pandemic crisis (See “Item 3.D. Risk Factors—Risks Relating to Our Business”, in particular “—An outbreak of a disease, including COVID-19, may have material adverse consequences on our operations including new projects”, which describes the potential impact of COVID-19 over certain of our projects.”). Any cost overruns could be material. In addition, any of these other factors may cause delays in the completion of expanded capacity at our existing power plants or the construction of our new power plant, which could have a material adverse effect on our business, financial condition and results of operations. These delays may also result in short-term sanctions by CAMMESA and, in extreme cases, sanctions for the duration of the contract.
Our business may require substantial capital expenditures for ongoing maintenance requirements and the expansion of our installed generation capacity
Incremental capital expenditures may be required to fund ongoing maintenance necessary to maintain our power generation and operating performance and improve the capabilities of our electric power generation facilities. Furthermore, capital expenditures will be required to finance the cost of our current and future expansion of our generation capacity. If we are unable to finance any such capital expenditures in terms satisfactory to us or at all, our business and the results of our operations and financial condition could be adversely affected. Our financing ability may be limited by market restrictions on financing availability for Argentine companies. See “—Risk Relating to Argentina— Argentina’s ability to obtain financing from international markets is limited, which could affect its capacity to implement reforms and sustain economic growth and may negatively impact our financial condition or cash flows” and “Item 4.B. Business Overview.”
Covenants in our indebtedness could adversely restrict our financial and operating flexibility
Some of our current indebtedness (including the debt of our subsidiaries, some of which is guaranteed by us) includes, and our future indebtedness may include, affirmative and restrictive covenants that limit our ability to create liens, incur additional indebtedness, making capital expenditures, dispose of our assets, pay dividends, or consolidate, merge or sell part of our businesses, and require us to maintain certain financial ratios. See “Item 5.B. Liquidity and Capital Resources—Indebtedness.” These restrictions may limit our ability to operate our business and may prohibit or limit our ability to enhance our operations or take advantage of potential business opportunities as they arise. The breach of any of these covenants or the failure to meet any of such conditions could result in a default under the relevant indebtedness. Our ability to comply with these covenants may be affected by events beyond our control, including prevailing economic, financial and industry conditions. If any such default occurs, the holders of such indebtedness may elect (after the expiration of any applicable notice or grace periods) to declare all outstanding amounts, together with accrued and unpaid interest and other amounts payable thereunder, to be immediately due and payable. Further, any such default occurs, it could, in turn, result in a default and acceleration of our other outstanding debt obligations, which would have a further material adverse effect on our business, ability to meet our payment obligations, financial condition, and results of operations. If any of our debt were to be accelerated, our assets may not be sufficient to repay in full that debt or any other debt that may become due as a result of that acceleration.
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We may be unable to refinance our outstanding indebtedness, or the refinancing terms may be materially less favorable than their current terms, which would have a material adverse effect on our business, financial condition and results of operations.
Factors beyond our control may impair our ability to meet our debt obligations or increase the cost of financing, which in turn, could have a material adverse effect on our cash flow, results of operations and overall financial position.
There is no assurance that we will be able to extend the maturity or otherwise refinance our outstanding indebtedness, or that we may be required to agree to refinancing terms that may be materially less favorable than the terms of our current loans. Any amendment to or refinancing of our indebtedness could result in higher interest rates and may require us to comply with more burdensome restrictive covenants, which may have a material adverse effect on our business, ability to meet our payment obligations, financial condition, and results of operations.
If we are unable to refinance our debt in favorable terms, we may be forced to reduce or delay capital expenditures seek additional equity capital, restructure our debt, curtail or eliminate our cash dividend to stockholders, or sell assets. Non-payment of our obligations or any other default under any of our debt instruments could, in turn, result in a default and acceleration of our other outstanding debt obligations, which would have a further material adverse effect on our business, ability to meet our payment obligations, financial condition, and results of operations. If any of our debt were to be accelerated, our assets may not be sufficient to repay in full that debt or any other debt that may become due as a result of that acceleration.
The non-renewal or early termination of the HPDA Concession Agreement would adversely affect our results of operations
The HPDA Concession Agreement executed between us and the Argentine Government, pursuant to which we are permitted to operate our Piedra del Águila plant, expires on December 28, 2023, and does not provide for an automatic renewal. This plant has a total installed capacity of 1,440 MW, and it represented approximately 18% of our total electric energy generation, and 9.2% of our total revenues in 2021. We currently intend to renew the HPDA Concession Agreement prior to its expiration. If the HPDA Concession Agreement expires without renewal, we will be required to revert the assets to the Argentine Government. The HPDA Concession Agreement also contains various requirements related to the operation of the hydroelectric plant and compliance with laws and regulations. The non-performance of the HPDA Concession Agreement could give rise to certain penalties and even the termination of the concession. If the concession were terminated, it would be granted to a new company organized by the Argentine Government and a tender offer would be carried out for selling the new company’s shares of stock. The proceeds to be received by us in such tender offer would be calculated based on a formula in which the proceeds of the tender decrease as the expiration of the concession term comes closer. Any non-renewal or early termination of the HPDA Concession Agreement would materially and adversely affect our financial condition and results of operation.
Our interests in TJSM, TMB were diluted and CVOSA will be significantly diluted
As of December 31, 2020, we had a 30.8752% interest in TJSM which was reduced to 9.6269% during 2021 and a 30.9464% interest in TMB which was also reduced during 2021 to 10.8312%. Both companies are engaged in managing the purchase of equipment, building, operating, and maintaining power plants constructed under the FONINVEMEM program. As of the date of this annual report, we also own 56.19% of CVOSA, the company that operates the thermal power plant in Timbúes.
After ten years of operations, TJSM and TMB were entitled to receive property rights to such power plants from the respective trusts currently holding such power plants. At such time, the term of the trusts expired and the Argentine Government, that financed part of the construction, should be incorporated as a shareholder of TJSM and TMB. Consequently, our interests in TJSM and TMB were diluted in 2021. In the case of TMB and TJSM, the ten-year period expired on January 7, 2020 and on February 2, 2020, respectively. From such dates, during the following 90-days, TJSM and TMB and their shareholders had to perform all the necessary acts to allow the Argentine Government to receive the corresponding shares in the equity stake of TJSM and TMB that their contributions entitle the Argentine Government to receive.
On January 3, 2020, before the aforementioned 90 days period commenced, the Argentine Government sent a notice to the Company (together to TSM, TMB and to other generation companies that are shareholders of TJSM and TMB) stating that, in accordance with FONINVEMEM Agreement, TJSM and TMB should perform all necessary acts to incorporate the Argentine Government as shareholder of both companies, claiming, in each case, the following equity interest rights: 65.006% in TMB and 68.826% in TJSM.
On January 9, 2020, the Company, together with the other generation companies, shareholders of TJSM and TMB, replied such notice stating that the Argentine Government’s equity interest claims did not correspond with the contributions made for the construction of the power plants under the terms of the FONINVEMEM Agreement that give rights to claim such equity interest. On March 4, 2020, the Argentine Government reiterated its previous claim to the Company.
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Additionally, on January 7, 2020 and on January 9, 2020, Central Puerto, together with the other shareholders of TJSM and TMB (as guarantors within the framework and the limits stated by the FONINVEMEM Agreement, the Note SE no. 1368/05 and the trust agreements), BICE, TJSM, TMB and the Energy Secretariat amended the Operation and Maintenance Agreement of the Manuel Belgrano Thermal Facility (the “TMB OMA”) and the Operation and Maintenance Agreement of the San Martín Thermal Facility ( the “TJSM OMA”), respectively. The amendments to the TMB OMA and TJSM OMA extended the agreements until each of the trust’s liquidation effective date.
In March 2020, Central Puerto filed an administrative appeal against the Argentine Government challenging their acts referred to above (the “Claim”). Pursuant to this Claim, the position of the shareholders of TJSM and TMB is that the Argentine Government equity interest in each of the companies should be lower but its incorporation as a shareholder in such companies is unchallenged. Therefore, even if we are successful with our Claim, our interests on TJSM and TMB is significantly diluted.
On May 4, 2020, and May 8, 2020, the extraordinary shareholders’ meetings of TMB and TJSM, respectively, approved the incorporation of the Argentine Government as shareholder of TJSM and TMB. In each of the extraordinary shareholders’ meetings, the equity interest that was approved was the equity interest that the Argentine Government claims that it is entitled to, which is: 65.006% in TMB and 68.826% in TJSM.
In each of the shareholders’ meetings, Central Puerto (and other shareholders), made the corresponding reservation of rights to continue with the Claim, and expressly stated that the incorporation of the Argentine Government as a shareholder in TMB and TJSM was approved for the sole purpose of achieving the transfer of the trust assets -which includes, among others, the power plants- from the respective trusts to TJSM and TMB.
On March 11, 2021, the Argentine Government has subscribed its shares and the equity of the shareholders of TJSM and TMB were diluted. In the case of our equity interest, from 30.8752% to 9.6269% in TJSM and from 30.9464% to 10.8312% in TMB.As of the date of this annual report, the transfer of power stations to TSM and TMB was not completed.
In the case of CVOSA, when the CVO Trust term expires after ten years of operation of the respective power plant the Argentine Government will be incorporated as shareholder, with a stake of at least 70% pursuant to FONINVEMEM arrangements for CVOSA.
The dilution of our interest in CVOSA will reduce our income from this power plant, adversely affecting our results of operations. See “Item 4.B. Business Overview—FONINVEMEM and Similar Programs.”
Future changes in the rainfall amounts in the Limay River basin could adversely affect the revenues from the Piedra del Águila concession and, therefore, our financial results
As a hydroelectric facility, Piedra del Águila depends on the availability of water resources in the Limay River basin for electric power generating purposes, which in turn depends on the rainfall amounts in the area and water from thaw. Lack of water resulted in lower electric power generation and, therefore, lower revenue.
In the event of critically low water levels, the Intergovernmental Basin Authority, which is in charge of managing the basin of the Limay, Neuquén and Negro rivers, is entitled to manage the water flows according to its flow control standards, which could result in lower water resources for us, which in turn, would result in decreased generation activities. Further, under the HPDA Concession Agreement, we are not entitled to receive any compensation for revenue losses as a result of such actions.
The Limay River basin’s flow may not be sufficient to maintain a regular generation level at Piedra del Águila and the enforcement authority may implement unfavorable measures for Piedra del Águila, and therefore, for us, which could adversely affect our financial condition and our results of operations. For further information about Piedra del Águila’s seasonality, see “Item 4.B. Business Overview—Seasonality.”
Our ability to operate wind farms profitably is highly dependent on suitable wind and associated weather conditions
The energy generated by, and the profitability of, wind farms are highly dependent on climate conditions, particularly wind conditions, which can vary materially across locations, seasons and years. Variations in wind conditions at wind farm sites occur as a result of daily, monthly and seasonal fluctuations in wind currents and, over the longer term, as a result of more general climate changes and shifts. Because turbines will only operate when wind speeds fall within certain specific ranges that vary by turbine type and manufacturer, if wind speeds fall outside or towards the lower end of these ranges, energy output at our wind farms would decline.
If in the future the wind resource in the areas where our wind farms are located is lower than expected, electricity production at such wind farms would be lower than expected and consequently could materially adversely affect our results of operations.
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Climate change and energy transition could affect our business
We are and will be, directly and indirectly, subject to the effects of climate change and may, directly or indirectly, be affected by local and national laws, as well as international treaties and conventions, and implementing regulations related to climate change. Any passage of climate control treaties, legislation, or other regulatory initiatives by the Argentine government that restrict emissions of greenhouse gases (“GHGs”) could require us to make significant financial expenditures that we cannot predict with certainty at this time. This could include, for example, the adoption of regulatory frameworks to reduce GHG emissions, such as carbon dioxide, methane and nitrogen oxides. Changes in the regulatory framework could also indirectly impact our business through changes in technology or consumer behavior.
In 2019, the Argentine Congress enacted Law No. 27,520 on Minimal Standards on Global Climate Change Adaptation and Mitigation, focusing on implementing policies, strategies, actions, programs and projects to prevent, mitigate or minimize the damages or impacts associated with climate change. During 2021, the Secretariat of Energy issued Resolution No. 1,036/2021 approving the Guidelines for an Energy Transition Plan to 2030 in order to comply with its new national decarbonization commitments. If additional requirements were adopted in Argentina, these requirements could increase our production costs (including compliance related costs such as for monitoring or reducing emissions) and adversely impact impact our competitiveness and may also shift demand toward low-carbon sources, such as renewable energies.
The risks associated with climate change could impact our operations due to severe weather events, change the consumer profile, talent attraction, and energy transitions in the world economy towards a lower carbon matrix. These factors may have a negative impact on the demand for our products and may affect the implementation and operation of our businesses, adversely impacting our operating and financial results and limiting our growth opportunities.
In addition, the pace and extent of the energy transition could pose a risk to our own transition towards decarbonization does not move in sync with society. If we are slower than society, our reputation may suffer and customers may prefer a different supplier which would adversely impact demand for our products, including the market value of our unconventional acreage and associated resources we expect to develop in the future. If we move faster than society, we risk investing in technologies, markets or low-carbon products that are unsuccessful because there is limited demand for them. Our failure to time the transition of our production to address climate-change related concerns could have a material adverse effect on our earnings, cash flows and financial condition.
Our power plants are subject to the risk of mechanical or electrical failures due to natural disasters, catastrophic accidents or terrorist attacks, and any resulting unavailability may affect our ability to fulfill our contractual and other commitments and thus adversely affect our business and financial performance
Our power generation units are at risk of mechanical or electrical failure and may experience periods of unavailability affecting our ability to generate electric power. Past failures on our generators, turbines and transformers have adversely affected our results of operations. Any unplanned unavailability of our generation facilities may adversely affect our financial condition or results of operations.
Our generation facilities, or the third-party fuel transportation or electric power transmission infrastructure that we rely on, may be damaged by flooding, fires, earthquakes and other catastrophic disasters arising from natural or accidental or intentional human causes. We could experience severe business disruptions, significant decreases in revenues based on lower demand arising from catastrophic events, or significant additional costs to us not otherwise covered by business interruption insurance clauses. There may be an important time lag between a major accident, catastrophic event or terrorist attack and our definitive recovery from our insurance policies, which typically carry non-recoverable deductible amounts, and in any event are subject to caps per event. In addition, any of these events could cause adverse effects on the energy demand of some of our customers and of consumers generally in the affected market. Some of these considerations, could have a material adverse effect on our business, financial condition, and our result of operations.
Although we comply with all applicable environmental safety laws and best practices, any accident involving the fuels with which we operate could have adverse environmental consequences and could damage our industrial facilities or our personnel. Any structural damage to the dam or any other structure located in any of our hydroelectric plants could compromise its electric power generating capacity. Any generation constraints resulting from structural damage could have a material adverse effect on our financial condition and results of operations.
Our insurance policies may not fully cover damage, and we may not be able to obtain insurance against certain risks
We maintain insurance policies intended to mitigate our losses due to customary risks. These policies cover certain of our assets against loss for physical damage, loss of revenue and also third-party liability. However, we may not have sufficient insurance to cover any particular risk or loss. If an accident or other event occurs that is not covered by our current insurance policies, such as cybersecurity risk, we may experience material losses or have to disburse significant amounts from our own funds, all of which could have a material adverse effect on our operations and financial position. In addition, an insufficiency in our insurance policies could have an adverse effect on us. In such case, our financial condition and our results of operations could be adversely affected.See “Item 4.B. Business Overview—Insurance.”
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We may be exposed to lawsuits and or administrative proceedings that could adversely affect our financial condition and results of operations
In the ordinary course of our business, we enter into agreements with CAMMESA and other parties. Litigation and/or regulatory proceedings are inherently unpredictable, and excessive verdicts do occur. Adverse outcomes in lawsuits and investigations could result in significant monetary damages, including indemnification payments, or injunctive relief that could adversely affect our ability to conduct our business and may have a material adverse effect on our financial condition and results of operations.
Energy demand is seasonal, largely due to climate conditions
Energy demand fluctuates according to the season and climate conditions may materially and adversely impact energy demand. During the summer (December through March), energy demand may increase significantly due to the need for air conditioning, and, during winter (June through August), energy demand may fluctuate according to the needs for lighting and heating. As a result, seasonal changes could materially and adversely affect the demand for energy and, consequently, affect our results of operations and financial condition.
We may undertake acquisitions and investments to expand or complement our operations that could result in operating difficulties or otherwise adversely affect our financial conditions and results of operations
In order to expand our business, from time to time, we may carry out acquisitions and investments which offer added value and are consistent with or complementary to our business strategy.
Therefore we may be exposed to various risks, including those arising from: (i) not having accurately assessed the value, future growth potential, strengths, weaknesses and potential profitability of potential acquisition targets; (ii) difficulties in successfully integrating, operating, maintaining or managing newly-acquired operations, including personnel; (iii) unexpected costs of such transactions; (iv) difficulties in obtaining the necessary financing and successfully reaching any required financial closing; or (v) unexpected contingent or other liabilities or claims that may arise from such transactions. If any of these risks were to materialize, it could adversely affect our financial condition and results of operations.
If we were to acquire another energy company in the future, such acquisition could be subject to the Argentine Antitrust Authority’s approval
The Antitrust Law No. 27,442 provides that any transactions involving the acquisition, transfer or control of another company’s assets will be subject to the Autoridad Nacional de la Competencia (“Argentine Antitrust Authority”) prior consent and approval in the event that the sum of the total turnover of all the companies involved exceeds the equivalent of one hundred million (100,000,000) “mobile units” (which value is actualized annually in line with the IPC).
The Argentine Antitrust Authority will determine whether any acquisition subject to its prior approval negatively impacts competitive conditions in the markets in which we compete or adversely affects consumers in these markets. Although we are not contemplating any business combination as of the date of this annual report, if the Argentine Antitrust Authority were to reject any business combination or if such authority were to take any action to impose conditions or performance commitments on us as part of the approval process for any business combination, it could adversely affect our financial condition and results of operations and prevent us from achieving the anticipated benefits of such acquisition.
We depend on senior management and other key personnel for our current and future performance
Our current and future performance depends to a significant degree on our qualified senior management team, and on our ability to attract and retain qualified management. Our future operations could be harmed if any of our senior executives or other key personnel ceased working for us. Competition for senior management personnel is intense, and we may not be able to retain our personnel or attract additional qualified personnel. The loss of a member of senior management may require the remaining executive officers to divert immediate and substantial attention to fulfilling his or her duties and of seeking a replacement. Any inability to fill vacancies in our senior executive positions on a timely basis could harm our ability to implement our business strategy, which would harm our business and results of operations.
We could be affected by material actions taken by the trade unions
Labor relations in Argentina are governed by specific legislation, such as labor Law No. 20,744 and Collective Bargaining Law No. 14,250, which, among other things, dictate how salary and other labor negotiations are to be conducted. Every industrial or commercial activity is regulated by a specific collective bargaining agreement (“CBA”) that groups companies together according to industry sectors and by trade unions. While the process of negotiation is standardized, each chamber of industrial or commercial activity separately negotiates the increases of salaries and labor benefits with the relevant trade union of such commercial or industrial activity.
Argentine employers, both in the public and private sectors, have experienced significant pressure from their employees and labor organizations to increase wages and to provide additional employee benefits. Due to the high levels of inflation, employees and labor organizations are demanding significant wage increases.
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Although we have stable relationships with our work force, in the past we experienced organized work stoppages and strikes, and we may face such work stoppages or strikes in the future. Also, we could be indirectly affected by actions taken by trade unions related to suppliers or other related parties. Labor claims are common in the Argentina energy sector, and in the past, unionized employees have blocked access and caused damages to the facilities of various companies in the industry. Moreover, we have no insurance coverage for business interruptions caused by workers’ actions, which could have an adverse effect on our results of operations.
Our equipment, facilities and operations are subject to environmental, health and safety regulations
Our generation business is subject to federal and provincial laws, as well as to the supervision of governmental agencies and regulatory authorities in charge of enforcing environmental laws and policies. We operate in compliance with applicable laws and in accordance with directives issued by the relevant authorities and CAMMESA; however, it is possible that we could be subject to controls, which could result in penalties to be imposed on us, such as the termination of the HPDA Concession Agreement. In addition, future environmental regulations could require us to make investments to comply with the requirements set by the authorities, instead of making other scheduled investments and, as a result, could have a material adverse effect on our financial condition and our results of operations.
We are subject to anticorruption, anti-bribery, anti-money laundering and other laws and regulations
We are subject to anti-corruption, anti-bribery, anti-money laundering and other laws and regulations. We may be subject to investigations and proceedings by authorities for alleged infringements of these laws. Although we perform compliance processes and maintain internal control systems, these proceedings may result in fines or other liabilities and could have a material adverse effect on our reputation, business, financial conditions and result of operations. If any such subsidiaries, employees or other persons engage in fraudulent, corrupt, or other unfair business practices or otherwise violate applicable laws, regulations, or internal controls, we could become subject to one or more enforcement actions or otherwise be found to be in violation of such laws, which may result in penalties, fines, and sanctions and in turn adversely affect our reputation, business, financial condition and result of operations.
A cyberattack could adversely affect our business, balance sheet, results of operations and cash flow
We depend on the efficient and uninterrupted operation of our inter-plant communication systems, for which we have all our links redundant, providing greater security and minimizing the risks of outage. Additionally, we have redundant links with CAMMESA. Temporary or long-lasting failures of our inter-plant communication systems, including their links redundant, could have a material adverse effect on our operations. In general, information security risks have increased in recent years as a result of the proliferation of new and more sophisticated technologies and also due to cyberattack activities. As part of our development and initiatives, more equipment and systems have been connected to the Internet. We also rely on digital technology including information systems to process financial and operational information. Due to the critical nature of our infrastructure and our business and the increased accessibility allowed through the Internet connection, we could face an increased risk of cyberattacks such as computer break-ins, phishing, identity theft and other disruptions that could negatively affect the security of information stored in and transmitted through our computer systems and network infrastructure. Despite significant efforts to create security barriers to cybersecurity threats, it is nearly impossible for us to completely mitigate these risks, in particular, as the frequency and sophistication of cyberattacks increases. For example, cybersecurity researchers anticipate an increase in cyberattack activity in connection with Russia’s actions in Ukraine. The security measures we have integrated into our internal networks and systems, and into our platform and products may not function as expected or may not be sufficient to protect our internal networks, platform and products against certain attacks.
In the event of a cyberattack, we could experience an interruption of our commercial operations, material damage and loss of customer information; a substantial loss of income or accounts balance, suffering response costs and other economic losses; and it could subject us to more regulation and litigation and damage to our reputation. Although we intend to continue to implement security technology devices and establish operational procedures to prevent disruption resulting from, and counteract the negative effects of cybersecurity incidents, it is possible that not all our current and future systems are or will be entirely free from vulnerability and these security measures will not be successful. Accordingly, cybersecurity is a material risk, and a cyber-attack could adversely affect our business, results of operations and financial condition.
Our ability to generate electricity at our thermal generation plants partially depends on the availability of natural gas and, to a lesser extent, liquid fuel
The supply and price of natural gas and liquid fuel used in our thermal generation plants has been in the past, and may in the future be, affected by, among other things, price fluctuations, geopolitical factors (including the current Russia Ukraine conflict and related sanctions on Russia by certain members of the European Union and the United Kingdom), as well as the availability of natural gas and liquid fuel in Argentina, given the current shortage of natural gas supply, especially during the winter, and declining reserves in Argentina. In particular, many oil and gas fields in Argentina are mature or require intensive capital investments to extract natural gas, and due to the current economic scenario have not been subject to significant investment into development and exploration activities and, therefore, reserves are likely to be depleted.
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CAMMESA is in charge of managing and supplying all fuels required to run our thermal plants except for the Lujan de Cuyo cogeneration plant and to a certain extent, gas provision for the Terminal 6 cogeneration plant related to steam production. We cannot assure you that we will be able to purchase natural gas or liquid fuel on terms comparable to the conditions we currently have with or that are fully reimbursable by CAMMESA. In addition, we cannot assure the supply in the above-mentioned conditions, if in the future we were required to purchase our own natural gas or liquid fuel from third parties for all our operations. Geopolitical factors, including the current Russia Ukraine conflict and related sanctions on Russia by certain members of the European Union, the United Kingdom, the United States, and certain other countries, has led to and is expected to continue to lead to an increase in the price and availability of natural gas and liquid fuel.
Even if we were able to source the requisite natural gas or liquid fuel and CAMMESA accepted to reimburse us for such amounts, it may be uncertain when such reimbursements would occur. In addition, natural gas delivery depends on the infrastructure (including barge facilities, roadways and natural gas pipelines) available to serve each generation facility. As a result, our thermal plants are subject to the risks of disruptions or curtailments in the fuel delivery chain and infrastructure. Any such disruption or curtailment may result in the unavailability, or higher prices, of natural gas or liquid fuel. Moreover, if in the future we are required to purchase our own natural gas or liquid fuel from third parties at prices that are not fully reimbursable by CAMMESA, such situation may have a material adverse effect on our financial condition and results of operations. Resolution No. 70/2018 enabled generators to purchase fuel in the open market. However, since the enactment of Resolution No. 12/2019, the effectiveness of Section 8 of Resolution No. 95/2013 and Section 4 of Resolution No. 529/2014 was reinstated, centralizing fuel purchases through CAMMESA.
We may be adversely affected by changes in LIBOR reporting practices or the method in which LIBOR is determined
As of December 31, 2021, we had trade receivables under the CVO Agreement for US$ 350.73 million (including VAT and accrued interests) after the CVO Commercial Approval which were indexed to the London Interbank Offered Rate (“LIBOR”). Furthermore, as of the date of this annual report, we have the outstanding loans listed below with maturity dates after 2021 indexed to LIBOR. The principal amount outstanding under each of such loans as of December 31, 2021, is the following:
| · | Loan with Kreditanstalt für Wiederaufbau (“KfW”) for US$ 45.59 million; |
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| · | CP Achiras and CP La Castellana Loans from the IIC—IFC Facilities for US$ 116.9 million; |
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| · | Vientos La Genoveva S.A.U. Loan from the IFC for US$ 70.9 million; |
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| · | Loan from Banco de Galicia y Buenos Aires S.A. to CPR Energy Solutions S.A.U. (wind farm La Castellana II) for US$9.28 million; |
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| · | Loan from Banco Galicia y Buenos Aires S.A. to our subsidiary Vientos La Genoveva II S.A.U. for US$ 26.9 million; and |
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| · | Loan from Citibank, N.A., JPMorgan Chase Bank, N.A. and Morgan Stanley Senior Funding, Inc. to Central Puerto for US$90.09 million |
On March 5, 2021, the United Kingdom Financial Conduct Authority (the “FCA”), which regulates LIBOR, announced that all LIBOR U.S. dollars settings will cease to be representative after June 30, 2023. LIBOR settings denominated in sterlings, euro, swiss francs and Japanese yens ceased to be representative after December 31, 2021. The FCA’s announcement coincides with the March 5, 2021, announcement of LIBOR’s administrator, the ICE Benchmark Administration Limited (the “IBA”), indicating that, as a result of not having access to input data necessary to calculate LIBOR tenors relevant to us on a representative basis after June 30, 2023, IBA would have to cease publication of such LIBOR tenors immediately after the last publication on June 30, 2023. These announcements mean that any of our LIBOR-based borrowings and receivables that extend beyond June 30, 2023 will need to be converted to a replacement rate. In the United States, the Alternative Reference Rates Committee (the “ARRC”), a committee of private sector entities with ex-officio official sector members convened by the Federal Reserve Board and the Federal Reserve Bank of New York, has recommended the Secured Overnight Financing Rate (“SOFR”) plus a recommended spread adjustment as LIBOR’s replacement. There are significant differences between LIBOR and SOFR, such as LIBOR being an unsecured lending rate while SOFR is a secured lending rate, and SOFR is an overnight rate while LIBOR reflects term rates at different maturities. A transition away from and/or changes to the LIBOR benchmark interest rate could adversely affect our business, financial condition, liquidity and results of operations. If our LIBOR-based borrowings are converted to SOFR, the differences between LIBOR and SOFR, plus the recommended spread adjustment, could result in interest costs that are higher than if LIBOR remained available, which could have a material adverse effect on our operating results. Although SOFR is the ARRC’s recommended replacement rate, it is also possible that lenders may instead choose alternative replacement rates that may differ from LIBOR in ways similar to SOFR or in other ways that would result in higher interest costs for us. It is not yet possible to predict the magnitude of LIBOR’s end on our borrowing costs given the remaining uncertainty about which rates will replace LIBOR. Any of these proposals or consequences could have a material adverse effect on our financing costs.
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An outbreak of a disease, including COVID-19, may have material adverse consequences on our operations including new projects
In late December 2019 a notice of pneumonia originating from Wuhan, Hubei province (COVID-19, caused by a novel coronavirus) was reported to the World Health Organization, with cases soon confirmed in multiple provinces in China, as well as in other countries. On March 11, 2020, the World Health Organization characterized the COVID-19 as a pandemic. Several measures have been undertaken by the Argentine government and other governments around the globe, including the use of quarantine, screening at airports and other transport hubs, travel restrictions, suspension of visas, nation-wide lockdowns, closing of public and private institutions, suspension of sport events, restrictions to museums and tourist attractions and extension of holidays, among many others. Even when, the virus has reduced its impact, as of the date of this annual report, has affected more than 192 countries and territories around the world, including Argentina. To date, the outbreak of the novel coronavirus has caused significant social, operational, economic and market disruption. The long-term effects to the global economy and the Company of epidemics and other public health crises, such as the novel coronavirus crisis, are difficult to assess or predict, and may include a further decline in the market prices of our shares and ADSs, risks to employee health and safety, risks for the deployment of our services, reduction in the demand of energy, and delays or suspensions in the construction of our expansion projects, among others. The prolonged restrictive measures, including policies limiting the efficiency and effectiveness of our operations such as home office policies, put in place in order to control the outbreak of the novel coronavirus or any other outbreak of a contagious disease or other adverse public health development that may occur in the future, has had, and may continue to have, or may in the future have, a material and adverse effect on our business operations. It is unclear whether these challenges and uncertainties will be resolved or won´t repeat in the future, and what effects they may have on the global political and economic conditions in the long term. Additionally, we cannot predict how the disease will continue to evolve in Argentina, including consequences of new outbreaks and new strains of coronavirus that have appeared, or the effectiveness of the vaccination campaign, nor anticipate what additional restrictions the Argentine government may impose. Coronavirus outbreak and the emergence of new strains of coronavirus for which current vaccines may be less effective, could exacerbate the factors described in this “Risk Factors” section and intensify the impact on our business and results of operations.
The quarantine and related restrictive measures had and may have a deep impact in the Argentine economy, including drastic reduction in the demand and supply of goods and services, increase in the unemployment rate and poverty levels, businesses bankruptcies, disruption in the payment chain, among many others. Although the Argentine government has adopted measures intended to alleviate the situation, such measures are expected to significantly increase the governments’ fiscal deficit. If that increase in the deficit is financed with monetary emission, it is highly possible that it will lead to an increase in the rate of inflation and disruptions in the foreign exchange markets.
We have identified the following items where this crisis has had and may have an impact in the Company:
| · | Reduction in the electric energy dispatched. Due to the Quarantine, most of the businesses in Argentina, especially in the industrial sector, have not been able to continue operating normally. According to information from CAMMESA, at the beginning of the Quarantine the total electric energy demand had significantly declined. This reduction had an impact in the Company’s termal energy generation, in particular our units with higher heat rate (less eficient) under the Energia Base Regulatory Framework. |
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| · | Increased delays in payments and/or risk of uncollectability from our private clients. Despite the fact that CAMMESA is paying its obligations, the reduced economic activity due to the Quarantine may also affect the cash flows of CAMMESA and of our private clients and it may increase the delays in their payments and the risk of uncollectabilty of private clients. |
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| · | Greater dependency of CAMMESA on subsidies from the Argentine government. CAMMESA’s cash flows depend on (i) payments from electric energy distribution companies, and (ii) subsidies from the Argentine government. Electric energy distribution companies may see a reduction in their collections from clients, which may reduce their payments to CAMMESA, which in turn, may increase CAMMESA’s dependency on subsidies received from the Argentine government to pay for electric energy generation, including payments to electric energy generation companies, such as Central Puerto. |
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| · | Personnel safeguard. Significant absence of workers may affect CPSA operations. We have set a protocol with multiple measures to protect the health of all our operations and maintenance personnel. Measures have been effective to protect our personnel, and at the date of these annual report, a low level of contagion has been registered within the Company’s personnel. |
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| · | Lack of necessary supplies/equipment, or delays in supplies. Any potential quarantines implemented in the future as a response to address new strains of COVID-19 may affect the provision of essential supplies. Although the provision of the necessary supplies is also considered an essential activity under the enacted emergency framework and we usually keep a stock of spare parts, we cannot assure you that the provision of the necessary supplies will not be affected. Furthermore, measures taken by foreign countries in which some of our supplies and spare parts for our units are produced, may also affect our stock of spare parts. Any delay in the provision of essential equipment or supplies may affect our operations. |
The COVID-19 outbreak has had an impact on the construction, development and expansion of the projects that were and are under construction as of the date of this annual report.
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Delays in the development and execution of the projects were mainly caused by: i) delays in the international manufacturing and delivery, ii) delays in the manufacturing and/or supply of local equipment, components and parts, iii) restrictions in the transport of material and components, iv) restrictions in the working methods due to compliance with COVID-19 health protocols that reduce the productivity of processes and tasks, and v) borders restrictions preventing foreign specialists from entering the country to conduct assembly or installation processes and for the start-up.
The Quarantine affected La Genoveva I project that started operations in November 2020 and also affected the construction of the Terminal 6-San Lorenzo thermal plant, which was suspended on March 20, 2020 (and later resumed) and its completion was delayed until August 15, 2021 due to measures adopted by the Argentine government to address the COVID-19 pandemic.
The effects of the COVID-19 crisis posed challenges to our expansion plans for the Brigadier López plant, delaying the start of construction of this project, not only because of the restrictions to the construction mentioned above, but also due to lower energy demand and difficulties to obtain the necessary financing for projects in the current market situation. For more information, see “Item 5. Operating and Financial Review and Prospects—Operating Results—Factors Affecting Our Results of Operations—The Impact of COVID-19—Projects under construction during the COVID-19 pandemic.” For further information see “Item 4.A.—Recent Developments—Measures Designed to Address the COVID-19 Outbreak”.
Finally, any additional measure taken by Argentina or any foreign country to mitigate the effects of the COVID-19 crisis, may directly or indirectly affect our operations, our results of operation and financial condition.
Risks Relating to our Shares and ADSs
It may be difficult for you to obtain or enforce judgments against us
We are incorporated in Argentina. All of our directors and executive officers reside outside the United States, and substantially all of our and their assets are located outside the United States. As a result, it may not be possible for you to effect service of process within the United States upon these persons or to enforce judgments against them or us in U.S. courts. We have been advised by our special counsel, Bruchou, Fernández Madero Lombardi, that there is doubt as to the enforceability in original actions in Argentine courts of liabilities predicated solely on U.S. federal securities laws and as to the enforceability in Argentine courts of judgments of U.S. courts obtained in actions predicated upon the civil liability provisions of U.S. federal securities laws. The enforcement of such judgments will be subject to compliance with certain requirements under Argentine law, such as Articles 517 through 519 of the Argentine Code of Civil and Commercial Procedure, including the condition that such judgments do not violate the principles of public policy of Argentine Law, as determined by an Argentine court. In addition, an Argentine court will not order an attachment on property located in Argentina and determined by such court to be essential for the provision of a public service.
Restrictions on transfers of foreign exchange and the repatriation of capital from Argentina may impair your ability to receive dividends and distributions on, and the proceeds of any sale of, shares underlying the ADSs
In 2001 and 2002 Argentina imposed exchange controls and transfer restrictions, substantially limiting the ability of companies to retain foreign currency or make payments abroad, including payments of dividends. In addition, new regulations were issued in the last quarter of 2011, which significantly curtailed access to the FX Market by individuals and private sector entities. In December 2015 the previous administration lifted many of the foreign exchange restrictions imposed in 2011, including the lifting of certain restrictions for the repatriation of portfolio investment by non-resident investors.
After almost four years of unrestricted capital flows, the Argentine Government reimposed restrictions on the conversion of Argentine currency into foreign currencies and on the remittance to foreign investors of proceeds from their investments in Argentina. Beginning in September 2019, the Argentine Government implemented monetary and foreign exchange control measures that included restrictions on the transfer of funds abroad, including dividends, without prior approval by the Central Bank or fulfillment of certain requirements. Also, the current administration has imposed further restrictions. In such a case, the Depositary for the ADSs may hold the Argentine pesos it cannot convert for the account of the ADS holders. In addition, any future adoption by the Argentine Government of additional restrictions to the movement of capital out of Argentina may affect the ability of our foreign shareholders and holders of ADSs to obtain the full value of their shares and ADSs and may adversely affect the market value of the ADSs.
We will be traded on more than one market, and this may result in price variations; in addition, investors may not be able to easily move shares for trading between such markets
Our common shares are listed on the BYMA and, since February 2, 2018, our ADSs are listed on the NYSE. Any markets that may develop for our common shares or for the ADSs may not have liquidity and the price at which the common shares or the ADSs may be sold is uncertain.
Trading in the ADSs or our common shares on these markets takes place in different currencies (U.S. dollars on the NYSE and pesos on the BYMA), and at different times (resulting from different time zones, different trading days and different public holidays in the United States and Argentina). The trading prices of the securities on these two markets may differ due to these and other factors. Any decrease in the price of our common shares on the BYMA could cause a decrease in the trading price of the ADSs on the NYSE. Investors could seek to sell or buy our shares to take advantage of any price differences between the markets through a practice referred to as arbitrage. Any arbitrage activity could create unexpected volatility in both our share prices on one exchange, and the ADSs available for trading on the other exchange. In addition, holders of ADSs will not be immediately able to surrender their ADSs and withdraw the underlying common shares for trading on the other market without effecting necessary procedures with the ADS Depositary. This could result in time delays and additional cost for holders of ADSs.
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Under Argentine Corporate Law, shareholder rights may be fewer or less well defined than in other jurisdictions
Our corporate affairs are governed by our bylaws and by the Argentine Corporate Law, which differ from the legal principles that would apply if we were incorporated in a jurisdiction in the United States (such as Delaware or New York), or in other jurisdictions outside Argentina. Thus, the rights of holders of our ADSs or holders of our common shares under the Argentine Corporate Law to protect their interests relative to actions by our Board of Directors may be fewer and less well defined than under the laws of those other jurisdictions. Although insider trading and price manipulation are illegal under Argentine law, the Argentine securities markets may not be as highly regulated or supervised as the U.S. securities markets or markets in some of the other jurisdictions. In addition, rules and policies against self-dealing and regarding the preservation of shareholder interests may be less well defined and enforced in Argentina than in the United States, or other jurisdictions outside Argentina, putting holders of our common shares and the ADSs at a potential disadvantage.
Holders of our common shares and the ADSs located in the United States may not be able to exercise preemptive or accretion rights
Under the Argentine Corporate Law, if we issue new shares as part of a capital increase, our shareholders may have the right to subscribe to a proportional number of shares to maintain their existing ownership percentage. Rights to subscribe for shares in these circumstances are known as preemptive rights. In addition, shareholders are entitled to the right to subscribe for the unsubscribed shares remaining at the end of a preemptive rights offering on a pro rata basis, known as accretion rights. Upon the occurrence of any future increase in our capital stock, United States holders of common shares or ADSs will not be able to exercise the preemptive and related accretion rights for such common shares or ADSs unless a registration statement under the Securities Act is effective with respect to such common shares or ADSs or an exemption from the registration requirements of the Securities Act is available. We are not obligated to file a registration statement with respect to those common shares or ADSs. We may not file such a registration statement, or an exemption from registration may not be available. Unless those common shares or ADSs are registered or an exemption from registration applies, a U.S. holder of our common shares or ADSs may receive only the net proceeds from those preemptive rights and accretion rights if those rights can be sold by the ADS Depositary; if they cannot be sold, they will be allowed to lapse. Furthermore, the equity interest of holders of common shares or ADSs located in the United States may be diluted proportionately upon future capital increases.
Voting rights, and other rights, with respect to the ADSs are limited by the terms of the deposit agreement
Holders may exercise voting rights with respect to the common shares underlying ADSs only in accordance with the provisions of the deposit agreement. There are no provisions under Argentine law or under our bylaws that limit ADS holders’ ability to exercise their voting rights through the ADS Depositary with respect to the underlying common shares, except if the ADS Depositary is a foreign entity and it is not registered with the IGJ. The ADS Depositary is registered with the IGJ. However, there are practical limitations upon the ability of ADS holders to exercise their voting rights due to the additional procedural steps involved in communicating with such holders. For example, Argentine Capital Markets Law requires us to notify our shareholders by publications in certain official and private newspapers of at least 20 and no more than 45 days in advance of any shareholders’ meeting. ADS holders will not receive any notice of a shareholders’ meeting directly from us. In accordance with the deposit agreement, we will provide the notice to the ADS Depositary, which will in turn, if we so request, as soon as practicable thereafter provide to each ADS holder:
| · | the notice of such meeting; |
| · | voting instruction forms; and |
| · | a statement as to the manner in which instructions may be given by holders. |
To exercise their voting rights, ADS holders must then provide instructions to the ADS Depositary how to vote the shares underlying ADSs. Because of the additional procedural step involving the ADS Depositary, the process for exercising voting rights will take longer for ADS holders than for holders of our common shares. Except as described in this annual report, holders of the ADS will not be able to exercise voting rights attaching to the ADSs.
Also, Section 7.6 of the deposit agreement provides that each of the parties to the deposit agreement (including, without limitation, each holder and beneficial owner) waives, to the fullest extent permitted by applicable law, any and all right to trial by jury in any legal proceeding against us and/ or the ADS Depositary. This provision may have the effect of limiting and discouraging lawsuits against us and/ or the ADS Depositary. Moreover, you may not be able to exercise your right to vote and you may have no legal remedy if the shares underlying your ADSs are not voted as you requested.
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The relative volatility and illiquidity of the Argentine securities markets may substantially limit our ADS holders’ ability to sell common shares underlying the ADSs at the price and time they desire
Investing in securities that trade in developing countries, such as Argentina, often involves greater risk than investing in securities of issuers in the United States (see “Risks Relating to Argentina— Substantially all of our revenues are generated in Argentina and thus are highly dependent on economic and political conditions in Argentina”). The Argentine securities market is substantially smaller, less liquid, more concentrated and can be more volatile than major securities markets in the United States and is not as highly regulated or supervised as some of these other markets. There is also significantly greater concentration in the Argentine securities market than in major securities markets in the United States. During the first quarter of 2022 the ten largest companies in terms of their weight in the MERVAL index represented approximately 77.3% of its composition. Accordingly, although holders of our ADSs are entitled to withdraw the common shares underlying the ADSs from the ADS Depositary at any time, their ability to sell such shares at a price and time at which they wish to do so may be substantially limited. Furthermore, new capital controls imposed by the Central Bank could have the effect of further impairing the liquidity of the BYMA by making it unattractive for non-Argentines to buy shares in the secondary market in Argentina. See “Item 10.D.—Exchange Controls.”
If there are substantial sales of our common shares or the ADSs, the price of the common shares or of the ADSs could decline
Sales of substantial number of our common shares or the ADSs could cause a decline in the market price of our common shares. In addition, if our significant shareholders, directors and members of senior management listed in “Item 6. Directors, Senior Management and Employees—Senior Officers”, who, as of April 21, 2022, own in aggregate 0.10%of our outstanding common shares, sell our common shares or the ADSs or the market perceives that they intend to sell them, the market price of our common shares or the ADSs could drop significantly.
Our shareholders may be subject to liability for certain votes of their securities
Our shareholders are not liable for our obligations. Instead, shareholders are generally liable only for the payment of the shares they subscribe. However, shareholders who have a conflict of interest with us and who do not abstain from voting may be held liable for damages to us, but only if the transaction would not have been approved without such shareholders’ votes. Furthermore, shareholders who willfully or negligently vote in favor of a resolution that is subsequently declared void by a court as contrary to Argentine Corporate Law or our bylaws may be held jointly and severally liable for damages to us or to other third parties, including other shareholders.
As a foreign private issuer, we are exempt from several rules under the U.S. securities laws and are permitted to file less information with the Commission than a U.S. company. This may limit the information available to holders of our ADSs
We are a “foreign private issuer,” as defined in the SEC’s rules and regulations and, consequently, we are not subject to all of the disclosure requirements applicable to companies organized within the United States. For example, we are exempt from certain rules under the Exchange Act that regulate disclosure obligations and procedural requirements related to the solicitation of proxies, consents or authorizations applicable to a security registered under the Exchange Act. In addition, our officers and directors are exempt from the reporting and “short-swing” profit recovery provisions of Section 16 of the Exchange Act and related rules with respect to their purchases and sales of our securities. Moreover, while we expect to submit quarterly interim consolidated financial data to the Commission under cover of the Commission’s Form 6-K, we are not required to file periodic reports and financial statements with the Commission as frequently or as promptly as U.S. public companies. Accordingly, there may be less information concerning our company publicly available than there is for U.S. public companies.
As a foreign private issuer, we are not subject to certain NYSE corporate governance rules applicable to U.S. listed companies
We rely on a provision in the NYSE Listed Company Manual that allows us to follow Argentine law with regard to certain aspects of corporate governance. This allows us to follow certain corporate governance practices that differ in significant respects from the corporate governance requirements applicable to U.S. companies listed on the NYSE.
For example, we are exempt from NYSE regulations that require a listed U.S. company, among other things, to:
| · | have a majority of our board of directors be independent; |
| · | establish a nominating and compensation composed entirely of independent directors; |
| · | adopt and disclose a code of business conduct and ethics for directors, officers and employees; and |
| · | have an executive session of solely independent directors each year. |
The market price for our common shares or ADSs could be highly volatile
The market price for our common shares or the ADSs after the global offering is likely to fluctuate significantly from time to time in response to factors including:
| · | fluctuations in our periodic operating results; |
| · | changes in financial estimates, recommendations or projections by securities analysts; |
| · | changes in conditions or trends in our industry; |
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| · | changes in the economic performance or market valuation of our competitors; |
| · | announcements by our competitors of significant acquisitions, divestitures, strategic partnerships, joint ventures or capital commitments; |
| · | events affecting equities markets in the countries in which we operate; |
| · | legal or regulatory measures affecting our financial conditions; |
| · | departures of management and key personnel; or |
| · | potential litigation or the adverse resolution of pending litigation against us or our subsidiaries. |
Volatility in the price of our common shares or the ADSs may be caused by factors outside of our control and may be unrelated or disproportionate to our operating results. In particular, announcements of potentially adverse developments, such as proposed regulatory changes, new government investigations or the commencement or threat of litigation against us, as well as announced changes in our business plans or those of competitors, could adversely affect the trading price of our common shares or the ADSs, regardless of the likely outcome of those developments or proceedings. Moreover, statements made about our Company, whether publicly or in private, may be misconstrued, particularly if read out of context.
Broad market and industry factors could adversely affect the market price of our common shares or ADSs at any time, regardless of our actual operating performance.
If we fail to maintain an effective system of internal control over financial reporting, we may not be able to accurately report our financial results or prevent fraud. As a result, shareholders could lose confidence in our financial and other public reporting, which would harm our business and the trading price of our common shares.
Effective internal controls over financial reporting are necessary for us to provide reliable financial reports and, together with adequate disclosure controls and procedures, are designed to prevent fraud. Any failure to achieve and maintain effective internal controls over financial reporting, implement required new or improved controls, or difficulties encountered in their implementation could cause us to fail to meet our reporting obligations, which in turn could have a material adverse effect on our business and our common shares or the ADSs. In addition, any testing by us or any subsequent testing by our independent registered public accounting firm conducted in connection with Section 404 of the Sarbanes-Oxley Act of 2002, may reveal deficiencies in our internal controls over financial reporting that are deemed to be material weaknesses or that may require prospective or retroactive changes to our financial statements or identify other areas for further attention or improvement. Matters impacting our internal controls may cause us to be unable to report our financial information on a timely basis and thereby subject us to adverse regulatory consequences, including sanctions by the SEC. There also could be a negative reaction in the financial markets due to a loss of investor confidence in us and the reliability of our consolidated financial statements. Confidence in the reliability of our consolidated financial statements also could suffer if we or our independent registered public accounting firm were to report a material weakness in our internal controls over financial reporting. This could in turn limit our access to capital markets and possibly, harm our results of operations, and lead to a decline in the trading price of our common shares or the ADSs.
We are required to disclose changes made in our internal controls and procedures and our management is be required to assess the effectiveness of these controls annually. Undetected material weaknesses in our internal controls could lead to financial statement restatements and require us to incur the expense of remediation.
The protections afforded to minority shareholders in Argentina are different from and more limited than those in the United States and may be more difficult to enforce
Under Argentine law, the protections afforded to minority shareholders are different from, and much more limited than, those in the United States. For example, the legal framework with respect to shareholder disputes, such as derivative lawsuits and class actions, is less developed under Argentine law than under U.S. law as a result of Argentina’s short history with these types of claims and few successful cases. In addition, there are different procedural requirements for bringing these types of shareholder lawsuits. 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.
Holders of our common shares may determine not to pay any dividends
In accordance with the Argentine Corporate Law, after allocating at least 5% of our annual net earnings to constitute a mandatory legal reserve, we may pay dividends to shareholders out of net and realized profits, if any, as set forth in our consolidated financial statements prepared in accordance with IFRS. The approval, amount and payment of dividends are subject to the approval by our shareholders at our annual ordinary shareholders’ meeting. The approval of dividends requires the affirmative vote of a majority of the shareholders entitled to vote at the meeting. As a result, we cannot assure you that we will be able to generate enough net and realized profits so as to pay dividends or that our shareholders will decide that dividends will be paid.
Pursuant to the terms of the amendment to the Brigadier Lopez Loan between the Company and Citibank N.A., JP Morgan Chase Bank N.A. and Morgan Stanley Senior Funding INC. dated December 22, 2020, the Company is precluded from making dividends payment during 2021 and limited to a maximum of US$ 25 million and US$ 20 million in dividends payment for 2022 and 2023, respectively. For more information see “Item 5.A. Operating Results—Indebtedness—Loan from Citibank N.A., JP Morgan Chase Bank N.A. and Morgan Stanley Senior Funding INC.”
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We may be a passive foreign investment company for U.S. federal income tax purposes
A non-U.S. corporation will be considered a passive foreign investment company, which we refer to as a PFIC, for U.S. federal income tax purposes in any taxable year in which 75% or more of its gross income is “passive income” or 50% or more of the value of its assets (generally determined on the basis of a quarterly average) is attributable to assets that produce or are held for the production of passive income.The determination as to whether a non-U.S. corporation is a PFIC is based upon the application of complex U.S. federal income tax rules (which are subject to differing interpretations), the composition of income and assets of the non-U.S. corporation from time to time and, in certain cases, the nature of the activities performed by its officers and employees.
Based upon our current and projected income, assets and activities, we do not expect to be considered a PFIC for our current taxable year or for future taxable years. However, because the determination of whether we are a PFIC will be based upon the composition of our income, assets and the nature of our business, as well as the income, assets and business of entities in which we hold at least a 25% interest, from time to time, and because there are uncertainties in the application of the relevant rules, there can be no assurance that we will not be considered a PFIC for any taxable year.
If we are a PFIC for any taxable year during which a U.S. Holder, as defined in “Item 10.E. Taxation—Certain United States Federal Income Tax Considerations,” holds the ADSs or common shares, the U.S. Holder might be subject to increased U.S. federal income tax liability and to additional reporting obligations. See “Item 10.E. Taxation—Certain United States Federal Income Tax Considerations—Passive Foreign Investment Company.” U.S. Holders are encouraged to consult their own tax advisors regarding the applicability of the PFIC rules to their purchase, ownership and disposition of the ADSs or common shares.
The requirements of being a public company may strain our resources and distract our management, which could make it difficult to manage our business
Since the global offering, we are required to comply with various regulatory and reporting requirements, including those required by the Commission in addition to our existing reporting requirements by the CNV. Complying with these reporting and regulatory requirements will be time consuming, resulting in increased costs to us or other adverse consequences. As a public company, we are subject to the reporting requirements of the Exchange Act, and the requirements of the Sarbanes-Oxley Act, as well as to the Argentine Law No. 26,831 (as amended and supplemented from time to time, the “Argentine Capital Markets Law”) and CNV rules. These requirements may place a strain on our systems and resources. The Exchange Act applicable to us requires that we file annual and current reports with respect to our business and financial condition. Likewise, CNV rules require that we make annual and quarterly filings and that we comply with disclosure obligations including current reports. The Sarbanes-Oxley Act requires that we maintain effective disclosure controls and procedures and internal controls over financial reporting. To maintain and improve the effectiveness of our disclosure controls and procedures, we committed significant resources, hired additional staff and provided additional management oversight. These activities may divert management’s attention from other business concerns, which could have a material adverse effect on our business, results of operations and financial condition.
Item 4. Information on the Company
Recent Developments
Shareholder’s General Meeting
On March 9, 2022, the Board of Directors of Central Puerto convened the Annual General Meeting of Shareholders and a Special Shareholders’ Meeting for April 29, 2022 to discuss the following items of the agenda:
| 1. | Appointment of two shareholders to sign the minutes. |
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| 2. | Consideration of the Annual Report and its exhibits, the Consolidated Income Statement, the Consolidated Statement of Comprehensive Income, the Consolidated Statement of Financial Position, the Consolidated Statement of Changes in Equity, the Consolidated Statement of Cash Flow, the Notes to the Consolidated Financial Statements and Exhibits, the Individual Statement of Income, the Individual Statement of Comprehensive Income, the Individual Statement of Financial Position, the Individual Statement of Changes in Equity, the Individual Statement of Cash Flow, the Notes to the Individual Financial Statements, the Brief, the Auditor Report, and the Statutory Auditing Committee Report, all of them for the period ended December 31, 2021. |
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| 3. | Consideration and destination of retained earnings as of December 31, 2021 (loss of thousand ARS: 733,517). |
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| 4. | Consideration of the Board of Directors performance during the fiscal year ended December 31, 2021. |
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| 5. | Consideration of the Statutory Audit Committee performance during the fiscal year ended December 31, 2021. |
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| 6. | Consideration of the compensation of the Company’s Board of Directors (Ps. 23,094,000 assigned amount) for the period ended December 31, 2021, which showed a computable loss in the terms of CNV Regulations. Consideration of the fees advanced payment to the Board of Directors for the period closing next December 31, 2022. |
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| 7. | Consideration of the compensation of the members of the Statutory Audit Committee for the fiscal year ended December 31, 2021, and the fee scheme for the period closing next December 31, 2022. |
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| 8. | Fixing of the number of Deputy Directors and appointment of Directors and Deputy Directors. Continuity of the current Chairman until the appointment by the Board of Directors of the Company. |
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| 9. | Appointment of the Statutory Audit Committee members and deputy members for the fiscal year closing next December 31, 2022. |
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| 10. | Consideration of the remuneration of the Company’s external accountant regarding the annual accounting documents for the fiscal year 2021. |
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| 11. | Appointment of the external accountant and of the deputy external accountant for the period closing next December 31, 2022, and the fixing of their remuneration. |
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| 12. | Approval of the Annual Budget for the functioning of the Supervisory Committee. |
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| 13. | Granting of authorizations. |
Measures Designed to Address the COVID-19 Outbreak
On March 11, 2020, the World Health Organization characterized the COVID-19 as a pandemic. A number of measures have been undertaken by the Argentine government and other governments around the globe to control the outbreak of this contagious disease.
In this regard, on March 20, 2020 the Argentine Government issued Decree No. 297/2020 establishing a preventive and mandatory social isolation policy (“the Quarantine” or “ASPO” -for its acronym in Spanish-,indistinctly) as a public health measure to contain the effects of the COVID-19 outbreak. Such decree provided that individuals were refrained from attending their workplaces, and were not allowed to travel along routes, roadsor public spaces. As from the adoption of the Quarantine, the government has extended it in many opportunities and it has ordered the preventive and mandatory social distancing (“DISPO” -for its acronym in Spanish-). However, as of the date of this annual report, ASPO and DISPO measures are no longer in effect.
Subsequently, the Argentine Executive Power ordered the “General Prevention Measures”. The last one of these measures was issued through Decree No. 678/2021 published in the Official Gazette on October 1, 2021 and it was in force until December 31, 2021. As of the date of this annual report , the Health Emergency established originally by Decree No. 260/2020, and extended until December 31, 2022 by Decree No. 867/2021, is in effect. In this sense, the Ministry of Health issued Resolution No. 705/2022, updating and flexibilizing the general recommendations for the prevention of COVID-19 and other respiratory diseases.
Moreover, as an additional measure to control the virus in Argentina, restrictions were imposed on the entering of people to the country and on international flights several times since the beginning of the pandemic. Nevertheless, pursuant to Administrative Decision No. 370/2022, the Argentine government reduced the requirements for the entry of individuals into the country due to the current favorable epidemiological situation and the vaccination levels of the population.
On the other hand, since late 2020, the vaccination campaign to prevent COVID-19 has commenced in Argentina. Pursuant to Decree 297/2020, minimum shifts ensuring the operation and maintenance of electric energy generators were exempted from the Quarantine. Furthermore, on April 7, 2020, pursuant to Administrative Decision 468/2020 issued by the Presidency of the Cabinet of Ministers, the construction of private sector energy infrastructure was included within the activities exempted from the ASPO.
Some of the main identified impacts that this crisis has and may have in the future for the Company are the following:
Operations - Power generation
– Reduction in the electric energy dispatched: Due to the Quarantine, most of the businesses in Argentina, especially in the industrial sector, experienced difficulties in their normal operations. At the beginning of the Quarantine the total electric energy demand had significantly declined, and although as of the date of this annual report, demand has returned to values similar to the ones previous to the pandemic, this situation reduced the Company’s generation of thermal power in such period and it could affect it in the future –but to a lower extent–, in particular our units with higher heat rate (which are less efficient).– Increased delays in payments and/or risk of uncollectability from the Company´s private clients. Despite the fact that CAMMESA is paying its obligations, the reduced economic activity due to the Quarantine also affected the cash flow of CAMMESA and the cash flow of our private clients. Even if as of the date of this annual report, the situation has considerably improved, there still exists the risk of delay in the payment of private clients and, therefore, the risk of uncollectability of private clients.
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– Personnel safeguard. Multiple measures have been implemented to protect the health of all the personnel who work in the operation and maintenance of the generation units, as well as in the works that were carried out by the Company. Some of those measures included: a) the isolation of the teams that operate the Company’s different units preventing contact between different teams, b) the avoidance of contact between personnel of different shifts, c) the use of extra protection, and additional sanitary measures, d)using virtual meetings, e) identifying key personnel in order to have the necessary back up teams should a contingency arise, f) drafting and publication of health and safety plans and/or protocols both for the plants in operation and works in development. These measures have been effective to protect the Company’s personnel, and as of the date of this annual report , a low contagion level has been registered within the Company’s personnel.
– Lack of necessary supplies/equipment, or delays in supplies. The pandemic has and may continue to affect the provision of essential supplies. Although the provision of the necessary supplies is also considered an essential activity under the enacted emergency framework and usually a stock of spare parts is kept as backup, the Company cannot assure that the provision of the necessary supplies will not be affected.
Furthermore, the measures taken by foreign countries in which some of the Company’s supplies and spare parts are produced, may also affect the Group’s stock of spare parts. Any delay in the provision of essential equipment or supplies may affect the Group’s operations.
Projects under construction during the pandemic
COVID-19 outbreak has had an impact on the projects that were under construction. Therefore, there have been delays in the completion dates originally set. Since the issuance of Administrative Decision 468/2020, the project construction activities were resumed. This required the implementation of health safety measures according to the requests established and recommended by health authorities. Regarding the foregoing, a procedure and a protocol were drafted, which have had to be complied with by the personnel, contractors and subcontractors.
Regarding the Terminal 6-San Lorenzo thermal plant, once the Administrative Decision 468/2020 was issued, construction was resumed on April 27, 2020. Additionally, as mentioned above, travel restrictions and national borders lockdown imposed by the government, among others, delayed the arrival of necessary personnel for the project, some of which were expected to arrive from countries affected by the outbreak. The Company notified CAMMESA and the Energy Secretariat on the situation and requested: (i) the suspension of agreement terms as from March 20, 2020 and until the situation is normalized, and (ii) the non-application of sanctions for the case in which the Company cannot comply with the committed dates on the Wholesale Demand Agreement entered into with CAMMESA, so as to avoid possible sanctions stemming from a delay in the completion of the project due to unforeseen and inevitable reasons. In this sense, on June 10, 2020, the Secretariat of Energy ordered CAMMESA to temporarily suspend the calculation of the terms set forth for those projects that had not obtained the commercial authorization, among which the cogeneration station Terminal 6 - San Lorenzo is included, for a maximum postponement term of six months from March 12 to September 12, 2020. On July 15, 2020, the Company communicated the Secretariat of Energy, with copy to CAMMESA, that the temporary suspension of the terms was not sufficient to comply with the new terms under the Wholesale Demand Agreement since the numerous measures adopted due to COVID-19 generated a strong slowdown in all the activities related to the work of the cogeneration unit Terminal 6 - San Lorenzo. Dated September 10, 2020, the Undersecretariat of Electrical Energy granted a new suspension of the terms for the commercial authorization of the projects between September 12, 2020 and November 25, 2020, being subject to certain requirements to be fulfilled before CAMMESA. Then, CAMMESA granted a new extension for 45 days. It is worth mentioning that on November 21, 2020, open cycle commercial operation had begun, while on August 15, 2021, the power station was authorized to operate commercially at combined cycle. On January 27, 2022, the Secretariat of Energy issued Resolution No. 39/2022, which allowed for those generators with projects under the scope of Resolution No. 287/2017, that had not been authorized on the date established within the extensions of the previously granted term, to set a new date. Within this context, the Company established August 15, 2021 as the new Commercial Authorization date of the project Terminal 6 San Lorenzo (effective completion date).
The effects of the COVID-19 crisis also pose challenges to the beginning of works for closing of the combined cycle at the Brigadier López plant, delaying the start of construction of such project, not only because of the restrictions to the construction mentioned above, but also due to difficulties to obtain the necessary financing for projects in the current market situation.
In addition, the COVID-19 crisis may reduce the possibility of new projects that would enable the use of the gas turbine included under "Gas turbines" item within property, plant and equipment.
Access to Capital Markets
Due to the outbreak of COVID-19, access to the capital and financial markets in Argentina and/or in foreign markets was also substantially reduced. Although cash flow and liquidity of the Group is deemed sufficient to meet the working capital, debt service obligations and capital expenditure requirements, any further deterioration of the current economic situation may result in a deterioration of the Company´s finances, in a context of lack of access or substantial reduction of credit availability in the financial markets.
See “Item 3.D Risk Factors— Risk Relating to Our Business — An outbreak of a disease, including COVID-19, may have material adverse consequences on our operations including new projects”
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Item 4. A History and development of the Company
Central Puerto S.A. (“Central Puerto” or the “Company”) is incorporated as a sociedad anónima under the laws of Argentina. Our principal executive offices are located at Avenida Thomas Edison 2701, C1104BAB Buenos Aires, Republic of Argentina. Our telephone number is +54 (11) 4317-5900.
We were incorporated pursuant to Executive Decree No. 122/92 on February 26, 1992. We were formed in connection with the privatization process involving Servicios Eléctricos del Gran Buenos Aires (“SEGBA”) in which SEGBA’s electric power generation, transportation, distribution and sales activities were privatized. We were registered with the Public Registry of Commerce of the City of Buenos Aires on March 13, 1992 and created for a term of 99 years from the date of such registration.
In April 1992, Central Puerto, the consortium-awardee, took possession over SEGBA’s Central Nuevo Puerto (“Nuevo Puerto”) and Central Puerto Nuevo (“Puerto Nuevo”) plants, and we began operations. In November 1999, the Puerto combined cycle plant, which was built on lands owned by Nuevo Puerto in the City of Buenos Aires, started to operate. In 2001, Central Puerto was acquired by the French company, Total S.A. At the end of 2006, Sociedad Argentina de Energía S.A. (“SADESA”) acquired a controlling interest in Central Puerto.
Our shares are listed on the BYMA and, since February 2, 2018, have been listed on the NYSE under the symbol “CEPU.”
The SEC maintains an internet site that contains reports and other information regarding issuers who, like us, file electronically with the SEC. The address of that website is http://www.sec.gov. Central Puerto routinely posts important information for investors in the Investor Relations support section on its website, www.centralpuerto.com. From time to time, Central Puerto may use its website as a channel of distribution of material Company information. Accordingly, investors should monitor Central Puerto’s Investor Support website, in addition to following the Company’s press releases, SEC filings, public conference calls and webcasts. The information contained on, or that may be accessed through, the Company’s website is not incorporated by reference into, and is not a part of, this annual report.
The below chart illustrates the development of our company through the years and the important milestones for Central Puerto and for the companies that were absorbed in the 2014 Merger and 2016 Merger:
The 2014 Merger
On October 1, 2014, we merged with three operating companies under the common control of SADESA: (i) HPDA, (ii) CTM and (iii) LPC. The purpose of the merger was to optimize operations and achieve synergies among the businesses. We refer to this merger as the “2014 Merger.” Following the 2014 Merger, each of HPDA, CTM and LPC were dissolved.
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Prior to the 2014 Merger, we owned and operated three thermal generation plants for electric power generation located within one complex in the City of Buenos Aires. Our Nuevo Puerto and Puerto Nuevo thermal generation plants are equipped with five steam turbine-generator units in the aggregate and have an installed capacity of 360 MW and 589MW, respectively. The third plant, the Puerto combined cycle plant has two gas turbines, two heat recovery steam generators and a steam turbine, and it has a total installed capacity of 798 MW. Prior to the 2014 Merger, we had a total installed capacity of 1,714 MW and were already one of the major SADI electric power generators.
As a result of the 2014 Merger, we added the Luján de Cuyo plant, the La Plata plant, which, effective as of January 5, 2018, we sold to YPF EE (for further information see “Item 4.A. History and development of the Company—La Plata Plant Sale”), and the Piedra del Águila hydroelectric complex.
As of December 31, 2021, we operated one hydroelectric generation plant, owned, and operated five thermal generation plants, and seven wind farms, for the generation of electric power in Argentina. We had a combined installed capacity of 4,809 MW and have significantly improved our position as a major SADI electric power generator, producing approximately 12.2% of the energy generated by private sector SADI generators in 2021.
Hidroeléctrica Piedra del Águila S.A. (HPDA)
HPDA was a sociedad anónima (corporation) incorporated in 1993 that operated the Piedra del Águila hydroelectric complex with an installed capacity of 1,440MW since it started commercial operation in 1993. HPDA entered into the HPDA Concession Agreement (as defined below) to operate and maintain the Piedra del Águila hydroelectric complex, that was assigned to us during the 2014 Merger. For further information regarding the HPDA and the HPDA Concession Agreement, see “—Electricity Generation from our Hydroelectric Complex—Piedra del Águila.”
HPDA’s controlling shareholder was Hidroneuquén S.A. (“HNQ”), a company that was under the control of the SADESA group, which held a 59.00% interest. The remaining shareholders were: (i) the Argentine Government (26.00% interest), (ii) the Province of Neuquén (13.00% interest) and (iii) HPDA’s Employee Stock Ownership Program (2.00% interest). HPDA held 21.00% of the shares of CVOSA, the company that operates the thermal power plant in Timbúes. Following the 2014 Merger, CVOSA became our subsidiary.
Centrales Térmicas Mendoza S.A. (CTM)
CTM was a sociedad anónima (corporation) incorporated in 1993 focused on electric power generation and steam production. Before the 2014 merger, CTM was focused on two primary activities: electric power generation and steam production. CTM owned the Luján de Cuyo plant located in Luján de Cuyo in the Province of Mendoza, which began commercial operation in 1971. With the installation of its first two steam turbines, had an installed capacity of 509 MW and was the top producer of electric power in the Cuyo region. For further information regarding CTM’s operations that were transferred to us in the 2014 Merger, see “—Electricity Generation from our Thermal Generation Plants—Luján de Cuyo plant.”
CTM’s controlling shareholder was Operating S.A. (“OSA”), a company that was under the control of the SADESA group and which held a 94.10% interest. The other shareholder was Empresa Mendocina de Energía, SAPEM, which held the remaining 5.89% interest. CTM held a minority interest in CVOSA, representing 9.36% of its capital stock.
Distribuidora de Gas Cuyana S.A. (DGCU) and Distribuidora de Gas del Centro S.A. (DGCE)
In addition, on January 7, 2015, acting individually, but simultaneously with other investors, we acquired non-controlling equity interests in DGCU (whose shares are listed on BYMA) and DGCE. Considering the direct and indirect interests, we acquired (i) a 22.49% equity stake in DGCU and (ii) a 39.69% equity stake in DGCE.
DGCU
DGCU was incorporated in 1992 by the Argentine Government as part of the privatization of Gas del Estado S.E. (“GES”). The Executive branch enacted Executive Order No. 2,453 in December 1992, whereby it granted a utility license to DGCU to distribute Natural gas through the networks in the provinces of Mendoza, San Juan and San Luis, for a term of 35 years from the date of taking possession (which occurred on December 28, 1992) with an option to extend it for ten additional years.
In December 1992, a transfer agreement was executed to transfer 60.00% of DGCU’s shares. The agreement was entered into among the Argentine Government, GES, the Province of Mendoza and IGCU, which formed the consortium that became the successful bidder in the bidding process at such time. On such date, GES transferred to DGCU the assets used in the licensed utility service, net of liabilities, as an irrevocable capital contribution pursuant to Executive Orders No. 1,189/92 and 2,453/92, and DGCU took possession of the facilities and commenced operations.
Following the Merger between IGCE, IGCU, RPBC and MAGNA (See Item 4.A - Merger between IGCE, IGCU, RPBC and MAGNA), as of the date of this annual report, IGCE holds a 51.00 % interest in DGCU, and we hold a 42.31% interest in IGCE. Therefore, we indirectly hold a 21.5781% equity interest in DGCU.
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DGCE
DGCE was incorporated in 1992 by the Argentine Government as part of the privatization of GES. The Executive branch enacted Executive Order No. 2,454/92 in December 1992, whereby it granted a utility license to DGCE to distribute natural gas through the networks in the provinces of Córdoba, Catamarca and La Rioja for a term of 35 years from the date of taking possession (which occurred on December 28, 1992) with an option to extend it for ten additional years.
In December 1992, a transfer agreement was executed to transfer 60.00% of DGCE’s shares. The agreement was entered into among the Argentine Government, GES and IGCE, which formed the consortium that became the successful bidder in the bidding process at such time. On such date, GES. transferred to DGCE the assets used in the licensed utility service, net of liabilities, as an irrevocable capital contribution pursuant to Executive Orders No. 1,189/92 and 2,454/92, and DGCE took possession of the facilities and commenced operations.
As of the date of this annual report, we hold a 42.31% interest in IGCE and a direct 17.20% interest in DGCE. Therefore, we hold, both directly and indirectly, a 40.590781% in DGCE.
IGCE is the controlling shareholder of Energía Sudamericana S.A. (“ESSA”), which is a private company not listed in any commercial stock exchange, and which prepares its financial statements in accordance with Argentine GAAP. However, there are no relevant differences between Argentine GAAP applicable to ESSA and the IFRS that we apply to our financial statements. ESSA’s principal activity is the sale of natural gas. We also own a 2.45 % direct equity interest in ESSA.
Ecogas has a gas distribution network covering 36,048 km and served approximately 1,391,055 customers as of December 31, 2021. In 2021, Ecogas distributed an average of 12,86 million cubic meters of natural gas per day; and in 2020, Ecogas distributed an average of 12.18 million cubic meters of natural gas per day. This volume of distribution represented approximately 14.86% and 14.37% of the gas delivered by all the distribution companies in Argentina in November 2021 and 2020, respectively, according to data from ENARGAS.
At a meeting of our shareholders on December 16, 2016, in accordance with the strategic objective of focusing on assets within the energy industry, the shareholders considered a potential sale of our equity interests in Ecogas but voted to postpone the decision. We are currently assessing various strategic opportunities regarding DGCU and DGCE, including a possible partial or total sale of our equity interest in them. On January 26, 2018, the shareholders of DGCE approved the admission of DGCE to the public offering regime in Argentina. On March 14, 2018, the Company authorized the offer of up to 10,075,952 common class B shares of DGCE, in a potential public offering authorized by the CNV, subject to market conditions. This authorization was encompassed within the February 23, 2018, authorization of the Board of Directors for the sale of up to 27,597,032 common B shares of DGCE. However, due to market conditions, DGCE shareholders decided to postpone the offer. On October 24, 2019, the CNV notified DGCE the cancellation of the authorization for the public offering.
Control Acquisition by Tender Offer of Third Parties in respect of DGCU shares
On January 7, 2015, the Company acquired 49% of interests in IGCU, the parent company of DGCU and, as a result, the Company held indirectly 24.49% of DGCU’s capital stock. Following this acquisition, Magna, RPBC, Central Puerto and Mr. Federico Tomasevich (jointly, the “Offerors”) resolved to participate proportionally in the tender offer for DGCU’s shares with voting rights that were publicly listed on the BYMA in order to acquire the remaining outstanding shares of DGCU that the Offerors did not already own. On October 30, 2015, the board of directors of the CNV approved the tender offer. Upon termination of the offer in January 2016, since no acceptances were tendered, no shares were acquired in this tender offer. During 2019, IGCE absorbed IGCU, RPBC and MAGNA. As of the date of this annual report, we own a 42.31% interest in IGCE and, as a result, we indirectly hold a 21.58% equity interest in DGCU. For further information on the merger of IGCE and IGCU, see “— Merger between IGCE, IGCU, RPBC and MAGNA.”
Merger between IGCE, IGCU, RPBC and MAGNA
On March 28, 2018, the Board of Directors of IGCE, IGCU, RPBC Gas S.A. (“RPBC”) and Magna Inversiones S.A. (“Magna”), approved the Preliminary Merger Agreement (Compromiso Previo de Fusión) of the companies (the “Merger”), in which IGCE will act as the surviving company and IGCU, RPBC and Magna, as absorbed companies.
On August 9, 2019, ENARGAS issued resolution No. RESFC-2019-458-APN-DIRECTORIO#ENARGAS, approving the merger in the terms of such resolution.
On September 12, 2019, the merger was registered with the Public Registry of the City of Buenos Aires (Inspección General de Justicia).
The 2016 Merger
On January 1, 2016, we merged with three holding companies: (i) SADESA, (ii) HNQ and (iii) OSA. The purpose of the merger was to reorganize and optimize our corporate structure. As a result of the merger, we reduced our share capital from Ps.199,742,158 to Ps.189,252,782. We refer to this merger as the “2016 Merger.” Following the 2016 Merger, each of SADESA, HNQ and OSA were dissolved.
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SADESA was a holding company with control over Central Puerto, HNQ and OSA that, prior to the 2016 Merger, held a 26.18% direct interest in Central Puerto, a 63.73% interest in HNQ, a 96.79% interest in OSA and a 5.10% direct interest in Proener S.A.U. HNQ was a holding company that prior to the 2016 Merger held a 17.74% interest in Central Puerto. OSA was a holding company that prior to the 2016 Merger held a 30.39% interest in Central Puerto, a 94.90% interest in Proener S.A.U. and a 20.00% interest in TGM. TGM is dedicated to the operation, maintenance, and commercialization of an international gas pipeline between Argentina and Brazil.
La Plata Plant Sale
On December 20, 2017, YPF EE accepted our offer to sell the La Plata plant for a total sum of US$31.5 million (without VAT), subject to certain conditions. On February 8, 2018, after such conditions were met, the plant was transferred to YPF EE, including generation assets, personnel and agreements related to the operation and/or maintenance of the La Plata plant’s assets, with effective date January 5, 2018. The contract between us and Transportadora de Gas del Sur (“TGS”) for the natural gas transportation capacity has remained effective after the sale of the La Plata plant. Pursuant to the terms of our agreement with YPF EE, we resell our gas transportation capacity to YPF EE through the resale system established by Resolution ENARGAS 419/97. The resale under such system is open to third parties and consequentially does not ensure that YPF EE will receive the gas transportation capacity needed to operate the La Plata plant. Therefore, on January 25, 2018, we requested to be registered with the Ministry of Energy and the ENARGAS as a natural gas marketer to permit the resale of our gas transportation capacity to YPF EE without the risk of intervention from interested third parties. On July 20, 2018, we were effectively registered as natural gas marketer. As of the date of this annual report, the delivery of the transportation capacity to YPF EE is done through the “Resale” mechanism.
Renewable energy projects
In 2016, we incorporated a subsidiary, CP Renovables S.A. (“CP Renovables”), to develop, renewable energy generation projects. As of the date of this annual report, the company participated in the Renovar Rounds 1.0 and 1.5, in which it was awarded with the La Castellana I and Achiras projects with 20-year PPA contracts with CAMMESA, each of the projects constructed by CP La Castellana S.A.U. (a subsidiary of CP Renovables S.A.) and CP Achiras (a subsidiary of CP Renovables S.A.). La Genoveva I is a project from RenovAr 2.0 developed constructed and operated by Vientos La Genoveva I (a subsidiary of Central Puerto S.A.).
In August 2018 and September 2018, respectively, the La Castellana I and Achiras wind farms started operations. The original COD of the La Genoveva I was expected for May 2020, but due to the outbreak of COVID-19, the construction of the plant was delayed . On November 21, 2020, La Genoveva I commenced full commercial operations.
In addition, the former Ministry of Energy and Mining through Resolution 281-E/ 2017, established the regulatory framework that allows Large Users to purchase renewable energy from private generating companies and the conditions for granting “dispatch priority” that allows such transactions to take place and ensures that the private generating companies will not be restricted in the future in its generation dispatch (see “Item 4.B. Business Overview—The Argentine Electric Power Sector—Resolution No. 281-E/17: The Renewable Energy Term Market in Argentina”). In July 2019, September 2019 , December 2019/January 2020/March 2020, and February 2020, the wind farms La Castellana II (developed by CPR Energy Solutions S.A.U.), La Genoveva II (developed by Vientos La Genoveva II S.A.U.), Manque (CP Manque S.A.U.), and Los Olivos (CP Los Olivos S.A.U.), respectively, reached their COD.As of the date of this annual report, we have already entered into long-term PPA contracts with private customers for 100% of the estimated energy generation capacity of our term market renewable energy projects developed under Resolution No. 281-E/17 regulatory framework.
Luján de Cuyo and Terminal 6-San Lorenzo thermal cogeneration plants
In 2017, the Secretariat of Electric Energy, pursuant to Resolution SEE No. 287-E/17, called for proposals for the supply of electric power to be generated through the installation of co-generation units, among others. We submitted bids on August 9, 2017, and, on September 25, 2017, we were awarded two co-generation projects, the Terminal 6-San Lorenzo and the Luján de Cuyo projects, which each of these projects will represent two additional sources of income to the Company: (i) electric power sales to CAMMESA through 15-year term PPAs which are priced in U.S. dollars; and (ii) steam sales pursuant to separate steam supply agreements negotiated with private offtakers.
On October 5, 2019, the Luján de Cuyo cogeneration project started operations.
Terminal 6-San Lorenzo project on November 21, 2020, obtained partial commissioning of its gas turbine (269,5 MW) to operate with natural gas and sell energy under the spot market regulation (Resolution SE No. 31/2020) and on August 15, 2021 the project reached full COD
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Purchase of the Brigadier López Plant
On June 14, 2019, Central Puerto, through an offer presented in a local and foreign public tender called by IEASA, purchased the Brigadier López Plant. The transference includes: a) personal property, recordable personal property, facilities, machines, tools, spare parts, and other assets used in connection with the operation of the Brigadier López Plant; b) IEASA’s contractual position in certain existing contracts (including Turbogas and Turbosteam supplying contracts with CAMMESA and the Brigadier López Financial Trust Agreement (as defined below), among others); c) permits and authorizations in effect related to the Brigadier López Plant operation; and d) Brigadier López Plant employees.
The Brigadier López Plant has installed a Siemens gas turbine of 280.5 MW. According to the tender specifications and conditions, the project already has the boiler and a steam turbine to reach the closing of the combined cycle, which is expected to generate 420 MW in total. The works for the closing of the combined cycle are pending. See “An outbreak of a disease, including COVID-19, may have material adverse consequences on our operations including new projects”
Item 4.B Business Overview
Overview
We are one of the largest private sector power generation companies in Argentina, as measured by generated power, according to data from CAMMESA. In the year ended December 31, 2021, we generated a total of 14,392 net GWh of power, representing approximately 12.2% of the power generated by private sector generation companies in the country during such period, according to data from CAMMESA. We had an installed capacity of 4,809 MW as of December 31, 2021.
We have a generation asset portfolio that is geographically and technologically diversified. Our facilities are distributed across the City of Buenos Aires and the provinces of Buenos Aires, Córdoba, Mendoza, Neuquén, Río Negro and Santa Fe. We use conventional and renewable technologies (including hydro power) to generate power, and our power generation assets include combined cycle, gas turbine, steam turbine, co-generation, hydroelectric, and wind turbines.
The following table presents a brief description of the power plants we owned and operated as of December 31, 2021.
Power plant |
| Location |
| Installed capacity (MW) |
| Technology |
Puerto Nuevo(1) |
| City of Buenos Aires |
| 589.00 |
| Steam turbines |
Nuevo Puerto(1) |
| City of Buenos Aires |
| 360.00 |
| Steam turbines |
Puerto combined cycle(1) |
| City of Buenos Aires |
| 798.00 |
| Combined cycle |
Luján de Cuyo plant |
| Province of Mendoza |
| 576.00 |
| Steam turbines, gas turbines, two cycles and mini-hydro turbine generator, producing electric power and steam |
Brigadier López plant |
| Province of Santa Fe |
| 280.50 |
| Gas turbine |
San Lorenzo plant |
| Province of Santa Fe |
| 391.00 |
| Gas turbine |
Piedra del Águila plant |
| Piedra del Águila (Limay River, bordering provinces of Neuquén and Río Negro) |
| 1,440.00 |
| Hydroelectric plant |
La Castellana I wind farm(2) |
| Province of Buenos Aires |
| 100.80 |
| Wind turbines |
La Castellana II wind farm(2) |
| Province of Buenos Aires |
| 15.20 |
| Wind turbines |
La Genoveva I wind farm(2) |
| Province of Buenos Aires |
| 88.20 |
| Wind turbines |
La Genoveva II wind farm(2) |
| Province of Buenos Aires |
| 41.80 |
| Wind turbines |
Achiras wind farm(2) |
| Province of Córdoba |
| 48.00 |
| Wind turbines |
Manque wind farm(2) |
| Province of Córdoba |
| 57.00 |
| Wind turbines |
Los Olivos wind farm(2) |
| Province of Córdoba |
| 22.80 |
| Wind turbines |
Total |
|
|
| 4,809 MW |
|
|
____________
(1) | Part of the “Puerto Complex” as defined in “Business.” |
(2) | La Castellana I, La Castellana II, Achiras, Manque, Los Olivos, La Genoveva I and La Genoveva II wind farms are owned by CP La Castellana S.A.U., CPR Energy Solutions S.A.U., CP Achiras S.A.U., CP Manque S.A.U., CP Los Olivos S.A.U., CP Vientos La Genoveva S.A.U. and Vientos La Genoveva II S.A.U., respectively, the first five of which are fully owned subsidiaries of CP Renovables S.A. while the last one is a fully owned subsidiary of Central Puerto S.A. We own a 100% interest in CP Renovables. See “Item 4.B. Business Overview—Our Subsidiaries”. |
In addition, we participate in two arrangements known as the FONINVEMEM and the CVO Agreement, which are managed by CAMMESA at the instruction of the Secretariat of Electric Energy (for further information see “Item 4.B. Business Overview—FONINVEMEM and Similar Programs”). The Argentine Government created the FONINVEMEM with the purpose of repaying power generation companies, like us, the existing receivables for electric power sales between 2004 and 2011 and funding the expansion and development of new power capacity. As of the date of this annual report, there are no outstanding receivables under the FONINVEMEM agreement. As a result of our participation in the CVO arrangement, we receive monthly payments for certain of our outstanding receivables with CAMMESA. Additionally, we have an equity interest in the companies that operate the FONINVEMEM and CVO Agreement’s new combined cycle projects, which will be entitled to have an ownership of the combined cycle projects.
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During 2020, we collected Ps.0.5 billion from FONINVEMEM receivables, and during 2021 and 2020 we collected Ps.8.2 and 9.5 billion from CVO receivables, respectively, in each case measured in current amounts as of December 31, 2021.
As of December 31, 2021, we held equity interests in the companies that operate the following FONINVEMEM thermal power plants:
Power plant |
| Operating Company |
| Location |
| Installed capacity (MW) |
| Technology |
| % Interest in the operating company(1) |
San Martín |
| Termoeléctrica José de San Martín S.A. (TJSM) |
| Timbúes, Province of Santa Fe |
| 865 |
| Combined cycle plant, which became operational in 2010 |
| 9.6269%
|
Manuel Belgrano |
| Termoeléctrica Manuel Belgrano S.A. (TMB) |
| Campana, Province of Buenos Aires |
| 873 |
| Combined cycle plant, which became operational in 2010 |
| 10.8312% |
Vuelta de Obligado |
| Central Vuelta de Obligado S.A. (CVOSA) |
| Timbúes, Province of Santa Fe |
| 816 |
| Combined cycle plant, which became operational in March 2018 |
| 56.1900% |
____________
(1) | In each case, we are the private sector generator with the largest ownership stake. |
On January 3, 2020, the Argentine Government sent a notice to the Company stating that, in accordance with FONINVEMEM Agreement, TJSM and TMB should perform all necessary acts to incorporate the Argentine Government as shareholder of both companies, claiming, in each case, the following equity interest rights: 65.006% in TMB and 68.826% in TJSM.
On March 11, 2021, the Argentine Government subscribed its shares and the equity of the shareholders of TJSM and TMB were diluted. In the case of our equity interest, from 30.8752% to 9.6269% in TJSM and from 30.9464% to 10.8312% in TMB.
See “Item 3D. Risk Factors—Risks Relating to our Business—Our interests in TJSM, TMB were diluted and CVOSA will be significantly diluted” and “Item 4.B. Business Overview—Our Affiliates—Termoeléctrica José de San Martín S.A. (TJSM) and Termoeléctrica Manuel Belgrano S.A. (TMB)”.
The following set of graphs shows our total assets under the FONINVEMEM program:
(1) | Future ownership structure of the operating companies is subject to the Claim that the Company filed against the Argentine government |
Source: TJSM, TMB and CVOSA
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The following graphic breaks down where our plants and power investments were located in Argentina as of December 31, 2021, and their installed capacity:
_____________
(2) | “FONINVEMEM Plants” refers to the plants José de San Martín, Manuel Belgrano and Vuelta de Obligado, see “Item 4.B. Business Overview—FONINVEMEM and Similar Programs.” |
(3) | Power capacity numbers have been rounded. The power capacity with respect to certain assets is the nominal power capacity of the plant, which may differ from the awarded capacity. |
In the year ended December 31, 2021, we had revenues of Ps.57 billion (or US$ 556 million).
In the year ended December 31, 2021, we sold approximately 81.26% of our electric energy sales (in MWh) under the Energía Base. Sales under Energía Base accounted for 41.72% of our revenues in the year ended December 31, 2021. In the year ended December 31, 2016, tariffs under the Energía Base were paid by CAMMESA based on a fixed and variable costs system which was determined by the former Secretariat of Electric Energy pursuant to Resolution SE No. 95/13, as amended. These tariffs were adjusted annually, denominated in pesos, and remained unchanged throughout the year. From February 2017 to February 2019, the Energía Base was regulated by Resolution SEE No. 19/17, which replaced Resolution SE No. 95/13, as amended. Resolution SEE No. 19/17 increased the Energía Base’s tariffs and denominated them in U.S. dollars. From March 2019 to and including January 2020, Energía Base was regulated by Resolution SRRyME No. 1/19, which abrogated Resolution SE No. 19/17. Resolution SRRyME No. 1/19 decreased the tariffs for the energy and power. On February 27, 2020, the Secretariat of Energy issued Resolution 31/20, which replaces the regulatory framework for Energía Base applicable from February 1, 2020, providing that prices would be set in Argentine pesos, and would be periodically adjusted through an inflation index
However, on April 8, 2020, the Secretary of Energy instructed CAMMESA to postpone until further notice the application of Annex VI, related to the price update mechanism described under “Item 4.B. Business Overview—The Argentine Electric Power Sector—Remuneration Scheme—The Current Remuneration Scheme”. Thus, since the settlement of the transaction due on March 2020, CAMMESA has not applied the adjustment mechanism. The non-application of the aforementioned Annex VI had an adverse effect on the operational results of the Company .
In February 2021 Resolution No. 440/21 was issued amending Resolution No. 31/20 and increasing prices for generators among other modifications. Under the Energía Base, the fuel required to produce the energy we generate is supplied by CAMMESA free of charge, and the price we receive as generators, for sales not made under term contracts, is determined by the Resolution SE No. 440/2021 without accounting for the fuel CAMMESA supplies. Our compensation under the Energía Base depends to a large extent on the availability and energy output of our plants, and in the case of the thermal units, the Utilization Factor of each machine.
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On November 7, 2018, pursuant to Res. SEE 70/18, the Argentine Government authorized generators to purchase their own fuel for assets under the Energía Base Regulatory framework. If generation companies opt to take this option, CAMMESA values and pays the generators their respective fuel costs in accordance with the Variable Costs of Production (CVP) declared by each generator to CAMMESA. The agency in charge of dispatch (Organismo Encargado del Despacho or “OED” using the Spanish acronym) -CAMMESA- continued to supply the fuel for those generation companies that do not elect to take this option. In accordance to Res. SEE 70/18, in November 2018, we started purchasing fuel for our Luján de Cuyo combined cycle, and in December 2018, for all our thermal units.
On December 27, 2019, the Ministry of Productive Development issued Resolution MDP No. 12/2019, repealing Res. SEE No. 70/18 and restoring Art. 8 of Res. SE 95/2013. Beginning January 2020, CAMMESA became the only fuel supplier for generation companies, except for (i) thermal units that had prior commitments with CAMMESA for energy supply contracts with their own fuel management and (ii) thermal units under the Energía Plus regulatory framework, authorized under Resolution SE No.1281/05 to supply energy to large private users.
Additionally, we have sales under contracts, including (i) term market sales under contract, (ii) MATER sales under contracts, (iii) Energía Plus sales under contract; and (iii) sales of energy under the RenovAr Program.
Term market sales under contract include sales of electric power under negotiated contracts with private and public sector counterparties. MATER sales under contracts include sales of electric power under negotiated contracts with private and public sector counterparties generated exclusively from renewable energy plants. In all cases, sales under contracts generally involve PPAs with customers and are contracted in U.S. dollars. Prices in term market sales under contracts from thermal units and Energía Plus contracts include price of fuel used for generation, cost of which is assumed by the generator, or include such cost as a component of the sale that is charged to the client. For terms longer than one year, these contracts typically include electric power price updating mechanisms in case of fuel price variations or the generator being required to use liquid fuels in the event of a shortage of natural gas. For further information regarding our main clients for term market sales under contract, see “Business—Our Customers.” Term market sales under contract, and MATER sales under contracts accounted 8% and 4% of our electric power sales (in MWh) and 32.78 % and 7.23% of our revenues for the year ended December 31, 2021, respectively.
In our Luján de Cuyo plant, we are also permitted to sell a minor portion (up to 16 MW) of our generation capacity and electric power under negotiated contracts with private sector counterparties under the Energía Plus, to encourage private sector investments in new generation facilities. Energía Plus sales under contracts accounted for 0.01% of our electric power sales (in MWh) and 0.14% of our revenues for the year ended December 31, 2021. These contracts typically have one-to-two-year terms, are denominated in U.S. dollars and are paid in pesos at the exchange rate as of the date of payment. Under the rules and regulations of the Energía Plus, the generator buys the fuel to cover the committed demand of electric power and supplies the electric power to large electric power consumers at market prices, denominated in U.S. dollars, previously agreed between the generator and its clients.
RenovAr sales under contracts include sales of electric power generated exclusively from renewable energy plants under negotiated contracts with public sector counterparties. We have long term contracts signed with CAMMESA. Prices under these PPA’s are in U.S. dollars and guaranteed by the FODER. In the RenovAr Program, our subsidiaries, Achiras, La Castellana I and La Genoveva I entered in a 20-year PPA with CAMMESA that establishes that 100% of the generation of the contracted capacity of the wind farm will be sold to CAMMESA at the awarded price plus the respective incentive and adjustment factors which increases the awarded price approximately by 10% to 15%. See “Item 4.B, Business Overview—The Argentine Electric Power Sector —Structure of the Industry—Renewable Energy Program”. Sales under RenovAr Program accounted for 7% of our electric power sales (in MWh) and 12.62 % of our revenues for the year ended December 31, 2021.See “Item 4.B. Business Overview—The Argentine Electric Power Sector.”
We also produce steam. As of December 31, 2021, we had an installed capacity of 125 tons per hour. Steam sales accounted for 3.00% of our revenues for the year ended December 31, 2021. Our production of steam for the year ended December 31, 2021, was 1,099 thousand metric tons. Our Luján de Cuyo plant, supplies steam under negotiated contracts with YPF.
Our Luján de Cuyo plant has a combined heat and power (CHP) unit in place, which started operations on October 5, 2019, replacing the previous CHP, and supplies up to 125 metric tons per hour of steam to YPF’s refinery in Luján de Cuyo under a steam supply agreement. This contract is denominated in U.S. dollars but can be adjusted in the event of variations in U.S. dollar-denominated prices for fuel necessary for power generation. This new steam supply contract with YPF was entered into on December 15, 2017, for a period of 15 years and replaced the contract in place with YPF. For further information on the steam supply agreements with YPF for the Luján de Cuyo plant, see “Item 5.A. Operating Results—Factors Affecting Our Results of Operations—Sales Under Contracts, Steam Sales and Others —Steam supply to YPF—Luján de Cuyo plant”.
The contract between us and Transportadora de Gas del Sur (“TGS”) for the natural gas transportation capacity has remained effective after the sale of the La Plata plant. Pursuant to the terms of our agreement with YPF EE, we resell our gas transportation capacity to YPF EE through the resale system established by Resolution ENARGAS 419/97. The resale under such system is open to third parties and consequentially does not ensure that YPF EE will receive the gas transportation capacity needed to operate the La Plata plant. Therefore, on January 25, 2018, we requested to be registered with the Ministry of Energy and the ENARGAS as a natural gas trader to permit the resale of our gas transportation capacity to YPF EE without the risk of intervention from interested third parties. On July 20, 2018, we were effectively registered as natural gas trader. As of the date of this annual report, the delivery of the transportation capacity to YPF EE is done through the “Resale” mechanism The resale to YPF EE of our natural gas transportation capacity accounted for 0.54% of our revenues for the year ended December 31, 2021.
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We also produce steam in the cogeneration plant Terminal 6-San Lorenzo. As of December 31, 2021, we had an installed capacity of 370 tons per hour. Our production of steam for the year ended December 31, 2021, was 110 thousand metric tons.
In addition, we have income derived from the operating fee that we receive for the management of the Central Vuelta de Obligado plant. The income from the management of the Central Vuelta de Obligado plant accounted for 1.97% of our revenues for the year ended December 31, 2021.
The following graph breaks down our revenues in the year ended December 31, 2021, by regulatory framework:
__________
Source: Central Puerto.
(1) | Includes (i) sales of energy and power to CAMMESA remunerated under Resolution No. 95, Resolution No. 19/2017, Resolution No. SE 1/2019, Resolution No. 31/20, and Resolution No. 440/21 (ii) spot sales of energy and power to CAMMESA not remunerated under Resolution No. 95 (as amended), and (iii) remuneration under Resolution No. 724/2008 relating to agreements with CAMMESA to improve existing Argentine power generation capacity (see “Item 4.B. Business Overview—The Argentine Electric Power Sector—Remuneration Scheme—The Previous Remuneration Schemes—Resolution SEE 70/18—Option to purchase fuel for units under Energía Base Regulatory Framework.”). See “Item 4.B. Business Overview—The Argentine Electric Power Sector—Structure of the Industry—Shortages in the Stabilization Fund and Responses from the Argentine Government—The National Program.” |
|
|
| Note: From February 27, 2020, a new remuneration scheme for Energía Base applicable from February 1, 2020, came into effect with Resolution 31/20 that was amended by Resolution No. 440/21. For further information see “Item 4.B. Business Overview—The Argentine Electric Power Sector—Remuneration Scheme—The Current Remuneration Scheme.” |
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The following graph breaks down our electric energy sales in the year ended December 31, 2021, by regulatory framework, in MWh:
Source: Central Puerto.
In 2015 and 2016, we acquired four heavy-duty, highly efficient gas turbines: (i) one General Electric gas turbine with a capacity of 373 MW; (ii) two Siemens gas turbines, each with a capacity of 298 MW; and (iii) one Siemens gas turbine with a capacity of 291 MW, which we installed in our Terminal 6 San Lorenzo co-generation project, which commenced operations as a combined cycle on August 15, 2021. During 2021 two Siemens gas turbines stored in Germany, each with a capacity of 298 MW were sold.With respect to the GE gas turbine, which is already in Argentina, we are considering it for potential projects in the future and analyzing other prospects. However, it is uncertain whether there will be new projects or other prospects that would enable us to use the GE gas turbine. Additionally, we have also acquired 130 hectares of land in the north of the Province of Buenos Aires, in a location that provides excellent conditions for fuel delivery and access to power transmission lines.
We also own long-term significant non-controlling investments in companies that have utility licenses to distribute natural gas through their networks in the provinces of Mendoza, San Juan, San Luis, Córdoba, Catamarca and La Rioja. Considering our direct and indirect interests, we hold (i) a 21.58% equity stake in DGCU and (ii) a 40.59% equity stake in DGCE (Ecogas).
Ecogas has a gas distribution network covering 36,048 km and served approximately 1,391,055 customers as of December 31, 2021. In 2021, Ecogas distributed an average of 12,86 million cubic meters of natural gas per day; and in 2020, Ecogas distributed an average of 12.18 million cubic meters of natural gas per day. This volume of distribution represented approximately 14.86% and 14.37% of the gas delivered by all the distribution companies in Argentina as of November 2021 and 2020, respectively, according to data from ENARGAS. In the year ended December 31, 2021, our interest in Ecogas produced Ps. -518.88 million in share of loss of an associate, which represented 80.09% of our net loss for such period.
At a meeting of our shareholders on December 16, 2016, in accordance with the strategic objective of focusing on assets within the energy industry, the shareholders considered a potential sale of our equity interests in Ecogas to Magna Energía S.A. but voted to postpone the decision. We are currently assessing various strategic opportunities regarding DGCU and DGCE, including a possible partial or total sale of our equity interest in them. On January 26, 2018, the shareholders of DGCE approved the admission of DGCE to the public offering regime in Argentina. On March 14, 2018, the Company authorized the offer of up to 10,075,952 common class B shares of DGCE, in a potential public offering authorized by the CNV, subject to market conditions. This authorization was encompassed within February 23, 2018, authorization of the Board of Directors for the sale of up to 27,597,032 common B shares of DGCE. However, due to market conditions, DGCE shareholders decided to postpone the offer. On October 24, 2019, the CNV notified DGCE the cancellation of the authorization for the public offering.
Through Resolution No. 17,949 dated January 7, 2016, the CNV granted a conditional authorization for the Company to enter the public offering regime through the issuance of simple, non-negotiable obligations. convertible into shares and the creation of a global program for the issuance of negotiable obligations (the “Program”) and, on March 16, 2016, the CNV decided to give effect to the Resolution. On September 9, 2019, the Company's Assembly resolved to approve the voluntary withdrawal of the Company from the Public Offering Regime in which it was, stating that the Company has not issued negotiable obligations, as well as the cancellation of the Program. On October 24, 2019, the CNV notified the Company of joint signature CNV Resolution No. RESFC-2019-20506-APN-DIR # CNV of the same date, through which it resolved to cancel, as of the date of Resolution , the authorization granted to make a public offering of its Negotiable Obligations, due to the lack of outstanding securities. Likewise, having the Shareholders' Meeting of January 26, 2018, resolved to approve the application of the Company to join the Public Offering of shares, the CNV authorized the Public Offering of class “B” shares (Resolutions No. 19,384 and No. 19,391 dated March 1, 2018 and March 8, 2018, respectively); However, the selling shareholders decided to postpone the offering, due to market reasons. Consequently, the CNV, on October 24, 2019, notified the Company of the CNV Resolution of joint signature No. RESFC-2019-20511-APN-DIR # CNV of the same date, through which it was resolved to cancel, as of that date, the authorization granted to the Company to make a public offering of its shares, due to the absence of placement of the negotiable securities.
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Our Competitive Strengths
We believe that we have achieved a strong competitive position in the Argentine power generation sector primarily as a result of the following strengths:
| · | One of the largest private sector power companies in Argentina. We are one of the largest private sector power generation companies in Argentina, as measured by power generated, according to data from CAMMESA. In the year ended December 31, 2021, we generated a total of 14,392 net GWh of power. As of December 31, 2021, we had an installed generating capacity of 4,809 MW. Our leading position allows us to develop a range of sales and marketing strategies, without depending on one market in particular. Additionally, our size within the Argentine market positions us well to take advantage of future developments as investments are made in the electric power generation sector. Our ample installed capacity is also an advantage, as we have enough capacity to support large, negotiated contracts. |
The following graphs shows the SADI’s total power generation by private companies and market share for 2021 (grouped by related companies and subsidiaries):
Source: CAMMESA. (i) Enel includes Enel Generación Costanera S.A., Central Dock Sud S.A. and Enel Generación El Chocón S.A.; (ii) Pampa Energía includes Central Térmica Güemes S.A., Central Térmica Loma la Lata S.A., Inversora Piedra Buena S.A., Inversora Diamante S.A., CTG and Inversora Nihuiles, and Petrobras Argentina S.A.; and (iii) AES Argentina Generación includes Central Térmica San Nicolás S.A. and Hidroeléctrica Alicurá S.A.
| · | High quality assets with strong operational performance. We have a variety of high-quality power generation assets, including combined cycle turbines, gas turbines, steam turbines, wind farms, hydroelectric technology and steam and power co-generation technology, with a combined installed generating capacity of 4,809 MW, as of the date of this annual report. Our efficiency levels compare favorably to those of our competitors due to our efficient technologies. The following chart shows the efficiency level for the period between January 2021 and December 2021 of each of our generating units compared to our main competitors based on heat rate, which is the amount of energy used by an electric power generator or power plant to generate one kWh of electric power. |
Source: CAMMESA.
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The following chart shows the availability ratio of our thermal assets as compared to the market average:
Source: Central Puerto, CAMMESA.
1Average market availability for thermal units.
We have long-term maintenance contracts with the manufacturers of our combined cycle units and co-generation plants with the largest capacity, namely the Puerto combined cycle unit , the Luján de Cuyo combined cycle unit at the Luján de Cuyo plant, the Brigadier López gas turbine , the co-generation units at the Luján de Cuyo plant , Terminal 6-San Lorenzo cogeneration plantand our windfarms, under which the manufacturers provide maintenance using best practices recommended for such units. Our remaining units receive maintenance through our highly trained and experienced personnel, who strictly follow the recommendations and best practices established by the manufacturers of such units. We are also capable of generating power from several sources of fuel, including natural gas, diesel oil and fuel oil. In addition, in recent years we have invested in adapting our facilities to be able to generate power from biofuels, and we have developed business relationships over the years with strategic companies from the oil and gas and the biofuel sectors. Our power generation units are also favorably positioned along the system’s power dispatch curve (the WEM marginal cost curve) as a result of our technologically diverse power generation assets and high level of efficiency in terms of fuel consumption, which ensures ample dispatch of energy to the system, even when taking into account new capacity additions expected in the coming years that were awarded pursuant to auctions to increase thermal generation capacity and capacity from renewable energy sources.
| · | Diversified and strategically located power sector assets. Our business is both geographically and technologically diverse. Our assets are critical to the Argentine electric power network due to the flexibility provided by the large fuel storage capacity, which allows us to store 32,000 tons of fuel oil (enough to cover 6.3 days of consumption) and 20,000 tons of gas oil (enough to cover 5.7 days of consumption) at our thermal generation plants, in addition to our access to deep water docks, our dam water capacity and our ability to store energy for 45 days operating at full capacity at Piedra del Águila. The prices for power transmission are regulated and based on the distance from the generating company to the user, among other factors. In this regard, our thermal power plants are strategically located in important city centers or near some of the system’s largest customers, which constitutes a significant competitive advantage. For example, approximately 38% of Argentine energy consumption was concentrated within the metropolitan area of Buenos Aires during 2021 according to the monthly report of December 2021 prepared by CAMMESA. Because the lack of capacity in SADI limits the efficient distribution of energy generated in other geographic areas, our generation plants in Buenos Aires and Mendoza are essential to the supply of energy to meet the high demand in these areas. In addition, this need to generate energy close to a high consumption area in Argentina means that our plants are less affected by the installation of new capacity in other regions. |
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The diversification of our fuel sources enables us to generate energy in different contexts, as shown in the following chart:
Source: Central Puerto
____________
(1) | Luján de Cuyo’s Siemens Combined Cycle unit (306 MW installed capacity) is CEPU’s only unit relying exclusively on natural gas. |
| · | Expansion of the current installed capacity. We have taken steps to improve our strategic position as a leader among conventional power generation technologies by expanding our thermal generation and renewable energy capacity. |
Thermal Generation. In 2015 and 2016, we acquired four heavy-duty, highly efficient gas turbines: (i) one General Electric gas turbine with a capacity of 373 MW; (ii) two Siemens gas turbines, each with a capacity of 298 MW; and (iii) one Siemens gas turbine with a capacity of 291 MW. We also acquired 130 hectares of land in the north of the Province of Buenos Aires. For example, we are currently using a Siemens gas turbine, with a capacity of 291 MW, for the Terminal 6 San Lorenzo co-generation project. During 2021 two Siemens gas turbines stored in Germany, each with a capacity of 298 MW were sold. With respect to the GE gas turbine, which is already in Argentina, we are considering it for potential projects in the future and analyzing other prospects. However, it is uncertain whether there will be new projects or other prospects that would enable us to use the GE gas turbine.
In addition, in 2018, we acquired two additional Siemens gas turbines with a capacity of 56 MW for a purchase price of SEK$381.37 million (which, converted at the exchange rate quoted by the Central Bank as of the date of each payment, equals US$45.46 million) for our Luján de Cuyo project, which started commercial operations on October 5, 2019.
The Secretariat of Electric Energy, pursuant to Resolution SEE No. 287-E/17, called for proposals for supply of electric power to be generated through existing units, the conversion of open cycle units into combined cycle units or the installation of co-generation units. We submitted bids on August 9, 2017, and, on September 25, 2017, we were awarded two co-generation projects at Terminal 6 San Lorenzo (with an awarded electric capacity of 330 MW and 317 MW for the winter and summer, respectively) that started operations on August 15, 2021 and Luján de Cuyo (with an awarded electric capacity of 93 MW and 89 MW for the winter and summer, respectively), which started operations on October 5, 2019, seven weeks ahead of the committed COD.
Renewable Generation.
In connection with our renewable energy efforts, Law No. 27,191, provides that Large Users, whose demand exceeds 300 KW of average annual power, should comply with the obligation to purchase renewable energy by entering into a contract with a generating company or through self-generation. The Ministry of Energy and Mining through Resolution 281-E/ 2017, established the regulatory framework that allows Large Users to purchase renewable energy from private generating companies and the conditions for granting the “dispatch priority” that allows such transactions to take place and ensures that the private generating companies will not be restricted in the future in its generation dispatch (see “Item 4.B. Business Overview—The Argentine Electric Power Sector—Resolution No. 281-E/17: The Renewable Energy Term Market in Argentina”). As of the date of this annual report, we have already signed long-term PPA contracts with private customers for 100% of the estimated energy generation capacity of our term market renewable energy projects developed under Resolution No. 281-E/17 regulatory framework and our seven wind farms commenced commercial operations.
We cannot assure you that the Argentine Government will open new auction processes, or our bids will be successful or that we will be able to enter into PPAs in the future. See “Item 3D. Risk Factors—Risks Relating to our Business— Factors beyond our control may affect or delay the completion of the awarded projects or alter our plans for the expansion of our existing plants.”
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Stable cash flow generation, partially supported by U.S. dollar denominated cash flows. Part of our cash flows are denominated in US dollars mainly from (a) long term contracts (PPAs) with CAMMESA, and (b) contracts signed directly under Energía Plus framework, MATER and Steam Sales. Such payments principally depend on two factors: (i) the availability of power capacity (in the case of thermal units) and (ii) the amount of power or steam generated. All variables have been relatively stable in recent years, as a result of the diversified technology and high efficiency of our power generation units. In addition, our cash flows have little exposure to the fuel price changes as the fuel needed to produce the energy under the Energía Base is supplied by CAMMESA without charge and our term market sales under contracts typically include price adjustment mechanisms based on fuel price variations, if applicable.
During the year ended December 31, 2021, we received Ps.23.144 billion (US$225.3 million) in U.S. dollar-denominated payments, considering the exchange rate of December 31, 2021, as quoted by Banco de la Nación Argentina for wire transfers) in principal and in interest for these receivables (excluding VAT).
During 2021, we collected Ps. 8.2 billion from the CVO receivables, measured in current amounts as of December 31, 2021.
Adequate financial position. We benefit from an adequate financial position, operating efficiency and a relative low level of indebtedness, allowing us to deliver on our business growth strategy and create value for our shareholders. In terms of our financial position, our total cash and cash equivalents and current other financial assets was Ps. 20.12 billion as of December 31, 2021 (approximately US$196.27 million). As of the date of this annual report, we also have uncommitted lines of credit with commercial banks, totaling approximately Ps. 10.94 billion.
Solid and experienced management team with a successful track record in delivering growth. Our executive officers have vast experience and a long track record in corporate management with, on average, 18 years of experience in the industry. Our management has diverse experience navigating different business cycles, markets and sectors, as evidenced by the growth and expansion we have undergone since the early 1990s. They also have a proven track record in acquisitions and accessing financial markets. On June 14, 2019, Central Puerto, in the context of a local and foreign public tender called by IEASA, which had been awarded to the Company, purchased the Brigadier López Plant. Our management successfully obtained US$180 million loan from Citibank N.A., JP Morgan Chase Bank N.A. and Morgan Stanley Senior Funding INC. to fulfill the acquisition. “See Item 5.B. Liquidity and Capital Resources—Indebtedness—Loan from Citibank N.A., JP Morgan Chase Bank N.A. and Morgan Stanley Senior Funding INC.”
Additionally, during 2018, 2019 and 2020, our management also obtained financing for the expansion of our installed capacity from multilateral credit agencies, export credit agencies, commercial banks and the local securities market, as described in “Item 5.B. Liquidity and Capital Resources—Indebtedness.”
In addition, in 2015, jointly with an investment consortium, we acquired non-controlling equity interests in Ecogas, which distributes natural gas through its network covering 36,048 km and serving approximately 1,391,055 customers as of December 31, 2021, further diversifying our interest in the sector. We believe that our management team has been successful in identifying attractive investment opportunities, structuring innovative business plans and completing complex transactions efficiently.
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| Our management has significant in-country know-how, with professionals who have taken an active role in project development and construction, developing private and public investment plans with both Argentine and international partners. In addition, our management team has business experience at the international and national level, are familiar with the operation of our assets in a constantly changing business environment and are strongly committed to our day-to-day decision-making process. |
|
|
|
|
| Finally, our executive officers have a solid understanding of Argentina’s historically volatile business environment. They have built and maintained mutually beneficial and long-lasting relationships with a diversified group of suppliers and customers and have cultivated relationships with regulatory authorities. |
|
|
|
| · | Strong corporate governance. We have adopted a corporate governance code to put into effect corporate governance best practices, which are based on strict standards regarding transparency, efficiency, ethics, investor protection and equal treatment of investors. The corporate governance code follows the guidelines established by the CNV. We have also adopted a code of ethics and an internal conduct code designed to establish guidelines with respect to professional conduct, morals, and employee performance. In addition, the majority of our Board of Directors qualifies as “independent” in accordance with the criteria established by the CNV, which may differ from the independence criteria of the NYSE and NASDAQ. |
Our Business Strategy
We seek to consolidate and grow our position in the Argentine energy industry by maintaining our existing asset base and by acquiring and developing new assets related to the sector. The key components of our strategy are as follows:
| · | Consolidating our leading position in the energy sector. We seek to consolidate our position in the energy sector by analyzing value-generating alternatives through investments with a balanced approach to profitability and risk exposure. We are committed to maintaining our high operating standards and availability levels. To this end, we follow a strict maintenance strategy for our units based on recommendations from their manufacturers, and we perform periodic preventive and predictive maintenance tasks. We plan to focus our efforts on optimizing our current resources from a business, administrative and technological perspective, in addition to capitalizing on operating synergies from the plants currently under construction that rely on similar systems, know-how, customers and suppliers. |
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| · | Becoming a leading company in renewable energy in Argentina. Several research studies from organizations such as the Cámara Argentina de Energías Renovables suggest that Argentina has a significant potential in renewable energy (mainly in wind and solar energy). We also believe that renewable energy will become a larger part of the installed capacity in Argentina. The Ministry of Energy and Mining, through Law No. 27,191, has established a target for renewable energy sources to account for 20% of Argentina’s electric power consumption by December 31, 2025. We intend to capitalize on this opportunity by expanding our investments into renewable energy generation. To achieve this goal, we are strengthening our renewable energy portfolio. In August 2018, September 2018, July 2019, September 2019, December 2019/January 2020, February 2020 and November 2020 our wind farms La Castellana I, Achiras, La Castellana II, La Genoveva II, Manque, Los Olivos and La Genoveva I started operations, respectively. Additionally, we are also exploring several other options to diversify our generation assets to include sustainable power generation sources (see Item 3D. Risk Factors—Risks Relating to our Business— Factors beyond our control may affect or delay the completion of the awarded projects or alter our plans for the expansion of our existing plants). In 2016, we formed our subsidiary, CP Renovables, to develop, construct and operate renewable energy generation projects. |
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|
|
| · | Maintaining an adequate financial position and sound cash flow levels. We have a relatively low level of debt, which reflects our adequate financial position and additional debt capacity. We believe our adequate financial position is the result of our responsible financial policies and stable cash flows. We will preserve our current cash flow levels in the coming years by, among other things, keeping a rigorous maintenance program for our production units, which we expect will help us continue the positive operational results we have experienced, particularly regarding our electric power dispatch availability. We intend to fund our expansion plans primarily with loan arrangements, such as credit facilities and project financing or capital markets in the case of our renewable energy projects. Each of CP La Castellana, CP Achiras, CPR Energy Solutions, Vientos La Genoveva I, Vientos La Genoveva II, entered into long term loans to fund the development of renewable energy projects they were awarded and to purchase wind turbines. We also obtained a long term loan from Kreditanstalt für Wiederaufbau (“KfW”) to support the construction of the new Luján de Cuyo cogeneration project, and a loan from Citibank N.A., JP Morgan Chase Bank N.A. and Morgan Stanley Senior Funding INC. to purchase the Brigadier López plant. Additionally, Manque and Los Olivos issued a bond in the local market. See “Item 5.A. Operating Results—Indebtedness.” We expect that the new capacity from these projects will allow us to further increase our cash flow, while enhancing our financial position. |
Our Subsidiaries
Central Vuelta de Obligado S.A.
CVOSA is a private, unlisted company, engaged in managing the purchase of equipment and building, operating and maintaining the CVOSA power plant that was constructed and began operations in March 20, 2018 under a program substantially similar to the FONINVEMEM program. In the year ended December 31, 2021, CVOSA accounted for a gain equaling 33.19% of our consolidated net loss.
We have 56.19 % of the voting rights in CVOSA, which grants us the power to unilaterally approve resolutions for which a majority is required at the relevant shareholders meeting. However, pursuant to a shareholders’ agreement entered into among Endesa Costanera S.A., Hidroeléctrica El Chocón S.A., Central Dock Sud S.A. (the “Other CVOSA Shareholders”) and us, we will only be able to approve the following decisions with the affirmative vote of the Other CVOSA Shareholders: (i) entering into a merger, spin-off, transformation or liquidation; (ii) increasing or decreasing the capital stock; (iii) receiving capital contributions; (iv) entering into transactions with related parties; (v) amending the bylaws; (vi) entering into an operating and maintenance agreement for the Vuelta de Obligado power plant; (vii) approving the trust agreement in connection with the Vuelta de Obligado power plant and its amendments; (viii) filing any lawsuit against any governmental authorities, CAMMESA and/or the FONINVEMEM trust fund currently holding the Vuelta de Obligado power plant; (ix) entering into engineering services, gas supply and transportation agreements; and (x) entering into a power purchase agreement with CAMMESA for the Vuelta de Obligado power plant. If such decisions are to be decided at a board of directors’ meeting, they can only be approved with the affirmative vote of at least one member of the board of directors appointed by the Other CVOSA Shareholders.
The board of directors of CVOSA consists of four members, two of which are appointed by us and the remaining two, by the Other CVOSA Shareholders. In addition, we have the right to appoint the chairman of the board of directors of CVOSA, who has double vote in case of a tie. In addition, we have the right to appoint one member of the supervisory committee of CVOSA.
Pursuant to the terms of the FONINVEMEM agreement relating to the Vuelta de Obligado power plant, on the tenth anniversary of the start of operations of the Vuelta de Obligado power plant, which occurred on March 20, 2018, all governmental entities that financed the construction of the Vuelta de Obligado power plant have the right to be incorporated as shareholders of CVOSA, which in turn may dilute our interest in CVOSA. If such dilution were to occur, we may no longer control CVOSA.
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Proener S.A.U.
Proener S.A.U. is a private, unlisted company. We hold a 100.00% interest in Proener S.A.U., a company engaged in investment activities, including the energy sector, both domestically in Argentina and internationally. In the year ended December 31, 2021, Proener S.A.U. accounted for a loss equaling 577.98% of our consolidated net loss.
CP Renovables S.A.
In 2016, we formed a subsidiary, CP Renovables S.A. (“CP Renovables”), to develop, construct and operate renewable energy generation projects. As of the date of this annual report, we directly own a 96.14% interest in CP Renovables. The remaining interest is owned through CPR Energy Solutions S.A.U. (0.36%) and Vientos La Genoveva II S.A.U. (3.49%).
On June 24, 2020, our Board of Directors authorized the purchase of 30% of the capital stock of the subsidiary CP Renovables S.A. from Mr. Guillermo Pablo Reca. On June 24, 2020, we acquired 993,993,952 shares, at a value of US$ 0.034418 per share, which were fully paid through the transfer of financial assets. Based on the Audit Committee’s report, the Board of Directors determined that such transaction was an arm´s length transaction. As a result of this transaction, as of the date of this annual report, the Company´s consolidated interest in the subsidiary CP Renovables S.A. amounts to 100% of its capital stock.
This transaction was accounted as a transaction with non-controlling interest in accordance with IFRS 10. Consequently, the difference of 1,966,148 between the book value of the non-controlling interest at the transaction date and the fair market value of the consideration paid was directly recognized in equity and attributed to holders of the parent company.
CP Renovables S.A. invests in renewable energy assets. In the year ended December 31, 2021, CP Renovables S.A. and its subsidiaries accounted for a consolidated gain, equaling 564.36% of our consolidated net loss.
CP Achiras S.A.U.
CP Achiras S.A.U. is a private, unlisted company. CP Renovables S.A. holds a 100% interest in the capital stock of CP Achiras S.A.U., a company engaged in the generation and commercialization of electric power through renewable sources. In the year ended December 31, 2021, CP Achiras accounted for a gain equaling 83.74% of our consolidated net loss.
CPR Energy Solutions S.A.U. (previously known as “CP Achiras S.A.U.”)
CPR Energy Solutions S.A.U. is a private, unlisted company. CP Renovables holds a 100% interest in the capital stock of CPR Energy Solutions S.A.U., a company engaged in generation and commercialization of electric power through renewable sources. In the year ended December 31, 2021, CPR Energy Solutions S.A.U. account for a gain of 36.46% of our consolidated net loss.
CP Patagones S.A.U.
CP Patagones S.A.U. is a private, unlisted company. CP Renovables holds a 100% interest in the capital stock of CP Patagones S.A.U., a company engaged in generation and commercialization of electric power through renewable sources. In the year ended December 31, 2021, CP Patagones S.A.U. did not account for any of our consolidated net loss.
CP La Castellana S.A.U.
CP La Castellana is a private, unlisted company. CP Renovables holds a 100% interest in the capital stock of CP La Castellana, a company engaged in generation and commercialization of electric power through renewable sources. In the year ended December 31, 2021, CP La Castellana accounted for a gain equaling 255.96% of our consolidated net loss.
Vientos La Genoveva S.A.U.
Vientos La Genoveva S.A.U. is a private, unlisted company. On March 7, 2018, our subsidiary CP Renovables S.A. acquired 100% of the equity interests in Vientos La Genoveva S.A. and, on that same date, transformed it into a S.A.U. On August 6, 2018, we purchased from our subsidiary, CP Renovables S.A., 100% of the equity interests in Vientos La Genoveva S.A.U. Vientos La Genoveva is a company engaged in generation and commercialization of electric power through renewable sources. In the year ended December 31, 2021, Vientos La Genoveva accounted for a gain equaling 303.08% of our consolidated net loss.
Vientos La Genoveva II S.A.U.
Vientos La Genoveva II S.A.U. is a private, unlisted company. On June 28, 2018, our subsidiary CP Renovables S.A. acquired 100% of the equity interests in Vientos La Genoveva II S.A. and, and was later transformed it into a S.A.U. On August 6, 2018, we purchased from our subsidiary, CP Renovables S.A., 100% of the equity interests in Vientos La Genoveva II S.A.U. In the year ended December 31, 2021, Vientos La Genoveva accounted for a gain equaling 120.60% of our consolidated net loss.
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CP Manque S.A.U.
CP Manque S.A.U. is a private, unlisted company. CP Renovables holds a 100% interest in the capital stock of CP Manque S.A.U., a company engaged in generation and commercialization of electric power through renewable sources. In the year ended December 31, 2021, CP Manque S.A.U. accounted for a gain equaling 166.46% of our consolidated net loss.
CP Los Olivos S.A.U.
CP Los Olivos S.A.U. is a private, unlisted company. CP Renovables holds a 100% interest in the capital stock of CP Los Olivos S.A.U., a company engaged in generation and commercialization of electric power through renewable sources. In the year ended December 31, 2021, CP Los Olivos S.A.U. accounted for a gain equaling 44.86% of our consolidated net loss.
Our Affiliates
Termoeléctrica José de San Martín S.A. (TJSM) and Termoeléctrica Manuel Belgrano S.A. (TMB)
TJSM and TMB are private, unlisted companies, which are engaged in managing the purchase of equipment, and building, operating and maintaining the San Martín and Belgrano power plants, respectively, each constructed under the FONINVEMEM program. In the year ended December 31, 2021, TJSM and TMB accounted for a loss equaling 5.83% and 4.37% of our consolidated net loss, respectively.
As of December 31, 2021, we had 9.6269% of the voting rights in TJSM and 10.8312% of the voting rights in TMB. While we do not have control over these companies, pursuant to a shareholders’ agreement entered into among Endesa Costanera S.A., Hidroeléctrica El Chocón S.A. Central Dock Sud S.A, AES Argentina Generación S.A., Central Dique S.A. and us, certain material actions can only be approved with our affirmative vote, such as, among others, entering into power purchase agreements with CAMMESA, engineering services agreements, gas supply and transportation agreements, and transactions with related parties.
The board of directors of each of TJSM and TMB consists of nine members.
After ten years of operations, TJSM and TMB were entitled to receive property rights to such power plants from the respective trusts currently holding such power plants. At such time, the term of the trusts expired and the Argentine Government, that financed part of the construction, should be incorporated as a shareholder of TJSM and TMB. Consequently, our interests in TJSM and TMB were diluted in 2021. In the case of TMB and TJSM, the ten-year period expired on January 7, 2020, and on February 2, 2020, respectively. From such dates, during the following 90-days, TJSM and TMB and their shareholders had to perform all the necessary acts to allow the Argentine Government to receive the corresponding shares in the equity stake of TJSM and TMB that their contributions entitle the Argentine Government to receive.
On January 3, 2020, before the aforementioned 90 days period commenced, the Argentine Government sent a notice to the Company (together to TSM, TMB and to other generation companies that are shareholders of TJSM and TMB) stating that, in accordance with FONINVEMEM Agreement, TJSM and TMB should perform all necessary acts to incorporate the Argentine Government as shareholder of both companies, claiming, in each case, the following equity interest rights: 65.006% in TMB and 68.826% in TJSM.
On January 9, 2020, the Company, together with the other generation companies, shareholders of TJSM and TMB, replied such notice stating that the Argentine Government’s equity interest claims did not correspond with the contributions made for the construction of the power plants under the terms of the FONINVEMEM Agreement that give rights to claim such equity interest. On March 4, 2020, the Argentine Government reiterated its previous claim to the Company.
Additionally, on January 7, 2020 and on January 9, 2020, Central Puerto, together with the other shareholders of TJSM and TMB (as guarantors within the framework and the limits stated by the FONINVEMEM Agreement, the Note SE no. 1368/05 and the trust agreements), BICE, TJSM, TMB and the Energy Secretariat amended the Operation and Maintenance Agreement of the Manuel Belgrano Thermal Facility (the “TMB OMA”) and the Operation and Maintenance Agreement of the San Martín Thermal Facility ( the “TJSM OMA”), respectively. The amendments to the TMB OMA and TJSM OMA extended the agreements until each of the trust’s liquidation effective date.
In March 2020, Central Puerto filed an administrative appeal against the Argentine Government challenging their acts referred to above (the “Claim”). Pursuant to this Claim, the position of the shareholders of TJSM and TMB is that the Argentine Government equity interest in each of the companies should be lower but its incorporation as a shareholder in such companies is unchallenged. Therefore, even if we are successful with our Claim, our interests on TJSM and TMB were significantly diluted.
On May 4, 2020, and May 8, 2020, the extraordinary shareholders’ meetings of TMB and TJSM, respectively, approved the incorporation of the Argentine Government as shareholder of TJSM and TMB. In each of the extraordinary shareholders’ meetings, the approved equity interest that was approved was the equity interest that the Argentine Government claims that it is entitled to, which is: 65.006% in TMB and 68.826% in TJSM.
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In each of the shareholders’ meetings, Central Puerto (and other shareholders), made the corresponding reservation of rights to continue with the Claim, and expressly stated that the incorporation of the Argentine Government as a shareholder in TMB and TJSM was approved for the sole purpose of achieving the transfer of the trust assets -which includes, among others, the power plants- from the respective trusts to TJSM and TMB.
On March 11, 2021, the Argentine Government has subscribed its shares and the equity of the shareholders of TJSM and TMB were diluted. In the case of our equity interest, from 30.8752% to 9.6269% in TJSM and from 30.9464% to 10.8312% in TMB.As of the date of this annual report, the transfer of power stations to TSM and TMB was not completed. See “Item 3D. Risk Factors—Risks Relating to our Business—Our interests in TJSM, TMB were diluted and CVOSA will be significantly diluted.”
In the case of CVOSA, when the CVO Trust term expires after ten years of operation of the respective power plant the Argentine Government will be incorporated as shareholder, with a stake of at least 70% pursuant to FONINVEMEM arrangements for CVOSA. The dilution of our interest in CVOSA will reduce our income from this power plant, adversely affecting our results of operations. This will also take place when the Argentine Government incorporates as a shareholder of CVOSA and our equity interest in that company is diluted. See “Item 4.B. Business Overview—FONINVEMEM and Similar Programs.”
Ecogas Group - Inversora de Gas del Centro S.A. (IGCE)
IGCE is a private, unlisted company. Its only significant assets are a 55.29% interest in DGCE, a company engaged in the distribution of natural gas in the provinces of Córdoba, La Rioja and Catamarca. and a 51.00% interest in DGCU, a company engaged in the distribution of natural gas in the provinces of Mendoza, San Juan and San Luis. During 2019, IGCE absorbed IGCU, RPBC and MAGNA. For further information on the merger of IGCE and IGCU, see “Item 4.A—Merger between IGCE, IGCU, RPBC and MAGNA.”
As of the date of this annual report, we hold a 42.31% interest in IGCE and a direct 17.20% interest in DGCE. Therefore, we hold, both directly and indirectly, a 40.59% of DGCE’s capital stock and indirectly have a 21.58% interest in DGCU’s capital stock.
In the year ended December 31, 2021, IGCE (including a direct interest in DGCE) accounted for a loss equaling 81.60% of our consolidated net loss (see “Item 4.A. History and development of the Company—Distribuidora de Gas Cuyana S.A. (DGCU) and Distribuidora de Gas del Centro S.A. (DGCE)” and “Item 4.A. History and development of the Company—Preliminary Merger Agreement between IGCE, IGCU, RPBC and MAGNA”).
Transportadora de Gas del Mercosur S.A. (TGM)
TGM is a private, unlisted company. We hold a 20.00% interest in the capital stock of TGM, which owns a natural gas pipeline extending from Aldea Brasilera (in the Province of Entre Rios) to Paso de los Libres (in the Province of Corrientes). In the year ended December 31, 2021, TGM accounted for a gain equaling 3.16% of our consolidated net loss.
The remaining 80.00% is owned by Total Gas y Electricidad Argentina S.A. (32.68%), Tecpetrol S.A. (21.79)%, RPM Gas S.A. (14.63%) and Compañía General de Combustibles S.A. (10.90%).
The pipeline is approximately 450 km long and its transportation capacity reaches up to 15 million cubic meters per day.
Energía Sudamericana S.A.
Energía Sudamericana S.A. is a private, unlisted company, engaged in natural gas commercialization. We hold a 2.45% direct interest in the capital stock of Energía Sudamericana S.A., plus a 41.06% indirect interest in its capital stock, through our equity interest in IGCE. In the year ended December 31, 2021, Energía Sudamericana S.A. did not account for a material portion of our net income.
COySERV S.A.
COySERV S.A. is a private, unlisted company, engaged in services and constructions related to the gas industry. We hold a 32.21% indirect interest in the capital stock of COySERV S.A., through our equity interests in IGCE, DGCE and DGCU. In the year ended December 31, 2021, COySERV S.A. did not account for a material portion of our net income
The Company (on an unconsolidated basis, excluding profits and losses from associates and subsidiaries) accounted for a loss equaling 543.25% of our consolidated net loss.
Business Overview
All of our operations are concentrated in thirteen plants in Argentina, and our portfolio can be divided into two types of electric power generation plants: (i) electric power generation from conventional sources and (ii) electric power generation from renewable sources.
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The table below details certain operating features regarding our power generation assets for the periods indicated:
|
| For the year ended December 31, |
| |||||||||
|
| 2021 |
|
| 2020 |
|
| 2019 |
| |||
Generation—GWh/year |
|
|
|
|
|
|
|
|
| |||
Puerto Complex |
|
| 6,593 |
|
|
| 6,796 |
|
|
| 7,108 |
|
Luján de Cuyo plant |
|
| 3,136 |
|
|
| 2,686 |
|
|
| 2,959 |
|
Brigadier López plant (3) |
|
| 93 |
|
|
| 71 |
|
|
| 127 |
|
Terminal 6 |
|
| 463 |
|
|
| 12 |
|
|
| - |
|
Piedra del Águila plant |
|
| 2,565 |
|
|
| 3,435 |
|
|
| 3,920 |
|
La Castellana I wind farm (2) |
|
| 416 |
|
|
| 437 |
|
|
| 418 |
|
la Castellana II wind farm (2) |
|
| 68 |
|
|
| 74 |
|
|
| 33 |
|
Achiras wind farm (2) |
|
| 191 |
|
|
| 213 |
|
|
| 202 |
|
Manque wind farm (2) |
|
| 236 |
|
|
| 228 |
|
|
| 18 |
|
Olivos wind farm (2) |
|
| 104 |
|
|
| 87 |
|
|
| - |
|
La Genoeva I wind farm (2) |
|
| 375 |
|
|
| 99 |
|
|
| - |
|
La Genoveva II wind farm (2) |
|
| 179 |
|
|
| 190 |
|
|
| 58 |
|
Total |
|
| 14,389 |
|
|
| 14,329 |
|
|
| 14,849 |
|
Sales under the Energía Base and electric power sales on the spot market—GWh/year |
|
|
|
|
|
|
|
|
|
|
|
|
Puerto Complex |
|
| 6,563 |
|
|
| 6,073 |
|
|
| 7,073 |
|
Luján de Cuyo plant |
|
| 2,409 |
|
|
| 1,932 |
|
|
| 2,722 |
|
Brigadier López plant (3) |
|
| 1 |
|
|
| - |
|
|
| - |
|
Terminal 6 |
|
| 158 |
|
|
| - |
|
|
| - |
|
Piedra del Águila plant |
|
| 2,565 |
|
|
| 3,435 |
|
|
| 3,920 |
|
La Castellana I wind farm (2) |
|
| - |
|
|
| - |
|
|
| - |
|
la Castellana II wind farm (2) |
|
| - |
|
|
| - |
|
|
| - |
|
Achiras wind farm (2) |
|
| - |
|
|
| - |
|
|
| - |
|
Manque wind farm (2) |
|
| 2 |
|
|
| - |
|
|
| - |
|
Olivos wind farm (2) |
|
| - |
|
|
| - |
|
|
| - |
|
La Genoeva I wind farm (2) |
|
| - |
|
|
| - |
|
|
| - |
|
La Genoveva II wind farm (2) |
|
| - |
|
|
| - |
|
|
| - |
|
Total |
|
| 11,699 |
|
|
| 12,146 |
|
|
| 13,715 |
|
Sales under contracts and Power Purchase Agreements—GWh/year |
|
|
|
|
|
|
|
|
|
|
|
|
Puerto Complex |
|
| - |
|
|
| 18 |
|
|
| 38 |
|
Luján de Cuyo plant |
|
| 727 |
|
|
| 774 |
|
|
| 237 |
|
Brigadier López plant (3) |
|
| 92 |
|
|
| 71 |
|
|
| 127 |
|
Terminal 6 |
|
| 306 |
|
|
| - |
|
|
| - |
|
Piedra del Águila plant |
|
| - |
|
|
|
|
|
|
| - |
|
La Castellana I Achiras(2) |
|
| 416 |
|
|
| 437 |
|
|
| 418 |
|
la Castellana II (2) |
|
| 71 |
|
|
| 71 |
|
|
| 33 |
|
Achiras (2) |
|
| 191 |
|
|
| 213 |
|
|
| 202 |
|
Manque (2) |
|
| 241 |
|
|
| 212 |
|
|
| 18 |
|
La Genoveva II (2) |
|
| 178 |
|
|
| 180 |
|
|
| 58 |
|
Olivos wind farm (2) |
|
| 96 |
|
|
| 79 |
|
|
| - |
|
La Genoeva I wind farm (2) |
|
| 375 |
|
|
| 46 |
|
|
| - |
|
Total |
|
| 2,694 |
|
|
| 2,100 |
|
|
| 1,133 |
|
Energy purchases—GWh/year |
|
|
|
|
|
|
|
|
|
|
|
|
Puerto Complex |
|
| 46 |
|
|
| 1 |
|
|
| 2 |
|
Luján de Cuyo plant |
|
| 7 |
|
|
| 3 |
|
|
| - |
|
Brigadier López plant (3) |
|
| 3 |
|
|
| - |
|
|
| - |
|
Terminal 6 |
|
| 6 |
|
|
| - |
|
|
| - |
|
Piedra del Águila plant |
|
| - |
|
|
| - |
|
|
| - |
|
La Castellana I (2) |
|
| 0.4 |
|
|
| - |
|
|
| - |
|
La Catellana II (2) |
|
| - |
|
|
| - |
|
|
| - |
|
Achiras (2) |
|
| 0.2 |
|
|
| - |
|
|
| - |
|
Manque (2) |
|
| 0.1 |
|
|
| - |
|
|
| - |
|
La Genoveva II (2) |
|
| 0.1 |
|
|
| - |
|
|
| - |
|
La Genoeva I wind farm (2) |
|
| 0.2 |
|
|
|
|
|
|
|
|
|
Total |
|
| 63 |
|
|
| 4 |
|
|
| 2 |
|
Steam production (metric tons/year) |
|
|
|
|
|
|
|
|
|
|
|
|
Luján de Cuyo plant |
|
| 1,099,223 |
|
|
| 1,081,959 |
|
|
| 1,031,044 |
|
Terminal 6 |
|
| 109,288 |
|
|
| - |
|
|
| - |
|
Total |
|
| 1,208,511 |
|
|
| 1,081,959 |
|
|
| 1,031,044 |
|
Natural gas consumption—MMm3/year |
|
|
|
|
|
|
|
|
|
|
|
|
Puerto Complex |
|
| 831 |
|
|
| 1,097 |
|
|
| 1,417 |
|
Luján de Cuyo plant |
|
| 673 |
|
|
| 553 |
|
|
| 587 |
|
Brigadier López plant (3) |
|
| 2 |
|
|
| 12 |
|
|
| 30 |
|
|
|
| 91 |
|
|
| - |
|
|
| - |
|
Total |
|
| 1,597 |
|
|
| 1,662 |
|
|
| 2,034 |
|
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| Table of Contents |
|
| For the year ended December 31, |
| |||||||||
|
| 2021 |
|
| 2020 |
|
| 2019 |
| |||
Gas oil consumption—thousands of m3/year |
|
|
|
|
|
|
|
|
| |||
Puerto Complex |
|
| 267 |
|
|
| 119 |
|
|
| 48 |
|
Luján de Cuyo plant |
|
| - |
|
|
| - |
|
|
| - |
|
Brigadier López plant (3) |
|
| - |
|
|
| 8 |
|
|
| 9 |
|
Terminal 6 |
|
| 8 |
|
|
|
|
|
|
|
|
|
Total |
|
| 275 |
|
|
| 126 |
|
|
| 57 |
|
Fuel oil consumption—thousands of tons/year |
|
|
|
|
|
|
|
|
|
|
|
|
Puerto Complex |
|
| 361 |
|
|
| 269 |
|
|
| 80 |
|
Luján de Cuyo plant |
|
| - |
|
|
| 11 |
|
|
| 6 |
|
Brigadier López plant (3) |
|
| - |
|
|
| - |
|
|
| - |
|
Terminal 6 |
|
| - |
|
|
| - |
|
|
| - |
|
Total |
|
| 361 |
|
|
| 279 |
|
|
| 86 |
|
Availability—% per year(1) |
|
|
|
|
|
|
|
|
|
|
|
|
Puerto Complex |
|
| 87.91 | % |
|
| 93,32 | % |
|
| 93.90 | % |
Luján de Cuyo plant |
|
| 84.44 | % |
|
| 71,89 | % |
|
| 89.38 | % |
Brigadier López plant (3) |
|
| 96.06 | % |
|
| 96,14 | % |
|
| 97.25 | % |
Piedra del Águila plant |
|
| 98.6 | % |
|
| 97,78 | % |
|
| 96.68 | % |
Terminal 6 |
|
| 84.42 | % |
|
| - |
|
|
| - |
|
Weighted average for thermal units(1) |
|
| 87.55 | % |
|
| 88,70 | % |
|
| 93.22 | % |
Weighted average for thermal and hydro plants(1) |
|
| 91.14 | % |
|
| 91,94 | % |
|
| 94.46 | % |
____________
Source: CAMMESA.
(1) | Weighted average based on the power capacity of each unit without considering renewable energy units, which do not receive payments tied to their availability. |
(2) | La Castellana I, La Castellana II, Achiras, Manque, Olivos, La Genoveva I and La Genoveva II wind farms are owned by CP La Castellana S.A.U., CPR Energy Solutions S.A.U., CP Achiras S.A.U., CP Manque S.A.U., CP Los Olivos S.A.U, Vientos La Genoveva I S.A.U and Vientos La Genoveva II S.A.U., respectively, the first five of which are fully owned subsidiaries of CP Renovables S.A. while the last two are a fully owned subsidiary of Central Puerto S.A. As of the date of this annual report, we own a 100% interest in CP Renovables. See “Item 4.B. Business Overview—Our Subsidiaries”. |
| As of December 31, 2019, Manque wind farm had an installed capacity of 38 MW. On January 23, 2020, the capacity of the plant was increased to 53.20 MW, and on March 3, 2019, it was increased to 57 MW, the total power of the project |
| As of December 31, 2019, La Castellana II wind farm had an authorized installed capacity of 14.40 MW. On February 21, 2020, CAMMESA granted the authorization to increase the output to the grid for up to 15.20 MW.. |
| On February 21, 2020, Los Olivos wind farm was granted the commercial authorization by CAMMESA for up to a power capacity of 22.80 MW. |
Additionally, the table below details shows the availability features regarding the three FONINVEMEM Plants for 2021:
Source: Central Puerto, CAMMESA
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The following graph shows the evolution of Central Puerto’s electric power generation for the period 2013-2021:
Source: CAMMESA. The graph (i) includes generation of companies that were absorbed by Central Puerto in 2014 (see Business Section—The 2014 merger) and (ii) excludes the La Plata plant, which effective as of January 5, 2018, we sold to YPF EE. For further information, see “Item 4.A. History and development of the Company—La Plata Plant Sale”.)
Electricity Generation from our Thermal Generation Plants
As of December 31, 2021, we owned six thermal generation plants across four complexes: Puerto Complex, Brigadier Lopez, Luján de Cuyo and San Lorenzo – T6.
Puerto Complex
Our Puerto Complex is composed of two facilities, Nuevo Puerto, including the Puerto combined cycle plant, and Puerto Nuevo (collectively, the “Puerto Complex”), located in the port of the City of Buenos Aires on the bank of the Río de la Plata. The two facilities are close to one another inside a complex of 246,475 square meters with a total installed capacity of 1,714 MW. Nuevo Puerto’s facilities (which includes both the Nuevo Puerto plant and the Puerto combined cycle plant) has 70,518 square meters. Puerto Nuevo has approximately 92,370 square meters.
Nuevo Puerto’s facilities were completed in 1926 and Puerto Nuevo’s facilities were completed in 1930. The two facilities were merged into a single company in the 1980s within SEGBA, which was later converted to Central Puerto after the privatization in 1992.
Nuevo Puerto is located at Av. Thomas Edison 2001/2151 in the City of Buenos Aires in the northern part of the complex and has two conventional steam turbine generator sets (steam turbine units 5 and 6). The plant can run on natural gas and fuel oil and has a current installed capacity of 360 MW.
The Puerto combined cycle plant was built at Nuevo Puerto’s facilities and commenced commercial operations in 2000. The Puerto combined cycle plant has an installed capacity of 798 MW and is composed of two General Electric 9FA gas turbines, two heat recovery steam generators and a General Electric D11 steam turbine. The Puerto combined cycle plant is one of the most modern and efficient plants in Argentina and can run on natural gas and gas oil. In addition, since 2011, the facilities were modified to allow for the use of a blend of up to 20.00% gas oil and biodiesel when running on liquid fuel.
Puerto Nuevo is located at Av. Thomas Edison 2701 in the City of Buenos Aires in the southern part of the complex and has three conventional steam turbine generator sets (steam turbine units 7, 8 and 9). The plant is capable of running on natural gas and fuel oil and has an installed capacity of 589 MW.
Technology. The steam turbine generators at both facilities include turbines with high, medium and low-pressure stages that run on superheated steam from a dedicated conventional heat generator. The steam turbine generator works on a cycle. Water flows towards a heat generator that creates steam. The expansion of the steam makes the turbine rotate, triggering an electric power producing generator. Once the steam has been used in the turbine, it is collected in condensers where it returns to its liquid form, and the water flows again towards the heat generator to produce more steam and feed the turbine again.
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The combined cycle technology is one of the most efficient fossil fuel-based electric power generation technologies available. It works by first feeding each gas turbine with a mix of fuel and air. The gas that is produced from this process expands rapidly due to combustion and the generator and turbine ultimately convert the resulting rotational energy into electric power. The exhaust gas from each turbine is collected and channeled to a heat recovery steam generator that uses the heat energy contained in the gas turbine exhaust gas to produce steam. The steam that is produced is injected into a steam turbine where it expands and transmits energy to the turbine, which converts the energy into electric power through a generator. Similar to the case of a conventional steam turbine, the steam is condensed and sent back to the circuit to produce more steam.
Location. The Puerto Complex is located inside the port of the City of Buenos Aires and has a right-of-way to use the port facilities, allowing it to receive and store fuel on a large scale. The liquid fuel (gas oil, fuel oil and biodiesel) is delivered by ships that dock near the premises, where the fuel is directly unloaded at the complex. To provide operating flexibility, the Puerto Nuevo and Nuevo Puerto facilities have underground connection systems, which are used to move fuel between plants based on each plant’s delivery needs.
The Puerto Complex’s location on the bank of the Río de la Plata is also convenient in terms of water supply, which is a basic input for our plants. Water is integral both for creating steam and cooling the generation units. Puerto Nuevo and Nuevo Puerto have water treatment facilities that are capable of taking water from the river and delivering it at the quality required for each stage of the electric power generation process.
We currently own the property where the Nuevo Puerto, Puerto combined cycle and Puerto Nuevo plants are located.
Supply. The electric power produced at each plant is delivered to the SADI through a transformer belonging to our generation units. The transformer adjusts the generator output voltage to the voltage required by the network. The electric power is delivered at 132 KV sub-stations neighboring the plants, which are currently operated by Edenor S.A. (the holder of the electric power distribution concession in the area where the Puerto Complex is located).
Luján de Cuyo Plant
The Luján de Cuyo plant is located in Luján de Cuyo, Mendoza and has an installed capacity of 576.3MW. The plant began operating in 1971.
Technology. The Luján de Cuyo plant has eleven generating units, seven gas turbines, three steam turbines and a mini-hydroelectric turbine (which began operating in 2013). The plant has a total installed capacity of 576.3 MW.
The main generator is a combined cycle unit composed of a Siemens gas turbine (TG25) and a Sköda steam turbine (TV15). We believe this is state-of-the-art technology is and our combined cycle unit is highly efficient.
The plant also has a combined heat and power (CHP) unit in place, which commenced operations on October 5, 2019. This unit supplies up to 125 tons per hour of steam to YPF’s refinery in Luján de Cuyo under a steam provision contract. The plant has two Siemens gas turbines (TG26 and TG27) and two heat recovery steam generators. The steam flows into YPF’s facilities through a steam duct that connects the plant to the refinery. Both gas turbines can operate on natural gas or gas oil.
The Luján de Cuyo plant also has two Alstom-branded Frame5-type gas turbines (TG23 and TG24). Prior to the commencement of operation of units TG26 and TG 27 described above, TG23 and TG24 supplied steam to the YPF Luján de Cuyo refinery in a combined heat and power (cogeneration) configuration. Beginning October 5, 2019, TG23 and TG24 have been set up to work in an open cycle configuration Both gas turbines can operate on natural gas or gas oil.
The Luján de Cuyo plant also had an ABB combined cycle unit in place composed of two gas turbines (TG21, TG22) and a steam turbine (TV14), which operates on natural gas or gas oil, or on blends of gas oil and biodiesel (up to 30.00%). Since TG21 had been out of service since 2014, we petitioned CAMMESA an authorization to disconnect this unit from the WEM, which was granted in April 2019. Additionally, we requested the disconnection of the steam turbine unit TV14, due to the low power output capacity of the unit, which was granted in October 2019. The technical characteristics of TG22 allow it to operate as an open cycle gas turbine. As a result, only the power capacity of TG22 was considered for the purpose of describing the total capacity of the Luján de Cuyo plant in this annual report.
In 2013, a mini hydroelectric turbine began operations under the GENREN program, a renewable energy program sponsored by the Ministerio de Planificación (Planning Ministry), (currently the Ministry of Energy). The operation consists of a turbine and a 1 MW Ossberger generator and relies on the waterfall inside the Luján de Cuyo plant’s premises to generate energy. The waterfall is connected to the Mendoza River, and the water from the waterfall is channeled towards the plant to cool the steam turbine condensers.
In 2013, we also made the necessary investments to generate and sell electric power in the Energía Plus. To such end, we augmented the combined-cycle facilities (TG25-TV15) to increase the power of the generator assembly by 16 MW. Under the rules and regulations of the Energía Plus, the generator buys the fuel to cover the committed demand of electric power and supplies the energy to large electric power consumers at market prices, denominated in U.S. dollars, previously agreed between the generator and its clients. Under these agreements, the generator needs to have a contract for the supply of fuel for generation purposes to cover the committed demand.
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Location. The plant is located inside the Provincial Industrial Park in Luján de Cuyo, Mendoza. The plant is close to other industrial facilities, including YPF’s Luján de Cuyo refinery.
The premises on which the Luján de Cuyo plant is located are on the banks of the Mendoza River, a major river in the Mendoza province. The Luján de Cuyo plant’s access to water from the Mendoza River provides it with a source of water to supply the generation process and to cool the condensers. The facility has a water treatment plant with production levels suitable to meet its requirements.
Supply. The electric power generated by the units installed in the Luján de Cuyo plant is delivered to the SADI through a connection between the network and the Luján de Cuyo 132 KV sub-station, which is adjacent to the plant. The sub-station is operated by Distrocuyo, an operator of the trunk pipeline system from the Cuyo region. Steam is delivered to YPF pursuant to separate contract (apart from the La Plata plant YPF agreement) through a short pipeline that connects our Luján de Cuyo plant with YPF’s adjacent Luján de Cuyo refinery.
Because the Luján de Cuyo plant is land-locked, liquid fuels must be transported by land, typically by truck. To accommodate the fuel supply chain, the plant has an unloading area for trucks with facilities equipped to receive gas oil, fuel oil and biodiesel. YPF is required to supply natural gas to be used on-site, and, in the event of a shortage, YPF is required to supply gas oil for up to 45 days per year. The location of the YPF-owned Luján de Cuyo refinery makes the logistics process easier due to the proximity of the Luján de Cuyo refinery to the Luján de Cuyo plant.
Brigadier López Plant
Brigadier López power plant is located in the Sauce Viejo Industrial Park, in the city of Sauce Viejo, Santa Fe. The plant has an installed capacity of 280.5 MW and has been in operation since August 2012.
In 2010, the public sector power generation company IAESA (formerly named ENARSA) began the construction of the plant. In 2012, ENARSA set the COD of the open cycle Gas Turbine, completing the first stage of the project. In June 2019, Central Puerto acquired the plant, with the objective to install a steam turbine, which was already acquired, with an installed capacity of up to 140 MW in a combined cycle configuration together with the existing gas turbine. As of the date of this annual report, the facilities construction of the combined cycle plant is pending (see Item 3D. Risk Factors—Risks Relating to our Business— Factors beyond our control may affect or delay the completion of the project, or alter our plans for the expansion of our existing plants” and “Item 3D. Risk Factors—Risks Relating to our Business—An outbreak of a disease, including COVID-19, may have a material adverse consequences on our business operations including new projects”).
Technology: The Brigadier Lopez Power Plant has one operating power generation unit, with 280.5 MW of installed capacity (which could reach up to 420 MW of total capacity, operating as a combined cycle unit). This generating unit is composed of a modern Siemens Gas Turbine (TG01) model SGT5-4000 F and an air-cooled Siemens power generator, model SG 1000A. The Gas Turbine can operate both on natural gas and gas oil (diesel oil).
In addition, the plant has at its location a 140 MW Steam Turbine model SST-900 RH Dual Casing and a Heat Recovery Steam Generator, installation of which has not been completed as of the date of this annual report. Under a combined cycle configuration, the Brigadier Lopez plant would operate as a highly efficient combined cycle, increasing both its efficiency and total power capacity.
Location: The plant is located in the Sauce Viejo Industrial Park, nearby many other industrial facilities. Sauce Viejo industrial park is located on the National Highway N° 11, 20 km from Santa Fe City, capital of the province of Santa Fe. This location is highly convenient due to its accessibility and logistic advantages.
Furthermore, the Brigadier López power plant is located on the banks of the Coronda River, one of the major branches of the Paraná River. Such access from the Coronda River provides a source of water supply for the generation process and the steam turbine’s condenser. The facility has a water treatment plant with production levels suitable to meet its requirements.
Supply: The electric power generated by the units installed in the Brigadier Lopez power plant is delivered to the SADI, first through a high voltage power transformer, and then through the Brigadier Lopez 132 kV power sub-station. While the transformer is property of Central Puerto, the sub-station is operated by EPE Santa Fe (holder of the electric distribution and transmission concession in the Province of Santa Fe). The transformer changes the generator’s voltage output to meet the required voltage of the electrical grid, and the sub-station serves as an interface between the Brigadier Lopez plant and the overhead transmission lines connected to the SADI.
The plant operates most of the time using natural gas. It is connected to the main gas pipeline (GNEA) through a 19 km dedicated pipeline that guarantees supply of natural gas. Alternatively, the plant can also be operated using liquid fuels which must be transported by land, typically by truck. To accommodate the fuel supply chain, the plant has an unloading area for trucks with facilities equipped to receive and deliver gas oil. Alternatively, the plant also has a dock (operation not available yet), that will be capable of receiving liquid fuels transported by ship.
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San Lorenzo – T6
San Lorenzo power plan is located near San Lorenzo city in the province of Santa Fe. This is a greenfield cogeneration project, with a total installed capacity of 391 MW and a steam generation capacity of 370 tn/h. The plant started commercial operations by the end of 2020 and started commercial operation under CAMMESA contract on August 15, 2021.
Technology: San Lorenzo power plant is a Siemens combined cycle able to generate up to 391 MW, with a 291 MW Gas turbine and a 100 MW Steam turbine. By electric output regulation, the plant can supply up to 370 tn/h of steam to our neighbour customer, T6 Industrial. Gas turbine can operate on natural gas or gas oil.
Supply. The electric power generated by the units installed in the San Lorenzo plant is delivered to the SADI through two connections. The steam turbine generator is connected by a 132 KV cable with Terminal 6 Substation (EPESF facility) and the gas turbine generator is connected by a 500 KV line to TRANSENER facilities.
Maintenance
The plants have repair shops, warehouses and facilities suitable for the operation and maintenance of the units. Maintenance of the plants is coordinated with CAMMESA to avoid shortage in the power grid. Repair and maintenance procedures are key to the success of our business and are conducted according to unit type by either our own staff or under long-term service agreements executed with leading global companies in the construction and maintenance of thermal generation plants, such as (i) General Electric, which is in charge of the maintenance of the Puerto combined cycle plant and part of the Luján de Cuyo-based units, and (ii) Siemens, which is in charge of the maintenance of the combined cycle and the new cogeneration unit based in Luján de Cuyo, under a contract that includes the provision of parts and labor.
Under long-term service agreements, suppliers provide materials, spare parts, labor and on-site engineering guidance in connection with scheduled maintenance activities, in accordance with the applicable technical recommendations.
Our own staff is in charge of the maintenance of the steam turbine generator sets. We maintain an inventory of the necessary spare parts on-site, which ensures the immediate availability of parts when needed. This reduces the time it takes to replace the spare parts while ensuring a supply of spare parts that may no longer be available in the market.
Our accurate planning of in-house maintenance and outsourced maintenance by General Electric and Siemens under the long-term service agreements allows us to minimize downtime and reduce the government-imposed outage rate of the units, thus maximizing their efficiency.
Fuel and Water Supply for Thermal Generation
Our conventional resource plants operate on three different types of fuel: (i) natural gas in all units, (ii) fuel oil in the steam turbines exclusively and (iii) gas oil in the gas turbines and combined cycle units. In addition, a mix of bio-diesel and gas oil may be used in certain percentages in our dual combined cycle units.
The table below shows the potential consumption (calculated as the standard consumption declared by CAMMESA based on the unit manufacturer’s specifications, assuming the unit produces energy throughout the entire day) of fossil fuel by the units in the conventional resource plants we owned as of December 31, 2021:
Plant |
| Unit |
| Natural gas (thousands of m3/day) |
|
| Gas oil (m3/day) |
|
| Fuel oil (tons/day) |
| |||
Puerto combined cycle |
| CEPUCC11 |
|
| 1,720 |
|
|
| 1,821 |
|
|
| - |
|
Puerto combined cycle |
| CEPUCC12 |
|
| 1,720 |
|
|
| 1,821 |
|
|
| - |
|
Nuevo Puerto |
| NPUETV05 |
|
| 794 |
|
|
| - |
|
|
| 710 |
|
Nuevo Puerto |
| NPUETV06 |
|
| 1,610 |
|
|
| - |
|
|
| 1,445 |
|
Puerto Nuevo |
| PNUETV07 |
|
| 980 |
|
|
| - |
|
|
| 867 |
|
Puerto Nuevo |
| PNUETV08 |
|
| 1,337 |
|
|
| - |
|
|
| 1,174 |
|
Puerto Nuevo |
| PNUETV09 |
|
| 1,601 |
|
|
| - |
|
|
| 1,432 |
|
Subtotal Puerto Complex |
|
|
|
| 9,763 |
|
|
| 3,643 |
|
|
| 5,628 |
|
Luján de Cuyo |
| LDCUCC25 |
|
| 1,418 |
|
|
| - |
|
|
| - |
|
Luján de Cuyo |
| LDCUTV11 |
|
| 447 |
|
|
| - |
|
|
| 411 |
|
Luján de Cuyo |
| LDCUTV12 |
|
| 457 |
|
|
| - |
|
|
| 409 |
|
Luján de Cuyo |
| LDCUTG22 |
|
| 282 |
|
|
| 286 |
|
|
| - |
|
Luján de Cuyo |
| LDCUTG23 |
|
| 70 |
|
|
| 68 |
|
|
| - |
|
Luján de Cuyo |
| LDCUTG24 |
|
| 70 |
|
|
| 68 |
|
|
| - |
|
Luján de Cuyo |
| LDCUTG26 |
|
| 203 |
|
|
| 198 |
|
|
| - |
|
Luján de Cuyo |
| LDCUTG27 |
|
| 203 |
|
|
| 198 |
|
|
| - |
|
Subtotal Luján de Cuyo plant |
|
|
|
| 3,150 |
|
|
| 818 |
|
|
| 820 |
|
Brigadier López |
| BLOPTG01 |
|
| 1,758 |
|
|
| 1,811 |
|
|
| 0 |
|
Subtotal Brigadier López |
|
|
|
| 1,758 |
|
|
| 1,811 |
|
|
| 0 |
|
Terminal 6 |
| TER6CC11 |
|
| 1,665 |
|
|
| 1,720 |
|
|
|
|
|
Subtotal Terinal 6 |
|
|
|
| 1,665 |
|
|
| 1,720 |
|
|
|
|
|
Total Central Puerto |
|
|
|
| 16,336 |
|
|
| 7,9928 |
|
|
| 6,449 |
|
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| Table of Contents |
Source: CAMMESA. Definitive Seasonal Programming February – April 2022
Our exposure to changes in fuel prices is limited because, under the existing regulations, the necessary fuel to produce our base energy is supplied by CAMMESA without any charge. In the case of our PPA contracts, variations in the cost of fuel are considered to determine the price of the electric power sold. The price that the generators receive for this energy is determined by the Secretariat of Electric Energy, without provisions for the price of the fuel supplied.
With respect to water consumption, water has an associated cost only in certain specific cases since we produce the necessary water with our own facilities. In the case of the supply of steam to YPF’s Luján de Cuyo plant in Mendoza, we pay for the water when the water consumption thresholds set forth in the contract with YPF are exceeded.
Electricity Generation from our Hydroelectric Complex
Piedra del Águila
The Piedra del Águila hydroelectric complex is the largest private sector hydroelectric generation complex in Argentina. It was completed in 1994 and is located approximately 1,200 kilometers to the southwest of Buenos Aires at the edge of Limay River and on the border of the Neuquén and Río Negro provinces. Piedra del Águila has an installed capacity of 1,440 MW from four 360 MW generating units.
Piedra del Águila has a gravity dam made of concrete, with a maximum height of 170 meters from its foundation, a power plant with four generating turbines of 360 MW each, intake and pipeline work, a spillway with an unloading capacity of 10,000 cubic meters per second, river diversion works, unloading equipment with a capacity of 1,500 cubic meters per second, and construction facilities, including access roads, a bridge and electric power supply. The dam is designed to be able to accommodate two additional turbines of 360 MW, although, as of the date of this annual report, we do not plan to have them installed (they would provide the plant with increased power to supply demand peaks but would not change the electric power generated per year since such generation depends on river water levels).
Water resources allow Piedra del Águila to generate an average of 44,478 GWh per year (based on historical operations between 1994 and 2021, exclusive of electric power generated for internal use). During this period, the maximum generation in a single year was 7,333GWh in 2006 and the lowest was 2,351GWh in 2016.
The following table shows the electric power generated by Piedra del Águila during the period 1994-2021:
Source: CAMMESA
The Dam. The Piedra del Águila dam is composed of approximately 2.8 million cubic meters of waterproof concrete. It is 860 meters long and approximately 170 meters high (from its foundation). The storage capacity of the dam totals 12 billion cubic meters, out of which six billion cubic meters are usable, which would allow for 45 days’ generation at a capacity of 1,440 MW on a 24-hour basis.
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Safety of the Paleochannel. On the left bank of the dam there is a fluvial valley filled with basalt, which we refer to as the “paleochannel.” This natural structure consists of the second part of the river closing, which was made waterproof to ensure stability. The paleochannel contained a potential leakage zone on the left bank. To mitigate risks associated with this potential leakage zone, a number of works were performed to reduce drainage gradients and ensure stability prior to the initial filling of the dam:
| · | Cutoff Curtain: To make the alluvial fill between the bedrock and the basalt contact area watertight, a cutoff curtain was created through grouting and chemical injections from horizontal tunnels of about 1,200 meters in length that were dug into the massif. |
| · | Diaphragm Wall: This is a transition concrete structure of about 150 meters in length that connects the cutoff curtain to the dam. |
| · | Drainage Curtain: This is a horizontal tunnel of over 400 meters in length dug in the rock massif that covers the entire transversal section of the paleochannel, from which drillings were performed to capture the leakage water that passes the cutoff curtain. |
| · | Drainage Wells: These consist of five vertical wells of about 40 meters in depth and five meters in diameter located in a downstream area of the drainage curtain, from which sub-horizontal holes were drilled directed towards the basalt-alluvium contact to capture the water draining through such highly permeable zone. |
| · | Pumping System: This consists of ten electric pumps installed in a gallery located in the amphitheater (the area at the bottom of the paleochannel massif) intended to maintain piezometric levels of one of the existing aquifers in the alluvium at predetermined levels to ensure the zone stability. |
The Power plant. The hydroelectric generation plant is located at the foot of the dam and has four Francis-type turbines with corresponding generators, transformers for each generator and operating, control and auxiliary equipment. The turbines are hydraulic turbines composed of vertical axes with a spiral steel casing. Each turbine has a rated capacity of 360 MW and a rated hydraulic load of 350 cubic meters per second and is designed to rotate at 125 rpm.
Each generator has a corresponding set-up transformer of 500 kV, which consists of a dual guide rod system, with a single SF-6 iron-isolated switch, to which all generating units are connected. The switch is connected to the SADI’s transformer substation through two transmission lines. Energy is delivered at Piedra del Águila’s 500 KV plant, which is operated by Compañía de Transporte de Energía Eléctrica en Alta Tensión S.A. (“Transener”), which owns, operates and maintains the largest high voltage electric power transmission system in Argentina.
During the shutdowns and start-ups of the power plant, there are two 13.2 kV lines in place that serve as auxiliary service related to the local distribution network operated by Neuquén’s energy regulatory authorities, two back-up generators, and two 110V stationary batteries, each of which is capable of supplying electric power.
The operation and maintenance of a hydroelectric plant are relatively simple compared to the labor-intensive requirements of thermal plants. To operate the plant, we mainly monitor the water flow, the electric power generation and the related equipment. The plant’s operations staff is organized into several departments: (i) civil engineering (in charge of monitoring the equipment and the dam structure); (ii) operations (in charge of monitoring the delivery of the electric power); (iii) special services and technical support; and (iv) administration. Our employees are in charge of plant maintenance.
Operation and maintenance of the hydroelectric plant are managed in accordance with manufacturers’ recommendations and industry standards. To monitor management of the plant, we use performance metrics specified in Standard 762 of the Institute of Electrical and Electronics Engineers (IEEE).
All ordinary operation and maintenance tasks are performed by company personnel. Electromechanical maintenance of generators and auxiliary equipment focuses on fault prediction and prevention and is intended to minimize corrective maintenance and maximize availability of the generators.
Generators are operated in accordance with the requirements of the Organismo Encargado del Despacho (OED) (the “Dispatching Agency”) and in compliance with the Normas de Manejo de Aguas (NMA) (Water Management Standards). Water management and dam operation are overseen by the Autoridad Interjurisdiccional de Cuencas (Intergovernmental Basin Authority).
The status of the dam and paleochannel is audited every five years by an independent expert panel under the supervision of the Organismo Regulador de Seguridad de Presas (ORSEP) (Dam Safety Regulator). Fish and water quality are also monitored in the dam and tributaries at least four times per year.
The HPDA Concession Agreement. We entered into a concession agreement with the Argentine Government that expires on December 28, 2023 (the “HPDA Concession Agreement”). Under the HPDA Concession Agreement, we are entitled to generate and sell electric power and use certain state-owned property, including the plant and its water resources. We can use the plant solely for the purpose of generating electric power. The Argentine Government and the Intergovernmental Basin Authority are entitled to allocate or use in any other manner the current or future water resources without any obligation to compensate us. The HPDA Concession Agreement and the rights granted therein may not be assigned without the Argentine Government’s prior consent. Upon the expiration of the concession term, the Argentine Government will recover possession of the plant without any obligation to compensate us. We currently intend to seek the renewal of the HPDA Concession Agreement prior to its expiration.
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Below we summarize certain terms of the HPDA Concession Agreement:
| · | Operations: We are required to comply with certain standards and conduct certain activities, including maintaining Ps.2.7 million as a guarantee, maintaining the plant and complying with certain safety and environmental obligations, contributing to a repair fund, maintaining books and maintaining insurance, among others. |
| · | Mandatory works: The Argentine Government may require us to carry out works jointly funded by it and us. |
| · | Fees and royalties: The Intergovernmental Basin Authority is entitled to a fee of 2.50% of the plant’s revenues, and the provinces of Río Negro and Neuquén are entitled to royalties of 12.00% of such revenues. |
| · | Indemnity: The Argentine Government indemnifies us in certain circumstances, including, among others, for damages or repairs that are not attributable to us, or our agents and damages caused by downstream waters, in each case subject to certain conditions. We also indemnify the Argentine Government in certain circumstances. |
| · | Fines: Any delay or failure by us to comply with the provisions of the HPDA Concession Agreement or the regulations concerning the generation and sale of electric power may result in fines imposed by the applicable regulatory authorities, calculated as a percentage of the plant annual revenues, depending on the type of breach. The Argentine Government may require that CAMMESA make payment of the fines directly to the Argentine Government out of proceeds from the electric power sold in the WEM. |
| · | Termination: We and the Argentine Government may terminate the HPDA Concession Agreement in certain circumstances in which we fail to perform our obligations under the agreement and in which we are subject to fines or do not comply with the certain laws and regulations, among others. |
Supply. Substantially all of the electric power produced by Piedra del Águila and other generators in the Comahue area is transported to locations where demand is higher. Demand is highest primarily in the Buenos Aires metropolitan area, which is located some 1,200 kilometers away from the plant. The distribution system from the Comahue region comprises two corridors with a total of four 500 kV transmission lines (the last of them started to operate in December 1999), in addition to a fifth line that connects Comahue to the Cuyo region, which started to operate in September 2011. Since the end of the construction of these last two lines, the plants in the Comahue region have been able to use the entire generation capacity.
Relationship with Provincial Governments. As members of the governing body of the Intergovernmental Basin Authority, the governments of Neuquén and Río Negro are involved in the regulatory oversight of the water resources used by Piedra del Águila. In accordance with the HPDA Concession Agreement and Section 43 of Law No. 15,336, we are required to pay a 12.00% royalty on the revenues derived from electric power generation. This royalty is distributed between the provinces of Neuquén and Río Negro in equal parts. The government of Neuquén owns a 4.13 % stake in us.
Electricity Generation from our Wind Generation Plants
As of the date of this annual report we operate seven wind farms: La Castellana I and II and Achiras, Manque, Los Olivos and La Genoveva I and II.
La Castellana I Wind Farm
La Castellana I is a wind farm operated by CP La Castellana S.A.U., a wholly-owned subsidiary of CP Renovables, in which we have a majority interest. The wind farm is located in the south of the province of Buenos Aires, near the cities of Villarino and Bahía Blanca, and started its operations in August 2018.
It has a total installed capacity of 100.80 MW, from 32 wind turbines, supplied from Nordex-Acciona, of 3.15 MW each.
Achiras Wind Farm
Achiras is a wind farm operated by CP Achiras S.A.U., a wholly-owned subsidiary of CP Renovables, in which we have a majority interest. The wind farm is located in the east of the province of Córdoba, near the city of Achiras, and started its operations in September 2018.
It has a total installed capacity of 48 MW, from 15 wind turbines, supplied from Nordex-Acciona, of 3.2 MW each.
La Castellana II Wind Farm
La Castellana II is a wind farm operated by CPR Energy Solutions S.A.U., a wholly-owned subsidiary of CP Renovables, in which we have a majority interest. The wind farm is located in the south of the province of Buenos Aires, near the cities of Villarino and Bahía Blanca, and started its operations in July 2019.
It has a total installed capacity of 15.20 MW, from 4 wind turbines, supplied by Vestas, of 3.6 MW each.
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Manque Wind Farm
Manque is a wind farm operated by CP Manque S.A.U., a wholly-owned subsidiary of CP Renovables, in which we have a majority interest. The wind farm is located in the east of the province of Córdoba, near the city of Achiras, and started its operations partially in December 2019 (38MW), in January 2020 (15.2 MW), and fully in March 2020 (3.8MW).
It has a total installed capacity of 57 MW, from 15 wind turbines, supplied by Vestas, of 3.80 MW each.
Los Olivos Wind Farm
Los Olivos is a wind farm operated by CP Los Olivos S.A.U., a wholly-owned subsidiary of CP Renovables, in which we have a majority interest. The wind farm is located in the east of the province of Córdoba, near the city of Achiras, and started its operations in February 2020.
It has a total installed capacity of 22.8 MW, from 6 wind turbines, supplied from Vestas, of 3.8 MW each.
La Genoveva I Wind Farm
La Genoveva I is a wind farm operated by Vientos La Genoveva I S.A.U., in which we have a majority interest. The wind farm is located in the south of the province of Buenos Aires, near the town of Cabildo and 30 km to the northwest of the city of Bahía Blanca and started its operations in November 2020.
It has a total installed capacity of 88.2 MW, from 21 wind turbines, supplied from Vestas, of 4.2 MW each.
La Genoveva II Wind Farm
La Genoveva II is a wind farm operated by Vientos La Genoveva II S.A.U., in which we have a majority interest. The wind farm is located in the south of the province of Buenos Aires, near the town of Cabildo and 30 km to the northwest of the city of Bahía Blanca and started its operations in September 2019.
It has a total installed capacity of 41.80 MW, from 11 wind turbines, supplied by Vestas, of 3.8 MW each.
FONINVEMEM and Similar Programs
Following Argentina’s economic crisis in 2001 and 2002 and the subsequent devaluation of the peso, there were significant imbalances between the electric power prices generators received and their operating costs. As resources in the country’s Stabilization Fund, a fund administered by CAMMESA intended to make up for fluctuations between the seasonal price paid by distributors and the spot price in the WEM, became scarce due to the Argentine Government’s decision to maintain seasonal prices (the energy prices paid by distributors) below the spot price paid to generators, the Argentine Government, through a series of resolutions, fixed a set of priorities with respect to payments made from this fund. This resulted in a system under which generators collected payment for only variable generation costs and power capacity, while the resulting monthly obligations to generators for the unpaid balance were to be considered LVFVD.
In 2004, through Resolution SE No. 826/2004, generators with receivables due to the lack of funds in the Stabilization Fund (including us) were invited to participate in forming the FONINVEMEM, created by Resolution SE No. 712/04. The FONINVEMEM allowed electric energy generators to link the collection of their outstanding receivables relating to electric power sales to CAMMESA from January 2004 through December 2006 to one or more combined cycle projects, with a right to receive payment of their receivables once the new combined cycle plants built with FONINVEMEM financing become operational.
In December 2004, we agreed to participate in the creation of the FONINVEMEM. We entered into an agreement on October 17, 2005, which stated that generators would receive (i) their receivables relating to sales of electric power from January 2004 through December 2006, amounting to US$157 million in our case, plus an interest rate of 360-day LIBOR plus 1.00% in 120 equal, consecutive monthly installments and (ii) their proportional equity interest in the generating companies formed for such projects, TJSM and TMB, which are in charge of managing the purchase of equipment, and of building, operating and maintaining each of the new power plants, and after ten years of operation would receive the property of these plants. The generation plants are not owned by TJSM and TMB but rather owned by two trusts, created by the Argentine Government, that receive revenue from the sale of electric power generated by the plants, among others, to repay the LVFVD receivables.
On October 16, 2006, we entered into two pledge agreements with the former Secretariat of Electric Energy to guarantee our performance obligations in favor of the two trusts under certain construction management and operation management agreements and provided as collateral: (a) 100% of our shares in TJSM and TMB and (b) 50% of the rights conferred by our LVFVD receivables for the duration of the construction management agreement and the operation management agreement.
On July 13, 2007, we agreed to include 50.00% of our total receivables relating to the sale of electric power to CAMMESA from January through December 2007 in the FONINVEMEM arrangement, which totaled US$30.3 million. These receivables were also reimbursed in 120 equal, consecutive monthly installments starting from the commercial launch date of the plants, converted into U.S. dollars at the applicable exchange rate pursuant to the FONINVEMEM arrangement, with an interest rate of 360-day LIBOR plus 2.00%. We received no additional equity interest in TJSM and TMB as a result of the inclusion of these additional receivables in the FONINVEMEM arrangement.
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After the commercial authorization was granted to the Manuel Belgrano power plant (on January 7, 2010) and the San Martín power plant (on February 2, 2010), we started to collect monthly payments of the receivables. As of December 31, 2021, there is no balance owed to us under the FONINVEMEM arrangement relating to the sale of electric power to CAMMESA from 2004 through 2007. As of December 31, 2021, we owned 9.6269% of TJSM and 10.8312% of TMB. The operating companies have a variable revenue (US$1.00 per MW generated) and a fixed revenue to compensate for their operating costs. In 2021, we received no dividends from our equity interests in TJSM and TMB.
See “Item 3D. Risk Factors—Risks Relating to our Business—Our interests in TJSM, TMB were diluted and CVOSA will be significantly diluted” and “Item 4.B. Business Overview—Our Affiliates—Termoeléctrica José de San Martín S.A. (TJSM) and Termoeléctrica Manuel Belgrano S.A. (TMB)”.
With respect to the LVFVD corresponding to the sales of electric power to CAMMESA from 2008 to 2011, on December 28, 2010, our Board of Directors approved an agreement with the former Secretariat of Electric Energy that established, among other agreements, a framework to determine a mechanism to settle receivables accrued by generators over the 2008-2011 period. For that purpose, (i) the construction of the new generation plant, CVOSA, was agreed upon, with receivables earned from January 1, 2008 through December 31, 2011 to be paid starting as of the commercial launch date of the CVOSA plant’s combined cycle unit; (ii) a managing company for this project, CVOSA, was created in which we hold a controlling interest and (iii) a trust was created by the Argentine Government to hold the property of the plant under construction. The combined cycle unit commenced operations on March 20, 2018.
After the CVOSA power plant became operational, in the case of receivables accrued between 2008 and September 2010, the amount due was converted into U.S. dollars at the exchange rate effective at the date of the CVO agreement (i.e., November 25, 2010), which was Ps.3.97 per U.S. dollar. Additionally, certain receivables that accrued after September 2010 and that were also included in the CVO Agreement, were converted into U.S. dollars at the exchange rate effective at the due date of each monthly sale transaction. The total estimated amount due to us under the Agreement for the LVFVD 2008-2011 was US$548 million (including VAT), plus the accrued interest after the CVO Commercial Approval. Under the CVO Agreement, we are entitled to receive payment for the LVFVD 2008-2011 receivables in the form of 120 equal, consecutive monthly installments, starting from March 20, 2018, the date of commencement of commercial operations of the combined cycle plant, bearing interest at a nominal annual rate of 30-day LIBOR plus 5.00%. The U.S. denominated monthly payments under the CVO Agreement are payable in pesos, converted at the applicable exchange rate in place at the time of each monthly payment.
As of March 20, 2018, CAMMESA granted the CVO Commercial Approval in the WEM, as a combined cycle, of the thermal plant Central Vuelta de Obligado. A PPA between the CVO Trust and CAMMESA, through which the CVO Trust makes energy sales and, consequently, receives the cash flow to pay the trade receivables, had to be signed in order to start the collections.
The PPA agreement was signed on February 7, 2019, with retroactive effect to March 20, 2018.
As a result, the original amortization schedule from the CVO Agreement is in full force and effect.
During 2021 and 2020, we collected Ps.8.2 billion and Ps.9.5 billion, respectively in CVO receivables, in each case measured in current amounts as of December 31, 2021.
In accordance with the CVO agreements, after the first ten years of operation, ownership of the combined cycle plants was transferred from the trust to the operating companies, and the operating companies began to receive revenues from the sale of electric power generated by the plants. At such time, since the Argentine government financed part of the construction, it was incorporated as shareholder of CVOSA, and our interests in CVOSA were significantly diluted. Although the effect of the potential dilution has also not yet been defined for the same reasons, the Argentine government’s stake in CVOSA will be at least 70% due to an agreement between the parties. The dilution of our interest in CVOSA will reduce our income, which could adversely affect our results of operations. See “Item 4.B. Business Overview—FONINVEMEM and Similar Programs.”
Market Area and Distribution Network
Market Area
Our plants are located at various locations in Argentina. All of them are connected to the SADI, enabling coverage for residential and industrial users nationwide.
Puerto plants: The Puerto Nuevo, Nuevo Puerto and Puerto combined cycle plants are situated in a unique location within the port of the City of Buenos Aires, one of the most populated metropolitan areas in the world, which reduces costs arising from lost power during transmission. In addition, the plants have three docks for unloading liquid fuels from large vessels, thus facilitating the supply of fuel.
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Piedra del Águila Hydroelectric Complex: the Piedra del Águila hydroelectric complex is located on the Limay river, which serves as the border between the Provinces of Río Negro and Neuquén. The dam is close to the city of Neuquén and is able to supply energy to cities far from the complex through existing transmission lines.
Brigadier López plant: The Brigadier López Plant is located in the province of Santa Fe, near the City of Sauce Viejo.
Terminal 6-San Lorenzo plant: The Terminal 6 San Lorenzo Plant is located in the province of Santa Fe, near the City of San Lorenzo.
Luján de Cuyo plant: The Luján de Cuyo plant is located within YPF’s Luján de Cuyo refinery and supplies steam to such refinery. This location enables it to obtain gas oil supplies from the refinery itself in case of natural gas shortages.
La Castellana I and II Wind Farms: La Castellana I and II wind farms are located in the province of Buenos Aires, near the cities of Villarino and Bahía Blanca.
La Genoveva I and II Wind Farms: La Genoveva I and II wind farms are located in the province of Buenos Aires, near the town of Cabildo and the city of Bahía Blanca.
Achiras Wind Farm: Achiras wind farm is located in the province of Córdoba, near the City of Achiras.
Manque Wind Farm: Manque wind farm is located in the province of Córdoba, near the City of Achiras.
Los Olivos Wind Farm: Los Olivos wind farm is located in the province of Córdoba, near the City of Achiras.
Manuel Belgrano plant: The Manuel Belgrano plant is located in the province of Buenos Aires, near the City of Campana.
San Martín plant: The San Martín Plant is located in the province of Santa Fe, near the City of Timbúes.
Vuelta de Obligado plant: The Vuelta de Obligado Plant is located in the province of Santa Fe, near the City of Timbúes.
Distribution Network
All of our plants are connected to the SADI, which allows us to reach almost all the users in the country. The SADI permits interaction among all agents in the Argentine WEM and allows generating companies to dispatch power to Large Users and distributors through the transmission companies. The system is regulated and allows participation of all WEM agents (generators, transmission companies, distributors, Large Users and the Argentine Government through CAMMESA), thus preventing discrimination among any involved participants.
The prices for power transmission are regulated and based on the distance from the generating company to the user, among other factors. In this regard, our thermal power plants are strategically located in important city centers or near some of the system’s largest customers (e.g., YPF’s refineries), which constitutes a significant competitive advantage.
Our Customers
|
|
|
| For the year ended December 31, |
| ||
Modality continuing operations |
| Main clients |
| 2021 |
| ||
|
|
|
| (in thousands of Ps.) |
| percentage of revenues |
|
Energía Base(1) (Resolution SRRyME 1/19; Res. SE No. 19/2017, SGE 70 and 95/2013, as amended Resolution No.440/21)(2) (3) |
| CAMMESA |
| 23,816,074 |
| 41.72 | % |
RenovAr Program sales under contracts |
| CAMMESA |
| 7,203,846 |
| 12.62 | % |
Term market sales under contracts |
| CAMMESA, |
| 18,708,042 |
| 32.78 | % |
(MATER sales under contracts |
| Cervecería y Maltería Quilmes (subsidiary of AB Inbev); San Miguel A.G.I.C.I y F.; Banco de Galicia y Buenos Aires S.A.; Minera Alumbrera Limited (subsidiary of Glencore in Argentina); Banco Supervielle S.A. |
| 4,125,513 |
| 7.23 | % |
Energía Plus sales under contracts |
| Banco de Galicia y Buenos Aires S.A., PBBPolisur S.A., Metrive S.A., Pet Food Saladillo S.A., Banco Supervielle S.A. |
| 77,801 |
| 0.14 | % |
Steam sales |
| YPF |
| 1,715,963 |
| 3.00 | % |
Other |
| YPF |
| 307,995 |
| 0.54 | % |
Revenues from CVO thermal plant management |
| Fideicomiso Central Vuelta de Obligado |
| 1,124,105 |
| 1.97 | % |
____________
(1) | From February 27, 2020, a new remuneration scheme for Energía Base applicable from February 1, 2020, came into force with Resolution No. 31/20 and was amended by Resolution No. 440/21. For further information see “Item 4.B. Business Overview—The Argentine Electric Power Sector—Remuneration Scheme—The Current Remuneration Scheme.” |
(2) | Includes income under Res. SEE 70/18. See “Item 4.B. Business Overview—The Argentine Electric Power Sector—Remuneration Scheme—The Previous Remuneration Schemes—.” |
(3) | Includes sales of energy and power not remunerated under Resolution No. 95 and, See “Item 4.B. Business Overview—The Argentine Electric Power Sector—Structure of the Industry—Shortages in the Stabilization Fund and Responses from the Argentine Government—The National Program” and “Item 5.A. Operating Results—Our Revenues—The Energía Base.” |
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For a discussion of the different regulatory regimes under which we sell our electric power, see “Operating and Financial Review and Prospects—Factors Affecting our Results of Operation—Our Revenues” and “Item 4.B. Business Overview—The Argentine Electric Power Sector—Structure of the Industry.”
Seasonality
Seasonality of Electricity Generation by Thermal Facilities
The following graphic breaks down our average thermal energy production over the last four years on a month-by-month basis:
Source: CAMMESA
Seasonality of Water Resources and Electricity Generation of Piedra del Aguila
The availability of water is the key factor for determining Piedra de Águila’s electric power generation capacity and is tied to annual and seasonal changes in rains in the upstream mountain area of Piedra del Águila. Water levels generally increase between May and December due to the winter rains and the spring thaw, and we are able to produce more energy over such periods.
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The following graphic breaks down our average hydroelectric energy production over the last four years on a month-by-month basis:
Source: CAMMESA
Seasonality of Wind Resources and Electricity Generation of Achiras, La Castellana I, La Castellana II, La Genoveva I, La Genoveva II, Manque and Los Olivos wind farms
The availability of wind resources is the key factor for determining the wind farms electric power generation capacity and is tied to annual and seasonal changes in wind speed in the areas where each farm is located. Wind speed is generally higher between May and September, and we are able to produce more energy over such periods.
The following graphic shows the energy production of our wind farms on a month-by-month since inception and until December 2021:
Competition
The demand for electric power in Argentina is served by a variety of generation companies, both state-owned and private-owned. These companies pursue the right to supply generation capacity and electric power and to develop projects to serve the demand for electric power in Argentina. Some of our foreign competitors are substantially larger and have substantially greater resources than our company. Because of the significant gap between the demand and supply of electric power in Argentina, voluntary and forced blackouts at times of seasonal peak consumption have occurred. During 2021 (and particularly on December 29, 2021) there was a historic demand peak recorded totaling 27.1 GW. In 2021 819 GWh were imported, representing a 32% decrease in energy imports as compared to 2020.
Our primary competitors in the electric power generation market are the Enel group, AES Argentina Generación S.A. (an affiliate of the AES Corporation), Pampa Energía S.A, and YPF EE S.A.
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Below we detail the installed capacity of the main private sector generators in Argentina, as of December 31, 2021:
Company and subsidiaries |
| Power (MW) |
| |
Central Puerto |
|
| 4,809 | (1)(2) |
The AES Corporation |
|
| 4,224 | (3) |
Grupo Enel |
|
| 4,015 | (4)(2) |
Pampa Energía S.A |
|
| 4,774 | (5) |
YPF EE |
|
| 2,610 | (6) |
Sources: (1) Based on the documentation officially declared to CAMMESA by Central Puerto for continuing operations (2) Based on company’s financial statements as of and for the year ended December 31, 2021, and data from CAMMESA. (3) Bases on data from company’s official corporate website as of February 2022. (4) Based on data from CAMMESA. Includes Enel Generación Costanera S.A., Enel Generación El Chocón S.A. and a 40.00% stake of Grupo Enel in Central Dock Sud S.A. (5) Based on company’s financial statements as of and for the year ended on December 31, 2019. (6) Based on data from CAMMESA.
The following graphs break down the market share of electric power generation supplied by private sector companies in Argentina as of December 31, 2021, based on data published by CAMMESA:
Source: CAMMESA
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The following graphs break down total market share of electric power generation supply and the market share from thermal units (from both private and public sector generators) in Argentina as of December 31, 2021, based on data published by CAMMESA:
Source: CAMMESA
Source: CAMMESA
The following table shows the installed capacity in terms of MW assigned to each regulatory framework (Energía Base, Energía Plus, Resolution No. 220/07, Renewable Energy) for us and each of our main competitors as of December 31, 2021:
In MW |
| Energía Base (Res. 1/2019 and 1/2020) |
|
| Energía Plus (Res. 1281/06) |
|
| Power Purchase Agreements Under Res. 220/07 |
|
| Power Purchase Agreements Under Res. 21/17 |
|
| Power Purchase Agreements Under Res. 287/17 |
|
| Term market for renewable energy (MATER) |
|
| RenovAr |
|
| Total |
| ||||||||
Central Puerto(1) |
|
| 3.652 |
|
|
| 16 |
|
|
| 280 |
|
|
| - |
|
|
| 384 |
|
|
| 137 |
|
|
| 237 |
|
|
| 4.709 |
|
AES Argentina Group |
|
| 3.049 |
|
|
| 416 |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| 120 |
|
|
| 180 |
|
|
| 3.765 |
|
ENEL Group |
|
| 4.015 |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| 4.015 |
|
Pampa Energía S.A.(2) |
|
| 3.294 |
|
|
| 113 |
|
|
| 479 |
|
|
| 305 |
|
|
| 381 |
|
|
| 101 |
|
|
| 100 |
|
|
| 4.774 |
|
YPF EE |
|
| 1.435 |
|
|
| - |
|
|
| 284 |
|
|
| 381 |
|
|
| 289 |
|
|
| 222 |
|
|
| - |
|
|
| 2.610 |
|
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Our efficiency levels compare favorably to those of our competitors due to our efficient technologies. The following chart shows the efficiency level of our most important generating units compared to the units of the rest of the market based on heat rate, which is the amount of energy used by an electrical generator or power plant to generate one kWh of electric power:
Source: CAMMESA’s seasonal programing
We are also one of the largest consumers of natural gas in Argentina’s electric power sector, as well as the one of the largest consumers of fuel oil, gas oil and biodiesel. Although CAMMESA is our current supplier of biodiesel, we have developed business relationships over the years with strategic companies from the oil and gas and the biofuel sectors, and in the past have participated in certain joint ventures with some of them.
Insurance
We carry commercial and personal insurance coverage for certain of our power generation plants, placed at different geographical locations within Argentina. The following list includes all the insurance risk covered:
| 1. | Operational All Risks - Including Material Damage Machinery Breakdown and Business Interruption (Loss of Profits) |
|
| This coverage protects against unexpected events due to a sudden or accidental cause, including weather, fire and natural disasters, that may damage property or fixed assets (Material Damage); and Mechanical and Electrical breakdown events that may cause sudden and unforeseen physical loss or damage to machinery (Machinery Breakdown) that is operational; any of which may damage our ability to generate power, including coverage for consequential Loss of Profits (Business Interruption) for a maximum period of 14 months. |
|
|
|
| 2. | Commercial General Liability |
|
| This coverage protects against the claims from third parties arising out of bodily injury or death and property damage resulting from the insured activities including Premises, Operations, Products and/or Completed operations. The coverage limit is up to US$ 10,000,000 per occurrence. |
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| 3. | Commercial Excess Liability (CPSA only) |
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| This coverage protects against the same risks described in the previous bullet point but covers “in excess” of the coverage limit of the underlying primary insurance for a combined limit (concurrent in all locations) of up to US$50,000,000. |
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| 4. | Port Operators Liability (CPSA only) |
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| Covers CPSA´s liability to third parties for Personal Injury or Property Damage as a result of an occurrence or event in connection with day-to-day Port Operator Activities. |
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| 5. | Director and Officers Liability (CPSA only) |
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| This policy covers individuals for claims made against them while serving on a board of directors and/or as an officer and it is payable to those directors and officers of a company, or to the organization(s) itself, as indemnification (or reimbursement) for losses or advancement of defense costs in the event an insured suffers such a loss as a result of a legal action brought for alleged wrongful acts in their capacity as directors and officers. |
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| 6. | Motor Vehicle + Mobile Equipment |
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| CPSA and its subsidiaries carry cover for all its fleet vehicles as well as trucks and mobile equipment for daily operation. The coverage goes from basic third-party liability in mobile equipment to Comprehensive Coverage in some cars (theft, fire, hail, vandalism, property and vehicle damage). |
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| 7. | Worker´s Compensation |
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| This coverage provides wage replacement and medical benefits to employees injured in the course of employment and/or while commuting to and from work. |
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| 8. | Compulsory Life Insurance |
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| This coverage is provided by the employer and guarantees the payment of a death benefit to named beneficiaries upon the death of the insured (employee). |
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| 9. | Optional Term Life Insurance |
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| This is an optional and additional coverage the employer pays over the basic Compulsory Life insurance in order to guarantee its employees the payment of 24 additional wages in case of death. This is part of an employee Benefits plan. |
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| 10. | Ocean Inland Transit All Risks (floating policy) |
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| Transit Coverage for an annual period during all stages of transit and delivery, whether marine, on the dock, by air or inland transportation from anywhere in the world to anywhere within the argentine territory and vice versa. Premiums are paid monthly at an Ex-Post basis. |
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| 11. | Commercial Business Combined |
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| This is a tailored policy to cover specifically the offices and warehouses owned by CPSA in the city of Neuquén, Piedra del Águila Town and Piedra del Águila Hydroelectric Dam. This is a comprehensive business coverage in a single policy, bringing together a range of coverages: Employers’ Liability, Public Liability, Product Liability, Legal Expenses, Material Damage and Theft, Goods in Transit and others |
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| 12. | Construction All Risks / Erection All Risks (CAR/EAR) |
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| This is a non-standard policy that provides coverage for Property Damage and third-party injury or damage claims during construction projects. We carry this insurance every time we undertake a new construction. |
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| 13. | Compulsory Environmental Pollution Insurance |
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| This coverage protects against third party personal injury; third party property losses; ecological damage and costs incurred in provision of emergency services and environmental clean-up. |
We believe that the level of insurance and reinsurance coverage we maintain is reasonably adequate in light of the risks we are exposed to and is comparable to the level of insurance and reinsurance coverage maintained by other similar companies doing business in the same industry.
Environment
As of the date of this annual report, we are not involved in pending or threatened judicial proceedings in connection with environmental issues.
As of the date of this annual report, we have obtained or have applied for the environmental permits required by the applicable environmental regulations and our environmental management plans have been approved by the applicable regulatory authorities. To maintain high environmental standards, we carry out periodic controls in accordance with applicable legislation.
We have developed a broad environmental compliance and management program, which is subject to periodic internal and external audits by TÜV Rheinland.
In July 2019, TÜV Rheinland completed a series of ISO recertification audits and in March 2021, the audit to expand the scope of the certificates was carried out to include two new sites, the Genoveva II Wind Farm and the San Lorenzo Cogeneration Plant. The details of the certificates are the following: Standard: ISO 14001:2015
Certificate Registr. No.: 01 10406 1629668
Certificate Holder: Central Puerto S.A. Av. Tomas Edison 2701 Ciudad Autónoma de Buenos Aires Argentina
Scope: Generation of electric energy from: hydraulic energy, thermal energy (gaseous and liquid fuls), wind energy. Steam production.
Validity: The certificate is valid from 2019-07-13 until 2022-07-12
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Including the locations:
No: | Name/Location | Scope |
1 | Central Planta Buenos Aires Av. Thomas Edison 2701 Ciudad Autónoma de Buenos Aires | Generation of electric energy from: thermal energy (gaseous and liquid fuels). |
2 | Central Mendoza Parque Industrial Provincial, Ruta 84 s/n, Lujan de Cuyo, Provincia de Mendoza | Generation of electric energy from: thermal energy (gaseous and liquid fuels). Steam production. |
3 | Central Hidroeléctrica Piedra del Águila Ruta Nacional 237, Km 1450.5 8315 Piedra del Águila Provincia de Neuquén | Generation of electric energy from: hydraulic energy |
4 | Parque Eólico Achiras, Lote 325, Parcela 1274 (Latitude 33° 12´ 44,23´´S, Longitude 65° 5´ 16,52´´O), Achiras, Córdoba – Argentina | Generation of electric energy from: wind energy. |
5 | Parque Eólico La Castellana, Camino rural a la altura de la RN 3, Km 712,5 (Latitud 38° 38´22,40´´ S, Longitud 62° 43´1,04´´ O), Villarino, Buenos Aires - Argentina | Generation of electric energy from: wind energy. |
6 | – Planta Brigadier López Ruta 11 Km 455 3017 Parque Industrial Sauce Viejo, Calle 8, Colectora Norte Santa Fe - Argentina | Generation of electric energy from: thermal energy (gaseous and liquid fuels). |
7 | Parque Eólico La Castellana II Ruta 3 km 712,5 sobre camino vecinal, Villarino, Buenos Aires - Argentina. | Generation of electric energy from: wind energy. |
8 | Parque Eólico La Genoveva II Ruta 51 Km 705, Cabildo, Buenos Aires - Argentina | Generation of electric energy from: wind energy. |
9 | Parque Eólico Manque (Latitude 33°13'35.26"S; Longitude 65° 4'38.69"O), Achiras. Córdoba – Argentina | Generation of electric energy from: wind energy. |
10 | Parque Eólico Los Olivos (Latitude 33°13'50.34"S; Longitude 65° 2'59.94"O) Achiras. Córdoba - Argentina | Generation of electric energy from: wind energy. |
11 | Parque Eólico La Genoveva I Ruta 51 Km 705, Cabildo, Buenos Aires, Argentina | Generation of electric energy from: wind energy. |
12 | - Planta Cogeneración San Lorenzo Combate Punta Quebracho s/n (esquina Vucetich), zona rural Puerto Gral. San Martín, Santa Fe, Argentina | Generation of electric energy from: thermal energy (gaseous and liquid fuels). Operation and maintenance of extra high voltage line (EVL) |
Additionally, pursuant to Section 22 of Argentina’s Environmental Policy Law No. 25,675, any individual or legal entity, whether public or private, engaged in activities that endanger the environment, ecosystems and their constituent elements, including us, must carry insurance for an amount sufficient to cover the cost of repairing the damages such individual or legal entity may cause. We fully comply with this regulation.
Security and Health
In managing occupational safety and health we seek to protect people and our own and third parties’ property, assuming that:
| · | all accidents and occupational diseases can be prevented. |
| · | compliance with applicable occupational and health standards is the responsibility of all individuals participating in activities in our facilities; and |
| · | raising awareness among individuals contributes to the welfare at the workplace and to the improved individual and collective development of the members of the work community. |
Our commitment to ongoing improvement compels us to review the sufficiency of our current policy and its stated goals on an ongoing basis to ensure conformance to the changes required by the market and the applicable laws.
In July 2021, TÜV Rheinland completed a series of ISO recertification audits, and we got the following certificates:
Standard: ISO 45001:2018
Certificate Register. No.: 02 213 219807
Certificate Holder: Central Puerto S.A. Central Hidroeléctrica Piedra del Águila Ruta Nacional 237, Km 1450.5 (8315) Piedra del Águila Provincia de Neuquén Argentina.
Scope: Generation of electric energy from: hydraulic energy and thermal energy (gaseous and liquid fuels).
Validity: The certificate is valid from 2021-10-05 until 2024-06-04
Including the locations:
1 | Central Hidroeléctrica Piedra del Águila Ruta Nacional 237, Km 1450.5 8315 Piedra del Águila Provincia de Neuquén | Generation of electric energy from: hydraulic energy |
2 | Central Puerto S.A. – Planta Brigadier López Ruta 11 Km 455 3017 Parque Industrial Sauce Viejo, Calle 8, Colectora Norte Santa Fe - Argentina | Generation of electric energy from: thermal energy (gaseous and liquid fuels). |
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Integrated Management System with ISO Certifications
Our management has put an integrated management system (“IMS”) in place for its electric power and steam generation plants in order to meet the needs and requirements of our internal policies and goals, as well as the needs and requirements of our clients, the applicable laws and regulations and ISO standards, namely, ISO 9001/2015 (quality), ISO 14001/2005 (environment) and ISO 45001/2018 (Occupational health and safety Assessment Series. Our IMS is certified by renowned international entities and audited from time to time, as required by the aforementioned standards.
The IMS seeks to achieve the following goals:
| · | equip the plants with useful and proactive management tools. |
| · | ensure process quality. |
| · | satisfy clients’ requirements. |
| · | pursue ongoing improvement in processes. |
| · | safeguard people and our own and third party’s property. |
| · | prevent pollution. |
| · | make efficient use of resources. |
| · | preserve the ecological balance; and |
| · | improve life quality. |
We identify the processes and the necessary support for the accurate operation of a sustainable, participatory and bureaucracy-free IMS that is useful for implementing the principles established by management with respect to environmental, quality, and occupational safety and health policies and for ensuring the availability of human, material and financial resources. We have used a management model based on planning-doing-checking-acting in order to guarantee the maintenance and ongoing improvement of the IMS in our facilities, which involves one or several of the following systems:
| · | Quality Management System |
| · | Environmental Management System |
| · | Occupational Safety and Health Management System |
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The individual scope of the IMS at each plant is as follows:
| · | Puerto Complex: | |
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| · | Nuevo Puerto plant: Environmental Management System with ISO 14001/2015 certificate and Quality Management System with ISO 9001/2015 certificate |
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| · | Puerto Nuevo plant: Environmental Management System with ISO 14001/20015 certificate and Quality Management System with ISO 9001/2015 certificate |
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| · | Puerto combined cycle plant: Environmental Management System with ISO 14001/2015 certificate and Quality Management System with ISO 9001/2015 certificate |
Certification body:
From 2004 through 2015: IRAM
From 2016-2022: TÜV Rheinland
| · | Luján de Cuyo plant: Environmental Management System with ISO 14001/2015 certificate and Quality Management System with ISO 9001/2015 certificate |
Certification body:
From 2004 through 2015: SGS
From 2016 through 2022: TÜV Rheinland
| · | Piedra del Águila plant: Environmental Management System with ISO 14001/2015 certificate, Quality Management System with ISO 9001/2015 certificate and Occupation Safety and Health Management System with ISO 45001:2018 (through March 2021) certificate |
Certification body:
From 2004 through 2015: IRAM
From 2016 through 2022 (through 2024 to ISO 45001): TÜV Rheinland
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| Brigadier López plant: Environmental Management System with ISO 14001/2015 certificate, Quality Management System with ISO 9001/2015 certificate and Occupation Safety and Health Management System with ISO 45001:2018 (through March 2021) certificate |
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| Certification body: |
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| From 2019 through 2022 (through 2024 to ISO 45001): TÜV Rheinland |
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| · | Wind Farms Achiras, La Castellana I, La Castellana II and La Genoveva II: Environmental Management System with ISO 14001/2015 certificate, Quality Management System with ISO 9001/2015 certificate. |
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| Certification body: |
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| From 2019 through 2022: TÜV Rheinland |
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| · | Wind Farms Manque and Los Olivos: Environmental Management System with ISO 14001/2015 certificate, Quality Management System with ISO 9001/2015 certificate. |
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| Certification body: |
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| From 2020 through 2022: TÜV Rheinland |
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| · | Wind Farms La Genoveva I: Environmental Management System with ISO 14001/2015 certificate, Quality Management System with ISO 9001/2015 certificate. |
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| Certification body: |
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| From 2021 through 2022: TÜV Rheinland |
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| · | Cogeneración San Lorenzo: Environmental Management System with ISO 14001/2015 certificate, Quality Management System with ISO 9001/2015 certificate. |
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| Certification body: |
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| From 2021 through 2022: TÜV Rheinland |
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It is our policy that the IMS be reviewed upon a change to our organizational structure, operating procedures, processes or facilities and that it be updated as applicable. Once updated, the IMS is subject to a comprehensive review considering the existing interrelations to avoid overlap or omissions. Where no changes have occurred, the IMS is reviewed every five years, unless a new version of the reference ISO standards is released during that period, in which case the IMS is adjusted to conform to the new standards.
The Argentine Electric Power Sector
The following is a summary of certain matters relating to the electric power industry in Argentina, including provisions of Argentine laws and regulations applicable to the electric power industry and to us. This summary is not intended to constitute a complete analysis of all laws and regulations applicable to the electric power industry. Investors are advised to review the summary of such laws and regulations published by the Secretariat of Energy (https://www.argentina.gob.ar/economia/energia),, CAMMESA (www.cammesa.com.ar) and the Ente Nacional Regulador de la Electricidad (Argentine Electricity Regulatory Entity, or “ENRE”) (www.enre.gob.ar) and to consult their respective business and legal advisors for a more detailed analysis. None of the information on such websites is incorporated by reference into this annual report.
History
During the majority of the second half of the 20th century, the assets and operation of the Argentine electric power sector were controlled by the Argentine Government. By 1990, virtually all of the electric power supply in Argentina was controlled by the public sector (97% of total generation). The Argentine Government had assumed responsibility for the regulation of the industry at the national level and controlled all of the national electric power companies. In addition, several Argentine provinces operated their own electric power companies. As part of the economic plan adopted by former President Carlos Menem, the Argentine Government undertook an extensive privatization program of all major state-owned industries, including those in the electric power generation, transmission and distribution sectors. Argentine Law No. 23,696 passed in 1989 (the “Federal Reform Law”) declared a state of emergency for all public services and authorized the Argentine Government to reorganize and privatize public companies. The privatization had two ultimate objectives: first, to reduce tariffs and improve service quality through free competition in the market, and second, to avoid the concentration of control of each of the three subsectors of the market in a small group of participants and thereby reduce their ability to fix prices. Separate limitations and restrictions for each subsector were imposed in order to reach these goals. In accordance with the Federal Reform Law, Decree No. 634/1991 established guidelines for the decentralization of the electric power industry, for the basic structure of the electric power market, and for the participation of private sector companies in the generation, transmission, distribution and trading sub-sectors.
General Overview of Legal Framework
Key Statutes and Complementary Regulations
The body of rules that constitutes the basic regulatory framework of the Argentine electric power sector currently in force are the following: (i) Law No. 15,336, enacted on September 20, 1960, as amended by Law No. 24,065, passed on December 19, 1991, partially promulgated by Decree No. 13/92, and regulated by Decree No. 1398/92 and Decree No. 186/95 (collectively, the “Regulatory Framework”), (ii) Law 24,065 implemented privatizations of government-owned companies in the electric power sector and separated the industry vertically into four categories: generation, transmission, distribution and demand, and it also provided for the organization of the WEM (described in greater detail below) based on the guidelines set forth in Decree No. 634/91; and (iii) Decree No. 186/95 also created the notion of “participant,” among which it is worth mentioning the “trader,” which is defined as a company that is not a WEM agent but trades electric power in bulk.
ENRE
Law No. 24,065 also created the Ente Nacional de Regulador de la Electricidad (Argentine National Electricity Regulator) (ENRE) as an autonomous entity within the scope of the former Secretariat of Electric Energy (currently, Secretariat of Energy), the main duties of which are as follows: (a) enforcing the Regulatory Framework and controlling the rendering of public services and the performance of the obligations set forth in the concession contracts at a national level; (b) issuing the regulations applicable to the WEM agents; (c) setting forth the basis for calculation of tariffs and approving the tariff schedules of transmission and distribution companies holding national concessions; (d) authorizing electrical conduit easements; and € authorizing the construction of new facilities. Besides, Law No. 24,065 has entrusted ENRE with a jurisdictional activity. Any dispute arising between WEM agents should be subject to prior compulsory jurisdiction of ENRE (subject to further judicial review).
Pursuant to Decree No. 258/16, the Executive branch appointed four interim members of the ENRE’s board of directors and ordered the former Ministry of Energy and Mining to put in place an open call (convocatoria abierta) to select the members of the ENRE’s board of directors.
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However, in 2019, section 6 of the Solidarity Law, authorized the Executive branch to intervene the ENRE’s board for one year. In that context, the ENRE was intervened by virtue of Decree No. 277/2020 until December 31, 2020. By virtue of Decree No. 1,020/2020, the Executive branch established the beginning of the tariff revision negotiations (for transmission and distribution companies under federal jurisdiction) and extended the intervention of the ENRE for one more year or until the tariff revision process ends, whichever comes first. On January 19, 2021, through Resolutions No. 16/2021 and 17/2021, the ENRE formally began the procedure for the temporary adjustment of tariffs of public energy transmission and distribution activities under federal jurisdiction, with the objective of establishing transitional tariffs, until a final renegotiation agreement is reached.
The intervention of the ENRE’s board was further extended until December 31, 2022, by means of Decree No.871/2021.
The Secretariat of Electric Energy
In addition to the ENRE, another of the main regulatory entities in Argentina is the Secretariat of Energy.
Its role is defined in Law No. 24,065 and Decree No. 50/2019. Pursuant to Decree No. 50/2019 (as amended by Decree No. 732/2020, Decree No. 804/2020 and Decree No. 740/2021), its main duties are, among others:
| · | to participate in the drafting and implementation of national energy policies; |
| · | to enforce the laws governing the development of the activities within its scope of competence; |
| · | to participate in the drafting of policies and regulations governing public services within the scope of its competence; |
| · | to oversee the entities and agencies governing works and public service concessionaries; |
| · | to engage in drafting regulations concerning licenses issued by the federal government or the provinces for public services within the scope of its competence; |
| · | to oversee the regulatory entities and agencies of privatized areas or areas operating under concessions within the scope of its competence; and |
| · | to enforce the Regulatory Framework and to oversee the regulations governing tariffs, fees, duties and taxes. |
Pursuant to Resolution No. 64/18, the former Ministry of Energy and Mining delegated some of its duties to the Undersecretariat of Electric Energy. Such delegated duties include:
| · | amending the Rules to Access the Electricity Transportation System Existing Capacity and Enlargement; |
| · | regulating the International Interconnection Transmission System (the “IITS”); |
| · | amending the rules governing the Procedures; |
| · | defining power and energy amounts and other technical parameters that distributors and Large Users are required to meet to access the WEM and authorizing the entry of new players to the WEM; |
| · | authorizing electric power imports and exports; |
| · | rendering final administrative decisions with respect to appeals brought against the ENRE’s resolutions, which are the last administrative remedies that can be filed in order to review the ENRE’s resolutions (the next step is a judicial appeal); |
| · | exercising the duties of the former Ministry of Energy and Mining within the Federal Electricity Council; and |
| · | administering the Provinces’ Special Fund for Electricity Development created by Section 33 of Law No. 15,336. |
Moreover, the former Ministry of Energy and Mining delegated to the Undersecretariat of Electric Energy the duties of the former Secretariat of Electric Energy pursuant to Sections 35, 36 and 37 of Law No. 24,065, through Resolution No. 64/18. These duties include:
| · | representing the state-owned equity interest in CAMMESA; |
| · | defining the rules governing CAMMESA; |
| · | ensuring transparency and equity; |
| · | determining the overall operating and maintenance costs that would allow fully or partially state-owned generation and transportation companies to maintain service quality, continuity and safety; and |
| · | administering the Stabilization Fund. |
Pursuant to Law 22,520, as modified by Decree No. 50/2019 (and Decree No. 732/2020, Decree No. 804/2020 and Decree No. 740/2021), these duties are now carried out by the Secretariat of Energy, under the jurisdiction of the Ministry of Economy.
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WEM (Wholesale Electricity Market)
Pursuant to Section 35 of Law No. 24,065 and other regulations, the Despacho Nacional de Cargas (National Dispatch Board) must be structured as a corporation. CAMMESA was created for such purpose (Decree No. 1192/92) and to coordinate the technical and administrative supply and demand of electric power within a real-time operation system, centralizing and processing information produced by the WEM agents. CAMMESA also acts as a collection entity for all WEM agents.
The WEM consists of:
| 1. | a term market, where contractual quantities, prices and conditions are freely agreed upon among sellers and buyers; (however, it should be noted that Resolution No. 95/2013 established the suspension of the incorporation of new contracts in the term market, with the exception of those contracts entered into under certain special regimes, and those contracts that have a differential remuneration regime. Since then, large users of the MEM must purchase their electricity demand directly from CAMMESA); |
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| 2. | a spot market, where prices are established on an hourly basis based on the economic production cost, represented by the short-term marginal cost measured at the system’s load center (market node); (however, in practice, this system has suffered significant changes since the year 2002. Purchases made in the spot market vary according to the nature of the buyer: large users, generators and self-generators pay the Spot Price, while distributors pay a seasonal price calculated by CAMMESA and approved by the SE. Seasonal prices are periodically established by CAMMESA and maintained for six-month periods (subject to quarterly adjustments), in order for distributors to pay a stabilized price, and thus be able to transfer it to the tariffs paid by end users. Finally, the electricity remuneration values for generators (Energía Base) are set by the National Executive Power; and |
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| 3. | a quarterly stabilization system of spot market prices, intended for the purchases of electric power by distributors. |
The following chart shows the relationships among the various actors in the WEM:
Procedures for the Programming of Operation, Dispatch and Price Calculation
For the purposes of implementing the provisions set forth in the Regulatory Framework, a set of regulatory provisions were issued, through former Secretariat of Electric Energy Resolution No. 61 of April 29, 1992, which are referred to as the “Procedures for the Programming of Operation, Dispatch and Price Calculation” (the “Procedures”). The Procedures have been amended, supplemented and extended by subsequent resolutions issued by the relevant authorities.
CAMMESA
CAMMESA is a non-profit corporation. The shareholders of CAMMESA each hold twenty percent stakes and are as follows: the Argentine Government (represented by the Secretariat of Energy) and the four associations representing the different segments of the electric power sector (generation, transmission, distribution and Large Users).
CAMMESA is managed by a board of directors composed of ten regular directors and up to ten alternate directors, which are appointed by its shareholders. Each of the associations that represent the different segments of the electric power sector is entitled to appoint two regular directors and two alternate directors. The two remaining regular directors of CAMMESA are the current Secretary of Energy, who serves as chairman of the board and an independent member who acts as vice chairman, appointed at a meeting of the shareholders. The decisions adopted by the board of directors of CAMMESA require the affirmative vote of a majority of the directors present at the meeting, including the affirmative vote of the chairman of the board.
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CAMMESA is in charge of managing the SADI in accordance with the Regulatory Framework, which includes:
| · | determining the technical and economic dispatch of electric power (including determining the schedule of production of all generation plants of a power system to balance the production with the demand) at the SADI; |
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| · | maximizing system security and the quality of electric power supplied; |
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| · | minimizing wholesale prices in the spot market; |
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| · | planning energy capacity requirements and optimizing energy use in accordance with the rules set forth periodically by the Secretariat of Electric Energy; and |
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| · | monitoring the operation of the term market and administering the technical dispatch of electric power under the agreements entered into in that market. |
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| · | acting as agent of the various WEM participants; |
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| · | purchasing and selling electric power from or to other countries by performing the relevant import/export transactions within the framework of existing agreements between Argentina and bordering countries and/or among WEM agents and third parties from bordering countries; and |
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| · | carrying out the commercial administration and dispatch of fuels for the WEM generation plants. |
In addition to the responsibilities mentioned above, under current applicable regulations, CAMMESA has been tasked with the role of acquiring and supplying the fuel for the electric power sold under the Energía Base free of cost to the generators.
Since January 1, 2021, and as a result of the implementation of the “GasAr” Plan (Plan Gas IV), the Secretariat of Energy established through Resolution 354/20 dated 12/1/2020, that those authorized Generators to carry out self-management of fuel in the MEM, and therefore not reached by resolutions 95/2013 and 529/2014, they may assign to CAMMESA the operational management of the gas volumes contracted with producers with gas volumes awarded in the Gas Plan IV and / or the gas transportation service / s contracted with Natural Gas carriers and / or Distribution companies, so that said contracts (volumes and transportation of natural gas) are assigned for their consumption in thermal generation in such a way to minimize the total costs of supplying the MEM
CAMMESA’s operating costs are funded by means of the mandatory contributions of all WEM participants.
On the other hand, the Secretariat of Energy, through Resolution 354/20, established, among other things, that as long as the Plan “GasAr” (Plan Gas IV) remains in force, the Generators of the MEM will be able to adhere to the centralized dispatch, assigning to CAMMESA the contracts that they had with natural gas producers or transporters, in order for said contracts to be used by the Dispatch Agency (OED) based on the dispatch criteria.
Likewise, Res. 354/20 established that generating agents that have obligations to supply their own fuel under the framework of Resolution No. 287/2017, will have the option of canceling such obligations and the consequent recognition of their associated costs, having to preserve the maintenance of the respective transport capacity for the purposes of its management in the centralized dispatch, as long as CAMMESA determines the convenience of having it.
Provincial Regulatory Powers
Provinces can (and do) regulate the electrical system within their territories, and are enforcement authorities in charge of granting and controlling electric power distribution concessions within their territories. Nonetheless, if a provincial electric power market participant is connected to the SADI, it must also comply with federal regulations. In general terms, provinces have followed federal regulatory guidelines and have established similar regulatory institutions. In addition, isolated provincial electric power systems are very rare, and most provincial market participants are connected to the SADI and buy and sell electric power in the WEM, which falls within the regulatory powers of the Argentine Government.
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Pursuant to Sections 6 and subsequent Sections of Law No. 15,336, electric power generation, whatever its source, transformation or transmission, is subject to exclusive federal jurisdiction when:
| 1. | it is related to national security; |
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| 2. | it is aimed to be used in the trade of electric power between different jurisdictions and districts inside the country (e.g., between two different provinces or between the City of Buenos Aires and a province); |
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| 3. | it is correlated to a place that is exclusively under jurisdiction of the Argentine Congress; |
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| 4. | it is related to hydroelectric or tidal energy facilities that need to be connected between them or with others of the same or different source for a rational and economic use of them; |
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| 5. | it is connected to the SADI in any spot of the country; |
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| 6. | it is related with the trade of electric power with a foreign nation; or |
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| 7. | it is related to electric power plants that use or transform nuclear or atomic energy. |
This exclusive federal jurisdiction implies, among other things, that provinces have limited taxing and police powers when generation, transformation and transmission facilities of electric power are involved.
Structure of the Industry
Generation and the WEM
According to Law No. 24,065, electric power generation is classified as an activity of general interest associated with the provision of the public service of transmission and distribution of electric power but conducted within the framework of a competitive market. As a result of the privatization and incorporation of new market players, the generation sector, even after a consolidation process that took place over the past few years, has a competitive structure with at least five major companies of similar size: (i) Central Puerto; (ii) Endesa Argentina S.A. (which includes Endesa Costanera S.A., Central Dock Sud S.A. and Hidroeléctrica el Colochón S.A.); (iii) Pampa Energía S.A. (which includes Central Térmica Güemes S.A., Central Térmica Loma la Lata S.A., Inversora Piedra Buena S.A., Inversora Diamante S.A., CTG and Inversora Nihuiles, and the plants formerly owned by Petrobras Argentina S.A., which were merged into Pamos Energía S.A.) and (iv) AES Argentina Generación S.A. (which includes Central Térmica San Nicolás S.A. and Hidroeléctrica Alicurá S.A.). In addition, a significant portion of the generation sector is controlled by state-owned and state-controlled companies (e.g., Yacyretá, Salto Grande, Atucha and Embalse and YPF) and other private sector generators (e.g., Orazul, Albanesi and Capex).
Thermal electric power generators (i.e., generation using natural gas, liquid fuels derived from oil, such as gas oil and fuel oil or coal) do not need a concession granted by the government to operate, whereas hydroelectric power generators do need a concession granted by the government to be able to use water sources. Typical terms included in concession agreements include the right to use water resources and facilities for a fixed amount of time (e.g., thirty years), in cases where the dam is owned by the Argentine Government or an Argentine provincial government, and the option to extend or renew the concession period for a fixed number of years. Usually, the concessionaire must make a one-time initial payment to the Argentine Government or an Argentine provincial government in exchange for the rights granted in the concession and periodically must pay a fee and/or royalties to the respective provincial government where the river is located in exchange for the use of this water resource. Normally, these periodic fees vary according to the amount of energy generated.
As of the date of this annual report, following the enactment of Resolution SE No. 95/2013, Large Users operating in the term market purchase electric power through agreements with CAMMESA, except for those power purchase agreements executed certain special regimes or under the scope of Resolution No. 281/2017 –which created the Renewable Energy Term Market-. See “Item 4.B. Business Overview— The Argentine Electric Power Sector—Remuneration Scheme—The Previous Remuneration Schemes” below.
Electricity Dispatch and Spot Market Pricing prior to Resolution SE No. 95/13
According to the Regulatory Framework, an electric power generators’ remuneration is a function of two components: (1) a variable component, based on quantity of energy sold in the market, and (2) a fixed component that aims to remunerate the generator for each MW of capacity of its units available per hour in the WEM, regardless of the consumption of the electric power generated by such units. The value of the fixed component depends on, among other things, the connection node to which the unit connects to the SADI.
In accordance with the spot market that was in place prior to Energía Base, electric power is traded at prices reflecting supply and demand. CAMMESA dispatches the available power units based on the variable costs of production determined by the generation agents, either based on the cost of fuel or the price of water determined, dispatching the most efficient power units first. The spot market price is determined by CAMMESA on an hourly basis at a specific geographic location, referred to as the “market node,” which is located in the system’s load center at Ezeiza, Province of Buenos Aires. The energy price consists of a value referred to as the “marginal system price” or “market price,” and represents the economic cost of generating the next MWh to satisfy an increase in demand at the same value. The seasonal price fixing system is directly related to the quarterly average prices of the spot market.
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CAMMESA is regulated in a manner that is intended to keep operating costs low and to optimize prices. Pursuant to the regulations and procedures enforced by the Secretariat of Energy, CAMMESA applies optimization models in accordance with applicable regulations, based on weather estimates, dam levels, rain forecasts for the following months and the availability of nuclear plants and thermal machines. These optimization models are aimed at keeping operating costs at the lowest possible level while satisfying the expected daily demand for electric power.
To meet electric power demand, CAMMESA organizes and coordinates the electric power dispatch of generators by prioritizing power units with a lower variable production cost, followed by those with a higher variable production cost, until all electric power demand has been satisfied. Generators must inform CAMMESA of the thermal generation plants’ variable production costs, which depend on the availability of different types of fuels provided by CAMMESA (e.g., natural gas, fuel oil and gas oil).
With respect to demand, CAMMESA calculates the typical hourly consumption curves considering the limitations of the transmission grid, the needs of distributors, Large Users and self-generators that purchase energy in the WEM, and demand from interconnected importing countries that only receive energy if there is excess supply in Argentina.
As a result of this process, CAMMESA defines an optimal market price, which results from adding the variable cost of transmission from the generator’s connection point to the market node to the accepted variable production cost.
The procedure described above is used to project the future needs of the SADI and WEM. However, often projections and actual market conditions differ, which creates differences between purchases by distributors at seasonal prices and payments to generators for energy sales at the spot price.
However, in practice, the Spot Market pricing mechanisms have suffered significant changes since 2002 (See “Item 4.B. Business Overview— The Argentine Electric Power Sector— General Overview of Legal Framework—Developments since the Public Emergency Law No. 25,561”).
The Stabilization Fund
Energy prices are passed on to end-users through the public utility distribution companies. To fix prices for end-users, CAMMESA analyzes electric power supply and demand for the period for which the price is being calculated. The seasonal price is a fixed quarterly price. The Regulatory Framework created the Stabilization Fund that absorbs the differences between the seasonal price and the spot price in the WEM. When the seasonal price is higher than the spot price, there is an accumulated surplus in the Stabilization Fund. Any surplus is used to offset any losses resulting from periods during which the spot price has been higher than the seasonal price.
Through the enacted Resolution No. 7/16, the former Ministry of Energy and Mining suspended any transfer of funds from the Stabilization Fund to EDENOR and EDESUR intended to fund these companies’ planned works, which would have been implemented through financing agreements with CAMMESA and funded by the Stabilization Fund.
Developments since the Public Emergency Law No. 25,561
Since the approval of the Public Emergency Law on January 6, 2002, a series of temporary provisions amended the original mechanism for the determination of prices in the WEM. The measures adopted pursuant to the Public Emergency Law also distorted this mechanism: in spite of an increase in the spot price, the seasonal price remained frozen for all users until 2004, when a partial adjustment was adopted that did not affect residential demand. As a result, the amounts collected based on seasonal prices have been lower than the amounts based on spot prices, therefore increasing the Stabilization Fund deficit.
Resolution No. 6/16 issued by the former Ministry of Energy and Mining on January 27, 2016, sought to gradually implement a standardization program of several macroeconomic variables, foster the efficient and rational use of electric power and ensure that the appropriate conditions are in place to benefit from private sector investments in the sector’s activities and segments. Pursuant to this resolution, the former Ministry of Energy and Mining acknowledged the gap between actual costs and prevailing prices. However, on the basis of social policy, the former Ministry of Energy and Mining had fixed a new seasonal price for the WEM that is was below actual supply costs, and thereafter, seasonal prices continued to be regularly approved by the relevant authorities. Recently, seasonal prices have been approved by means of Resolution SE No. 40/2022.
The former Ministry of Energy and Mining also created incentives for residential customers to save electric power, which consist of lower tariffs for users who reduce their consumption over a given period compared to the same period during the previous year and fixed a social tariff to be applied to certain sectors of demand.
Import and Export Transactions
Pursuant to Decree No. 974/97, import and export transactions are conducted through the TEII (Sistema de Transporte de Energía Eléctrica de Interconexión Internacional), a public service subject to the concession granted by the former Secretariat of Electric Energy. Under such system, through Resolution No. 348/99, the former Secretariat of Electric Energy granted Interandes Sociedad Anónima a concession for the TEII through the Güemes Transmission System, which connects the Central de Salta Thermal Generation plant located in Güemes, Salta, with the Sico Border Crossing, on the border with the Republic of Chile.
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All import and export transactions conducted through the term market require the prior authorization of the Secretariat of Electric Energy and CAMMESA.
Transmission and Distribution
Pursuant to Law No. 24,065, transmission and distribution activities are regulated as public services due to the fact that they are natural monopolies. The Argentine Government has granted concessions to private entities conducting these activities, subject to certain conditions, such as service quality standards and fixing the tariffs they are entitled to collect for their services.
Electricity transmission is comprised of (i) a high-voltage transmission system (operated by the company Transener, which is currently co-controlled by the Eling Group, Transelec and Integración Energética Argentina S.A. -formerly known as ENARSA), which connects the main electric power production and consumption areas allowing the transmission of electric power between different Argentine regions and (ii) several regional trunk systems, which transmit electric power within a particular region and connect the generators, distributors and Large Users that operate in such region.
Electricity distribution is regulated only at the federal level for the City of Buenos Aires and the districts in the metropolitan areas of Greater Buenos Aires. EDENOR operates in the northern area of both the City of Buenos Aires and Greater Buenos Aires, and EDESUR operates in the southern area of both the City of Buenos Aires and Greater Buenos Aires. In the rest of the country, the electric power distribution service is regulated at the provincial level and subject to concession granted by provincial authorities. Section 124 of Law No. 27,467 established that both EDENOR and EDESUR would be transferred to the regulatory jurisdiction of the Province of Buenos Aires and the City of Buenos Aires, as applicable. However, such transfer was not implemented, and was later suspended by the Solidarity Law that established that the ENRE will retain its regulatory powers over such companies for as long as the emergency declared by such law remain in force.
Transmission services are rendered by concessionaires that operate and use high and medium voltage transmission lines. Transmission services consist of the transformation and transmission of electric power from generators’ delivery points to distributors or Large Users’ reception points. Law No. 24,065 provides that energy transmission companies must be independent from other WEM participants and prohibits them from purchasing or selling electric energy.
Distribution companies are in charge of supplying electric power to end-users who cannot contract with an independent electric power supply source due to their consumption levels, such as residential end-users.
The main characteristics of concession contracts for the transmission and distribution of electric power are: (i) service quality standards with penalties that are applied in case of breach; (ii) a concession term of 95 years for the monopoly of the supply service in a supply area or network, divided into “management periods,” with an initial term of 15 years and subsequent terms of ten years (at the end of each management period, the Argentine Government must call for bids to sell the majority stake of the corresponding transmission or distribution company); and (iii) tariffs fixed based on economic criteria with a price cap system and predefined processes regarding their calculation and adjustment.
Tariffs
The tariffs charged by electric power transmission companies include: (i) a connection charge, (ii) a transmission capacity charge and (iii) a charge for actually transmitted energy. In addition, transmission companies may receive income derived from the expansion of the system. Transmission tariffs are passed on to final users through the distributors.
The amounts that distribution companies charge to end-users include: (i) the price for the purchase of energy in the WEM (the seasonal price as described above), (ii) transmission costs, (iii) the value-added for distribution (“VAD”), which compensates the distributor, and (iv) taxes. The VAD is the marginal cost of providing services, including the network development and investment costs, operation maintenance and commercialization costs, as well as depreciation and a reasonable return on the invested capital. The tariffs determined as set forth above must enable an efficient distributor to cover its operating costs, finance the renovation and improvement of its facilities, satisfy increasing demand, comply with established quality standards and obtain a reasonable return, while also enabling such distributor to comply with certain operating efficiency standards and operate in a manner consistent with the amounts it has invested and the national and international risks inherent in its operations.
In December 2019, the Solidarity Law froze tariffs applied by distribution and transmission companies under federal jurisdiction for a 180-day period, at the values effective as of December 23, 2019. In addition, the Solidarity Law empowered the Executive branch to renegotiate tariffs effective as of such date aiming to reduce the tariff burden placed on households, stores and industrial facilities for the year 2020.
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Through the Solidarity Law, the Argentine Government also invited provinces to freeze and review tariffs applied by distribution and transmission companies under provincial jurisdiction.
Moreover, Decree No. 311/2020 established the prohibition for distribution companies (among other public services concessionaries) to suspend the relevant services to certain end users -considered more vulnerable- in the event of default or non-payment of up to seven (7) consecutive or alternate invoices. Such measure was later extended by Decree No. 756/2020 and On June 19, 2020, through Decree No. 543/2020, the tariff freeze decided through the Solidarity Law was further extended for 180 additional days from the expiration of the previous term.
On December 16, 2020, the Executive branch issued Decree No. 1020/2020, which establishes the beginning of the tariffs revision negotiations for gas and energy transmission and distribution companies under federal jurisdiction. Likewise, on January 19, 2021, through Resolutions No. 16/2021 and 17/2021, the ENRE formally began the procedure for the temporary adjustment of tariffs of energy transmission and distribution activities under federal jurisdiction, with the objective of establishing transitional tariffs, until a final renegotiation agreement is reached.
On March 4, 2021, ENRE Resolutions No. 53/2021, 54/2021, 55/2021, 56/2021 and 57/2021 were published in the Official Gazette, calling for public hearings in order to inform and hear opinions regarding the “Transition Tariff Regime” of the following companies, respectively: EDENOR and EDESUR; TRANSENER; TRANSBA and DISTROCUYO; TRANSPA, TRANSCO and EPEN; TRANSNEA and TRANSNOA. The public hearing of EDENOR and EDESUR was held on March 30, 2021, and the other hearings took place on March 29, 2021.
On April 30, 2021, the ENRE issued Resolutions No. 106 and 107, through which the values of the Distribution Cost and the values of the tariff chart of EDESUR (106) and EDENOR (107) were approved, effective as from May 1, 2021 (Transition Tariff Regime).
On August 9, 2021, the ENRE issued Resolutions No. 262/2021 (amended by Resolution No. 265/2021) and No. 263/2021 (amended by Resolution No. 266/2021), whereby the tariff charts of EDENOR and EDESUR, respectively, were approved, effective as from August 1, 2021.
On November 19, 2021, ENRE Resolution 491/2021 was published in the Official Gazette, approving the Injection Tariffs for User-Generators of the concession areas of EDENOR and EDESUR S.A., effective as of August 1, 2021.
On January 27, 2022, Resolution No. 28/2022 of the Secretariat of Energy was published in the Official Gazette. The Secretary instructed the ENRE to include the treatment of the seasonal reference prices of the Stabilized Energy Power and the Stabilized Price of Transportation in the WEM and for the WEM of the Tierra del Fuego System, as part of the public hearings to be held within the framework of the transitional adjustments of tariffs of the Public Service of Electric Energy Transportation of national scope, the treatment of the seasonal reference prices of the Stabilized Power, Stabilized Energy and the Stabilized Price of Transportation in the WEM and for the WEM of the Tierra del Fuego System, in order to broaden the dissemination of the respective information and facilitate a greater participation of the users of the electric service of the different jurisdictions in the treatment of such matter.
By means of Resolution No. 25/2022, the ENRE proceeded as instructed: it called for a Public Hearing in order to inform and hear opinions regarding: (i) the treatment of the determination of the seasonal reference prices of Power, Stabilized Energy in the WEM, as well as the Stabilized Price of Transportation and for the WEM of the Tierra del Fuego System; (ii) the proposals of the electric power transmission and distribution public service concessionaires, aimed at obtaining a transitory adjustment of tariffs, within the Integral Tariff Review renegotiation process and prior to defining the tariffs to be applied by the concessionaires. The Public Hearing was held on February 17, 2022.
On February 4, 2022, ENRE Resolutions No. 41/2022 and No. 42/2022 were published in the Official Gazette. These resolutions approved the new tariff scheme to be applied by EDENOR and EDESUR, respectively, as from February 1, 2022. They also set forth that the average tariff value -as of February 1, 2022-, is 5.452 Pes./kWh for EDENOR, and 5.362 Pes./kWh for EDESUR.
Large Users
The WEM classifies Large Users of energy into three categories: (i) Grandes Usuarios Mayores (Major Large Users, or “GUMAs”), (ii) Grandes Usuarios Menores (Minor Large Users, or “GUMEs”) and (iii) Grandes Usuarios Particulares (Particular Large Users, or “GUPAs”).
GUMAs are users with a maximum capacity equal to or greater than 1 MW and a minimum annual energy consumption of 4,380 MWh. These users are required to contract at least 50.00% of their demand and purchase the rest from the spot market. Their transactions in the spot market are invoiced by CAMMESA.
GUMEs are users with a maximum capacity ranging from 0.03 to 2 MW. They are not required to have any minimum annual demand. These users are required to contract all of their demand and do not affect any transactions in the spot market.
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GUPAs are users with a minimum capacity of 0.030 MW and a maximum of 0.1 MW. They are not required to have any minimum annual demand. These users are required to contract all of their demand and do not operate in the spot market.
Traders
Since 1997, traders have been authorized to participate in the WEM by intermediating block sales of energy. Currently, there are thirty-one authorized traders in the WEM.
Vertical and Horizontal Restrictions
The WEM agents are subject to vertical restrictions, pursuant to Law No. 24,065 and Decree No. 1398/92, according to which:
| 1. | neither a generation or distribution company nor a Large User or any of its controlled companies or its controlling company, can be an owner or a majority shareholder of a transmission company or the controlling entity of a transmission company. Nevertheless, the Executive branch may authorize a generation or distribution company or a Large User to build, at its own cost and for its own need, a transport network for which it will establish the modality and form of operation. |
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| 2. | the holder of a distribution concession cannot be the owner of generation units; however, the shareholders of the electric power distributor may own generation units, either by themselves or through any other entity created with the purpose of owning or controlling generation units; and |
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| 3. | no transmission company may purchase or sell electric energy. |
Section 33 of the Argentine Corporate Law states that “companies are considered as controlled by others when the holding company, either directly or through another company: (1) holds an interest, under any circumstance, that grants the necessary votes to control the corporate will in board meetings or ordinary shareholders’ meetings; or (2) exercises a dominant influence as a consequence of holding shares, quotas or equity interest or due to special linkage between the companies.” However, we cannot assure you that the electric power regulators will apply this standard of control in implementing the restrictions described above. According to the ENRE resolutions, a company controlled by or controlling an electric power transmission company is a company that owns more than 51% of the voting shares of the controlled company and exercises a majority control.
Both electric power transmitters and distributors are also subject to horizontal restrictions. The horizontal restrictions applicable to transmission companies are the following:
| 1. | two or more transmission companies can merge into or be part of a same economic group only if they obtain an express approval from the ENRE; such approval is also necessary when a transmission company intends to acquire shares in another electric power transmission company; |
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| 2. | pursuant to the terms of the concession agreement that govern the transmission of electric power through transmission lines above 132 kv and below 140 kv, the transmission service is rendered exclusively in the specific areas indicated in such agreement; and |
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| 3. | pursuant to the terms of the concession agreement of the company that renders electric power transmission services through lines with voltage equal to or higher than 220 kv, the service must be rendered exclusively and without territorial restrictions, throughout Argentina. |
The horizontal restrictions applicable to electric power distribution companies are the following:
| 1. | two or more distribution companies can merge into or be part of a same economic group only if they obtain an express approval from the ENRE; such approval is also necessary when a distribution company intends to acquire shares in another electric power distribution company; and |
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| 2. | the distribution service is rendered within the areas specified in the respective concession contracts. |
The Impact of the Public Emergency Law No. 25,561 of 2001 and its Implementation
The electric power sector has been significantly affected by the Public Emergency Law and the measures adopted as a consequence thereof. As a result of the law, electric power transmission and distribution tariffs were converted into pesos and frozen for more than six years. They were only subject to limited and small-scale increases.
The contract renegotiation process provided for by the Public Emergency Law for public contracts subject to federal jurisdiction, including the concessions granted for electric power transmission and distribution in the City of Buenos Aires and La Plata, progressed very slowly. After more than five years of negotiations, electric power transmission and distribution companies reached an agreement with the Argentine Government with the participation of the UNIREN, which was created within the scope of the Ministry of Economy and the former Ministry of Federal Planning, Public Investment and Services. As a result of these negotiations, transmission tariffs were subject to the abovementioned limited and small-scale increases.
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In the distribution sector, the Renegotiation Agreements provided for limited increases in income and to a portion of the tariffs (namely, the VAD). Such increases were generally applied to commercial and industrial users, while a comprehensive review of tariffs that would include residential users has been proposed on several occasions. This delay in updating rates caused an imbalance in the payments that distributors made to CAMMESA and those charged by the generators to CAMMESA, which resulted in shortages in the stabilization fund and delays in payments to generators. See “—Shortages in the Stabilization Fund and Responses from the Argentine Government.”
The UNIREN was dissolved through Decree No. 367/16, dated February 17, 2016, which provided that the procedures for renegotiating works and public service contracts should take place within the scope of the ministries governing such contracts. Furthermore, this decree empowers the competent ministries, jointly with the Ministry of Economy and Public Finance, to execute partial contractual Renegotiation Agreements and apply interim tariff and price adjustments as necessary to ensure the continuity of the respective ordinary services until full contractual Renegotiation Agreements are entered into, which must take into account the outcomes of the full tariff review.
Shortages in the Stabilization Fund and Responses from the Argentine Government
The shortage in the supply of natural gas has also had a significant impact on the industry. Because Resolution SE No. 240/03 provides that the spot price must be calculated as if there were no natural gas supply shortage, electric power generators have not been able to pass increases in the price of fuel on to buyers. This situation has led to the depletion of the Stabilization Fund, which has resulted in the inability to pay the electric power generators’ bills.
As a result of the deficit in funds required to pay WEM agents, the Secretariat of Electric Energy issued Resolution No. 406/03. Section 4 of such resolution provides that if there are insufficient resources, the order of priority to settle debts owed to WEM creditors should be the following: (i) the amounts due as receivables payable to the unified fund created by Section 37 of Law No. 24,065; (ii) the monthly income to be allocated to the WEM funds and accounts; (iii) the amount necessary to pay for the receivables of WEM agents once the remuneration items set forth in subsections (iv), (v) and (vi) have been paid; (iv) the items related to the payment of remuneration for the capacity and services rendered to the WEM; (v) the amounts pertaining to: (a) the energy produced and delivered in the hourly spot market valued at its operating cost based on the variable production costs declared and approved for thermal generation plus all the relevant transmission charges, (b) the energy produced and delivered at the hourly spot market by hydroelectric plants, valued at the representative average operation and maintenance cost of a hydroelectric power plant established in Annex 26 to the Procedures plus the total amount of the relevant transmission charges (Ps.2 per MW per hour), (c) the remuneration payable to electric power transmission companies and (d) the additional providers of technical transmission services that are not distributors and have receivables in the WEM in connection with the transactions of Large Users in the market; and (vi) the commitments assumed in relation to Annexes II, III, IV of Resolution SE No. 01/03.
To overcome these problems and consider the forecasts of the future increase in demand, the Argentine Executive branch launched different programs and policies promoting the availability of new generation capacity. For example, the Energía Plus and Energía Distribuida programs were implemented to encourage private sector investments in new generation facilities, allowing owners to sell the energy produced at prices sufficient to cover the cost of the projects plus a reasonable profit. The purpose of these measures is not only to overcome the energy shortage situation but also to add installed capacity to satisfy the steady growth in demand that is expected in the short and medium term.
The FONINVEMEM and Similar Programs
In 2004, the Argentine Government, seeking to increase generation capacity, created the FONINVEMEM (Resolution SE No. 712/2004), a fund to be administered by CAMMESA. Its purpose is to raise funds to be invested in energy generation projects. To provide capital for the FONINVEMEM, the former Secretariat of Electric Energy invited all WEM participants holding LVFVDs that originated from January 2004 to December 2006 to contribute these credits to the FONINVEMEM. In the initial stages of the FONINVEMEM, generators were entitled to participate in the construction of two new 800 MW combined cycle thermal generation plants. Consequently, on December 13, 2005, the generation companies TMB and TJSM were created.
The FONINVEMEM reimburses the private sector contributors the amount of their contributed receivables in 120 equal, consecutive monthly installments starting from the commercial launch date of the plants, converted into U.S. dollars at the rate effective as of the date of the applicable agreement, with interest at the interest rate specified in the applicable agreement for each project. For further information, see “Item 4.B. Business Overview —FONINVEMEM and Similar Programs.”
Subsequently, in 2010, a new agreement with WEM generators was entered into to promote new electric power generation to satisfy the increase in the energy and capacity demand and also to facilitate the settlement of the generators’ receivables from CAMMESA for electric power sales. Within the framework of such agreement, Central Puerto and the Endesa and Duke groups submitted a project for the construction of a thermal combined cycle plant named Central Vuelta de Obligado, in Timbúes, Province of Santa Fe, and, in turn, The AES Group submitted a project for the construction of Central Guillermo Brown, located in Bahía Blanca, Province of Buenos Aires. In connection with the former, the generation company CVOSA was created.
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Resolution SE No. 146/2002
Resolution SE No. 146 of October 23, 2002, provides that any generator that needs to perform major or extraordinary maintenance works and needs resources for such works may request financing, subject to the availability of funds and the performance of the conditions set forth by such rule.
Energía Plus
In September 2006, the former Secretariat of Electric Energy issued Resolution No. 1281/06 which created the Energía Plus Service, in an effort to respond to the sustained increase in energy demand and to foster new private sector interested parties to invest fresh capital into the energy sector in order to generate new energy sources.
The resolution provided that:
| 1. | The energy available in the market will be used primarily to serve residential customers, public lighting, public entities and industrial and commercial users whose energy demand is at or below 300 kW and that have not entered into term contracts. |
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| 2. | GUMAs, GUMEs and large customers of distribution companies (in all cases with consumption equal or higher than 300 kilowatts) are allowed to satisfy any consumption in excess of their base demand (equal to their demand in 2005) with energy from the Energía Plus service, consisting of the supply of additional energy generation from new generators and generation agents, co-generators or self-generators that are not agents of the WEM or who, as of the date of publication of the resolution, were not interconnected with the WEM. The price required to pay for excess demand, if not previously contracted for under the Energía Plus, was originally fixed to be equal to the marginal cost of operation. The marginal cost is equal to the generation cost of the last generation unit transmitted to supply the incremental demand from electric power at any given time. With the Energía Plus, the price has been amended to for GUMAs and GUMEs and has been maintained for large customers of distribution companies for their excess demand (Note No. 111/16 issued by the Secretariat of Electric Energy). |
Distributed Energy (Energía Distribuida)
Resolution 220/07
Pursuant to Resolution No. 220/07, the Secretariat of Energy authorized the execution of Power Purchase Agreements (“PPAs”) between the WEM (represented by CAMMESA) and companies that offer additional generation to the system (i.e., the so-called offer of additional generation and associated energy from generation, co-generation and self-generation agents that, as of the date of publication of the resolution, were not WEM agents or did not have the generation facilities to commit to such supply). PPAs are applicable to all such projects for additional energy generation that involved the participation of the Argentine Government or IEASA or those that be determined by the former Ministry of Federal Planning, Public Investment and Services (currently, the Secretariat of Energy).
Resolution No. 220/07 sets forth the standard terms of PPAs, including:
| 1. | Effective Term: Maximum of ten years. |
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| 2. | Parties: The company whose offer has been approved by the former Secretariat of Electric Energy, as seller, and the WEM as a whole, represented by CAMMESA, as buyer. |
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| 3. | Remuneration: To be determined based on the costs accepted by the former Secretariat of Electric Energy and approved by the former Ministry of Planning. |
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| 4. | Delivery Point: The connection node of the plant with the SADI. |
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| 5. | Remedies: The PPAs must include remedies for breach based on the effect that the unavailability of the units committed under the PPAs may have on the proper supply of the electric power demand in the SADI. |
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| 6. | Dispatch: The machines and plants assigned to the PPAs will generate electric power to the extent they are dispatched by CAMMESA. |
Furthermore, such resolution details the requirements that the additional generation offers must meet for an PPA to be executed. The respective investment projects must be submitted to the Secretariat of Electric Energy and include the following information: (i) the units to be approved that will assume the commitment; (ii) guaranteed availability of the units; (iii) the offered duration of the PPAs; (iv) the effective term of the offer; (v) the availability of capacity committed for the period offered in MW; the former Secretariat of Electric Energy may establish committed capacity value limits; and (vi) a breakdown of fixed and variable costs, in particular, those related to the funding used for the installation of the new capacity offered and supporting documents of such breakdown, along with backing documentation.
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Based on the information provided, the Secretariat of Electric Energy must evaluate the submitted offers and inform CAMMESA of those that are accepted for contracts, expressly stating the annual payment amount for the installation costs to be considered and/or the calculation method to be applied for such purposes, as well as the fixed or variable costs associated with the PPAs. The Secretariat of Electric Energy then must send CAMMESA the text of the contract to be executed and the methodology that should be used for its inclusion in the economic transactions of the WEM.
The capacity assigned and the energy supplied in connection with the PPAs will be compensated by means of a monthly payment calculated based on the annual installation costs to be considered, and the fixed and variable costs required for the proper operation of the committed equipment, based on a method that must be defined in the relevant agreement.
The generation agents that are parties to the PPAs must meet all the requirements set forth in the Procedures, including determining the variable production costs and water costs of the units committed in accordance with the methods in force and the maximum costs acknowledged pursuant to Resolution No. 220/07.
As long as Resolution SE No. 406/2003 is applicable, the payment obligations under the PPAs will have the payment priority provided in subsection (e) of Section 4 of Resolution SE No. 220/07.
To reduce the risk arising from payment for sales under the PPAs, the costs associated with such agreements must have payment priority over the receivables of other agents in the market. In this context, the order of priority to be applied for the settlement of payment obligations derived from such contracts must be equal to or higher than thermal generators’ obligations in respect of operating costs. In other words, the recovery of costs associated with the PPAs must have at least the same priority level as the recovery, for instance, of the costs of fuel used for the generation of electric power that is already installed.
Pursuant to Resolution SE No. 1836/07, the former Secretariat of Energy instructed CAMMESA to execute with IEASA the PPAs pertaining to energy projects located in specific sites communicated in each case by such secretariat, approving, as Annex I, the sample contract to be executed and providing for the specific conditions of each PPA that should be approved by the former Secretariat of Electric Energy.
Law No. 27,424 (and related Decree No. 986/2018).
Law No. 27,424, enacted in 2017, established the “Régimen de Fomento a la Generación Distribuida de Energía Renovable Integrada a la Red Eléctrica Pública” (i.e. Promotion of Distributed Energy from Renewable Sources Regime). Law No. 27,424 was later implemented through Decree No. 986/18 (both Law No. 27,424 and Decree No. 986/2018, its amendments and its complementary regulations, the “Promotion Regime”).
The Promotion Regime sets forth the policies and contractual terms for the generation of electricity from renewable sources by users of the electricity distribution service, either for self-consumption or, eventually, for the supply of additional energy to the grid.
It also established the obligation of the electricity distribution companies to allow such energy supply by the abovementioned user-generators, securing free access to the distribution grid. Distributed generation of electricity from renewable sources was declared of national interest.
The goal of the Promotion Regime is to achieve 1.000 MW of installed capacity within twelve (12) years as of the day in which Decree No. 986/2018 came into force (November 3, 2018).
Every user of the distribution service has the right to install equipment to generate power from renewable energy sources to a capacity equal to the one contracted and demanded to its own distributor, provided such user-generator falls within the scope of section 6 of Law No. 27,424 and subject to the distributor’s previous authorization. In the event the user-generator intends to install a larger capacity, a special authorization shall be requested to the corresponding distributor.
After obtaining the abovementioned authorization, the user-generator and the distributor shall execute a Distributed Electricity Generation Agreement, under the terms of the Promotion Regime. Pursuant to it, the distributor shall enable the user-generator’s facilities to supply energy to the grid.
In case of controversies among the distributor and the user-generator, Law No. 27,424 establishes that the latter can bring its claim before the competent regulatory entity.
The compensation and remuneration scheme for the supplied energy shall be administered by the distributor in the following terms:
| (a) | The user-generator shall receive a tariff for the supply of each kilowatt per hour (KW/h) delivered to the grid, as of the moment the measuring equipment is installed by the distributor. The pricing shall be in Argentine pesos. The applicable tariff scheme was approved by ENRE Resolution No. 189/2019 (see “Tariff Scheme – ENRE Resolution No. 189/2019” below). |
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| (b) | In the usual bills for the provision of electricity, the distributor shall reflect the energy provided to the user-generator, and the energy supplied by the user-generator to the grid, with the price for each KW/h. The user-generator shall pay the net value before taxes. No additional tax charges can be made over the energy supplied by the user-generator. In the event there is a surplus amount in favor of the user-generator, a credit against the distributor will be accounted for further periods. If such surplus amounts accrue for a certain period of time, a retribution can be requested to the distributor. |
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| (c) | Profits from supplying electricity to the grid by user-generators with up to 300kw of contracted capacity, in compliance with the regulations, will be exempt from income tax and value added tax. |
The current enforcement authority of the Promotion Regime is the Secretariat of Energy. Among other things, such authority is empowered to: (i) establish the technical and administrative standards for the approval of distributed energy projects; (ii) establish the requirements to be fulfilled to authorize the connection to the grid requested to distributors by user-generators; (iii) establish the value of the tariff for the supply of electricity through distributed energy projects; (iv) establish the general guidelines of the Distributed Electricity Generation Agreements to be executed among distributors and users-generators.
Any breach of the distributors obligations under the Promotion Regimen will be subject to sanctions, and the user-generator will have a right for compensation.
The Promotion Regime also created the “Fondo Fiduciario para el Desarrollo de la Generación Distribuida de Energías Renovables” (“FODIS”), with the purpose of granting loans, incentive, guarantees, capital contributions and acquisition of other financial instruments, destined to the implementation of systems of distributed generation from renewable resources.
The Federal Government (through the enforcement authority of the Promotion Regime) would be the FODIS Trustor, while the selected public bank would be the Trustee. The Beneficiaries would be all the people domiciled in Argentina and businesses incorporated in Argentina, whose projects of distributed generation have obtained approval from the FODIS authorities, pursuant to the applicable regulations.
The FODIS model agreement was approved by means of Disposition No. 62/2019 of the former Undersecretariat of Renewable Energy and Energetic Efficiency. Such disposition also named Banco de Inversión y Comercio Exterior (BICE) as the FODIS Trustee.
Activities performed within the FODIS are subject to tax benefits.
Finally, the Promotion Regime also sets forth the “Régimen de Fomento para la Fabricación Nacional de Sistemas, Equipos e insumos para la Generación Distribuida a partir de fuentes renovables” (“FANSIGED”), currently under the scope of the Ministry of Productive Development.
FANSIGED will be applicable for ten (10) years as of the enactment of the Promotion Regime (2017). The National Executive Branch can extend it for an additional 10-year term.
The activities falling within the scope of the FANSIGED are research, design, development, investment in capital goods, production, certification and installation services for the distributed generation of energy from renewable sources.
A series of tax benefits are applicable under the FANSIGED.
Micro, small and medium size companies incorporated in Argentina, who develop any of the activities falling within the scope of the FANSIGED can adhere to the regime.
Resolution No. 314/2018 also created the Registro Nacional de Usuarios-Generadores de Energías Renovables (RENUGER), applicable to projects who obtained the Certificate of User-Generator and are included in the Promotion Regime.
Resolution No. 314/2018 approved further regulations to the Promotion Regime, which include, among others:
| (i) | The distinction between Small User-Generators (up to 3 kW of capacity), Medium User-Generators (from 3 KW up to 300 kW of capacity) and Large User-Generators (from 300 KW up to 2 MW of capacity). |
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| (ii) | The procedure to follow for the connection of user-generators, and technical criteria. |
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| (iii) | The guidelines for the execution of Distributed Electricity Generation Agreements, setting forth the parties’ rights and obligations, causes for suspension, and causes for termination. |
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| (iv) | Specifications for the measurement systems. |
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| (v) | Billing and compensation mechanisms. |
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| (vi) | Further regulations for the promotional benefits regime. |
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The former Undersecretariat of Renewable Energy and Energetic Efficiency issued Disposition No. 28/2019 to complement the provisions of Resolution No. 314/2018.
Tariff Scheme – ENRE Resolution No. 189/2019
ENRE Resolution No. 189/2019 approved the applicable tariffs to User-Generators for the supply of energy to the grid as of May 2019, valued in Argentine pesos per hourly kilowatt ($/kwh).
On November 19, 2021, ENRE Resolution 491/2021 was published in the Official Gazzette, approving the Injection Tariffs for User-Generators of the concession areas of EDENOR and EDESUR S.A., effective as of August 1, 2021.
The National Program
The former Secretariat of Electric Energy issued Resolution No. 724/2008, which authorized the execution of WEM committed supply agreements associated with the repair or repowering of diesel generation groups and related equipment with WEM generation agents. The compensation to be received by the seller will be paid according to the payment priority provided in subsector “I” of Section 4 of Resolution SE No. 406/03.
On November 11, 2009, Resolution SE No. 762/2009, which created the National Hydroelectric Works Program (the “National Program”), was published in the Official Gazette.
The purpose of the National Program is to promote and support the construction of hydroelectric plants within Argentina through the creation of funding sufficient to assure the repayment of investments made and loans provided in such framework.
Within this framework, the Argentine Government has provided that CAMMESA and the WEM generation agents to be determined by the former Ministry of Energy and Mining may enter into electric power supply agreements in respect of the energy generated by the hydroelectric works that are part of the National Program. One of the purposes of the supply agreements for hydroelectric works is to repay the investments made and the loans used to complete all hydroelectric works included in the National Program.
The standard term of such agreements may be of up to 15 years, but such agreements may be extended by the former Ministry of Energy and Mining. Upon expiration of such term, each hydroelectric plant that is part of the National Program may sell the energy generated by it at the price then specified by the WEM.
The terms and conditions of the agreements were determined by the former Secretariat of Electric Energy taking into account principles of economic reasonableness, equity and operating benefits for the electric power system as a whole, according to which it will qualify the hydroelectric works to be executed within the scope of the National Program.
PPAs with IEASA (former ENARSA)
Resolution SE No. 712/09 approved the sample contracts to be executed between CAMMESA and ENARSA –now IEASA for the supply of electric power derived from renewable sources generated under the contracts awarded in ENARSA’s Bidding Process No. 1/09.
Resolution SE No. 712/09 also added Annex 39 and replaced Annex 40 of the Procedures. In this regard, the new Annex 39 sets forth the guidelines for renewable energy generation, excluding hydroelectric and wind energy, while Annex 40 set forth the guidelines for wind power generation.
Regarding the contracts to be awarded, prior to their execution, ENARSA had to carry out certain efforts with the former Secretariat of Electric Energy to obtain approval for the generation availability offer pursuant to which it intends to execute each agreement with CAMMESA.
Based on the assessment of the requests received, the former Secretariat of Electric Energy will consider the merits of contracting for the availability of generation and related energy, instruct CAMMESA to execute a contract with those parties whose requests have been accepted and send the text of the contract to be executed with the specific provisions for each contract.
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The main characteristics of these sample contracts approved by Resolution SE No. 712/09 are the following:
| 1. | The energy supplied must be generated by designated units in conformity with CAMMESA’s dispatch requirements and must be adequate for the generator’s capacity. |
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| 2. | The term of the contracts must be for a maximum of 15 years, which may be extended for a maximum term of 18 additional months. |
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| 3. | In cases of contracts for energy generated from renewable sources other than biofuels (such as wind and solar energy), no capacity payment is provided. In these cases, the consideration shall consist of the payment for the energy supplied, a management charge and the payment of a portion of fixed costs (charges for transport, expenses, fees and other charges specifically provided for). The price of the energy supplied shall remain constant throughout the term of the specific contract. |
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| 4. | A guarantee fund will be established to ensure the performance of the obligations under the PPAs, which shall be set up by CAMMESA, until reaching a limit of 10.00% of the future obligations assumed under each of the contracts at which point the fund ceases to accumulate funds |
Resolution SE No. 108/2011, dated April 13, 2011, authorized the execution of new PPAs between CAMMESA, on behalf of the WEM, and certain parties offering availability of electric power generation using the renewable sources set forth in Law No. 26,190 that meet the following requirements:
| 1. | at the time of the publication of Resolution No. 108/2011, such parties do not have the generation facilities to be committed under such offers or, having completed the interconnection to the WEM, have not committed their availability of generation and related energy under any form of contract; and |
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| 2. | they present projects where the Argentine Government, IEASA or other generation agents have an interest. |
The remuneration is paid on a monthly basis in U.S. dollars and is determined based on the costs and annual income acknowledged by the former Secretariat of Electric Energy. For such purposes, the fixed and variable installation costs required for the proper operation of the committed equipment shall be considered based on the method determined in each PPA.
Both Resolutions 712/2009 (except Annex 39 and 40) and 108/2011 of the Secretariat of Energy were repealed by the former Ministry of Energy and Mining, by means of Resolution 202-E/2016.
Renewable Energy Program
In recent years, Argentina has prioritized the generation of electric power from renewable sources. In such regard, it has not only issued regulations intended to regulate and incorporate this type of energy into the WEM, but it has also promoted it by granting incentives in the form of tax benefits and preferential or subsidized tariffs.
To promote renewable energy, Law No. 26,190 was enacted in December 2006 and approved the National Promotional Regime for the Use of Sources of Renewable Energy destined to Electric Production (the “Promotional Regime”). The renewable energy sources provided for in this system include wind, solar, geothermal, tidal, hydraulic (hydroelectric power plants up to 30 MW), biomass, landfill gas, sewage-treatment plant gas and biogas (except for the uses provided for in Law No. 26,093 on biofuels). The purpose of Law No. 26,190 is to increase the proportion of energy provided by renewable energy sources to 8% of the national electric power consumption within ten years from its effective date. Law No. 26,190 also established a system of investments for the construction of new works intended to generate electric power from renewable energy sources, which will remain in force for a term of ten years. The system set forth by Law No. 26,190 has been excluded from the general remuneration scheme regulated by Resolution No. 95 (as described below).
The beneficiaries of this system are individuals and legal entities that hold investments and concessions for new renewable energy generation works in Argentina that have been approved by the enforcement authority. The energy must be intended for the WEM and the project must be related to the rendering of public services.
On September 23, 2015, Law No. 26,190 was amended by Law No. 27,191. The amendments seek to establish a legal framework to increase investments in renewable energies and foster the diversification of the electric power generation mix, increasing the participation of renewable sources. To such end, the law, among other things:
| 1. | sets renewable energies consumption targets for all of Argentina’s electric power consumers, as minimum percentages of renewable energies electric power that they are required to consume as of December 31 of the following years: 8% for 2017, 12% for 2019, 16% for 2021, 18% for 2023, and 20% for 2025; |
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| 2. | amends and expands the tax benefits for eligible projects; |
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| 3. | establishes the FODER as a trust fund for which the Argentine Government serves as the trustor, Banco de Inversión y Comercio Exterior (BICE) serves as the trustee and the owners of the approved investment projects are the beneficiaries. The trust fund must allocate the trust assets to extend credit, make capital contributions and acquire all such other financial instruments as required for the execution and financing of eligible projects involving electric power generation from renewable sources; and |
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| 4. | establishes obligations for Large Users and large demand: clients of electric power distribution providers or distribution agents with capacity demand equal to or higher than 300 KW must meet gradual goals through self-generation or otherwise purchase such electric power from generators (directly or through electric power distributors or brokers or from the wholesale market operator CAMMESA), at a price which may not exceed an average of US$113/MWh until March 30, 2018, and thereafter at a price determined by the former Ministry of Energy and Mining. In this respect the former Ministry of Energy and Mining by means of Resolution 281-E/2017, established the regulatory framework that allows Large Users to purchase renewable energy from private generating companies. |
Pursuant to Decree No. 531/16, the Argentine Government set forth general guidelines and principles for the development of energy projects, by delegating the procedures for compliance with energy goals, bids or auctions for the implementation of the FODER to the former Ministry of Energy and Mining, particularly to the Undersecretary of Renewable Energies. The most important aspects of these regulations are as follows:
| 1. | The former Ministry of Energy and Mining must be the enforcement authority of the law. (currently the Secretariat of Energy). |
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| 2. | The system is applicable to projects for the construction of new facilities or for expanding or upgrading existing ones, the acquisition of new or second-hand equipment, to the extent new assets, works and other services are used for the project and are directly connected to the project. Access to the system is allowed for projects for which, after having been selected under Resolutions Nos. 220/2007, 712/2009 and 108/2011 set forth by the former Secretariat of Electric Energy, construction has not yet begun and that have been selected by the enforcement authority and the executed agreement is terminated. Projects for which construction has begun may also be eligible to the extent amendments to the executed contracts are allowed, as required by the enforcement authority. The enforcement authority must establish the merit order for projects that have been approved and determine the granting of the promotional benefits for each project. |
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| 3. | The goals established by the law must be audited annually commencing on December 31, 2018. Users are allowed a 10% margin of error per year for achieving the goals related to energy consumption from renewable sources established by the law. |
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| 4. | The enforcement authority must establish the terms and conditions under which it will allocate a portion of the funds of FODER’s financing account to finance the development projects of the value chain of local production of power generating equipment, using renewable energy sources, parts or components. |
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Tax Benefits Under Law No. 26,190
The former regime includes the following tax benefits:
| · | Early refund of the VAT on the project’s new depreciable assets: the VAT as invoiced to the beneficiaries on the purchase, production, manufacture or final import of capital goods or the execution of infrastructure works shall be credited against other taxes by the AFIP as soon as at least three fiscal periods have elapsed, as counted from the fiscal period in which the investments were made, or it shall be recoverable in the term provided upon approving the project, under conditions and with the guarantees set forth in that respect. |
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| · | Accelerated asset depreciation for purposes of income tax: the beneficiaries may apply depreciations on the investments associated with the projects subsequent to their approval and under the terms set forth therein. These depreciations are subject to a differential treatment depending on their timing, within the first, second or third twelve-month period after project approval. This alternative is subject to the condition that the assets are to remain as property of the project holder for at least three years. |
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| · | Non-calculation of the minimum presumed income tax provided by Law No. 25,063 on the assets allocated to the projects initiated under the system created by the renewable energy law: this benefit applies to the three fiscal periods preceding the completion of the relevant project. The assets must be connected to the relevant project and must be acquired by the company after the approval of the project. Pursuant to Law No. 27,260, passed by the Argentine Congress on June 29, 2016, the minimum presumed income tax was eliminated for tax periods beginning as of January 1, 2019. |
The regime also provides for certain additional compensation. In that regard, the projects will be entitled to an additional compensation equivalent to US$0.015 per KW/h payable to the generators that produce electric power from renewable sources, except in the case of solar-based electric power, for which generators will collect US$0.9 per KW/h. Such additional compensation will be paid according to: (i) fuel substitution, (ii) the involvement of Argentine industries and job creation opportunities and (iii) the amount of time it takes to launch the project.
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Tax benefits under Law No. 27,191
Law No. 26,190, as amended by Law No. 27,191, together with Decree No. 531/2016 and the regulations of the Ministry of Mining and Energy, set forth the National Promotional Regime for the Use of Renewable Sources of Energy (the “Promotional
Regime”). The Promotional Regime includes the following tax benefits:
| 1. | Early refund of VAT and accelerated depreciation of assets for income tax purposes, with beneficiaries being able to apply for both benefits simultaneously, subject to reduced benefits based on the actual commencement date of the project’s execution. |
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| 2. | Extension to ten years of the tax loss carry forward term. Tax loss carry forwards arising from the promoted activity may only be set off against net income arising from the same activity. |
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| 3. | Exclusion of assets connected to the activity subject to the Promotional Regime from the taxable base related to the minimum presumed income tax until the eighth fiscal year following the project’s commencement (inclusive of the first year). Excluded assets are those connected to the project subject to the Promotional Regime and included in the owner’s net worth after the approval of such project. |
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| 4. | A 10% exemption on tax on the dividends distributed by the companies that own the projects subject to the Promotional Regime, which are reinvested in new infrastructure projects within Argentina. However, this benefit would not apply to the tax created by Law No. 27,430, as amended. In addition, due to the amendments introduced by Law No. 27,630, dividends originated in profits obtained during fiscal years initiated after January 1, 2021 onward would be subject to a 7% income tax withholding on the amount of such dividends. |
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| 5. | Tax certificate applicable to the payment of income tax, VAT, minimum presumed income tax and excise taxes for an amount equal to 20% of the value of components of electromechanical facilities made in Argentina, provided that at least 60% of the components (excluding civil works) are made in Argentina. Where there is insufficient or a lack of production in Argentina, the percentage is reduced to 30%. The assignment of the tax certificate is conditioned upon the fact that the taxpayer cannot have liquidated debts due and payable to the AFIP. |
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| 6. | Other benefits, including the possibility of shifting increased costs arising from tax increases to the price of the renewable energy sold; exemption from import duties and the statistical rate for the import of new capital assets, special equipment and related parts and components that are necessary for, among other things, the execution of the project; and the exemption from special taxes, fees and royalties of any jurisdiction imposed on the access to and use of renewable sources of energy within participating jurisdictions until December 31, 2025, excluding potential fees payable on the use of the state-owned land where the projects are based. |
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| 7. | Those who wish to participate in the Promotional Regime must waive the benefits afforded by previous systems under Laws No. 25,019 and 26,360, and the projects that benefitted from such systems may only have access to the Promotional Regime if the works committed under the contracts executed thereunder have not commenced as of the date of the application. |
RenovAR (Round 1, Round 1.5 and Round 2): Bidding Process for Renewable Energy Generation Projects
After carrying out a public consultation period to submit comments and suggestions to the preliminary version of the bidding terms and PPAs and due to the proximity of the period for submitting bids to the “Round 1” from the RenovAR Program, Presidential Decree No. 882/16, published on July 22, 2016, in the Official Gazette on the grounds of “necessity or urgency,” which decree has modified and established different precisions regarding the legal framework for the Promotional Regime.
Below are the main measures introduced by the Decree No. 882/16:
| 1. | Fiscal Quota: For the year ended December 31, 2016, a budget of US$1,700,000,000 was approved in order to be allocated to the promotional benefits under the Promotional Regime. In case the specified budget is not allocated in full in 2016, it will be automatically transferred to the following year. |
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| 2. | PPAs term: In order to recover the investment and obtain a reasonable return, the PPAs will have a maximum term of 30 years. |
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| 3. | Put and Call Options: The PPAs may grant rights to: (a) the Argentine Government to purchase the power generation or their assets upon material breaches of the contract that constitute ground for termination; the purchase price will be lower than the unamortized investment at the time the option is exercised; and (b) the owner of the project to sell the power generation or their assets upon the occurrence of any of the “grounds for put option” for a price, which in no case may exceed the unamortized investment at the time the option is exercised. |
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| 4. | PPAs are subject to Argentine private law. |
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| 5. | Choice of Forum: In the event of any dispute concerning the interpretation or execution of the PPAs for disputes arising out of the contracts signed between the Argentine Government or the FODER with the beneficiaries of the Promotional Regime, alternative dispute resolution methods from Argentina or abroad can be included in the PPAs. |
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| 6. | FODER: As a result of the Decree No. 13/2015 in which the former Ministry of Energy and Mining was established, the Decree No. 882/16 replaced paragraphs 2, 3, 7, 8 and 9 of Section 7 of Law 27,191 and proceeded to modify the Argentine Government’s role in the FODER, establishing the former Ministry of Energy and Mining as trustor and trustee of the FODER. It also granted power to the Minister of Energy and Mining (or his designee or replacement) to approve the trust agreement of the FODER and sign the trust agreement with the trustee. |
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| 7. | Guarantee of payment for put option: The decree empowers the Ministry of Treasury and Public Finance to issue and deliver treasury bills to the FODER (up to a maximum nominal value of US$3,000,000,000 or its equivalent in other currencies) for and on behalf of the former Ministry of Energy and Mining and to guarantee the payment in the event that the owner exercises the put option and sells the generation plant. |
Resolution No. 136/16, issued by the former Ministry of Energy and Mining and published in the Official Gazette on July 26, 2016, launched the public auction process for submitting bids for Round 1 of the RenovAR Program. Resolution No. 136/16 also approved both the bidding terms and conditions of the above-mentioned auction and the PPAs with CAMMESA.
According to the terms and conditions of such bid, the relevant PPAs shall include the following features and provisions:
| 1. | Purpose: The purpose of the agreement must be to supply the amount of electric power associated with the new equipment for electric power generation from renewable sources to the WEM beginning on the date on which the power plant is permitted to operate in the WEM until the termination of the contractual term. |
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| 2. | Seller: The generation, co-generation or self-generation agent of the WEM whose bid is accepted pursuant to the provisions of this resolution and supplementary regulations set forth by the Secretariat of Electric Energy. |
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| 3. | Buyer: CAMMESA, on behalf of the distribution agents and Large Users of the WEM (until such role is reassigned among distribution agents or Large Users of the WEM), to meet the goals of renewable energy source contribution set since December 31, 2017, for the demand of electric power in the WEM. |
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| 4. | Term: Up to twenty years from the date on which operations commence. |
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| 5. | Type and technology of the energy to be supplied. |
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| 6. | Electricity committed to be delivered per year. |
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| 7. | Generation capacity of each unit and total installed capacity committed. |
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| 8. | Remuneration to be received by the seller and paid by the buyer for the electric power to be supplied, determined on the basis of the bid price in U.S. dollars per megawatt/hour (US$/MWh). |
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| 9. | The terms and conditions of the seller’s contractual performance guarantee. |
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| 10. | The point of delivery of the electric power purchased shall be the connection node to the SADI. |
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| 11. | The remedies for contractual breach. |
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| 12. | The enforcement of the guarantee for payment through FODER’s escrow account. |
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| 13. | Contracts for the purchase of electric power shall have first priority in payment and rank equally with payments to the WEM. |
On September 5, 2016, after concluding the period for submitting bids to the first round of the RenovAr Program, the Minister of Energy and Mining, Juan José Aranguren, and the Undersecretary of Renewable Energies, Sebastián Kind, pursuant to Resolution No. E 205/16 signed by the Minister of Energy and Mining, announced that 123 bids were submitted, requesting 6,346 MW (six times more than 1,000MW originally tendered), of which 105, a total of approximately 5,209 MW, were technically qualified. This consisted of 42 wind projects with a total installed capacity of approximately 2,780 MW, 50 solar projects with a total installed capacity of approximately 2,304 MW and 13 biomass, biogas and small hydroelectric power projects with a total installed capacity of approximately 35 MW.
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Pursuant to Resolution No. 213-E/16 of the Minister of Energy and Mining, the results of the tender were published on October 7, 2016. A total of 29 projects with a total installed capacity of 1,141.51 MW, located in nine different provinces were awarded:
| · | 12 wind projects for a total installed capacity of 707 MW, with a weighted average price of US$59.39/MWh, a minimum price of US$49.10/MWh and a maximum price of US$67.20/MWh; |
| · | four solar projects for total installed capacity of approximately 400 MW, with a weighted average price of US$59.75/MWh, a minimum price of US$59.00/MWh and a maximum price of US$60.00/MWh; |
| · | five small hydro projects for total installed capacity of 11.37 MW, all at a price of US$105/MWh; |
| · | six biogas projects with a total installed capacity of approximately 8.64 MW, with a weighted average price of US$154 /MWh, a minimum price of US$118/MWh and a maximum price of US$160/MWh; and |
| · | two biomass projects, for a total installed capacity of 14.5 MW, both at a price of US$110/MWh. |
Round 1.5 of the RenovAr Program: Public Bid Process for New Renewable Energy Generation Units
In October 2016, the former Ministry of Energy and Mining also issued Resolution No. 252-E/16, calling for national and international bids under round 1.5 of the RenovAr Program to auction an additional 600 MW of renewable energy (400 MW of wind and 200 MW of solar). On November 11, 2016, CAMMESA began analyzing the technical aspects of the bids that were filed, which included 47 projects totaling 2,486.4 MW.
Pursuant to Resolution No. 281-E/16 of the Minister of Energy and Mining, the results of the tender were published on November 25, 2016. A total of 30 projects with a total installed capacity of 1,281.53 MW, located in 12 different provinces were awarded:
| · | ten wind projects for a total installed capacity of 765.35 MW, with a weighted average price of US$53.34/MWh, a minimum price of US$46/MWh and a maximum price of US$59.38/MWh; and |
| · | 20 solar projects for total installed capacity of approximately 516.18 MW, with a weighted average price of US$54.94/MWh, a minimum price of US$48.00/MWh and a maximum price of US$59.20/MWh. |
Round 2 of the RenovAr Program: Public Bid Process for New Renewable Energy Generation Units
Following Rounds 1 and 1.5 of the RenovAR Program, the former Ministry of Energy and Mining pursuant to Resolution No. 275/17, launched Round 2 of the program on August 17, 2017 and granted awards in the amount of 2,043 MW of renewable power capacity.
We submitted bids for Round 2 of the RenovAR Program on October 19, 2017 and, on November 29, 2017, we were awarded a wind energy project called, “La Genoveva I,” which allowed us to add an additional capacity of 86.6 MW to our portfolio.
Round 2.5 of the RenovAr Program: Public Bid Process for New Renewable Energy Generation Units
After Round 2.0, the former Ministry of Energy and Mining issued Resolution No. 473/2017 of November 30, 2017, which launched Round 2.5. The companies invited to participate in this new round were those companies that filed bids in Round 2.0 and were unsuccessful due to a small margin.
As a result of Round 2.5 by means of Resolution 488-E/2017 of the former Ministry of Energy and Mining, issued on December 19, 2017, 22 additional projects (totaling 634.3 MW of projected power) were awarded.
Round 3.0 of the RenovAr Program: Public Bid Process for New Renewable Energy Generation Units
Through Resolution No. 100/2018, dated November 14, 2018, the Government Secretary of Energy launched Round 3.0 of the RenovAr program and issued the bidding terms and conditions ruling such bidding contest.
In this new round, participants can submit bids with respect to electricity projects of no more than 10MW of capacity each, regardless of the applicable technology (wind, solar, etc.). The total capacity to be awarded in this round is 400MW of renewable energy.
On August 2, 2019, pursuant to Disposition SSERyEE 91/2019 the awarding of the PPAs was decided for a total of 259 MW
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Pursuant to the RenovAR regulatory framework, we were awarded with 3 wind projects: La Castellana I in Round 1, Achiras in Round 1.5 and La Genoveva I in Round 2.0. The wind farm La Castellana I reached commercial operation date (COD), in August 2018, and Achiras reached commercial operation date on September 2018 while La Genoveva I on November 2020. The following table shows the main characteristics of each of the wind farms:
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| La Castellana I |
| Achiras |
| La Genoveva I |
Location |
| Province of Buenos Aires |
| Province of Córdoba |
| Province of Buenos Aires |
Status |
| In operation |
| In operation |
| In operation |
Commercial operation date / Expected commercial operation date |
| August 2018 |
| September 2018 |
| November 21, 2020 |
Awarded power capacity in the bidding process(1) |
| 99 MW |
| 48 MW |
| 86.60MW |
Current/Expected power capacity (1) |
| 100.80 MW |
| 48 MW |
| 88.2 MW |
Regulatory Framework |
| RenovAr 1.0 |
| RenovAr 1.5 |
| RenovAr 2.0 |
Awarded price per MWh |
| US$61.50 |
| US$59.38 |
| US$40.90 |
Contract length |
| 20 years, starting from commercial operation |
| 20 years, starting from commercial operation |
| 20 years, starting from commercial operation |
Power purchase agreement signing date |
| January 2017 |
| May 2017 |
| July 2018 |
Number of units |
| 32 wind turbines |
| 15 wind turbines |
| 21 wind turbines |
Wind turbine provider |
| Acciona Windpower—Nordex |
| Acciona Windpower—Nordex |
| Vestas |
(1) The companies that were awarded with project during the bidding process were authorized pursuant to the conditions of such bidding process to introduce minor changes in the power capacity of the project
Changes to the Electric Power Sector under the previous Administration
On December 15, 2015, the Executive branch declared a state of emergency with respect to the Argentine electric power sector until December 31, 2017. Pursuant to Decree No. 134/2015, the former Ministry of Energy and Mining (as well as its successors) must:
| 1. | prepare and put in place a plan of action addressing the issues affecting the electric power generation, transportation and distribution sectors within its jurisdiction in order to adjust the quality and safety of the electric power supply and ensure the supply of electric power under suitable technical and economic conditions; and |
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| 2. | work in coordination with other agencies of the Argentine Government to develop a program for the efficient use of energy. |
The former Ministry of Energy and Mining set forth Resolutions No. 6 and No. 7 under this scheme.
Additionally, on October 31, 2017, the Executive branch issued Decree No. 882/2017 ordering the restructuring of the Argentine Government’s energy sector assets aimed at the reduction of government participation.
Pursuant to the Decree 882/2017, the former Ministry of Energy and Mining was mandated to execute the merger of ENARSA and Emprendimientos Energéticos Binacionales S.A (EBISA). EBISA is a company responsible for selling the electricity generated by certain binational energy projects in which the Argentine Government is a party. In accordance with the provisions of such decree, ENARSA would absorb EBISA and would change its name to IEASA. Through Resolution 11-E/2018, the former Ministry of Energy and Mining instructed the boards of directors of the aforementioned companies to carry out all diligences necessary to perform the merger.
According to Decree No. 882/2017, IEASA will also be responsible for continuing certain energy infrastructure public work projects previously performed by the former Ministry of Energy and Mining (acting as a contracting entity). Pursuant to such decree, the former Ministry of Energy and Mining can also assign to IEASA with any other public work project to be performed by such ministry.
Through Decree No. 882/2017, the Executive branch granted IEASA a concession to develop the Condor Cliff and La Barrancosa hydroelectric power plants.
Decree No. 882/2017 also instructed the former Ministry of Energy and Mining (acting as a shareholder of IEASA), to implement the necessary measures so that IEASA sells, assigns or transfers its assets, rights and/or shares (as the case may be) related to Ensenada Barragan, Brigadier López and Manuel Belgrano II thermal power plants and Compañía Inversora de Transmisión Eléctrica CITELEC S.A.
Pursuant to Decree No. 882/2017, the former Ministry of Energy and Mining was also instructed to implement the necessary measures and procedures to execute the sale, assignment or transfer (as the case may be) of (i) the Argentine Government’s shares in Central Puerto S.A equity and the equity of other energy companies (Central Dique S.A, Central Térmica Güemes S.A, Centrales Térmicas Patagónicas S.A, TRANSPA and Dioxitek S.A), (ii) the rights held by the Argentine Government regarding the following power plants, companies and shares: Termoeléctrica Manuel Belgrano, Termoeléctrica José de San Martín (Central Timbúes), Termoeléctrica Vuelta de Obligado and Termoeléctrica Guillermo Brown.
The subsequent sales and transfers must contemplate public and competitive procedures which must protect the rights established in the companies’ bylaws and related corporate and contractual documentation.
The bidding terms and conditions of the bidding contest to transfer Ensenada Barragan and Brigadier Lopez power plants were approved by means of Resolution No. 289/2018 of the former Ministry of Energy. We submitted offers for both power plants, and on February 27, 2019, and we were notified that we had been awarded Brigadier López Power Plant, which was effectively transferred on June 14, 2019.
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On June 14, 2019 the transfer agreement for the production unit part of Brigadier López Plant and for the premises on which the Brigadier López Plant is located, was executed, also including: a) personal property, recordable personal property, facilities, machines, tools, spare parts, and other assets used in connection with the operation of the Brigadier López Plant; b) IEASA’s contractual position in the following contracts: (i) Turbogas and Turbosteam supplying contracts with CAMMESA, (ii) the Brigadier López Financial Trust Agreement (as defined below), (iii) the long term maintenance agreement with Siemens, (iv) the spare part sales agreement with Siemens, (iv) insurance contracts. and the, among others); c) permits and authorizations in effect related to the Brigadier López Plant operation; and d) Brigadier López Plant employees.
The Brigadier López Plant has a 280.50 MW Siemens gas turbine installed. It is expected that such gas turbines will be supplemented with a boiler and a steam turbine to complete the combined cycle, which will allow the Brigadier López Plant to generate 420 MW in the aggregate. The installation of all necessary items for the completion of the combined cycle have not been finalized as of the date of this annual report (see Item 3D. Risk Factors—Risks Relating to our Business— Factors beyond our control may affect or delay the completion of the awarded projects or alter our plans for the expansion of our existing plants) .
Under the above-mentioned trust agreement (the “Brigadier López Financial Trust Agreement”), Central Puerto replaced IEASA as the trustor of the Brigadier López Financial Trust Agreement, and BICE Fideicomisos is the trustee. The financial debt balance of the trust as of June 14, 2019, was US$154,662,725. The amount paid on June 14, 2019, amounted to US$165,432,500, formed by a cash amount of US$155,332,500, plus an amount of US$10,100,000 settled through the assignment of LVFVD to IEASA.
Under the terms of the trust agreement, the financial debt accrues interest at an annual rate equal to the greater of (i) LIBOR plus 5% or (ii) 6.25% and amortizes principal on a monthly basis. BICE Fideicomisos as the trustee, is in charge of the administration, and pays such debt, using for that purpose the proceeds from certain components of the sales of Brigadier Lopez power plant that were assigned to the Brigadier López Financial Trust Agreement and are paid monthly directly from CAMMESA to the Brigadier López Financial Trust Agreement. Additionally, there is a reserve account founded, for a total amount of two monthly debt services. In case of insolvency by the Brigadier López Financial Trust Agreement, creditors have no recourse against other assets of Central Puerto.As of the date of this annual report, this financial debt has been cancelled.
Changes to the Electric Power Sector under the current Administration
As of the date of this annual report, the following measures have been adopted in the electric power sector since the elected administration took office on December 10, 2019:
| · | The Governmental Secretariat of Energy –under the jurisdiction of the former Ministry of Treasury- was reorganized as the Secretariat of Energy –within the scope of the Ministry of Economy |
| · | By means of the Solidarity Law, tariffs applied by distribution and transmission companies under federal jurisdiction were frozen for 180 days, at the values in force as of the day in which the law came into force (December 21st, 2019). This measure was extended by means of Decree No. 543/2020 (180 days) and Decree No. 1020/2020 (90 days, or until the new tariff regimes enter in force). |
| · | The Executive branch was empowered to renegotiate tariffs effective as of December 21, 2019, with the aim of reducing the tariff burden placed on households, stores and industrial facilities for 2020 and said process was formally began by the ENRE. |
| · | By means of the Solidarity Law, the National Executive branch was empowered to intervene the ENRE board of directors per one year. This measure was implemented by means of Decree No. 277/2020 and extended by means of Decree No. 1020/2020 (until December 31, 2021) and Decree No. 871/2021 (until December 31, 2022). |
| · | The transfer of EDENOR and EDESUR to the jurisdictions of the City of Buenos Aires and the Province of Buenos Aires, as applicable, was suspended. Therefore, such companies still remain under the regulatory power of the national government |
| · | On December 27, 2019, the Ministry of Productive Development issued Resolution MDP No. 12/2019, repealing Resolution SGE No. 70/2018 and restoring Art. 8 of Res. SE 95/2013. Beginning in January 2020, CAMMESA became the only fuel supplier for generation companies, except for (i) thermal units that had prior commitments with CAMMESA for energy supply contracts with their own fuel management and (ii) thermal units under the Energía Plus regulatory framework, authorized under Resolution SE No.1281/05 to supply energy to large private users. |
| · | On February 27, 2020, the Secretariat of Energy issued Resolution 31/20 applicable from February 1, 2020, which replaces the regulatory framework for Energía Base, changing the energy and power capacity prices for the units under this regulatory framework. For the details of this regulation see “Item 4.B. Business Overview—The Argentine Electric |
| · | Power Sector—Remuneration Scheme—The Current Remuneration Scheme.” |
| · | Resolution Secretariat of Energy 354/2020. Through this resolution it was established, mainly among other things, that as from the validity of the “GasAr” Plan (Plan Gas IV), the MEM Generators will be able to adhere to the centralized dispatch, assigning to CAMMESA the operational management of the contracts that these have with producers awarded with gas volumes in the Plan Gas IV and / or with natural gas transporters and / or distributors, so that said contracts are used by the Dispatch Agency (OED) in order to minimize total costs supply criteria for the MEM dispatch criteria and for a given priority of dispatch of natural gas according to its origin (Natural Gas from Plan Gas IV natural gas imprinted from Bolivia by IEASA, LNG and the rest of natural gas in local basins outside the Plan Gas IV). In particular, Res. 354 also established that generating agents that have obligations to supply their own fuel within the framework of Resolution No. 287/2017, will have the option to nullify the aforementioned obligation, having to preserve the maintenance of the respective transport capacity for the purposes of its management in the centralized dispatch, as long as CAMMESA determines the convenience of having it. |
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| On January 19, 2021, the ENRE initiated, with the enactment of Resolutions 16/2021 and 17/2021, the proceedings for the transitory adjustments of the tariffs of the public utilities of distribution and transportation of energy, with the purpose of establishing a Transitional Tariff Regime, until a Final Renegotiation Agreement is reached. |
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| ● | On January 21, 2021, the SE created through Resolution 40/2021 two regimes: |
| (i) | a “Special Regime for the Regularization of Obligations” for the debts maintained with CAMMESA and/or with the WEM of the electricity distributors agents of the MEM, whether for energy consumption, power, interest and/or penalties, accumulated as of September 30, 2020; |
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| (ii) | a “Special Credits Regime” for those electricity distributors that, being WEM agents, do not register debt with CAMMESA and/or the WEM or are considered within reasonable values in relation to their level of transactions as of September 30, 2020; |
| · | Both regimes will be implemented through the signing of particular “Actas Acuerdo” that will be signed between the electric power distributors agents of the WEM and its granting authority and/or control entity and the SE, where the treatment of the entirety of the comprised debt and the obligations to which the distributor will be subject. |
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| · | By means of Resolution No 53/2021, issued on March 3, 2021, the ENRE called for a public hearing to discuss the “Transition Tarff Regime” to be applied by EDENOR and EDESUR, all within the integral tariff revision process |
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| · | Later, on March 5, 2021, ENRE issued Resolution 58/2021. Through this Resolution, ENRE instructed EDENOR and EDESUR issue the invoices for the electricity distribution public service including only the amounts due for consumption in the invoiced period, and separately, inform debts originated or accrued during the mandatory quarantine (ASPO) and the social distancing measure (DISPO), without contemplating interests. It also ordered both distributors to refrain from suspending the supply of their services due to amounts owed up to February 28, 2021. |
| · | On April 30, 2021, the ENRE issued Resolutions No. 106 and 107, through which the values of the Distribution Cost and the values of the tariff chart of EDESUR (106) and EDENOR (107) were approved, effective as from May 1, 2021 (Transition Tariff Regme). |
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| · | On August 9, 2021, the ENRE issued Resolutions No. 262/2021 (amended by Resolution No. 265/2021) and No. 263/2021 (amended by Resolution No. 266/2021), whereby the tariff charts of EDENOR and EDESUR, respectively, were approved, effective as from August 1,2021. |
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| · | On November 19, 2021, ENRE Resolution 491/2021 was published in the Official Gazette, approving the Injection Tariffs for User-Generators of the concession areas of EDENOR and EDESUR S.A., effective as of August 1,2021. |
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| · | On January 27, 2022, Resolution No. 28/2022 of the Secretariat of Energy was published in the Official Gazette. The Secretary instructed the ENRE to include the treatment of the seasonal reference prices of the Stabilized Energy Power and the Stabilized Price of Transportation in the WEM and for the WEM of the Tierra del Fuego System, as part of the public hearings to be held within the framework of the transitional adjustments of tariffs of the Public Service of Electric Energy Transportation of national scope, the treatment of the seasonal reference prices of the Stabilized Power, Stabilized Energy and the Stabilized Price of Transportation in the WEM and for the WEM of the Tierra del Fuego System, in order to broaden the dissemination of the respective information and facilitate a greater participation of the users of the electric service of the different jurisdictions in the treatment of such matter. |
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| · | By means of Resolution No. 25/2022, the ENRE proceeded as instructed: it called for a Public Hearing in order to inform and hear opinions regarding: (i) the treatment of the determination of the seasonal reference prices of Power, Stabilized Energy in the WEM, as well as the Stabilized Price of Transportation and for the WEM of the Tierra del Fuego System; (ii) the proposals of the electric power transmission and distribution public service concessionaires, aimed at obtaining a transitory adjustment of tariffs, within the Integral Tariff Review renegotiation process and prior to defining the tariffs to be applied by the concessionaires. The Public Hearing was held on February 17, 2022. |
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| · | On February 4, 2022, ENRE Resolutions No. 41/2022 and No. 42/2022 were published in the Official Gazette. These resolutions approved the new tariff scheme to be applied by EDENOR and EDESUR, respectively, as from February 1, 2022. They also set forth that the average tariff value -as of February 1, 2022-, is 5.452 Pes./kWh for EDENOR, and 5.362 Pes./kWh for EDESUR. |
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Call for Bids for New Thermal Generation Capacity and Associated Electricity Generation
Pursuant to Decree No. 134/15 and Resolution No. 6/16 set forth by the former Ministry of Energy and Mining, the Secretariat of Electric Energy issued Resolution No. 21/16 (“Resolution No. 21”) calling for bids for thermal generation capacity and associated electric power generation. The energy was to be made available in the WEM to meet essential demand requirements beginning with the following seasons: summer 2016/2017, winter 2017 and summer 2017/2018.
Resolution No. 21 provided for the following bid specifications:
| 1. | Bids may only be submitted to CAMMESA by such parties that already were or had simultaneously submitted an application to the Secretariat of Electric Energy to become, generation, co-generation or self-generation agents of the WEM under the terms of the Procedures. |
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| 2. | Bids had to be for projects to install new generation capacity, in addition to the expected capacity for the period in which commercial operation of the project was committed. |
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| 3. | Bidders did not have to offer pre-existing generation units that were connected to the SADI or units in which the power capacity being offered was already committed and partially performed under agreements approved by the former Secretariat of Electric Energy. If, in the case of the latter, there was no partial performance of the agreements and bidders submitted bids under Resolution No. 21, CAMMESA had to submit the matter to the former Secretariat of Electric Energy. |
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| 4. | Bids did not have to commit, at each proposed connection point, a generation capacity lower than 40 MW and the net power of each generating unit for such location did not have to be lower than 10 MW. |
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| 5. | The committed equipment had to be capable of running on two types of fuel and be able to operate on either of them as needed by the WEM economic dispatch. If there was ongoing and unlimited availability of a given fuel or if deemed logistically beneficial by the bidder, bidders had to submit an alternative offer with generating equipment capable of running on a single type of fuel. |
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| 6. | There was no pre-established ceiling for the capacity of power that could be offered, and the location of the projects could be freely chosen, but both the capacity and the location of the projects was limited by the capacity of the transmission system and the supply of fuel. |
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| 7. | For each generating unit at the proposed interconnection spot, bidders had to offer a price for power availability (expressed in U.S. dollars per month) and a price for the electric power generated (expressed in U.S. dollars per hour), estimating the value of non-fuel related variables for each type of fuel on which the power plant was able to run, and the related committed maximum specific consumption stated in kilocalories per kilowatt-hour. |
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| 8. | Bidders were required to submit evidence of full compliance with applicable environmental laws, including but not limited to the related statement of Environmental Impact and Environmental Impact Study. |
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| 9. | Bids had to be submitted in two envelopes. One envelope had to include technical information in connection with the availability of the power being offered. The other envelope had to include the bid price for the committed power availability and the electric power generated, the maximum specific consumption being offered, the committed due date by which the generation capacity being offered would have been commercially available for service, the requested term for the contract, the bid bond and the pro forma guarantee of compliance with the committed due date. |
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| 10. | Before submitting the bids, the Secretariat of Electric Energy could specify or supplement the contents of Resolution No. 21 and the information and documents to be submitted. |
The agent whose bid was finally accepted was required to enter into a contract for the sale of electric power generation capacity availability and the related generated electric power in the WEM (a “wholesale demand contract”) with the distribution agents and Large Users of the WEM represented by CAMMESA.
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Resolution No. 21 sets forth the guidelines for wholesale demand contracts, which included, among other things, the following terms: (i) the contractual term is required to be between five and ten years; (ii) the maximum specific consumption of each generating unit by type of fuel used is required to be lower than 2,500 kilocalories per kilowatt-hour; (iii) a set of remedies are required to be defined for failures to comply with the committed availability of generation capacity; (iv) the supply of and recognition of the cost of fuel used by the machines and power plants involved is required to be included in accordance with applicable regulations; (v) contracts are required to have first priority in payment and rank equally with existing supply agreements with the Banco de Inversión y Comercio Exterior (BICE) in its role as trustee of the trusts “Central Termoeléctrica Manuel Belgrano” and “Central Termoeléctrica Timbúes” since January and February 2010, respectively, and priority in payment must rank equally with payment obligations in respect of liquid fuel purchases for electric power generation; and (vi) the contracts are required to include other features stemming from the provisions of Resolution No. 21.
The bids submitted are required to be reviewed by CAMMESA following the methodology established by the Secretariat of Electric Energy. This methodology included following a streamlined simulation model of the expected operation of the generation units committed in each bid, considering certain requirements set forth by Resolution No. 21. The bid assessment process is required to consider the risks of undelivered electric power expected for the summer 2016/2017, winter 2017 and summer 2017/2018, estimating the value the early incorporation of the generation capacity being offered would have for the electric power system. Bids are required to be ordered and selected based on the increasing costs each of them would have on the electric power system. CAMMESA is required to assess and report to the Secretariat of Electric Energy the costs that each of the bids deemed acceptable under the approved methodology would represent for the system and, if applicable, the bids that have been excluded at such stage for their failure to meet the bid specifications.
CAMMESA was required to issue the commercial documentation deemed necessary for making payments to selling agents under such wholesale demand contracts during the term of the emergency declared under Decree No. 134/15 or until the enactment of regulations governing the transfer to the selling agents of the responsibility to issue such commercial documentation.
As long as such duty is performed by CAMMESA, it must document and certify to the selling agent the proportional part that Large Users and distributors must pay for the electric power they consume to initiate summary collection proceedings.
As required by Resolution No. 21, CAMMESA prepared the terms of reference that govern the call for bids under Resolution No. 21, with such terms of reference having been approved by Note 161/16 set forth by the Secretariat of Electric Energy.
In accordance to Resolution No.21, the Secretariat of Electric Energy received bids for 6,611 MW and awarded an aggregate amount of 2,871 MW.
Pursuant to Resolution No. 155/16 and Resolution No. 216/16, the Secretariat of Electric Energy authorized CAMMESA to subscribe the wholesale demand contracts with every winning bidder, for 1,915 MW with an average price of US$21.833/MW-month, and for 956 MW with an average price of US$19.907/MW-month, respectively. In addition, through Resolution No. 387/16, the Secretary of Electric Energy authorized CAMMESA to execute additional wholesale demand contracts for two generation projects (one for 100 MW and the other for 137 MW).
Resolution 287/2017 of the former Secretary of Electric Energy
Through Resolution No. 287/2017, of May 11, 2017, the former Secretariat of Electric Energy called for a new thermal power tender for the execution of long-term power purchase agreements. The tender focuses on combined cycle conversion projects and co-generation project.
The main features of the tender were as follows (further requirements and conditions apply):
| a) | Combined cycle conversion projects had to be related to thermal power plants (i) existing at that time or near to reach commercial operation in simple cycle mode; (ii) with low specific consumption; (iii) with the possibility of improving its efficiency once converted into a combined cycle; (iv) that its conversion did not affect the current grid transmission capacity (being any required expansion to be borne by the bidder); (v) which had the appropriate fuel infrastructure system to guarantee permanent operation of the combined cycle; and (vi) with, in principle, a maximum construction term of 30 months. |
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| b) | Co-generation projects (i) had to be efficient, (ii) did not affect the current grid transmission capacity, (iii) had to guarantee its own principal and alternative permanent fuel supply, and (iv) had to entail, in principle, a maximum construction term of 30 months. |
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| c) | 15-year PPAs extension. |
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| d) | CAMMESA-as the offtaker, acting on behalf of distributors and large users of the Argentine Wholesale Electricity Market. The PPAs might be proportionally assigned to large users and distributors at a later stage. |
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| e) | The generator would receive both a fixed capacity payment (subject to power availability) and a variable payment for actual power supplied to the grid. |
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| f) | Prices under the PPAs should be established in US dollars. However, CAMMESA should make payment in Argentine pesos at the prevailing exchange rate on the business day immediately before the payment date established in the sales liquidation document issued by CAMMESA. |
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| g) | Payments under the PPAs will benefit from a priority payment mechanism (equal to the one established for the payment of fuel costs for power generation). |
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| h) | Within three months after execution of the PPAs, CAMMESA had to constitute a Payment Guarantee Fund to guarantee the obligations undertaken under each PPA. It should cover six months of the estimated capacity payments under each PPA. The Secretariat of Electricity should provide the specifics with respect to the Fund’s constitution and administration. |
PPAs were awarded to different projects, by means of Resolutions No. 820/2017 and 926/2017 of the former Secretary of Electricity.
Remuneration Scheme
The Current Remuneration Scheme for generators (Energia Base)
On February 27, 2020, the Secretary of Energy issued Resolution
31/20, establishing a remuneration scheme applicable as from February 1, 2020 for Authorized Generators in the Wholesale Electricity Market. On May 21st, 2021, the Secretary of Energy issued Resolution 440/21, which abrogated Resolution No. 31/20, updating the remuneration scheme applicable from February 1, 2021.
Remuneration of thermal generators
Resolution 440/21 (as amended) sets forth, regarding generation from thermal sources, that Authorized Thermal Generators will be remunerated for (i) monthly available capacity and (ii) energy.
Remuneration for available capacity is comprised of (i) a minimum price associated to the actual available capacity (DRP) and (ii) a price for guaranteed capacity according to the fulfilment of an offered guaranteed capacity availability (DIGO). DIGO is the capacity availability offered by an Authorized Thermal Generator for each “g” generation unit for each DIGO period (which are: (a) summer period: December-January-February, (b) winter period: June-July-August, (c) remaining periods: (c1) March-April-May, (c2) September-October-November). The power remuneration will be affected according to the Utilization Factor (FU) of the generation unit.
Remuneration for energy will be the sum of two items: (i) Generated Energy and (ii) Operated Energy (associated to the rotating power in each hour). The hourly volume of Operated Energy must correspond with the optimal dispatch for the fulfilment of energy and reserves assigned. Remuneration for energy is determined at the connection node of the generator.
Finally, there’s an additional remuneration concept for energy, concerning the first 25 (HMRT-1) and second 25 (HMRT-2) hours of maximum thermal dispatch (“HMRT”) in the month, also establishing a distinction between the summer period, the winter period and the remaining periods.
Remuneration for Available Capacity: the base price to remunerate capacity from thermal sources will be determined pursuant to the following values of capacity base price (PrecBasePot), price of guaranteed capacity (PrecPotDIGO) and Utilization Factor (FU):
Technology / Scale |
| PrecBasePot (Ps./MW-month) |
Combined-cycle Large 150 MW |
| 129,839 |
Combined-cycle Small = 150 MW |
| 144,738 |
Steam Turbine Large 100 MW |
| 185,180 |
Steam Turbine Small = 100 MW |
| 221,364 |
Gas Turbine Large 50 MW |
| 151,124 |
Gas Turbine Small = 50 MW |
| 195,822 |
Internal Combustion Engines=42MW |
| 221,364 |
Technology/Scale |
| PrecPotDIGO (Ps./MW-month) | ||
| Winter and Summer |
| Remaining periods | |
Combined-cycle Large 150 MW |
| 464,400 | 348,300 | |
Combined-cycle Small = 150 MW |
| 464,400 | 348,300 | |
Steam Turbine Large 100 MW |
| 464,400 | 348,300 | |
Steam Turbine Small = 100 MW |
| 464,400 | 348,300 | |
Gas Turbine Large 50 MW |
| 464,400 | 348,300 | |
Gas Turbine Small = 50 MW |
| 464,400 | 348,300 | |
Internal Combustion Engines=42MW |
| 581,800 | 425,700 | |
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Utilization Factor (FU):
In each “n” month of economic transactions a FU will be calculated for each generation unit (“g”), which is defined as:
Fugn = GenopAñoMóvn / (DRPg.n.prom x hs año móvil)
Where:
GenopAñoMovn: the total operated energy of the generator unit “g” in the mobile year prior to month “n” in which the declaration of economic transaction (DTE) is issued.
Hs año móvil: total hours in a mobile year prior to month “n” in which the declaration of economic transaction (DTE) is issued.
DRPg.n.prom: the average actual available capacity of the generation unit “g” in the mobile year prior to the “n” month in which the DTE is issued.
Where:
mes = month.
kFM = hours of the month outside the agreed maintenance period, divided by the hours of the month.
In addition to the abovementioned, the remuneration for available capacity will also depend on the actual available capacity (DRP), which is the average monthly availability corresponding to the “m” month of each generation unit (“g”) that is not under programmed and agreed maintenance and that will be calculated for Authorized Thermal Generators considering the hourly values registered during the month. The application in the calculation for the “m” month will be made taking into consideration the values registered during the month.
Following the abovementioned, Resolution No. 440/21sets forth that the monthly remunerating for available capacity shall be proportional to the monthly availability, the Utilization Factor of the generation unit and capacity price. Capacity price depends on the option taken by the generator regarding DIGO declaration or Base capacity price.
In case of generators that do not declare DIGO, their capacity remuneration is determined by:
REM BASE (Ps./month) = PrecBasePot * DRP (MW) * kFM
Being kFM: hours of the month outside agreed maintenance/hours of the month
In case of generators that declare DIGO, their capacity remuneration is determined by using the following:
| a) | If DRP ≥ DIGO |
|
|
|
|
| REM DIGO (Ps./month) = (DRP – DIGO) (MW) * kFM * PrecMinPot + DIGO (MW) * kFM * |
|
|
|
|
| PrecPotDIGO |
|
|
|
| b) | If DRP DIGO |
|
|
|
|
| REM DIGO (Ps./month) = MAX {REM BASE; DRP (MW) * kFM * PrecPotDIGO * DRP / DIGO} |
Where kFM = hours of the month outside of agreed maintenance period/hours of the month
The total remuneration for available capacity of generators will depend on whether they declared DIGO or not.
Total Remuneration for Available Capacity for Generators that do not declare DIGO: Total remuneration for available capacity will be calculated, for generators that do not declare DIGO, exclusively pursuant to the concepts explained above and its application will be made considering the Utilization Factor (FU):
| · | If FU 30% REM TOT (Ps./month) = REM BASE * 0.7 |
| · | If 30 %= FU 70% REM TOT (Ps./month) = REM BASE * (FU * 0.75+0,475) |
| · | If FU = 70% REM TOT (Ps./month) = REM BASE |
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Total Remuneration for Available Capacity for Generators that declare DIGO: The sum of the remunerations mentioned above and its application will be made considering the Utilization Factor (FU):
| · | If FU 30% REM TOT (Ps./month) = REM DIGO * 0.7 |
| · | If 30 %= FU 70% REM TOT (Ps./month) = REM DIGO * (FU * 0.75+0,475) |
| · | If FU = 70% REM TOT (Ps./month) = REM DIGO |
The following picture show the effect of FU on Available Capacity Remuneration:
Energy Remuneration
Energy remuneration is comprised of two items: (i) generated energy and (ii) operated energy. This remuneration is determined at the connection node of the generator.
Remuneration for Generated Energy
For conventional thermal generation, a maximum value (depending on the kind of fuel used by the generation unit “g”) will be considered in concept of non-fuel variable costs (CostoOYMxComb), as indicated in the below chart, for the energy delivered in each hour:
Technology/Scale |
| CostoOYMxComb | ||||||
| Natural Gas (Ps./MWh) |
| FuelOil/GasOil (Ps./MWh) |
| BioComb (Ps./MWh) |
| Mineral Coal (Ps./MWh) | |
Combined-cycle Large 150 MW |
| 310 |
| 542 |
| 774 |
| – |
Combined-cycle Small = 150 MW |
| 310 |
| 542 |
| 774 |
| – |
Steam Turbine Large 100 MW |
| 310 |
| 542 |
| 774 |
| 929 |
Steam Turbine Small = 100 MW |
| 310 |
| 542 |
| 774 |
| 929 |
Gas Turbine Large 50 MW |
| 310 |
| 542 |
| 774 |
| – |
Gas Turbine Small = 50 MW |
| 310 |
| 542 |
| 774 |
| – |
Internal Combustion Engines=42MW |
| 310 |
| 542 |
| 774 |
| – |
Remuneration for Operated Energy
Operated Energy remuneration is 108 $/MWh and applies to the addition of rotating capacity along the month. When a generating unit is operating under forced condition, requested by the generator, Operated Energy remuneration will be determined considering only 60% of its installed capacity.
Maximum Thermal Dispatch Hours
Maximum Thermal Dispatch Hours (HMRT) applies to the average delivered capacity during the 25 hours of HMRT in the relevant month, earlier described as HMRT-1 and HMRT-2.
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Remuneration price “PrecPHMRT” is 48,375 Ps./MW, and is affected by seasonal factor FRPHMRT, as indicated in the following chart:
HMRT |
| FRPHMRT | ||||||
| Summer |
| Autumn |
| Winter |
| Spring | |
HMRT-1 |
| 1.2 |
| 0.2 |
| 1.2 |
| 0.2 |
HMRT-2 |
| 0.6 |
| – |
| 0.6 |
| – |
Remuneration during HMRT (RemPHMRT) for thermal plants is determined as:
RemPHMRT = Potgemhrt1 * PrecPHRT * FRPHMRT1 + Potgemhrt2 * PrecPHRT * FRPHMRT2
Where
Potgemhrt1: average generated capacity during HMRT-1.
Potgemhrt2: average generated capacity during HMRT-2.
Remuneration of hydroelectrical generators
Remuneration of Authorized Hydroelectrical Generators is comprised of (i) a payment for monthly available capacity and (ii) a payment for energy (which is comprised of two items: (a) generated energy and (b) operated energy).
Remuneration for Available Capacity
This remuneration will depend on the DRP and a capacity base price. The latter will be determined pursuant to the following values considering the technology of the generation unit and its size.
Technology/Scale |
| Capacity Base Price (PrecBasePot) (Ps./MW-month) |
Large HI Units with P 300 MW |
| 134,095 |
Medium size HI Units with P 120 and 300 MW |
| 178,794 |
Small HI Units with P 50 and 120 MW |
| 245,842 |
Renewable HI Units with P 50 MW |
| 402,287 |
Large HB pumping Units with P 300 MW |
| 134,096 |
Medium size HB pumping Units with P 120 and 300 MW |
| 178,794 |
Prices shown on table were increased by maintenance factor (1.05)
DRP is the average monthly available capacity corresponding to the “m” month of each generation unit (“g”) that is not under programed and agreed maintenance and that will be calculated for hydroelectrical authorized generators considering the monthly average real availability determined independently from the real level of the dam or the inputs and expenditures. The application in the calculations for month “m” is made taking into consideration the values registered in the month. In the case of hydroelectrical pumping units (HB), it must be considered, for the evaluation of its availability, both the corresponding to its operation as a turbine in all the hours of the period, as well as its availability as pump in all the hours of the period.
Following the abovementioned, remuneration of availability capacity (REM PBASE Ps./month) is calculated pursuant to the following formula:
REM PBASE (Ps./month) = PrecBasePot * DRP (MW) * kFM
Where
kFM: hours of the month outside agreed maintenance period/hours of the month
Remuneration for Energy
This remuneration, which is determined at the connection node of the generator, is comprised of two items (i) remuneration for generated energy and (ii) remuneration for operated energy.
With respect to the remuneration for generated energy, in each hour, the price of the energy generated will be 271 Ps./MWh.
Regarding remuneration for operated energy, generators will receive a monthly remuneration, represented by the integration of hourly powers in the period, equal to 108 Ps./MWh. The hourly volume of operated energy must correspond to the optimal dispatch for the fulfilment of energy and reservoirs assigned.
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With relation to hydroelectrical pumping plants operating as a synchronic compensator, the price of the energy generated will be 77 Ps./MVAr and 108 Ps-/MWh for its operated energy.
Maximum Thermal Dispatch Hours
This remuneration is applicable to the average operated available capacity of a hydroelectrical power plants during the 25 HMRT indicated as HMRT1 and HMRT2.
HMRT Remuneration | ||
Technology/Scale |
| PrecPOHMRT |
| Ps./MW-HMRT | |
Hydro 300 MW |
| 35,475 |
Hydro 120 and = 300 MW |
| 41,925 |
Hydro 50 and = 120 MW |
| 41,925 |
Renewable Hydro 50 MW |
| 45,150 |
Pump 300 MW |
| 35,475 |
Pump 120 and = 300 MW |
| 41,925 |
Remuneration price “PrecPOHMRT”, is affected by seasonal factor FRPHMRT, as indicated in the following chart:
HMRT |
| FRPHMRT |
|
| ||||
| Summer |
| Autumn |
| Winter |
| Spring | |
HMRT-1 |
| 1.2 |
| 0.2 |
| 1.2 |
| 0.2 |
HMRT-2 |
| 0.6 |
| – |
| 0.6 |
| – |
Remuneration during HMRT “RemPOHMRT” for hydroelectrical power plants is determined as follows:
RemPHMRT = Potopmhrt1 * PrecPOHRT * FRPHRT1 + Potopmhrt2 * PrecPOHRT * FRPHRT2
Where
Potopmhrt1: average operated capacity during HMRT-1.
Potgemhrt2: average operated capacity during HMRT-2.
Other generating technologies in the spot market
Resolution 440/21 sets forth that energy generated form non-conventional resources (solar, eolic, biomass, biogas) will be priced at 2.167 Ps./MWh for its generated energy.
Following this, the Non-Conventional Energy Remuneration will be calculated by the hourly integration in the month of the energy generated by generation unit “g” in each hour “h” (EGengh) by PENC in that hour:
REM ENC ($/month) = ∑h.month (PENC * EGengh)
Generation coming from units that are in a stage prior to commercial authorization will be granted 50% of the corresponding remuneration until reaching such authorization.
Temporary changes: due to extraordinary energy exportation requirements, Energy Secretariat instructed CAMMESA to consider for all Authorized Thermal Generators, the use of “FU” equal to 70% for capacity remuneration calculations, and also sets a plus in energy price (generated energy) that depends on monthly energy exportations. These changes are valid from September 2021 to February 2022 through Resolution No.1037/2021.
The Previous Remuneration Schemes
Resolution SE No. 31/20
On February 27, 2020, the Secretary of Energy of the National Ministry of Production Development issued Resolution 31/20, which abrogated Resolution No. 1/19, reducing the remuneration scheme applicable from February 1, 2020 for Authorized Generators in the Wholesale Electricity Market.
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Remuneration of thermal generators
Resolution 31/20 sets forth, regarding generation from thermal sources, that authorized thermal generators will be remunerated for (i) monthly available capacity and (ii) energy.
Remuneration for available capacity is comprised of (i) a minimum price associated to the real available capacity (DRP) and (ii) a price for guaranteed capacity according to the fulfilment of an offered guaranteed capacity availability (DIGO). DIGO is the capacity availability offered by an authorized thermal generator for each “g” generation unit for each DIGO period (which are: (a) summer period: December-January-February, (b) winter period: June-July-August, (c) remaining periods: (c1) March-April-May, (c2) September-October-November). The power remuneration will be affected according to the Utilization Factor (FU) of the generation unit.
Remuneration for energy will be the sum of two items: (i) Generated Energy and (ii) Operated Energy (associated to the rotating power in each hour). The hourly volume of Operated Energy must correspond with the optimal dispatch for the fulfilment of energy and reserves assigned. Remuneration for energy is determined at the connection node of the generator.
In addition, Resolution 31/20 introduced a new remuneration criteria, concerning the first 25 (HMRT-1) and second 25 (HMRT-2) hours of maximum thermal dispatch (“HMRT”) in the month, also establishing a distinction between the summer period, the winter period and the remaining periods.
All remuneration prices are set in Argentine pesos with a monthly adjustment parameter, considering IPIM and IPC indices, according with the following formula:
Where
“IPIM”: WPI, published by INDEC
“IPC”: CPI, published by INDEC
However, the Energy Secretariat instructed CAMMESA not to use the updated formula.
Remuneration for Available Capacity: the base price to remunerate capacity from thermal sources will be determined pursuant to the following values of capacity base price (PrecBasePot), price of guaranteed capacity (PrecPotDIGO) and Utilization Factor (FU):
Technology / Scale |
| PrecBasePot (Ps./MW-month) |
Combined-cycle Large 150 MW |
| 100,650 |
Combined-cycle Small = 150 MW |
| 112,200 |
Steam Turbine Large 100 MW |
| 143,550 |
Steam Turbine Small = 100 MW |
| 171,600 |
Gas Turbine Large 50 MW |
| 117,150 |
Gas Turbine Small = 50 MW |
| 151,800 |
Internal Combustion Engines=42MW |
| 171,600 |
Technology/Scale |
| PrecPotDIGO (Ps./MW-month) | ||
| Winter and Summer |
| Remaining periods | |
Combined-cycle Large 150 MW |
| 360,000 | 270,000 | |
Combined-cycle Small = 150 MW |
| 360,000 | 270,000 | |
Steam Turbine Large 100 MW |
| 360,000 | 270,000 | |
Steam Turbine Small = 100 MW |
| 360,000 | 270,000 | |
Gas Turbine Large 50 MW |
| 360,000 | 270,000 | |
Gas Turbine Small = 50 MW |
| 360,000 | 270,000 | |
Internal Combustion Engines=42MW |
| 420,000 | 330,000 | |
Utilization Factor (FU):
In each “n” month of economic transactions a FU will be calculated for each generation unit (“g”), which is defined as:
FUgn = GenAñoMóvn / (DRPg.n.prom x hs año móvil)
Being DRPg.n.prom: the average real available capacity of the generation unit “g” in the mobile year prior to the “n” month in which the declaration of economic transaction (DTE) is issued.
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Where:
mes = month.
kFM = hours of the month outside the agreed maintenance period, divided by the hours of the month.
Hs año móvil: the total hours of the mobile year prior to the “n” month in which the DTE is issued.
GenAñoMovn: the total generation of the generation unit “g” in the mobile year prior to the “n2” month in which the DTE is issued.
In addition to the abovementioned, the remuneration for available capacity will also depend on the real available capacity (DRP), which is the average monthly availability corresponding to the “m” month of each generation unit (“g”) that is not under programmed and agreed maintenance and that will be calculated for thermal authorized generators considering the hourly values registered during the month. The application in the calculation for the “m” month will be made taking into consideration the values registered during the month.
Following the abovementioned, Resolution No. 31/20 sets forth that the monthly remunerating for available capacity shall be proportional to the monthly availability, the Utilization Factor of the generation unit and a price that will vary periodically.
In that sense, the resolution under comment differences remuneration of generators that do not declare DIGO from generators that do declare it.
In case of generators that do not declare DIGO, the remuneration is the DRP of the month valued at the capacity base price mentioned above. Availability is calculated detracting forced unavailable capacity and unavailable power due to agreed or programmed maintenance works.
REM BASE (Ps./month) = PrecBasePot * DRP (MW) * kFM
Where:
kFM: hours of the month outside agreed maintenance period/hours of the month
In case of generators that declare DIGO, their remuneration for offered guaranteed capacity is a remuneration of available capacity (with cap as physical magnitude to be computed in the DIGO) that is valued as PrecPotDIGO (Ps./MW-month) according to following:
| c) | If DRP ≥ DIGO |
|
|
|
|
| REM DIGO (Ps./month) = (DRP – DIGO) (MW) * kFM * PrecMinPot + DIGO (MW) * kFM * |
|
|
|
|
| PrecPotDIGO |
|
|
|
| d) | If DRP DIGO |
|
|
|
|
| REM DIGO (Ps./month) = MAX {REM BASE; DRP (MW) * kFM * PrecPotDIGO * DRP / DIGO} |
Where:
kFM = hours of the month outside of agreed maintenance period/hours of the month
The total remuneration for available capacity of generators will depend on whether they declared DIGO or not.
Total Remuneration for Available Capacity for Generators that do not declare DIGO: Total remuneration for available capacity will be calculated, for generators that do not declare DIGO, exclusively pursuant to the concepts explained above and its application will be made considering the Utilization Factor (FU):
| · | If FU 30% REM TOT (Ps./month) = REM BASE * 0.6 |
| · | If 30 %= FU 70% REM TOT (Ps./month) = REM BASE * (FU * 0.3) |
| · | If FU = 70% REM TOT (Ps./month) = REM BASE |
Total Remuneration for Available Capacity for Generators that declare DIGO: The sum of the remunerations mentioned above and its application will be made considering the Utilization Factor (FU):
| · | If FU 30% REM TOT (Ps./month) = REM DIGO * 0.6 |
| · | If 30 %= FU 70% REM TOT (Ps./month) = REM DIGO * (FU * 0.3) |
| · | If FU = 70% REM TOT (Ps./month) = REM DIGO |
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Energy Remuneration
Energy remuneration is comprised of two items: (i) generated energy and (ii) operated energy. This remuneration is determined at the connection node of the generator.
Remuneration for Generated Energy
For conventional thermal generation, a maximum value (depending on the kind of fuel used by the generation unit “g”) will be considered in concept of non-fuel variable costs (CostoOYMxComb), as indicated in the below chart, for the energy delivered in each hour:
Technology/Scale |
| CostoOYMxComb | ||||||
| Natural Gas (Ps./MWh) |
| FuelOil/GasOil (Ps./MWh) |
| BioComb (Ps./MWh) |
| Mineral Coal (Ps./MWh) | |
Combined-cycle Large 150 MW |
| 240 |
| 420 |
| 600 |
| – |
Combined-cycle Small = 150 MW |
| 240 |
| 420 |
| 600 |
| – |
Steam Turbine Large 100 MW |
| 240 |
| 420 |
| 600 |
| 720 |
Steam Turbine Small = 100 MW |
| 240 |
| 420 |
| 600 |
| 720 |
Gas Turbine Large 50 MW |
| 240 |
| 420 |
| 600 |
| – |
Gas Turbine Small = 50 MW |
| 240 |
| 420 |
| 600 |
| – |
Internal Combustion Engines=42MW |
| 240 |
| 420 |
| 720 |
| – |
Remuneration for Operated Energy
Operated Energy remuneration is 84 $/MWh and applies to the addition of rotating capacity along the month. When a generating unit is operating under forced condition, requested by the generator, Operated Energy remuneration will be determined considering only 60% of its installed capacity.
Maximum Thermal Dispatch Hours
Maximum Thermal Dispatch Hours (HMRT) applies to the average delivered capacity during the 25 hours of HMRT in the relevant month, earlier described as HMRT-1 and HMRT-2.
Remuneration price “PrecPHMRT” is 37,500 Ps./MW, and is affected by seasonal factor FRPHMRT, as indicated in the following chart:
HMRT |
| FRPHMRT | ||||||
| Summer |
| Autumn |
| Winter |
| Spring | |
HMRT-1 |
| 1.2 |
| 0.2 |
| 1.2 |
| 0.2 |
HMRT-2 |
| 0.6 |
| – |
| 0.6 |
| – |
Remuneration during HMRT (RemPHMRT) for thermal plants is determined as:
RemPHMRT = Potgemhrt1 * PrecPHRT * FRPHMRT1 + Potgemhrt2 * PrecPHRT * FRPHMRT2
Where:
Potgemhrt1: average generated capacity during HMRT-1.
Potgemhrt2: average generated capacity during HMRT-2.
Remuneration of hydroelectrical generators
Remuneration of Authorized Hydroelectrical Generators is comprised of (i) a payment for monthly available capacity and (ii) a payment for energy (which is comprised of two items: (a) generated energy and (b) operated energy).
_____________________
3 Comercial
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Remuneration for Available Capacity
This remuneration will depend on the DRP and a capacity base price. The latter will be determined pursuant to the following values considering the technology of the generation unit and its size.
Technology/Scale |
| Capacity Base Price (PrecBasePot) (Ps./MW-month) |
Large HI Units with P 300 MW |
| 99,000 |
Medium size HI Units with P 120 and 300 MW |
| 132,000 |
Small HI Units with P 50 and 120 MW |
| 181,500 |
Renewable HI Units with P 50 MW |
| 297,000 |
Large HB pumping Units with P 300 MW |
| 99,000 |
Medium size HB pumping Units with P 120 and 300 MW |
| 132,000 |
DRP is the average monthly available capacity corresponding to the “m” month of each generation unit (“g”) that is not under programed and agreed maintenance and that will be calculated for hydroelectrical authorized generators considering the monthly average real availability determined independently from the real level of the dam or the inputs and expenditures. The application in the calculations for month “m” is made taking into consideration the values registered in the month. In the case of hydroelectrical pumping units (HB), it must be considered, for the evaluation of its availability, both the corresponding to its operation as a turbine in all the hours of the period, as well as its availability as pump in all the hours of the period.
Following the abovementioned, remuneration of availability capacity (REM PBASE Ps./month) is calculated pursuant to the following formula:
REM PBASE (Ps./month) = PrecBasePot * DRP (MW) * kFM
Where:
kFM: hours of the month outside agreed maintenance period/hours of the month
Remuneration for Energy
This remuneration, which is determined at the connection node of the generator, is comprised of two items (i) remuneration for generated energy and (ii) remuneration for operated energy.
With respect to the remuneration for generated energy, in each hour, the price of the energy generated will be 210 Ps./MWh.
Regarding remuneration for operated energy, generators will receive a monthly remuneration, represented by the integration of hourly powers in the period, equal to 84 Ps./MWh. The hourly volume of operated energy must correspond to the optimal dispatch for the fulfilment of energy and reservoirs assigned.
With relation to hydroelectrical pumping plants operating as a synchronic compensator, the price of the energy generated will be 60 Ps./MVAr and 84 Ps-/MWh for its operated energy.
Maximum Thermal Dispatch Hours
This remuneration is applicable to the average operated available capacity of a hydroelectrical power plants during the 25 HMRT indicated as HMRT1 and HMRT2.
HMRT Remuneration | ||
Technology/Scale |
| PrecPOHMRT |
| Ps./MW-HMRT | |
Hydro 300 MW |
| 25.700 |
Hydro 120 and = 300 MW |
| 32.500 |
Hydro 50 and = 120 MW |
| 32.500 |
Renewable Hydro 50 MW |
| 32.500 |
Pump 300 MW |
| 32.500 |
Pump 120 and = 300 MW |
| 32.500 |
Remuneration price “PrecPOHMRT”, is affected by seasonal factor FRPHMRT, as indicated in the following chart:
HMRT |
| FRPHMRT | ||||||
| Summer |
| Autumn |
| Winter |
| Spring | |
HMRT-1 |
| 1.2 |
| 0.2 |
| 1.2 |
| 0.2 |
HMRT-2 |
| 0.6 |
| – |
| 0.6 |
| – |
Remuneration during HMRT “RemPOHMRT” for hydroelectrical power plants is determined as follows:
RemPHMRT = Potopmhrt1 * PrecPOHRT * FRPHRT1 + Potopmhrt2 * PrecPOHRT * FRPHRT2
Where:
Potopmhrt1: average operated capacity during HMRT-1.
Potgemhrt2: average operated capacity during HMRT-2.
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Other generating technologies in the spot market
Resolution 31/20 sets forth that energy generated form non-conventional resources (solar, eolic, biomass, biogas) will be priced at 1680 Ps./MWh for its generated energy.
Following this, the Non-Conventional Energy Remuneration will be calculated by the hourly integration in the month of the energy generated by generation unit “g” in each hour “h” (EGengh) by PENC in that hour:
REM ENC ($/month) = ∑h.month (PENC * EGengh)
Generation coming from units that are in a stage prior to commercial authorization will be granted 50% of the corresponding remuneration until reaching such authorization.
Resolution No. 281-E/17: The Renewable Energy Term Market in Argentina
On August 22, 2017, the Ministry of Energy and Mining published Resolution No. 281-E/17 (“Resolution No. 281”) for the Renewable Energy Term Market (private PPAs between generators and Large Users, self-generation, co-generation and traders). Resolution No. 281was later modified by means of Resolution No. 230/2019 issued by the former Governmental Secretariat of Energy, and Resolutions No. 551/2021 and 14/2022 issued by the Secretariat of Energy.
Resolution No. 281 seeks to promote and encourage a dynamic participation in the term market and to foster the increase of private agreements between the WEM’s agents and participants. Its aim is to provide a feasible alternative for the purchase of energy to tenders by CAMMESA.
Resolution No. 281 makes it possible for Large Users to comply with their renewable energy consumption quotas through either (i) the joint purchase system (i.e., through CAMMESA), (ii) the execution of a private PPA or (iii) the development of a self-generation project or a co-generation project.
As a general principle, PPAs executed in the term market (outside the joint purchase system) may be freely negotiated between the parties with respect to term, priorities, prices and other contractual conditions.
Section 7 of Resolution No. 281 provides that, in the case of curtailment, the following power generation plants will have (i) equal dispatch priority between them and (ii) first dispatch priority over renewable generation projects operating in the term market without an assigned dispatch priority:
| 1. | run-of-the-river hydropower plants and renewable power plants having commenced commercial operation prior to January 1, 2017; |
|
|
|
| 2. | power plants supplying energy pursuant to PPAs executed in connection with Resolutions No. 712/2009 or No. 108/2011 having commenced commercial operation prior to January 1, 2017; |
|
|
|
| 3. | renewable power plants supplying energy pursuant to PPAs executed with CAMMESA through the RenovAr Program (e.g., the La Castellana Project and the Achiras Project); |
|
|
|
| 4. | renewable power plants supplying energy pursuant to Resolution MINEM No. 202/2016; and |
|
|
|
| 5. | renewable power plants operating in the term market (e.g., private PPAs) which have obtained dispatch priority in accordance with the regime established pursuant to Resolution No. 281. |
Only the expansion of the abovementioned projects need to file the request for dispatch priority with CAMMESA, who will then evaluate submissions on a quarterly basis and prepare a list of granted dispatch priorities in interconnection points or transmission corridors with restrictions to the transmission capacity.
Evolution of Supply and Demand in the Argentine Energy Sector Structure
Structural Characteristics of the Energy Sector
The evolution of the demand and the energy consumption in Argentina is correlated with the evolution of the GDP, which implies that the higher the economic growth, the higher the energy demand. For example, the historical growth of energy consumption was of 2.89% annually over the past 60 years, with an annual average of 2.0% since 2002, although between 2002 and 2021 the economic growth rose to an average of 3% annually (including exports and losses).
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The growth of energy consumption during the last decade is similar to the historical average, since it was not driven by a large increase in consumption of the industrial sector, but predominantly by that of the residential and commercial sectors, as noted in the consumption parameters of gas, gasoline and especially electric power.
The elasticity of energy consumption in relation to the GDP during the last two decades is lower than in earlier decades, so restrictions on energy demand or the need for energy imports, if domestic supply is insufficient, could increase if the industrial sector expands in the future.
The restrictions on the supply of certain energy products such as natural gas in the last cycle of high economic growth and the relatively moderate growth in energy demand in broad terms, are based primarily on problems related to the supply of these energy products and also on a significant growth of the demand of the residential and commercial segments in a context of weak industrial activity with few new expansions of greater productive capacity for large energy consumers.
The structure of electric energy consumption in Argentina is strongly dependent on hydrocarbons, at approximately 64% in 2021, compared to 61.36% in 2020, 61.06% in 2019, 63.86% in 2018 and 64.87% in 2017. Large amounts of natural gas liquefied natural gas and gas oil are imported in order to try to satisfy demand. During 2019 such imports decreased, mainly due to an increase in the domestic production of natural gas. However, demand for natural gas is usually unsatisfied during the winter in the industrial segment and in the thermoelectric generation segment. In certain circumstances, the Argentine Government has imposed restrictions on consumption because of the lack of adequate supply of gas to supply other segments that do not have the capacity to replace natural gas with other fuels (among others, propane, butane and fuel).
Although current energy consumption in Argentina signals a dependence on hydrocarbons, we believe that Argentina is currently undergoing an important shift to a more modern and diversified energy mix arising from the inclusion of renewable energy into the mix, in accordance with the requirements set forth in Law No. 27,191 of 2015.
Source: Secretariat of Energy
As a summary, the following characteristics are specific to energy demand and supply in Argentina:
| · | Atypical structure, with a bias towards oil and gas, which is a characteristic of countries with large reserves of hydrocarbons such as Middle Eastern countries, Russia, African oil-producing countries, and Venezuela. |
| · | 54% of the energy supply is dependent on natural gas, which is higher than in most countries that have a large surplus production of natural gas. |
| · | Stagnation in the local energy supply since investments in recent years in the oil and gas sector have been insufficient to effectively increase domestic supply enough to satisfy the demand. |
| · | Enhanced demand due to the abnormally low prices of gas and electric power in the residential and commercial sectors during the 2012-2016 period, which caused the growth rate of residential energy consumption to be higher than the usual trend, which was partially reverted during the 2017-2019 period. |
Structure of the Electric Power Supply in Argentina
The nominal installed capacity in Argentina was reported by CAMMESA to be 42,989 MW as of December 31, 2021. However, the operational electric power generation capacity effectively available at any given time could be estimated at around 32,274 MW as an average of 2020. Availability estimated by CAMMESA for thermal units is approximately 80% due to the lack of proper fuel supply, difficulties in achieving nominal efficiency and unavailability of several generating units under maintenance. Moreover, the generation supply depends heavily on liquid fuel use that diminishes capacity availability and there are certain transmission restrictions.
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Over recent decades, the Argentine government (spanning administrations with different ideological orientation) has favored the deployment of thermoelectric generating units. One reason for this is that these units require smaller capital investments and take less time to deploy compared to other types of generating units. The increased dependency on hydrocarbons for these new power plants was not considered a disadvantage since the required fuels have always been produced in Argentina and the production has always been predictable and growing. However, the constant deployment of thermoelectric generation has increased the demand for fossil fuels, particularly those based on natural gas, and has led to shortages and the imposition of certain restrictions on the provision to thermal generators of locally produced fuels.
During the 1990s, private sector investors also concentrated their investments in thermoelectric generation, almost without exception. The economic crisis of 2002 accelerated even more the tendency to invest in thermoelectric plants, given their lower cost of startup. After the crisis of 2002, investments in the electrical sector continued mainly with state intervention, expanding the installed capacity based on thermoelectric generation but without meeting the increasing demand. The financial constraints of the Argentine Government in the last decades, the high amount of capital needed and the long periods necessary to develop the projects have negatively impacted on the decision of the Argentine Government to invest and deploy hydroelectric and nuclear power plants. In addition, the recurrent fiscal crises of the recent past have forced the Argentine Government to delay or cancel major projects that would have increased and diversified Argentina’s generation capacity.
Nominal Power Generation Capacity
Nominal power generation capacity is dominated by thermoelectric generation. A considerable number of thermoelectric power units experience high levels of unavailability, especially during the winter, due to fuel provision restrictions.
In the summer of 2021, the maximum power consumed reached 27,088 MW on December 29.
There are three main centers of electric power supply in Argentina:
| · | Buenos Aires-Greater Buenos Aires-Coastline |
| · | Comahue |
| · | Northeast Argentina |
Electric power supply and demand were linked in the past by a radial system to Buenos Aires. This system presented risks of instability in various regions whose demand had grown but had insufficient local generation (e.g., Cuyo, Northwest Argentina in Salta, Central and Greater Buenos Aires). For this reason, the Argentine Government changed the system and now is using a peripheral system. The Argentine Government has made very large investments in a substantial expansion of electric transmission, totaling 500 kV. Such investments include laying peripheral high voltage lines totaling 550 kV (that may not have an immediate economic impact but will have positive effects on the system in the long-term) in the following locations:
| · | Northeast and northwest Argentina |
| · | Comahue-Cuyo |
| · | Southern Patagonia |
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The following chart shows the development of electric power generation by type of source:
Source: CAMMESA
The following chart shows the development of electric power generation capacity by type of source:
Source: CAMMESA
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Renewable Energy Generation in Argentina
Certain regions of Argentina benefit from levels of wind or sunlight that provide a strong potential for renewable energy generation. The maps below show the mean wind speed at 80 meters of elevation and the average global horizontal irradiance in Argentina, respectively.
Average Wind Speeds
Source: Vaisala - 3Tier
Average Global Horizontal Solar Irradiance (GHI)
Source: Vaisala - 3Tier
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The Structure of Electric Power Demand in Argentina
Electric power demand depends to a significant extent on economic and political conditions prevailing from time to time in Argentina, as well as seasonal factors. In general, the demand for electric power varies depending on the performance of the Argentine economy, as businesses and individuals generally consume more energy and are better able to pay their bills during periods of economic stability or growth. As a result, electric power demand is affected by Argentine Governmental actions concerning the economy, including with respect to inflation, interest rates, price controls, foreign exchange controls, taxes and energy tariffs.
The following chart shows the demand for electric power in 2021 by customer type:
Source: CAMMESA
The following chart shows the evolution of the demand for electric power over the last several years:
Source: CAMMESA
The following chart shows the power demand from November 2006 to February 2021:
Source: CAMMESA
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The correlation between the evolution of GDP and electric power demand is strong, although when there is a strong reduction of the GDP, electric power demand falls relatively little. It should also be noted that, in an environment of low economic growth, electric power demand grows at rates higher than the GDP, as shown below:
Source: CAMMESA, INDEC
CAMMESA divides Argentina into regions that have similar characteristics in terms of demand, socio-economic characteristics and electric subsystems. Such regions are: (i) the City of Buenos Aires and its suburbs, (ii) the Province of Buenos Aires, (iii) Santa Fe and Northwest Buenos Aires, (iv) the Center, (v) the Northwest, (vi) Cuyo, (vii) the Northeast, (viii) Comahue and (ix) Patagonia.
Demand is significantly concentrated in the areas of the City of Buenos Aires, the Province of Buenos Aires, Santa Fe and Northwest Buenos Aires, which comprises approximately 62 % of the demand. Changes to the concentration of the demand structure are not substantial over the period of measurement.
The chart below shows electricity demand by region for 2021:
Source: CAMMESA
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Seasonality also has a significant impact on the demand for electric power, with electric power consumption peaks in summer and winter. The impact of seasonal changes in demand is registered primarily among residential and small commercial customers. The seasonal changes in demand are attributable to the impact of various climatological factors, including weather and the amount of daylight time, on the usage of lights, heating systems and air conditioners.
The impact of seasonality on industrial demand for electric power is less pronounced than on the residential and commercial sectors for several reasons. First, different types of industrial activity by their nature have different seasonal peaks, such that the effect of climate factors on them is more varied. Second, industrial activity levels tend to be more significantly affected by the economy, and with different intensity levels depending on the industrial sector.
Energy demand throughout the hours of each month grew in 2006, reflecting a sharp increase in industrial activity and mass consumption in the economy. Such demand declined due to restrictions on industrial power consumption in the winter of 2007, and the international crisis at the end of 2008 and early 2009. However, such decline in consumption reversed between mid-2011 and 2016 due to a growth in demand. Between 2016 and 2018, electricity demand remained stable, and decreased in 2019 due to a general decrease of the economic activity in Argentina. For 2020, electricity demand continued to decrease due to a decline in economic activity and the impact of COVID-19. In 2021, electricity demand recovered from the previous year, mainly due to an increase in industrial demand.
A direct annual analysis—as opposed to a twelve-month moving average, which is useful to show inertial trend changes (i.e., the underlying trend that includes only a few months and therefore better shows gradual changes to stability)—shows growth rates in energy demand during 2010 and early 2011, with an abrupt slowdown (including negative values) in 2012 and, after the winter of 2012, an increase in energy demand during 2013. In December 2013 and January 2014, there was exponential growth in demand by residential and commercial consumers due to the heat wave that hit the central region of Argentina during those periods. In December 2014, the demand growth trend was reversed with a sharp drop in demand with the return of normal temperatures. The demand for electric power in the residential sector resumed a high growth trend in 2015. In 2016, residential consumers demand increased 4.5%, despite moderate increases in rates to a small portion of consumers. During 2017, 2018, 2019 and 2020, residential demand decreased 2.03%, increased 1.99%, decreased 2.80%, and increased 8%, respectively, as compared to the same period the previous year, in the case of the decrease during 2019, due to a GRP drop of 2.20% in 2019. In 2020, due to the , COVID-19 pandemic, the Quarantine and other restrictive measures taken by the Argentine Government, citizens had to work remotely and thus staying at their houses for longer periods of time. Schools and universities were closed for most part of 2020. On the other hand, during 2020 there was no residential electricity tariff increase and services cuts due to non-payment was suspended, which may have contributed to residential users consuming more electricity. During 2021, as a consequence of the removal of restrictive measures associated with the COVID-19 pandemic, demand of electricity recovered from the previous year (+5.2%), mainly due to a 13.2% increase in industrial demand and a 4.4% increase in commercial demand. Residential demand in 2021 increased 9.5% compared to 2020, mainly explained by the fact that there was not any increase in residential electricity tariffs, in a context of increasing energy generation costs for the entire system.
In addition to the growth of energy demand during the 2011-2016, which placed pressure on the supply of fuels to thermal plants, demand also affects the availability of generation plants to meet peak demand for power at nighttime during the winter or during the afternoon in the summer.
To minimize the risks of sudden interruptions to the residential and commercial segment in 2013, there were scheduled supply interruptions in December 2013 and January 2014, which was similar to what occurred in the winter of 2010 and 2011 but did not reach the extraordinary levels of the winter of 2007. No interruptions were necessary in 2012. During the summer and winter of 2015, it was not necessary to apply restrictions to industrial consumers to supply residential electric power demand, although there were some forced interruptions due to certain problems with electrical distribution. However, during February 2016, certain restrictions to consumption of an approximate amount of 1,000 MW were applied by CAMMESA and the Ministry of Energy and Mining due to the above average temperatures recorded in February 2016.
During January and February 2016 there were successive high peaks of consumption of electric power for a business day, after two years of not surpassing the previous record reached in January 23, 2014. A peak of consumption of 25,380 MW was reached on February 12, 2016, but restrictions were implemented to the demand of the distributors of Buenos Aires, Greater Buenos Aires and La Plata. A new peak of consumption of 26,320 MW was reached on February 8, 2018, without major demand restrictions.
In addition, on January 29, 2019, a new electric energy consumption record was reached with a total of 544.4 GWh consumed, but no restrictions on demand, as the ones mentioned above, were implemented.
|
| Power and energy consumption records |
| |||||||||||||||||
|
| Previous records |
|
| New records |
|
| Variation (%) |
|
| Variation (MW) |
| ||||||||
|
| Peak of electric power capacity (MW) |
|
|
| |||||||||||||||
Working day |
| Feb 8, 2018 |
|
| 26.320 |
|
| Dec 29,2021 |
|
| 27.088 |
|
|
| 2.9 | % |
|
| 768 |
|
Saturday |
| Dec 30, 2017 |
|
| 22.543 |
|
| Dec 31, 2021 |
|
| 23.577 |
|
|
| 4.6 | % |
| 1034 |
| |
Sunday |
| Feb 28, 2017 |
|
| 22.346 |
|
| Jun 27, 2021 |
|
| 23.301 |
|
|
| 4.3 | % |
|
| 955 |
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||||
|
| Energy (GWh) |
|
| Variation(%) | Variation(GWh) |
| |||||||||||||
Working day |
| Feb 8, 2018 |
|
| 543.0 |
|
| Jan 29, 2019 |
|
| 544.4 |
|
|
| 0.3 | % |
|
| 1.4 |
|
Saturday |
| Jan 18, 2014 |
|
| 477.9 |
|
| Dec 30, 2017 |
|
| 478.4 |
|
|
| 0.1 | % |
|
| 0.5 |
|
Sunday |
| Feb 26, 2017 |
|
| 437.6 |
|
| Jan 24, 2021 |
|
| 457.8 |
|
|
| 4.6 | % |
|
| 20.2 |
|
Source: CAMMESA
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The peak demand of power of December 29, 2021, was covered with a thermal supply of 16,038 MW, a hydroelectric supply of 5,929 MW, nuclear supply of 1,339 MW, and renewable energy supply of 2,791 MW.
As with the case of natural gas, the strong seasonality of electric power demand in Argentina—both in terms of energy and power—influences the needs for investment since investments are made to meet the maximum peak winter demand, which generates significant surpluses at other times of the year that cause lower costs and competition in those periods. The maximum demand for electric power is during the afternoon or evening hours in summer. In the case of winter, the maximum demand is generally during the evening, due to the high use of electric heaters that are preferred by consumers because of the differential cost and simplicity in comparison with natural gas heaters.
Not all the generation capacity is available at times of peak demand. Both in summer and especially in winter, there is an effective generation capacity to meet the demand. The effective capacity available (which means the capacity available) is significantly lower than the nominal installed capacity.
Despite all efforts, it is unlikely for there to be complete nominal capacity available at any given time. Instead, the power generation capacity industry generally anticipates and considers a percentage of unavailability that can range between approximately 20% and 25%.
This critical variable is central to the efforts made by CAMMESA and the generators to invest in the proper maintenance of the units. Although the unavailability factor over the long-term in the thermal plants in Argentina has historically been approximately 30%, it fell below 20% for a period in the early 2000s. In general, the unavailability factor of the hydroelectric plants in Argentina is not significant. The Yacyretá hydroplant capacity considers the available power for Argentina, 2,745 MW. The total capacity of Yacyretá is 3100 MW, achievable at maximum level and with the units at full capacity. In the nuclear sector, historical unavailability has been important because of the periodic maintenance that units have to go through. In particular, the Embalse nuclear plant commenced, starting in January 1, 2016, a two-year period in which it was not in operation. Additionally, the Atucha II nuclear plant, which was generating energy on a trial basis since 2015, received its commercial authorization during the first half of 2016, adding a nominal capacity of 745 MW to the SADI.
Energy generation may be influenced by the physical and economic capacity to provide fuel to thermoelectric generators. In recent years and until 2014 fuel prices increased the generating cost, although the fall in oil and fuel prices significantly reduced such cost in 2015 and 2016. The lack of local production of natural gas led to an increased use of fuel oil and gas oil in those generating plants with TS and TG units, in addition to imports of gas and LNG. Most of the TS units are shipped with fuel oil, and only the Central Térmica San Nicolas can burn coal, in addition to fuel oil or natural gas. TS or TG groups that operate in combined-cycle are included in this area in previous tables.
Fuel availability is a factor that contributes to technical unavailability. The costs and logistics for importing and supplying fuel oil, gas oil, and coal instead of natural gas are key to the future availability of thermal units and will continue to be important if the current international conditions are maintained. Since 2007 the limited supply of natural gas in winter caused a large increase in consumption of fuel oil and gas oil, with record prices in the first half of 2008. Prices of liquid fuels decreased in 2009 due to the international crisis and then increased between 2010 and mid-2014 from the third quarter of 2014 until the first quarter of 2016, liquid fuel prices decreased sharply, with moderate increases after that (while remaining lower than the first half of 2014). Prices generally recovered through the years up to the first half of 2018, and since then have decreased. In the first quarter of 2020, there was a sudden drop in the prices due to COVID-19. Prices have been recovering since then but have remained lower than the peak of 2018.
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Fuel Consumption for Commercial Electric Power Generation
Source: CAMMESA, Company analysis
After the winter of 2014, there was a sharp drop in international oil prices that led to reduced thermoelectric generation costs. Due to the shortage of gas, there was an increase in the amount of alternative fuels used to generate electric power, which since 2016, has been almost completely reverted, as shown in the chart above, mainly due to higher natural gas production from non-conventional oil fields. Thermoelectric generation is expected to continue to make up a larger portion of the energy mix in the coming six years as a result of the 2.9 GW of new electric generation capacity.
The price for generation of CAMMESA constitutes an effective price only to certain segments of the electric power market, especially industrial consumers, with the exception of those that are commercially supplied by electric power distributors.
Anti-Money Laundering
Anti-Money Laundering and Terrorism Financing Regime
The concept of money laundering is generally used to denote transactions aimed at introducing funds from illicit activities into the institutional system and thus transform gains from illegal activities into assets of a seemingly legitimate source.
Terrorist financing is the act of providing funds for terrorist activities. This may involve funds raised from legitimate sources, such as personal donations and profits from businesses and charitable organizations, as well as from criminal sources, such as drug trade, weapons and other goods smuggling, fraud, kidnapping and extortion.
On April 13, 2000, the National Congress passed Law No. 25,246, (subsequently amended and complemented, (the “AML/ CFT Law”), which created at the national level the Anti- Money Laundering and Terrorism Financing Regime (“AML/CFT Regime”), criminalizing money laundering, creating and designating the UIF as the enforcement authority of the regime, and establishing the legal obligation for various public and private sector entities and professionals to provide information and cooperate with the UIF.
The UIF is a decentralized agency that operates with autonomy and financial independency under the Ministry of Economy, and its mission is to prevent and deter the crimes of money laundering and terrorist financing.
The following are certain provisions relating to the AML/CFT Regime established by the AML/ CFT Law and its amending and complementary provisions, including regulations issued by the UIF, and the CNV and the Central Bank. It is recommended that investors consult their own legal advisors and read the AML/ CFT Law and its complementary regulations.
Money laundering and terrorist financing in the Argentine Criminal Code
(a) Money laundering
Section 303 of the Argentine Criminal Code (the “ACC”) defines money laundering as a crime committed whenever a person converts, transfers, manages, sells, encumbers, conceals or in any other way puts into circulation in the market, property derived from an unlawful act, with the possible consequence that the origin of the original property or the subordinate property acquires the appearance of a lawful origin, either in a single act or by the repetition of various acts linked to each other. Section 303 of the ACC establishes the following penalties:
(i) If the amount of the operation exceeds Ps.300,000, imprisonment for a term of three (3) to ten (10) years and fines of two to ten times the amount of the operation shall be imposed. This penalty will be increased by one third of the maximum and half of the minimum, when:
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(a) the person performs the act on a habitual basis or as a member of an illicit association constituted for the continuous commission of acts of this nature;
(b) the person is a public official who committed the act in the exercise or on the occasion of his/her functions. In this case, he/she shall also be subject to a penalty of special disqualification of three to ten years. The same penalty shall be imposed to anyone who has acted in the exercise of a profession or occupation requiring special qualification.
(ii) Anyone who receives money or other property from a criminal offense for the purpose of applying them in an operation as described above, which gives them the possible appearance of a lawful origin, shall be punished with imprisonment for a term of six (6) months to three (3) years.
(iii) If the value of the goods does not exceed Ps. 300,000, the penalty shall be imprisonment for a term of six months to three years.
(b) Penalties for legal persons.
Furthermore, Section 304 of the ACC provides that when the criminal acts have been committed in the name of, or with the intervention of, or for the benefit of a legal person, the following sanctions shall be imposed to the entity jointly or alternatively:
(i) fine of two (2) to ten (10) times the value of the property subject to the offense;
(ii) total or partial suspension of activities, which in no case shall exceed ten (10) years;
(iii) debarment for public tenders or bidding processes or any other State-related activities, which in no case shall exceed ten (10) years;
(iv) dissolution and liquidation of the legal person when it was created for the sole purpose of committing the offense, or such acts constitute the main activity of the entity;
(v) loss or suspension of any State benefit that it may have;
(vi) publication of an extract of the condemnatory sentence at the expense of the legal entity.
In order to calibrate these sanctions, the Court will take into account the failure to comply with internal rules and procedures, the omission of vigilance over the activity of the authors and participants; the extent of the damage caused, the amount of money involved in the commission of the offense, the size, nature and economic capacity of the legal entity. In the cases in which it is essential to maintain the operational continuity of the entity, or of a public work, or particular service, the sanctions of suspension of activities or dissolution and liquidation of the legal person shall not be applicable.
(c) Terrorism financing
Section 306 of the ACC criminalizes the financing of terrorism. This offense is committed by any person who directly or indirectly collects or provides property or money, with the intention of it being used, or in the knowledge that it will be used, in full or in part:
(i) to finance the commission of acts which have the aim of terrorizing the population or compelling national public authorities or foreign governments or agents of an international organization to perform or refrain from performing an act (according to section 41.5 of the ACC);
(ii) by an organization committing or attempting to commit crimes for the purpose set out in (i);
(iii) by an individual who commits, attempts to commit or participates in any way in the commission of offenses for the purpose set out in (i).
The penalty is imprisonment for a term of five (5) to fifteen (15) years and a fine of two (2) to ten (10) times the amount of the operation. Likewise, the same penalties shall apply to legal persons as described for the crime of money laundering.
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Reporting Subjects obliged to inform and collaborate with the UIF
The AML/CFT Law, in line with international AML/CFT standards, not only designates the UIF as the agency in charge of preventing money laundering and terrorism financing, but also establishes certain obligations to various public and private sector entities and individuals, which are designated as Reporting Subjects (“Sujetos obligados”), which are legally bound to inform and collaborate with the UIF.
In accordance with the AML/ CFT Law and the regulations complementing it, the following persons, among others, are Reporting Subjects before the UIF:
(i) banks, financial entities and insurance companies;
(ii) exchange agencies and natural and legal persons authorized by the Central Bank to intervene in the purchase and sale of foreign currency with funds in cash or checks issued in foreign currency or through the use of debit or credit cards or in the transfer of funds within or outside the national territory;
(iii) settlement and clearing agents, trading agents; natural and/or legal persons registered with the CNV acting in the placement of investment funds or other collective investment products authorized by such agency; crowdfunding companies, global investment advisors and the legal persons acting as financial trustees whose trust securities are authorized for public offering by the CNV, and the agents registered by the above mentioned controlling agency that intervene in the placement of negotiable securities issued within the framework of the above mentioned financial trusts;
(iv) government organizations such as the Central Bank, the Federal Public Revenue Administration (“AFIP”, as per its acronym in Spanish), the Superintendence of Insurance of the Nation (“SSN”, as per its acronym in Spanish), the CNV and the IGJ; and
(v) professionals in the area of economic sciences and notaries public.
The Reporting Subjects have the following duties:
(i) obtaining from clients’ documents that indisputably prove their identity, legal status, domicile and other information, concerning their operations needed to accomplish the intended activity (know your customer policy);
(ii) conduct due diligence procedure on their clients and report any suspicious operation or fact (which, in accordance with the usual practices of the area involved, as well as the experience and competence of the Reporting Subjects, are operations that are attempted or completed which were previously identified as unusual operations by the regulated entity, as well as any operation without economic or legal justification or of unusual or unjustified complexity, whether performed in isolated or repeated manner, regardless of the amount); and
(iii) refraining from disclosing to the client or third parties the actions being conducted in compliance with the AML/ CFT Law. Within the framework of suspicious operation report analysis, Reporting Subjects shall not object disclosure to UIF of any information required from them alleging that such information is subject to banking, stock market or professional secrecy or confidentiality agreements of a legal or contractual nature.
Pursuant to Annex I of Resolution No. 154/2018 of the UIF (which establishes the supervision and inspection mechanism of the UIF), both the Central Bank and the CNV are considered “Specific Control Agencies”(“Órganos de Contralor Específico”). In such capacity, they must collaborate with the UIF in the evaluation of compliance with AML/CFT procedures by the Reporting Subjects subject to their control. For these purposes, they are entitled to supervise, monitor and inspect these entities. Denial or obstruction of inspections by the Reporting Subjects may result in administrative penalties by the UIF and criminal penalties.
The Central Bank and the CNV must also comply with the AML/CFT regulations established by the UIF, including the reporting of suspicious transactions. In turn, Reporting Subjects regulated by these agencies are subject to UIF Resolutions No. 30/2017 and 21/2018, respectively. Such regulations provide guidelines that such entities shall adopt and apply to manage, in accordance with their policies, procedures and controls, the risk of being used by third parties for criminal purposes of money laundering and financing of terrorism.
Essentially, the aforementioned regulations (the consolidated texts of which were subsequently approved by UIF Resolution No. 156/18), change the formal regulatory compliance approach to a risk-based approach (“RBA”), based on the revised recommendations issued by the Financial Action Task Force (the “FATF”) in 2012, in order to ensure that the implemented measures are proportional to the identified risks. Therefore, the Reporting Subjects shall identify and evaluate their risks and, based on this, adopt measures for the management and mitigation of such risks, in order to more effectively prevent money laundering and terrorist financing. Likewise, the provisions of UIF Resolution No. 4/17 established the possibility of conducting special due diligence procedures with respect to clients supervised abroad (formerly called “international investors”) and local clients who are Reporting Subjects to the UIF.
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Asset Freezing Regime
Decree No. 918/2012 establishes the procedures for the freezing of assets linked to terrorism financing, and the creation and maintenance procedures (including the inclusion and removal of suspected persons) for registries created in accordance with the relevant United Nations Security Council’s resolutions.
Additionally, UIF Resolution No. 29/2013, regulates the implementation of Decree No. 918/2012 and establishes: (i) the procedure to report suspicious transactions of terrorism financing and the persons obligated to do so, and (ii) the administrative freezing of assets procedure on natural or legal persons or entities designated by the United Nations Security Council pursuant to Resolution 1267 (1999) and subsequent, or linked to criminal actions under Section 306 of the Argentine Criminal Code, both prior to the report issued pursuant to UIF Resolutions No. 121 and 229, and as mandated by the UIF after receiving such report.
In order to help the Reporting Subjects to fulfill these duties, Executive Decree No. 489/2019 created the Public Registry of Persons and Entities linked to acts of Terrorism and its Financing (RePET, for its acronym in Spanish), which is an official database that includes the consolidated list of the United Nations Security Council.
Politically Exposed Persons
Resolution No. 134/2018 of the UIF (amended by Resolutions No. 15/2019 and 128/2019), establishes the rules that Reporting Parties must follow regarding clients that are Politically Exposed Persons (PEPs).
Following the aforementioned RBA, Resolution 134/2018 establishes that Reporting Parties must determine the level of risk at the time of beginning or continuing the contractual relationship with a PEP, and must take due diligence measures, adequate and proportional to the associated risk and the operation or operations involved.
In addition, the UIF has issued the Guide for the management of risks of money laundering and financing of terrorism in relation to customers (and ultimate beneficiaries) that are PEPs, which sets up guidelines for Reporting Parties in order to comply with the Resolution No. 134/2018.
CNV Regulations
The CNV regulations stipulate, among other provisions, that the Reporting Subjects under its control shall only perform the operations provided for under the public offering system when these operations are performed or ordered by persons constituted, domiciled or resident in countries, domains, jurisdictions, territories or associated states not considered to be non-cooperative or high risk by the FATF.
Similarly, they establish the payment modalities and control procedures for the reception and delivery of funds from and to clients.
Central Bank Rules
Pursuant to Communication “A” 6399 of the Central Bank, as amended and supplemented, including without limitation, by Communication “A” 6709, Reporting Subjects must keep - for a period of 10 years - written records of the procedure applied in each case for the discontinuation of a client's operations. Among these records, they shall keep a copy of any notification sent to the customer requesting further information and/or documentation, the corresponding notices of receipt and the documents identifying the officials who took part in the decision, in accordance with the respective procedural manuals.
Tax Amnesty System
The voluntary system of declaration under the Tax Amnesty Law No.27.260 and its Regulatory Decree No. 895/16 (jointly the “Tax Amnesty System”) established that the information voluntarily submitted under such system may be used for the investigation and punishment of the crimes of money laundering and financing of terrorism. For such purpose, the UIF has the power to communicate information to other public intelligence or investigation agencies, based on a previous resolution of the UIF’s President and provided that there are serious, precise and concordant indications of the commission of money laundering and/or terrorism financing crimes. Furthermore, the AFIP remains obliged to report to the UIF suspicious operations detected within the framework of the Tax Amnesty System and to provide it with all information required by it, not being able to oppose fiscal secrecy.
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Corporate Criminal Liability Law
The Corporate Criminal Liability Law No. 27,401 sets forth a criminal liability regime applicable to legal entities involved in certain corruption offenses directly or indirectly committed in their name, on their behalf or in their interest and from which a benefit may arise. The individual offenders may be employees or third parties — even unauthorized third parties, provided that the company ratified the act, even tacitly.
For an extensive analysis of the money laundering regime in effect as of the date of this annual report, investors should consult legal counsel and read Title XIII, Book 2 of the Argentine Criminal Code and any regulations issued by the UIF, the CNV and the Central Bank in their entirety. For such purposes, interested parties may visit the websites of the Argentine Ministry of Economy, at www.argentina.gob.ar/economia, the Argentine Ministry of Justice and Human Rights, at www.infoleg.gob.ar, the UIF, at www.argentina.gob.ar/uif, the CNV, at www.argentina.gob.ar/cnv, or the Central Bank, at www.bcra.gov.ar. The information found on such websites is not a part of this annual report.
Item 4.C Organizational structure
The following diagram illustrates our organizational structure as of the date of this annual report. Percentages indicate the ownership interest held.
(1) | Percentages reflect our equity interests in the operating companies TJSM, TMB and CVO. For further information, see “Item 4.B. Business Overview—FONINVEMEM and Similar Programs.” |
(2) | Percentages indicate direct and, through Inversora de Gas del Centro S.A. -IGCE-, indirect investments of the Company in DGCU, DGCE. |
(3) | The percentage for Energía Sudamericana S.A., includes a 2.45% direct interest plus a 41.06% indirect interest in its capital stock, through our equity interest in IGCE. The percentage for Coyserv S.A. includes a 32.21% indirect interest in its capital stock, through our equity interest in IGCE, DGCE and DGCU. |
(4) | See “Item 4.B. Business overview—Our Subsidiaries” |
For further information on our subsidiaries, see “Item 4.B. Business overview—Our Subsidiaries.”
Item 4.D Property, plants and equipment
Property, Plant and Equipment
Most of our property, plant and equipment is intended to be used in the generation of electric power and 100.00% of it is located in Argentina.
We have no significant assets under capital lease or lease agreements.
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The following table provides certain information regarding the operation of our power plants that we owned as of December 31, 2021:
Site |
| Plant |
| Unit |
| Installed capacity |
| Type |
| Fuel type (if any) | |||||
Puerto Complex |
|
|
|
|
|
| 1,714 |
|
| MW |
|
|
|
| |
|
| Puerto Nuevo plant |
|
|
|
| 589 |
|
| MW |
|
|
|
| |
|
|
|
| PNUETV07 |
|
| 145 |
|
| MW |
| Thermal |
| NG / FO | |
|
|
|
| PNUETV08 |
|
| 194 |
|
| MW |
| Thermal |
| NG / FO | |
|
|
|
| PNUETV09 |
|
| 250 |
|
| MW |
| Thermal |
| NG / FO | |
|
| Nuevo Puerto plant |
|
|
|
| 360 |
|
| MW |
|
|
|
| |
|
|
|
| NPUETV05 |
|
| 110 |
|
| MW |
| Thermal |
| NG / FO | |
|
|
|
| NPUETV06 |
|
| 250 |
|
| MW |
| Thermal |
| NG / FO | |
|
| Puerto combined cycle plant |
|
|
|
| 798 |
|
| MW |
|
|
|
| |
|
|
|
| CEPUCC GE |
|
| 798 |
|
| MW |
| Thermal |
| NG / GO | |
Piedra del Águila |
|
|
|
|
|
| 1,440 |
|
| MW |
|
|
|
| |
|
| Piedra del Águila plant |
|
|
|
| 1,440 |
|
| MW |
|
|
|
| |
|
|
|
| PAGUHI |
|
| 1,440 |
|
| MW |
| Hydroelectric |
|
| |
Luján de Cuyo |
|
|
|
|
|
|
|
|
| MW |
|
|
|
| |
|
| Luján de Cuyo plant |
|
|
|
|
|
|
| MW |
|
|
|
| |
|
|
|
| LDCUCC25 |
|
| 5 |
|
| MW |
| Thermal |
| NG | |
|
|
|
| LDCUTG23 |
|
| 22.80 |
|
| MW |
| Thermal |
| NG / GO | |
|
|
|
| LDCUTG24 |
|
| 22.80 |
|
| MW |
| Thermal |
| NG / GO | |
|
|
|
| LDCUTV11 |
|
| 60 |
|
| MW |
| Thermal |
| NG / FO | |
|
|
|
| LDCUTV12 |
|
| 60 |
|
| MW |
| Thermal |
| NG / FO | |
|
|
|
| LDCUTG22 |
|
| 24.2 |
|
| MW |
| Thermal |
| NG / GO | |
|
|
|
| LDCUTG26 |
|
| 47.25 |
|
| MW |
| Thermal |
| NG / GO | |
|
|
|
| LDCUTG27 |
|
| 48.07 |
|
| MW |
| Thermal |
| NG / GO | |
|
|
|
| LDCUHI |
|
| 1 |
|
| MW |
| Hydroelectric |
|
| |
Brigadier López |
|
|
|
|
|
| 280.5 |
|
| MW |
|
|
|
| |
|
| Brigadier López plant |
| BLOPTG01 |
|
| 280.5 |
|
| MW |
| Thermal |
| NG / GO | |
Terminal 6 |
| Terminal 6 plant |
| TER6CC11 |
|
| 330 |
|
| MW |
| Thermal |
| NG/ GO | |
La Genoveva |
|
|
|
|
|
| 130 |
|
|
|
|
|
|
| |
|
| La Genoveva II wind farm |
|
|
|
| 88.2 |
|
|
|
|
|
|
| |
|
| La Genoveva II wind farm |
| GNV2EO |
|
| 41.80 |
|
| MW |
| Wind |
|
| |
La Castellana |
|
|
|
|
|
| 116 |
|
| MW |
| Wind |
|
| |
|
| La Castellana I wind farm |
| LCASEO |
|
| 100.80 |
|
| MW |
| Wind |
|
| |
|
| La Castellana II wind farm |
| LCA2EO |
|
| 15.2 |
|
| MW |
| Wind |
|
| |
Achiras |
|
|
|
|
|
| 127,8 |
|
| MW |
|
|
|
| |
|
| Achiras wind farm |
| ACHIEO |
|
| 48 |
|
| MW |
| Wind |
|
| |
|
| Manque wind farm |
| MANQEO |
|
| 57 |
|
| MW |
| Wind |
|
| |
|
| Los Olivos wind farm |
| OLIVEO |
|
| 22.8 |
|
| MW |
| Wind |
|
| |
____________
Reference: NG: natural gas; FO: fuel oil; GO: gas oil
La Castellana I, La Castellana II, Achiras, Manque, Los Olivos, La Genoveva II and La Genoveva I wind farms are owned by CP La Castellana S.A.U., CPR Energy Solutions S.A.U., CP Achiras S.A.U., CP Manque S.A.U., CP Los Olivos S.A.U, Vientos La Genoveva II S.A.U, and Vientos La Genoveva I S.A.U., respectively, the first five of which are fully owned subsidiaries of CP Renovables S.A. while the last two are a fully owned subsidiary of Central Puerto S.A. See “Item 4.B. Business Overview—Our Subsidiaries”.
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We believe that all of our production facilities are in good operating condition. We believe that we have satisfactory title to our plants and that our facilities are in accordance with standards generally accepted in the electric power industry. As of December 31, 2021, the consolidated net book value of our property, plant and equipment was Ps.110.6 billion.
The following table lists the value of our property, plant and equipment as of December 31, 2021:
Main Item |
| As of December 31, 2021 |
| |
|
| (in thousands of Ps.) |
| |
Lands and buildings |
|
| 11,593,726 |
|
Electric power facilities |
|
| 59,197,306 |
|
Wind turbines |
|
| 30,977,424 |
|
Gas turbines |
|
| 1,609,263 |
|
Construction in progress |
|
| 5,914,364 |
|
Others |
|
| 1,331,243 |
|
Total |
|
| 110,623,326 |
|
____________
For information on our plants under construction, see “Item 5.A Operating Results—Expansion of Our Generating Capacity.”
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For information on environmental issues that may affect our utilization of assets, see “Item 3.D.—Risk Factors—Risks relating to Our Business—Climate change and energy transition could affect our business”, and “—Our ability to operate wind farms profitably is highly dependent on suitable wind and associated weather conditions”.
Item 4A Unresolved Staff Comments
Not applicable.
Item 5. Operating and Financial Review and Prospects
Item 5.A Operating Results
This section contains forward‑looking statements that involve risks and uncertainties. Our actual results may differ materially from those discussed in the forward‑looking statements as a result of various factors, including, without limitation, those set forth in “Forward‑looking Statements,” “Item 3.D Risk Factors,” and the matters set forth in this annual report generally.
This discussion should be read in conjunction with our Audited Consolidated Financial Statements which are included elsewhere in this annual report.
Financial Presentation
We maintain our financial books and records and publish our consolidated financial statements in Argentine pesos, which is our functional currency. Our Audited Consolidated Financial Statements are prepared in Argentine pesos and in accordance with the IFRS as issued by the IASB.
Factors Affecting Our Results of Operations
Argentine Economic Conditions
We are an Argentine sociedad anónima (corporation). Substantially all of our assets and operations and our customers are located in Argentina. Accordingly, our financial condition and results of operations depend to a significant extent on macroeconomic and political conditions prevailing from time to time in Argentina.
As Central Puerto is affected by the conditions of Argentina’s economy, which have historically been volatile, and have negatively and materially affected the financial condition and prospects of multiple industries, including the electric power sector, the following discussion may not be indicative of our future results of operations, liquidity or capital resources.
The following table sets forth information about certain economic indicators in Argentina for the periods indicated.
|
| 2017 |
|
| 2018 |
|
| 2019 |
|
| 2020 |
|
| 2021 |
| |||||
Economic activity |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||
Nominal GDP in current US$(1) (in millions of US$) |
|
| 637,173 |
|
|
| 503,897 |
|
|
| 442,159 |
|
|
| 383,761 |
|
|
| 487,286 |
|
Real gross domestic investment(2) (pesos of 2004) (% change) as % of GDP |
|
| 10.27 | % |
|
| (1.57 | %) |
|
| (15.63 | %) |
|
| (3.36 | %) |
|
| 20.53 | % |
Price indexes and exchange rate information |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
INDEC CPI (% change)(3) |
|
| 24.8 | % |
|
| 47.6 | % |
|
| 53.8 | % |
|
| 36.1 | % |
|
| 50.9 | % |
Economic activity |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Inflation (as measured by the City of Buenos Aires CPI) (% change)(4) |
|
| 26.1 | % |
|
| 45.50 | % |
|
| 50.60 | % |
|
| 30.5 | % |
|
| 49.29 | % |
Inflation (as measured by the Province of San Luis CPI) (% change)(4) |
|
| 24.3 | % |
|
| 50.00 | % |
|
| 57.60 | % |
|
| 41.8 | % |
|
| 50.70 | % |
Wholesale price index (WPI) (% change) |
|
| 18.8 | % |
|
| 73.50 | % |
|
| 58.50 | % |
|
| 35.4 | % |
|
| 51.30 | % |
Nominal exchange rate(5) (in Ps./US$ at period end) |
|
| 18.65 |
|
|
| 37.70 |
|
|
| 58.89 |
|
|
| 84.15 |
|
|
| 102.73 | |
___________
Sources: Ministry of Public Works of Argentina, Banco de la Nación Argentina and Instituto Nacional de Censos y Estadísticas (INDEC).
(1) | Calculations based on the nominal GDP in pesos as reported by INDEC in December 2018, divided by the average nominal Ps./US$ exchange rate for each period as reported by the Banco de la Nación Argentina. |
(2) | Calculations for years 2016 through 2020 based on real gross domestic investment (pesos of 2004) and GDP as reported by INDEC in March 2022 |
(3) | The INDEC authorities, that took office in December 2015, declared an emergency with respect to Argentina’s statistics system. In this respect, the INDEC’s website warns that the statistical information published from January 2007 through December 2015 should be considered with caution, except for that information which has been revised in 2016, as expressly stated in by the INDEC on its website. The INDEC, pursuant to the authority conferred by Regulations 181/15 and 55/16, initiated the research required in order to restore the regularity of procedures for data collection, its processing, the development of economic indicators and their dissemination. The CPI for 2016 contains the data from April to December 2016 (the only published data). |
(4) | On January 8, 2016, based on its determination that the INDEC had failed to produce reliable statistical information, including with respect to CPI, the previous administration declared the national statistical system and the INDEC in a state of administrative emergency through December 31, 2016. The INDEC implemented certain methodological reforms and adjusted certain macroeconomic statistics on the basis of these reforms.” During the first six months of this reorganization period, the INDEC published official CPI figures published by the City of Buenos Aires and the Province of San Luis for reference, which we include here. |
(5) | Pesos to U.S. dollars exchange rate as quoted by the Banco de la Nación Argentina for wire transfers (divisas). |
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According to the revised data published by the INDEC on March 22, 2017, in 2012, Argentina’s real GDP dropped 1.0%. This economic contraction was attributed to local and external factors, primarily the deceleration of growth in developing economies, including Argentina’s principal trading partners, and an extended drought affecting agricultural production. Following the contraction in 2012, Argentina’s real GDP recovered in 2013, growing 2.4% as compared to 2012, as domestic demand in 2013 helped to offset weak demand from the rest of the world. In 2014, Argentina’s real GDP decreased 2.5%, compared to 2013, reflecting the impact of the deceleration of growth in developing economies on Argentina’s exports, growing uncertainty in the financial sector and fluctuations in foreign exchange rates.
During 2017, as compared to 2016, Argentina’s GDP increased 10.27%, primarily as the result of (i) an increase of a 13.4% in gross investments, (ii) a 4.2% increase in private consumption and (iii) a 2.6% increase in public consumption (iv) a 2.6% increase in exports. These factors were partially offset by an increase of 15.6% in imports.
During 2018, as compared to 2017, Argentina’s GDP decreased 1.57%, primarily as the result of (i) a decrease of a 5.7% in gross investments, (ii) a 2.2% decrease in private consumption and (iii) a 1.9% decrease in public. These factors were partially offset by a decrease of 4.5% in imports.
During 2019, as compared to 2018, Argentina’s GDP decreased 15.63%, primarily as the result of a 15.9% decrease in capital goods investments, a 6.4% decrease in private sector consumption, and a 7.3% decrease in public consumption. These factors were partially offset by a 9.1% increase in exports and a 19% decrease in imports.
During 2020 as compared to 2019, Argentina’s GDP decreased 3.36%, primarily as the result of a 12.9% decrease in capital goods investments, a 13.8% decrease in private sector consumption, and a 3.3% decrease in public consumption and a 17.3% decrease in exports and a 17.9% /decrease in imports.
During 2021 as compared to 2020, Argentina’s GDP increased 10.30%, primarily as the result of a 32% increase in capital goods investments, a 10.20% increase in private sector consumption, a 7.8% increase in public consumption, a 9 % increase in exports and a 21.5% increase in imports.
As of the date of this annual report, the country faces significant challenges, including the need to attract investments in capital goods that will permit sustainable growth and reduce inflationary pressures, as well as renegotiate utility contracts and resolve the current energy crisis. See “Item 3.D. Risk Factors—Risks Relating our Operations ”, in particular “An outbreak of a disease, including COVID-19, may have material adverse consequences on our operations including new projects”, “Item 3.D. Risk Factors—Risks relating to our business— Factors beyond our control may affect or delay the completion of the awarded projects, or alter our plans for the expansion of our existing plants” and “Item 5.B—Liquidity and Capital Resources”.
In light of these uncertainties, the long-term evolution of the Argentine economy remains uncertain. The real GDP growth rate decreased in 2019, and the inflation rate was 53.83%. In 2020, the real GDP growth rate decreased, and the inflation rate was 36.1%. In 2021, the real GDP growth rate increased 10.30%, and the inflation rate was 50.9%.
During 2019, aggregate economic activity in Argentina was mainly affected by periods of volatility in the exchange rate and financial indicators, which increased after the primary elections held in August. After a modest economic recovery registered through the second quarter of the year, the financial turmoil in the third quarter generated a double dip in the activity. In general terms, most economic sectors were adversely affected by the general macroeconomic context to different degrees (with the exception of the agricultural sector that outperformed significantly). During 2020, aggregate economic activity in Argentina was mainly affected by COVID-19 and the lock-down measuares imposed causing a sharp drop in activity as many industries closed. In the third quarter of 2020 and due to more flexible lock-down measures, aggregate economic activity started to recover by with levels below the ones before que COVID-19 crisis.
During 2021, aggregate economic activity in Argentina was mainly affected by periods of volatility in exchange rates and financial indicators, a high rate of inflation and macroeconomic uncertainty, mainly explained by the lack of foreign exchange reserves in the Central Bank and by the need to reach an agreement with the IMF regarding payments to be made during 2022. Economic activity in Argentina in 2021 was also affected by the COVID-19 pandemic and the diverse measures adopted by the Argentine government to address its consequences.
Inflation
Argentina has faced and continues to face inflationary pressures. From 2012 to date, Argentina experienced increases in inflation as measured by CPI and WPI that reflected the continued growth in the levels of private consumption and economic activity (including exports and public and private sector investment), which applied upward pressure on the demand for goods and services.
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During periods of high inflation, effective wages and salaries tend to fall and consumers adjust their consumption patterns to eliminate unnecessary expenses. The increase in inflationary risk may erode macroeconomic growth and further limit the availability of financing, causing a negative impact on our operations. See “Item 3.D. Risk Factors—Risks Relating to Argentina—Substantially all of our revenues are generated in Argentina and thus are highly dependent on economic and political conditions in Argentina.”
Inflation increases also have a negative impact on our cost of sales, selling expenses and administrative expenses, in particular our payroll and social security charges. We cannot give any assurance that increased costs as a result of inflation will be offset in whole or in part with increases in prices for the energy we produce.
IAS 29, Financial Reporting in Hyperinflationary Economies, requires that financial statements of any entity whose functional currency is the currency of a hyperinflationary economy, whether based on the historical cost method or on the current cost method, be stated in terms of the measuring unit current at the end of the reporting period. Even though the standard does not establish an absolute rate at which hyperinflation is deemed to arise, it is common practice to consider there is hyperinflation where changes in price levels are close to or exceed 100% on a cumulative basis over the last three years, along with other several macroeconomic-related qualitative factors.
Due to macroeconomic factors, the triennial inflation was above that figure in 2018 and Argentina has been considered hyperinflationary since July 1, 2018. Such conditions remained during 2019, 2020 and 2021. See “Risks Relating to Argentina—As of July 1, 2018, the Argentine Peso qualifies as a currency of a hyperinflationary economy and we are required to restate our historical financial statements to apply inflationary adjustments, which could adversely affect our results of operations and financial condition and those of our Argentine subsidiaries
Therefore, our financial statements as of and for the year ended December 31, 2021, including the figures for the previous periods (this fact not affecting the decisions taken on the financial information for such periods), and unless otherwise stated, the financial information included elsewhere in this annual report, have been restated to consider the changes in the general purchasing power of the functional currency of the Company (Argentine peso) pursuant to IAS 29 and General Resolution no. 777/2018 of the CNV.
Furthermore, as a consequence of the application of IAS 29, maintaining net monetary assets generates loss of purchasing power, while maintaining net monetary liabilities generates improvement of purchasing power, provided that such items are not subject to an adjustment mechanism that compensates to some extent such loss or improvement . This loss or income is booked in the statement of comprehensive income.
Accordingly, we have recognized a loss regarding the effect of adjustment by inflation of Ps 1,654 million for 2021, we have recognized a gain regarding the effect of adjustment by inflation of Ps. 1,750 million for 2020 and we have recognized a loss regarding the effect of adjustment by inflation of Ps 4,997 million for 2019. See Note 2.1.2 to our financial statements.
On June 16, 2021, the Argentine Executive Power passed Law No. 27,630, which established changes in the corporate income tax rate for the fiscal periods commencing as from January 1, 2021. Such law establishes payment of the tax based on a structure of staggered rates regarding the level of accumulated taxable net income. The scale consists of three segments: 25% up to an accumulated taxable net income of 5 million Ps.; 30% for the excess of such amount up to 50 million Ps.; and 35% for the excess of such amount. The estimated amounts in this scale will be annually adjusted as from January 1, 2022, considering the annual variation of the consumer price index provided by the INDEC corresponding to October of the year prior to the adjustment compared with the same month of the previous year.
The Impact of COVID-19
For information relating to the impact of the COVID-19 pandemic in our business, see “Item 3.D. Risk Factors—Risks Relating our Operations—An outbreak of a disease, including COVID-19, may have material adverse consequences on our operations including new projects” and “Item 4.A.—Recent Developments—Measures Designed to Address the COVID-19 Outbreak.”
Foreign Currency Fluctuations
We are exposed to exchange rate risk in connection with the U.S. dollar to the Argentine peso exchange rate, as part of our capital expenditures, financial obligations and operating expenditures are denominated in U.S. dollars. See “Item 3.D. Risk Factors—Risks Relating to Argentina—Significant fluctuations in the value of the peso could adversely affect the Argentine economy and, in turn, adversely affect our results of operations” and “Item 10.D. Exchange Controls.”
The devaluation of the peso with respect to the U.S. dollar totaled 17.36% in 2017, 102.16% in 2018, 58.86% in 2019, 40.67% in 2020 and 22.07% in 2021.
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As of December 31, 2021, we did not have derivatives that met the requirements established by IFRS to be designated as an effective hedge for this particular risk. As of December 31, 2021, we had trade receivable, financial assets at fair value through profit or loss, cash and short-term investments denominated in foreign currency totaling US$496.6 million, while at the same time we had liabilities denominated in foreign currency totaling US$442.5 million.
Any significant depreciation of the peso would result in an increase in the cost of servicing our debt and in the cost of imported supplies or equipment and, therefore, may have a material adverse effect on our results of operations. With respect to fuel used in connection with the energy we sell under the Energía Base (which represented around 41.7% of our energy sales in terms of output in 2021), the exposure to changes in fuel prices is not material since, under current applicable regulation, the fuel for the electric power sold under the Energía Base is required to be acquired from and supplied by CAMMESA, free of any cost to us; hence, it is not currently an integral part of the price charged by the generator.
The Argentine Government has taken measures to stabilize the foreign exchange situation, restrictions to the purchase of foreign currency, and in some cases, an additional tax. For further information, see “Item 10.D. Exchange Controls.”
Our Revenues
The following chart shows a breakdown of our revenues for the periods indicated:
|
| 2021 |
|
| 2020 |
|
| 2019 |
| |||||||||||||||
|
| (in thousands of Ps.) |
|
| Percentage of revenues |
|
| (in thousands of Ps.) |
|
| Percentage of revenues |
|
| (in thousands of Ps.) |
|
| Percentage of revenues |
| ||||||
Energía Base (Resolution SE No. 19/2017, SGE 70 and 95/2013, as amended)(1) |
|
| 23,816,074 |
|
|
| 41.72 | % |
|
| 26,375,183 |
|
|
| 45.86 | % |
|
| 56,261,695 |
|
|
| 76.14 | % |
Sales under contracts(2) |
|
| 30,115,202 |
|
|
| 52.77 | % |
|
| 27,766,903 |
|
|
| 48.27 | % |
|
| 15,105,173 |
|
|
| 20.44 | % |
Steam sales (3) |
|
| 1,715,963 |
|
|
| 3.00 | % |
|
| 1,607,183 |
|
|
| 2.79 | % |
|
| 893,170 |
|
|
| 1.21 | % |
Resale of gas transport and distribution capacity |
|
| 307,995 |
|
|
| 0.54 | % |
|
| 595,979 |
|
|
| 1.04 | % |
|
| 588,289 |
|
|
| 0.80 | % |
Revenues from CVO thermal plant management |
|
| 1,124,105 |
|
|
| 1.97 | % |
|
| 1,175,831 |
|
|
| 2.04 | % |
|
| 1,048,505 |
|
|
| 1.41 | % |
Total revenues from ordinary activities |
|
| 57,079,339 |
|
|
| 100 | % |
|
| 57,521,079 |
|
|
| 100 | % |
|
| 73,896,832 |
|
|
| 100 | % |
____________
(1) | Includes (i) sales of energy and power to CAMMESA remunerated under Resolution No. 95, Resolution No. 19/2017, Resolution No. SE 1/2019, Resolution SE No. 31/2020 and Resolution No. 440/21 (ii) spot sales of energy and power to CAMMESA not remunerated under Resolution No. 95 (as amended), (iii) remuneration under Resolution No. 724/2008 relating to agreements with CAMMESA to improve existing Argentine power generation capacity and (iv) income related to Resolution No. SEE 70/18. See “Item 4.B. Business Overview—The Argentine Electric Power Sector—Structure of the Industry—Shortages in the Stabilization Fund and Responses from the Argentine Government—The National Program.” |
(2) | Includes (i) term market sales under contracts, (ii) energy sold under the Energía Plus, (iii) contracts under the MATER framework and (iv) RenovAr Program sales under contracts (for further information regarding term market sales under contract, see “Item 4.B. Business Overview—Our Customers”). |
(3) | Includes steam sold under steam sale contract with YPF from the Luján de Cuyo Plant and Terminal 6-San Lorenzo site. |
Beginning in February 2021, sales under contracts are regulated by Resolution 440/21, and from February 2020 to January 2021 sales under contracts were regulated by Resolution 31/20. From February 2019 to January, 2020, sales under the Energía Base were regulated by Resolution SRRyME No. 1/19, from February 2017 to February 28, 2019, sales under the Energía Base were regulated by the Resolution SEE No. 19/17, which replaced Resolution SE No. 95/13, as modified by Resolution SE No. 529/14, Resolution SE No. 482/15 (the “Resolution No. 482”) and Resolution SEE No. 22/16, and denominated the relevant rates in U.S. dollars. In the year ended December 31, 2019, we sold over 92.37% of the electric power we generated and derived 76.14% of our revenues under the Energía Base. In the year ended December 31, 2020, we sold over 85% of the electric power we generated and derived 45.85% of our revenues under the Energía Base. In the year ended December 31, 2021, we sold over 81% of the electric power we generated and derived 41.72% of our revenues under the Energía Base. We also continue to sell a portion of electric power in the spot market under the regulatory framework established prior to the Energía Base. For further information see “Item 4.B. Business Overview—The Argentine Electric Power Sector—Remuneration Scheme—The Current Remuneration Scheme.”
In addition, we sell generation capacity and electric power under negotiated contracts with private sector counterparties under the Energía Plus and other outstanding contracts with private sector counterparties that were entered into prior to the implementation of the Energía Base (both shown under the line item “Sales under contracts”). Sales under contracts generally involve PPAs with customers and are contracted in U.S. dollars. The prices in these contracts include the price of fuel used for generation, the cost of which is assumed by the generator. For terms longer than one year, these contracts typically include electric power price updating mechanisms in the case of fuel price variations or if the generator is required to use liquid fuels in the event of a shortage of natural gas.
Below we summarize key aspects of our most significant sources of revenue, which include: (i) the Energía Base, and (ii) contracts with YPF and T6 for steam.
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The Energía Base (spot sales)
The Energía Base accounts for our largest source of revenue. Resolution SE No. 95/13, which was enacted in February 2013, changed the manner in which electric power was remunerated in the spot market and established the Energía Base. From February 2020 to January 2021 (included), sales under the Energía Base were regulated by Resolution of Secretary of Energy of the National Ministry of Production Development No. 31/20. Since February 1, 2021, the Energía Base sales have been regulated by Resolution SE No. 440/21.
Under Resolution SE No. 95/13, as amended, the applicable regulatory entity (as of the date of this annual report, the Secretariat of Electric Energy and in prior years the former Secretariat of Electric Energy) set electric power prices that were updated annually.
Effective February 2014 and 2015, prices were increased by the enforcement authority through Resolution SE No. 529/14 (“Resolution No. 529”) and Resolution SE No. 482/15, respectively. These increases were intended to allow generators to cover, at least in part, increases in business costs resulting from inflation and the currency devaluation. However, in light of the fact that the resolutions failed to provide a pricing mechanism with a pre-established frequency, the adjustments were discretionary.
Within this framework, in March 2016, the Secretariat of Electric Energy enacted Resolution SEE No. 22/16, whereby it adjusted the electric power prices established through Resolution SE No. 95/13. These adjustments became effective as of February 2016. In reference to the rationale for this resolution, the Secretariat of Electric Energy noted that it was enacted “for the sole purpose of supporting the operation and maintenance of affected equipment and power plants on a provisional basis, until the regulatory measures being considered by the Executive branch come into force progressively with the aim of returning the WEM to normal.”
On January 27, 2017, the Secretariat of Electric Energy issued Resolution SEE No. 19/17 (published in the Official Gazette on February 2, 2017), which replaced Resolution SE No. 95/13, as amended.
Pursuant to this resolution, which was in effect until February 28, 2019 (included), the Secretariat of Electric Energy established that electric power generators, co-generators and self-generators acting as agents in the WEM and which operate conventional thermal power plants, may make guaranteed availability offers (ofertas de disponibilidad garantizada) in the WEM. Pursuant to these offers, these generation companies may commit specific capacity and power output of the generation, provided that such capacity and energy had not been committed under PPAs entered into in accordance with (i) Resolutions Nos. 1193/05, 1281/06, 220/07, 1836/07 and 200/09 of the former Secretary of Energy, (ii) Resolution No. 21/16 of the Secretariat of Electric Energy and (iii) Resolutions Nos. 136/16 and 213/16 of the Ministry of Energy and Mining, as well as PPAs subject to a differential remuneration scheme established or authorized by the Ministry of Energy and Mining. The offers must be accepted by CAMMESA (acting on behalf of the WEM agents demanding electric power), which entity will be the purchaser of the power under the guaranteed availability agreements (compromisos de disponibilidad garantizada). Resolution SEE No. 19/17 established that such agreements may be assigned to electricity distribution companies and Large Users of the WEM once the state of emergency of the electric power sector in Argentina has ended (according to Decree No. 134/1995, such emergency was declared until December 31, 2017). Generator agents fully or wholly-owned by the Argentine government were excluded from the scope of Resolution SEE No. 19/17.
The term of the guaranteed availability agreements in Resolution SEE No. 19/17 was 3 years, and their general terms and conditions were established in Resolution SEE No. 19/17.
The remuneration in favor of the generator was calculated in U.S. dollars pursuant to the formulas and values set forth in the aforementioned resolution and comprises of (i) a price for the monthly capacity availability and (ii) a price for the power generated and operated.
Resolution SEE No. 19/17 also established that WEM agents that operate conventional hydroelectric power plants, pumped hydroelectric power plants and power plants using other energy resources shall be remunerated for the energy and capacity of their generation units in accordance with the values set forth in such resolution, and provided that such energy and capacity has not been committed under PPAs entered into in accordance to Resolutions Nos. 1193/05, 1281/06, 220/07, 1836/07 and 200/09 of the former Secretary of Energy, Resolution No. 21/16 of the Secretariat of Electric Energy, and Resolutions Nos. 136/16 and 213/16 of the Ministry of Energy and Mining.
On November 11, 2018, the Secretariat of Energy issued Resolution SGE No. 70/2018, which substitutes Art. 8 of Res. SE 95/2013. This new resolution allows electric energy generators, self-generators, and cogenerators acting in the WEM to purchase their own fuel. However, prior commitments assumed by generators with CAMMESA for energy supply contracts are not altered by this new regulation. If generation companies opt to take this option, CAMMESSA will value and pay the generators their respective fuel costs in accordance with the Variable Costs of Production (CVP) declared by each generator to CAMMESA. According to CAMMESA’s procedure, the machines with the lower CVPs are dispatched first, and consequently, may produce more electric energy. The Agency in Charge of Dispatch (Organismo Encargado del Despacho or “OED” using the Spanish acronym) -CAMMESA- will continue to supply the fuel for those generation companies that do not elect to take this option.
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On December 27, 2019, the Ministry of Productive Development issued Resolution MDP No. 12/2019, repealing Resolution SGE No. 70/2018 and restoring Art. 8 of Res. SE 95/2013. Beginning January 2020, CAMMESA became the only fuel supplier for generation companies, except for (i) thermal units that had prior commitments with CAMMESA for energy supply contracts with their own fuel management and (ii) thermal units under the Energía Plus regulatory framework, authorized under Resolution SE No.1281/05 to supply energy to large private users.
During 2021, 2020 and 2019 Central Puerto purchased the necessary fuel (natural gas) for the operation of some of its thermal units, as shown below:
|
| 2021 |
|
| 2020 |
|
| 2019 |
| |||||||||||||||
Month |
| CTM m3 |
|
| San Lorenzo m3 |
|
| CTM m3 |
|
| San Lorenzo m3 |
|
| CPSA |
|
| CTM m3 |
| ||||||
Jan |
|
| 18,504,503 |
|
|
| - |
|
|
| 18,088,392 |
|
|
| 0 |
|
|
| 129,311,174 |
|
|
| 57,738,667 |
|
Feb |
|
| 16,781,755 |
|
|
| - |
|
|
| 16,072,372 |
|
|
| 0 |
|
|
| 99,378,355 |
|
|
| 49,195,525 |
|
Mar |
|
| 18,445,797 |
|
|
| - |
|
|
| 16,226,818 |
|
|
| 0 |
|
|
| 93,962,355 |
|
|
| 55,703,130 |
|
Apr |
|
| 17,989,779 |
|
|
| - |
|
|
| 18,927,528 |
|
|
| 0 |
|
|
| 125,897,219 |
|
|
| 41,313,743 |
|
May |
|
| 17,437,714 |
|
|
| - |
|
|
| 18,656,982 |
|
|
| 0 |
|
|
| 86,879,731 |
|
|
| 45,126,615 |
|
Jun |
|
| 18,243,763 |
|
|
| - |
|
|
| 17,998,719 |
|
|
| 0 |
|
|
| 6,300,000 |
|
|
| 23,251,170 |
|
Ju |
|
| 19,058,930 |
|
|
| - |
|
|
| 19,853,079 |
|
|
| 0 |
|
|
| 0 |
|
|
| 1,183,000 |
|
Aug |
|
| 18,786,859 |
|
|
| 3,800,800 |
|
|
| 21,460,971 |
|
|
| 0 |
|
|
| 8,875,000 |
|
|
| 35,521,872 |
|
Aep |
|
| 18,478,034 |
|
|
| 7,297,078 |
|
|
| 19,938,216 |
|
|
| 0 |
|
|
| 62,316,850 |
|
|
| 44,932,188 |
|
Oct |
|
| 18,972,571 |
|
|
| 3,312,013 |
|
|
| 17,757,944 |
|
|
| 41,589 |
|
|
| 125,410,098 |
|
|
| 55,461,812 |
|
Nov |
|
| 16,962,509 |
|
|
| 3,034,497 |
|
|
| 19,978,440 |
|
|
| 1,930,951 |
|
|
| 118,767,704 |
|
|
| 41,883,285 |
|
Dec |
|
| 15,961,667 |
|
|
| 2,060,498 |
|
|
| 20,382,345 |
|
|
| 0 |
|
|
| 152,041,056 |
|
|
| 57,162,085 |
|
Total 2021 |
|
| 215,623,882 |
|
|
| 19,504,886 |
|
|
| 225,341,806 |
|
|
| 1,972,540 |
|
|
| 1,009,139,542 |
|
|
| 508,473,092 |
|
Prices for sales of energy under Resolution SE No. 95/13 framework were set and paid in pesos, while prices under Resolution SEE No. 19/17 were set in U.S. dollars and paid in pesos at the exchange rate as of day prior to the due date of each monthly sale of energy under Resolution SEE No. 19/17. In both cases, prices do not include the cost of fuel as, under these regulations, they are provided to the applicable generation company by CAMMESA free of charge.
Payments by CAMMESA to generators related to the sale of energy under the Energía Base during each month are due 42 days following the end of such month. As a result of delays in payments from distributors due to frozen tariffs, since 2012 we have seen a delay in the full payment for the monthly transactions by CAMMESA, which completes their monthly payment up to 80 days following the end of the relevant month, and on occasion as many as 101 days following the end of the month. However, from September 2016 to November 2017 CAMMESA has paid without delays, and since then, there were short periods in which CAMMESA experienced delays in paying. (for further information on the duration of these delays see “Item 11. Quantitative and Qualitative Disclosures about Market Risk—Credit Risk”).
From February 1, 2020, a new remuneration scheme for Energía Base came into force with Resolution SE No. 31/20, The main changes were:
| · | Prices are set in Argentine pesos. |
|
|
|
| · | Initial variable energy price although denominated in Argentine pesos, remained almost unchanged. The applicable exchange rate between the new price in Argentine pesos and the previous price in U.S. dollars was Ps.60 per U.S. dollar, similar to the average exchange rate during January 2020, of Ps. 60.01 per US dollar. |
|
|
|
| · | Initial power price for energy from thermal units were approximately reduced by16% and set in Argentine pesos. |
| · | Generation units with less than 30% Utilization Factor in the last twelve months receive 60% of the price, compared to up to 70% before. Additionally, if the Utilization Factor is between the 30-70% threshold the generation units receive a linear proportion between 60 and 100% of the power price, and if the Utilization factor is 70% or greater, the generation units receive 100% of the price. |
|
|
|
| · | Initial fixed power price for hydroelectric plants was approximately reduced by 45 % and set in Argentine pesos. |
|
|
|
| · | A new remuneration scheme for peak demand hours generation was established to partially mitigate the fixed power price, taking into consideration the equipment the generating company has. |
|
|
|
| · | The prices set in pesos will have a monthly adjustment with the following formula: (i) 60% of the CPI, plus (ii) 40% of the WPI (Stated in Annex VI of the Resolution 31). |
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Since February 2021, remuneration prices described above, were updated by about 29% by Resolution SE 440/21. This new resolution also introduced other changes regarding generation revenues.
For further information see “Item 4.B. Business Overview—The Argentine Electric Power Sector—Remuneration Scheme—The Current Remuneration Scheme” and “—The Previous Remuneration Schemes.”
Sales Under Contracts, Steam Sales and Others
Steam supply to YPF—Luján de Cuyo plant
On December 15, 2017, we signed a new steam supply contract with YPF for a period of 15 years. New cogeneration units were set in place, in order to provide YPF Lujan de Cuyo refinery with 125 tn/h of steam. Commercial operation started on October 5, 2019, This contract is denominated and invoiced in U.S. dollars. For further information on the steam supply agreements with YPF for the Luján de Cuyo plant, see “Item 5.A. Operating Results—Factors Affecting Our Results of Operations—Sales Under Contracts, Steam Sales and Others —Steam supply to YPF—Luján de Cuyo plant”.
Steam supply to T6 Industrial S.A.—Terminal 6 San Lorenzo plant
On December 27, 2017, we entered into a 15-year steam supply agreement with T6 Industrial S.A. for the new co-generation unit at our Terminal 6 San Lorenzo plant. The new cogeneration can supply up to 370 tn/h of steam to T6 Industrial. Commercial operation started on October 31, 2021
Resale of natural gas transportation capacity
The contract between us and TGS for the natural gas transportation capacity has remained effective after the La Plata Plant Sale in 2018. Pursuant to the terms of our agreement with YPF EE, we resell our gas transportation capacity to YPF EE through the resale system established by Resolution ENARGAS 419/97. The resale under such system is open to third parties and consequentially does not ensure that YPF EE will receive the gas transportation capacity needed to operate the La Plata plant. Therefore, on January 25, 2018, we requested to be registered with the Ministry of Energy and the ENARGAS as a natural gas seller to permit the resale of our gas transportation capacity to YPF EE without the risk of intervention from interested third parties. On July 20, 2018, we were effectively registered as natural gas sellers.
Electric Power Demand and Supply
Demand for electric power depends, to a significant extent, on economic and political conditions prevailing from time to time in Argentina, as well as seasonal factors. In general, the demand for electric power varies depending on the performance of the Argentine economy, as businesses and individuals generally consume more energy and are better able to pay their bills during periods of economic stability or growth. As a result, electric power demand is affected by Argentine Governmental actions concerning the economy, including with respect to inflation, interest rates, price controls, taxes and energy tariffs.
Following the 2001-2002 economic crisis, demand for electric power in Argentina grew consistently each year driven by the economic recovery and frozen tariffs. During 2014, electric power demand grew 0.98% compared to 2013, from 125,239 GWh to 126,467 GWh. During 2015, electric power demand grew 4.45% compared to 2014, from 126,467 GWh to 132,110 GWh, while during 2016, electric power demand grew 0.65% to 132,970 GWh. A new 26,320 MW record of capacity load was registered on February 8, 2018, which was 3.7% above the peak for 2016.On January 29, 2019 there was a new record for energy demand for a business day of 544.4 GWh.
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Electricity generation increased by 5.7% in 2021, from 134,177 GWh in 2020 to 141,797 GWh in 2021. Electricity generation increased by 2.3% in 2020, from 131,163 GWh in 2019. The chart below shows the supply of electric power in Argentina by source, including generation within Argentina from hydroelectric, thermal, nuclear, renewables, as well as electric power imported from neighboring countries (net of exports):
Source: CAMMESA.
The following chart shows the demand of energy for the year ended December 31, 2021:
Demand by region for year 2021 | Total Energy Demand | Generation of Central Puerto plants | |||||||||||||||||||||||
Puerto Complex | Luján de Cuyo Plant | Brigadier López Plant | Terminal 6 Plant | Piedra del Águila Plant | La Castellana | La Castellana II | Achiras | Los Olivos | Manque | La Genoveva | La Genoveva II | ||||||||||||||
MWh | % | MWh | % | MWh | % | MWh | % | MWh | % | MWh | % | MWh | % | MWh | % | MWh | % | MWh | % | MWh | % | MWh | % | ||
Great Buenos Aires | 50,651,258 | 6,562,913 | 13.0% | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - |
Litoral | 16,462,315 | - | - | - | - | 93,216 | 0.6% | 463,298 | 2.8% | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - |
Province Buenos Aires | 16,176,040 | - | - | - | - | - | - | - | - | - | - | 416,077 | 2.6% | 67,658 | 0,4% | - | - | - | - | - | - | 375,086 | 2.3% | 178,914 | 1.1% |
Center | 11,588,658 | - | - | - | - | - | - | - | - | - | - | - | - | - | - | 190,682 | 1.6% | 103,964 | 0.9% | 235,958 | 2.0% | - | - | - | - |
Northwest | 10,696,153 | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - |
Northeast | 9,840,344 | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - |
Cuyo | 7,996,938 | - | - | 3,136,287 | 39.2% | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - |
Patagonia | 5,543,716 | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - |
Comahue | 4,916,162 | - | - | - | - | - | - | - | - | 2,565,225 | 52.2% | - | - | - | - | - | - | - | - | - | - | - | - | - | - |
(1) | Demand data for 2021. |
(2) | Generation data for 2021. |
(3) | Generation by Central Puerto plants. |
During 2021, thermal generation continued to be the main source of electricity supply, contributing 90,073 GWh (64%), followed by hydroelectric generation net of pumping, which contributed 24,116 GWh (17%), nuclear generation, which contributed 10,170 GWh (7%) and photovoltaic and wind generation, which contributed 17,435 GWh (12%). There were also imports to cover domestic demand, in the amount of 819 GWh (0.6% of the total energy supplied, 32% lower than in 2020) from Uruguay, Paraguay and Brazil, and exports to Brazil in the amount of 3,089Wh (1.083% higher than in 2019) and transmission losses in the amount of 4,392 GWh (1.08% lower than in 2019Hydroelectric generation in 2020 registered a 17.7% decrease when compared to 2019, mainly due to a decrease of water levels, while thermal generation registered an increase of 2.7% mainly due to lower domestic demand, and the introduction of new renewable energy units. Nuclear generation registered a 26.3% increase when compared to 2019, due to higher generation availability in 2020, as compared to 2019. In this sense, thermal generation continued to be the main source for the supply of electric power, fueled both by natural gas and by liquid fuels (diesel oil and fuel oil), as well as mineral coal, mainly during the winter months. Finally, renewable energy generation increased 63% as compared to 2019, mainly due to the introduction of new wind and solar farms.
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During 2021, generation facilities increased their installed capacity from 41,951 MW in 2020 to 42,989 MW. This increase was caused mainly by the commencement of operations of new thermal and renewable energy units.
The State of Emergency of the Argentine Electric Power Sector
In December 2015, the prior administration enacted Decree No. 134/2015 declaring the state of emergency of the Argentine electric power sector until December 31, 2017. Pursuant to such decree, the Ministry of Energy was entrusted with the duties of developing and putting in place an action plan in connection with the electric power generation, transportation and distribution segments in order to improve the quality and security of electric power supply and guarantee the provision of this public service under suitable technical and economic conditions. These goals required additional investments in the several sectors of the productive chain in order to accommodate Argentina’s electric power supply and demand, which represent both a challenge and an opportunity for the sector’s players.
With respect to electric power generation, the Ministry of Energy publicly noted in 2016 the need for new generating capacity, which it stated should be addressed by the expansion of thermal and renewable energy sources by private sector companies, and, consequently, it took measures to boost generation capacity in order to ensure the supply of electric power and reduce the need for imports from neighboring countries. In this respect, the Ministry of Energy stressed that the country needed to incorporate 10 GW of generating capacity from conventional energy sources and 10 GW of generating capacity from renewable sources in order to meet increasing demand over the next ten years. Due to the situation of the industrial sector and the macroeconomic situation in Argentina, which led to a decrease in the demand of electric energy generation, it is unclear if the current administration will continue to pursue that goal.
Public Bid Process for Thermal Energy Generation Units
Pursuant to Resolution SEE No. 21/16, the Secretariat of Electric Energy called for bids to install new thermal generation units to become operational between Summer 2016/2017 (some of which are now operational) and Summer 2017/2018. The power generation companies awarded the bids entered into a PPA with CAMMESA, denominated in U.S. dollars, and electric power and capacity from these units will be remunerated at the price indicated in the bid and under the terms established in Resolution SEE No. 21/16.
Pursuant to Resolution SEE No. 287-E/17, the Argentine Government called for proposals for the supply of electric power to be generated through existing units, the conversion of open combined cycle units into closed combined cycle units or the installation of co-generation units. The main objectives behind this process were to (i) increase the supply of electric power generation from thermal generation units and (ii) strengthen the reliability of the Argentine electric power system with efficient generation units that have their own permanent and guaranteed fuel supply thus reducing the need for electric transportation and lowering the costs of the Argentine Government and the WEM.
Public Bid Process for New Renewable Energy Generation Units
On March 22, 2016, the Secretariat of Electric Energy called for bids to install 1,000 MW of new renewable energy units (the “RenovAR Program”). This bid process is governed by Law No. 27,191 and Decree No. 531/16, which encouraged the increase of energy generation from renewable sources by providing, among other things, significant tax benefits. See “Item 4.B. Business Overview—The Argentine Electric Power Sector—Structure of the Industry—RenovAR (Round 1, Round 1.5 and Round 2): Bidding Process for Renewable Energy Generation Projects.”
During 2015, electric power generation from renewable sources was 0.4% of the total supply of electric power in Argentina. As established in Section 2 of the Law referenced above, the purpose of this law is to have these renewable energy sources account for, at least, 8% of Argentina’s electric power consumption by December 31, 2017. During the second stage of the “National System for the Promotion of the Use of Renewable Energy Sources for Electricity Production,” the goal is to have renewable energy sources account for 12% of Argentina’s electric power consumption by December 31, 2019, 16% by December 31, 2021, 18% by December 31, 2023, and 20% by December 31, 2025, pursuant to Law No. 27,191.
The above framework provides a significant growth opportunity in the field of clean and renewable energies, especially considering that Large Users will be required to purchase energy from renewable sources in the same percentages mentioned above and will be subject to penalties if they do not comply with these requirements.
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Resolution No. 136/16, issued by the Ministry of Energy and Mining and published in the Official Gazette on July 26, 2016, launched the public auction process for submitting bids for Round 1 of the RenovAR Program. On October 7, 2016, the Ministry of Energy and Mining finalized the auction process for the installation of new renewable energy units and, under Resolution No. 136/16, granted awards in the amount of 1,108.65 MW, with an average price of US$59.58, including one biomass project, 12 wind energy projects and four solar energy projects. Of these, we were awarded one wind energy project for 99 MW of generating capacity at the price of US$61.50 per MWh, as further explained below in “Expansion of Our Generating Capacity.”
On October 31, 2016, the Ministry of Energy and Mining, pursuant to Resolution No. 252/16, launched Round 1.5 of the RenovAR Program as a continuation of Round 1. On November 25, 2016, the Ministry of Energy and Mining finalized the auction process for the installation of new renewable energy units and, under Resolution No. 281/16, granted awards in the amount of 1281.5 MW, with an average price of US$53.98 per MWh, including 10 wind energy projects and 20 solar energy projects. Of these, we were awarded one wind energy project for 48 MW of generating capacity at the price of US$59.38 per MWh, as further explained below in “Proposed Expansion of Our Generation Capacity.”
Following Rounds 1 and 1.5 of the RenovAR Program, the Ministry of Energy and Mining pursuant to Resolution No. 275/17, launched Round 2 of the programs on August 17, 2017, and granted awards in the amount of 2,043 MW of renewable power capacity.
We submitted bids for Round 2 of the RenovAR Program on October 19, 2017, and, on November 29, 2017, we were awarded a wind energy project called, “La Genoveva I,” which allowed us to add an additional capacity of 86.6 MW to our portfolio and to continue to build a presence in the renewable energies sector.
Expansion of Our Generating Capacity
The chart below shows the evolution of our power generating capacity since 2017:
Source: Central Puerto
____________
(1) | Effective as of January 5, 2018, we sold the La Plata plant to YPF EE. For further information, see “Item 4.A. History and development of the Company—La Plata Plant Sale.” |
(2) | On June 14, 2019 we purchased the Brigadier López plant. |
As of the date of this annual report, we have an aggregate installed capacity of 4,809 MW.
Currently, although power capacity is considered to be enough to supply the demand, there is a need for the incorporation of new efficient capacity in Argentina, from both conventional and renewable sources, in order to replace old inefficient units.
In recent years, we acquired 130 hectares of land in the north of the Province of Buenos Aires, in a convenient location for fuel delivery and future potential connection to power transmission lines. However, we cannot predict if or when the Argentine Government will open new auctions of new capacity and because of the competition among generation companies in these auction processes, we cannot predict whether we will be awarded the projects and whether we will be able to utilize these assets as intended.
We are also currently exploring several other options to diversify our generation assets to include sustainable power generation sources.
We believe we are well-positioned to identify and execute new growth opportunities. However, we cannot assure you that the Argentine Government will open new auction processes or that our bids will be successful or that we will be able to enter into new PPAs in the future. See “Item 3D. Risk Factors—Risks Relating to our Business— Factors beyond our control may affect or delay the completion of the awarded projects, or alter our plans for the expansion of our existing plants.”
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Sale of the La Plata Plant
On December 20, 2017, YPF EE accepted our offer to sell the La Plata plant for a total sum of US$31.5 million (without VAT), subject to certain conditions. On February 8, 2018, after such conditions were met, the plant was transferred to YPF EE, including generation assets, personnel and agreements related to the operation and/or maintenance of La Plata plant’s assets, with effective date January 5, 2018. Consequently, as of December 31, 2017, the La Plata plant was classified as a disposal group held for sale and its respective results were classified for the years ended December 31, 2018, and 2017 as a discontinued operation.
Presentation of Financial Statements in Pesos
Critical Accounting Policies
This discussion and analysis of our financial condition and results of operations is based upon our Audited Consolidated Financial Statements, which have been prepared in accordance with IFRS. The preparation of our Audited Consolidated Financial Statements requires us to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses and related disclosure of contingent liabilities.
Critical accounting policies are those that reflect significant judgments, estimates or uncertainties and could potentially lead to materially different results under different assumptions and conditions. We base our estimates on historical experience and on various other assumptions that we believe to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Existing circumstances and assumptions about future developments, however, may change due to market changes or circumstances arising beyond our control. Such changes are reflected in the assumptions when they occur. Therefore, actual results may differ from these estimates under different assumptions or conditions. These assumptions are reviewed at the end of each reporting period.
We have described below what we believe are our most critical accounting policies that involve a high degree of judgment and/or estimates and the methods of their application. For further information on the accounting policies and the methods used in the preparation of the Audited Consolidated Financial Statements, see Note 2.2 to our Audited Consolidated Financial Statements.
Impairment of Property, Plant and Equipment and Intangible Assets
We assess at each reporting period-end whether there is an existing event or one that took place after the reporting period and provides additional evidence of conditions that existed at the end of the reporting period, indicates that an individual component or a group of property, plant and equipment and/or intangible assets with limited useful lives may be impaired. If any indication exists, the Company estimates the asset’s recoverable amount. An asset’s recoverable amount is the higher of the fair value less costs to sell, and the value-in-use. That amount is determined for an individual asset, unless the asset does not generate cash inflows that are largely independent of those from other assets or groups of assets; in which case, such assets are considered together as a cash-generating unit (“CGU”).
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Where the carrying amount of an individual asset or CGU exceeds its recoverable amount, the individual asset or CGU, as the case may be, is considered impaired and is written down to its recoverable amount.
In assessing value in use of an individual asset or CGU, the estimated future cash flows are discounted to their present value using a pre-tax discount rate that reflects current market assessments of the time value of money and the risks specific to the individual asset or CGU, as the case may be.
In determining fair value less costs to sell, recent market transactions are taken into account, if available. If no such transactions can be identified, an appropriate valuation model is used, including obtaining appraisals from valution specialits. These calculations are verified by valuation multiples, quoted values for similar assets on active markets and other available fair value indicators, if any.
We base our impairment calculation on detailed budgets and forecast calculations which are prepared separately for each of the Company’s CGU to which the individual assets are allocated. These detailed budgets and forecast calculations generally cover a five-year period. For longer periods, if applicable, a long-term growth rate may be calculated and applied to project future cash flows after the fifth year. Budgets and calculations related to Complejo Hidroeléctrico Piedra del Águila are limited to the term of the concession contract.
Impairment losses are recognized in a specific line of the consolidated statement of income.
In addition, for the assets for which an impairment loss had been booked, as of each reporting period-end, an assessment is made whether there is any indication that previously recognized impairment losses may no longer exist or may have decreased.
Should there be such triggering event, the Company makes an estimate of the recoverable amount of the individual asset or of the cash generating unit, as the case may be.
A previously recognized impairment loss is reversed only if there has been a change in the assumptions used to determine the individual assets or CGU’s recoverable amount since the last impairment loss was recognized. The reversal is limited so that the carrying amount of the asset or CGU does not exceed its recoverable amount, nor exceed the carrying amount that would have been determined, net of the related depreciation or amortization, had no impairment loss been recognized for the asset or CGU in prior periods. Such reversal is recognized in the statement of income in the same line in which the related impairment charge was previously recognized (generally under the cost of sales or other operating expenses), unless the asset is carried at a revalued amount, in which case, the reversal is treated as a revaluation increase.
We have identified indicators of potential impairment of our property, plant and equipment and our intangible assets with limited useful life, affecting the CGUs related to the electric power generation from conventional sources operating segment, due to the repeal of the spot market price update mechanism established by Resolution 440, combined with the current economic uncertainties. We have also identified indicators of potential impairment of the Company’s gas turbine due to the uncertainty about new projects that would enable the use of such turbine.
In order to measure the recoverability of its property, plant and equipment and its intangible assets with a limited useful life that present indicators of impairment, we estimated the value in use of such assets, with the exception of the generating group classified as “Gas turbines”, for which the Company estimated the fair value less cost of sale. As a result of the recoverability analysis, we determined that the net book value of the assets related to the cogeneration unit Luján de Cuyo and hydroelectric power station Piedra del Águila and the generating group classified as “Gas turbines”, did not exceed their recoverable value as at December 31, 2021.
CGUs Thermal Station Brigadier López, Luján de Cuyo Combined Cycle Power Plant, Nuevo Puerto combined cycle power plant and Terminal 6 San Lorenzo cogeneration unit.
We estimated that the book value related to the Thermal Station Brigadier López exceeded its recoverable value by Ps. 4,703.1 million. Therefore, an impairment loss was recognized in the consolidated statement of income for the year ended December 31, 2021 as “Impairment of property, plant and equipment and intangible assets”. The impairment was allocated on a pro-rata basis to property, plant and equipment by Ps. 3,634.1 million to "Electric power facilities", "Lands and buildings", "Construction in progress" and "Others" and to intangible assets by Ps. 1,069 million. After recognizing this impairment, the net book value of property, plant and equipment and intangible assets related to Thermal Station Brigadier López amounted to Ps. 9,954.9 million and Ps. 2,279.4 million, respectively.
In addition, we estimated that the book value of the assets related to Luján de Cuyo Combined Cycle Power Plant exceeded its recoverable value by Ps. 599.2 million. Therefore, an impairment loss was recognized in the consolidated statement of income for the year ended December 31, 2021 as “Impairment of property, plant and equipment and intangible assets”. The impairment was allocated on a pro-rata basis to “Electric power facilities”, “Lands and buildings” and “Others”. After recognizing such impairment, the net book value of property, plant and equipment of Luján de Cuyo Combined Cycle Power Plant is Ps. 3,720.6 million.
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Also, we estimated that the book value of the assets related to Nuevo Puerto combined cycle power plant exceeded its recoverable value by Ps. 1,025.2 million. Therefore, an impairment loss was recognized in the consolidated statement of income for the year ended December 31, 2021 as “Impairment of property, plant and equipment and intangible assets”. The impairment was allocated on a pro-rata basis to “Electric power facilities”, “Lands and buildings” and “Others”. After recognizing such impairment, the net book value of property, plant and equipment of Nuevo Puerto combined cycle power plant is Ps. 4,221.9 million.
Finally, we estimated that the book value of the assets related to Terminal 6 San Lorenzo cogeneration unit exceeded its recoverable value by Ps. 1,437.5 million. Therefore, an impairment loss was recognized in the consolidated statement of income for the year ended December 31, 2021 as “Impairment of property, plant and equipment and intangible assets”. The impairment was allocated on a pro-rata basis to “Electric power facilities” and “Lands and buildings”. After recognizing such impairment, the net book value of property, plant and equipment of Terminal 6 San Lorenzo cogeneration unit is Ps. 37,402.8 million.
We estimated the recoverable value considering probability weighted scenarios in relation with the evolution of prices for energy and power. This approach required preparing scenarios with different estimations of the expected cash flows considering such variables and assigning occurrence probabilities, based on the experience and expectations of the Company about the outcome of the uncertainties involved.
Key assumptions to estimate the value in use are the following:
| - | Gross margin: the margin has been determined for the budgeted period (5 years) based on the energy prices arising from Resolution 440 adjusted for projections of price increases and applicable energy supply signed agreements, whereas the cost of sale was determined based on the costs incurred in the past. The most relevant cost was the plant maintenance, which was estimated with the provisions from the agreements in force with the suppliers General Electric and Siemens S.A. No growth rates were considered after the budgeted period, pursuant to IAS 36. |
|
|
|
| - | Discount rate: it represents the current market assessment of the specific risks of the Company, taking into consideration the time-value of money. Discount rate calculation is based on the circumstances of the market participants and it is derived from the weighted average cost of capital (WACC). The WACC rate takes into consideration both debt and equity. The cost of equity is derived from the expected return on investment by market participant investors, whereas the cost of debt is based on the conditions of the debt which market participants could access to. The specific risks of the operational segment are incorporated by applying individual beta factors, which are annually assessed from the available public information of the market. |
|
|
|
|
| The post-tax discount rate used for determining the value in use as of December 31, 2021 was 12.69%. |
|
|
|
|
| Any increase in the discount rate would result in an additional impairment loss. |
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|
| – | Macroeconomic variables: estimated inflation and devaluation rates, as well as exchange rates, were obtained from external sources, which are well known consulting firms dedicated to the local and global economic analysis, widely experienced in the market. An increase in inflation rates over devaluation rates, regarding the variables considered for the determination of the value in use, would entail an additional impairment loss. |
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| Thermal Station Brigadier López, Luján de Cuyo Combined Cycle Power Plant, Nuevo Puerto combined cycle power plant and Terminal 6 San Lorenzo cogeneration unit belong to the electric power generation from conventional sources operating segment. |
New standards and interpretations adopted
As from the fiscal year beginning January 1, 2021, we have applied for the first time certain new and/or amended standards and interpretations as issued by the IASB. A brief description of the new and/or amended standards and interpretations adopted by us and their impact on these consolidated financial statements, are presented below.
Interest Rate Benchmark Reform - Phase 2: Amendments to IFRS 9, IAS 39, IFRS 7, IFRS 4 and IFRS 16
The UK Financial Conduct Authority (FCA), advocated a transition away from reliance on LIBOR to alternative reference rates and stated that it would no longer persuade or compel banks to submit rates for the calculation of the LIBOR rates after 2021. The FCA Announcement formed part of ongoing global efforts to reform LIBOR and other major interest rate benchmarks. At this time, the nature and overall timeframe of the transition away from LIBOR is uncertain and no consensus exists as to what rate or rates may become accepted alternatives to LIBOR.
In this sense, the IFRS amendments provide temporary reliefs which address the financial reporting effects when an interbank offered rate (IBOR) is replaced with an alternative nearly risk-free interest rate (RFR).
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As of December 31, 2021, we have trade receivables under the CVO Agreement as well as loans with due date after 2021, which were indexed to LIBOR and for which the replacement alternative interest rate has not been identified.
These amendments are effective for annual periods beginning on or after 1 January 2021. As of the date of this annual report, these amendments had no significant impact.
IFRS Standards and Interpretations Issued but not yet effective
The following new and/or amended standards and interpretations have been issued but were not effective as of the date of issuance of our Audited Consolidated Financial Statements. In this sense, only the new and/or amended standards and interpretations that the Company expects to be applicable in the future are indicated. In general, the Company intends to adopt these standards, as applicable, when they become effective.
Amendments to IAS 1 - Classification of liabilities as current or non-current
On January 23, 2020, the IASB issued an amendment to IAS 1 Presentation of Financial Statements that affects the classification of liabilities as current and non-current. The changes affect the requirements of IAS 1 for the presentation of liabilities. Specifically, it clarifies the criteria for classifying liabilities as non-current. The date of application of the modification is set for fiscal years beginning on or after January 1, 2023, with retroactive application. We are evaluating the impact of these amendments for the presentation of liabilities.
Amendments to IAS 16 - Property, plant and equipment (“PPE”) - Earnings ahead of schedule
In May 2020, the IASB issued an amendment to IAS 16 that prohibits entities from deducting from the cost of an item of PPE, any proceeds of the sale of items produced while bringing that asset to the location and condition necessary for it to be capable of operating in the manner intended by management. Instead, an entity recognises the proceeds from selling such items, and the costs of producing those items, in profit or loss.
The amendments are effective for annual periods beginning on or after January 1, 2022 and must be applied retrospectively only to items of PPE made available for use on or after the beginning of the earliest period presented when the entity first applies the amendment.
The amendments are not expected to have a significant impact on our financial statements.
Amendments to IAS 37 - Onerous Contracts: Cost of Fulfilling a Contract
In May 2020, the IASB issued amendments to IAS 37 to specify which costs an entity needs to include when assessing whether a contract is onerous or loss-making.
The amendments apply a “directly related cost approach”. The costs that relate directly to a contract to provide goods or services include both incremental costs and an allocation of costs directly related to contract activities.
The amendments are effective for annual reporting periods beginning on or after January 1, 2022 and are not expected to have a significant impact on our financial statements.
Amendments to IFRS 3 - Reference to the Conceptual Framework
In May 2020, the IASB issued amendments to IFRS 3 Business Combinations - Reference to Conceptual Framework. The amendments are intended to replace a reference to a previous version of the IASB’s Conceptual Framework (the 1989 Framework) with a reference to the current version issued in March 2018 (the Conceptual Framework) without significantly changing its requirements.
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The amendments are effective for periods beginning on or after January 1, 2022 and must be applied retrospectively. Earlier application is permitted if, at the same time or earlier, an entity also applies all of the amendments contained in the Amendments to References to the Conceptual Framework in IFRS Standards (March 2018). The amendments will promote consistency in financial reporting and avoid potential confusion from having more than one version of the Conceptual Framework in use.
The amendments are not expected to have a significant impact on our financial statements.
Amendments to IAS 8 - Definition of Accounting Estimates
In February 2021, the IASB issued amendments to IAS 8, in which it introduces a new definition of “accounting estimates". The amendments clarify the distinction between changes in accounting estimates and changes in accounting policies and the correction of errors. Also, they clarify how entities use measurement techniques and inputs to develop accounting estimates.
The amended standard clarifies that the effects on an accounting estimate of a change in an input or a change in a measurement technique are changes in accounting estimates if they do not result from the correction of prior period errors. The previous definition of a change in accounting estimate specified that changes in accounting estimates may result from new information or new developments. Therefore, such changes are not corrections of errors.
The amendment is effective for annual periods beginning on or after January 1, 2023 and is not expected to have a significant impact on our financial statements.
Amendments to IAS 1 Presentation of Financial Statements
In February 2021, the IASB issued amendments to IAS 1 and IFRS Practice Statement No. 2 Making Materiality Judgements, in which it provides guidance and examples to help entities apply materiality judgements to accounting policy disclosures.
The amendments aim to help entities provide accounting policy disclosures that are more useful by:
| - | Replacing the requirement for entities to disclose their “significant” accounting policies with a requirement to disclose their “material” accounting policies, and |
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|
|
| - | Adding guidance on how entities apply the concept of materiality in making decisions about accounting policy disclosures. |
In assessing the materiality of accounting policy information, entities need to consider both the size of the transactions, other events or conditions and the nature of them.
The amendments are effective for annual periods beginning on or after January 1, 2023. Earlier application of the amendments to IAS 1 is permitted as long as this fact is disclosed. We are evaluating the impact of the amendments.
Amendments to IAS 12 - Deferred tax related to assets and liabilities arising from a single transaction
In May 2021, the IASB issued amendments to IAS 12, which narrow the scope of the initial recognition exception under IAS 12, so that it no longer applies to transactions that give rise to equal taxable and deductible temporary differences.
The amendments clarify that where payments that settle a liability are deductible for tax purposes, it is a matter of judgement (having considered the applicable tax law) whether such deductions are attributable for tax purposes to the liability recognised in the financial statements (and interest expense) or to the related asset component (and interest expense). This judgement is important in determining whether any temporary differences exist on initial recognition of the asset and liability.
Under the amendments, the initial recognition exception does not apply to transactions that, on initial recognition, give rise to equal taxable and deductible temporary differences. It only applies if the recognition of a lease asset and lease liability (or decommissioning liability and decommissioning asset component) give rise to taxable and deductible temporary differences that are not equal.
Nevertheless, it is possible that the resulting deferred tax assets and liabilities are not equal (e.g., if the entity is unable to benefit from the tax deductions or if different tax rates apply to the taxable and deductible temporary differences). In such cases, an entity would need to account for the difference between the deferred tax asset and liability in profit or loss.
The amendments are effective for annual periods beginning on or after January 1, 2023 and are not expected to have a significant impact on our financial statements.
Amendments to IFRS 10 Consolidated Financial Statements and IAS 28 Investments in Associates and Joint Ventures - Sale or Contribution of Assets between an Investor and its Associate or Joint Venture
The amendments address the conflict between IFRS 10 Consolidated Financial Statements and IAS 28 Investments in Associates and Joint Ventures in dealing with the loss of control of a subsidiary that is sold or contributed to an associate or joint venture.
The amendments clarify that a full gain or loss is recognised when a transfer to an associate or joint venture involves a business as defined in IFRS 3. Any gain or loss resulting from the sale or contribution of assets that does not constitute a business, however, is recognised only to the extent of unrelated investors’ interests in the associate or joint venture.
The IASB decided to defer the effective date of the amendments until such time as it has finalised any amendments that result from its research project on the equity method. The amendments must be applied prospectively. Early application of the amendments is still permitted and must be disclosed.
We will evaluate the impact of the amendments once effective and if there is any transaction to which the amendments apply.
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Segment Reporting
As of December 31, 2021, we divided our business into three segments: electric power generation from conventional sources, electric power generation from renewable sources and natural gas transport and distribution. Management and operations activities are not included in these these segments given that such information is not material for our business operations.
Results of Operations for the Years Ended December 31, 2021, 2020 and 2019
We discuss below: (i) our results of operations for the year ended December 31, 2021 as compared with our results of operations for the year ended December 31, 2020; and (ii) our results of operations for the year ended December 31, 2020 as compared with our results of operations for the year ended December 31, 2019.
|
| Year ended December 31, |
|
| Change December 31, |
| ||||||||||||||
|
| 2021 |
|
| 2020 |
|
| 2019 |
|
| 2021/2020 |
|
| 2020/2019 |
| |||||
|
| (in thousands of Ps.) |
|
| (in percentages) |
| ||||||||||||||
Revenues |
|
| 57,079,339 |
|
|
| 57,521,079 |
|
|
| 73,896,832 |
|
| (0.77 | %) |
| (22.16 | %) | ||
Cost of sales |
|
| (29,562,588 | ) |
|
| (25,381,445 | ) |
|
| (38,954,605 | ) |
|
| 16.47 | % |
| (34.84 | %) | |
Gross income |
|
| 27,516,751 |
|
|
| 32,139,634 |
|
|
| 34,942,227 |
|
| (14.38 | %) |
| (8.02 | %) | ||
Administrative and selling expenses |
|
| (4,151,623 | ) |
|
| (4,486,896 | ) |
|
| (5,411,458 | ) |
| (7.47 | %) |
| (17.09 | %) | ||
Impairment of property, plant and equipment and intangible assets |
|
| (7,765,017 | ) |
|
| (6,062,276 | ) |
|
| (9,050,812 | ) |
|
| 28.09 | % |
| (33.02 | %) | |
Other operating income |
|
| 10,919,061 |
|
| 21,280,499 |
|
|
| 37,714,518 |
|
| (48.69 | %) |
| (43.57 | %) | |||
Other operating expenses |
|
| 807,635 |
|
| (689,930 | ) |
|
| (556,380 | ) |
|
| 17.06 | % |
|
| 24.00 | % | |
Operating income |
|
| 25,711,537 |
|
|
| 42,181,031 |
|
|
| 57,638,095 |
|
| (39.04 | %) |
| (26.82 | %) | ||
(Loss) Gain on net monetary position |
|
| (1,653,978 | ) |
|
| 1,749,785 |
|
|
| (4,997,078 | ) |
| (194.52 | %) |
| (135.02 | %) | ||
Finance income |
|
| 1,942,647 |
|
|
| 7,788,279 |
|
|
| 7,399,195 |
|
| (75.06 | %) |
|
| 5.26 | % | |
Finance expenses |
|
| (17,815,205 | ) |
|
| (33,655,663 | ) |
|
| (32,724,460 | ) |
| (47.07 | %) |
|
| 2.85 | % | |
Share of the profit of associates |
|
| (564,502 | ) |
|
| 164,149 |
|
|
| 2,287,745 |
|
| (443.90 | %) |
| (92.82 | %) | ||
Income before income tax |
|
| 7,620,499 |
|
|
| 18,227,581 |
|
|
| 29,603,497 |
|
| (58.19 | %) |
| (38.43 | %) | ||
Income tax for the year |
|
| (8,268,362 | ) |
|
| (7,725,155 | ) |
|
| (11,806,062 | ) |
| 7.03 | % |
| (34.57 | %) | ||
Net (loss) income for the year |
|
| (647,863 | ) |
|
| 10,502,426 |
|
|
| 17,797,435 |
|
| (106.17 | %) |
| (40.99 | %) | ||
Revenues
|
| Year ended December 31, |
|
| Change December 31, |
| ||||||||||||||
|
| 2021 |
|
| 2020 |
|
| 2019 |
|
| 2021/2020 |
|
| 2020/2019 |
| |||||
|
| (in thousands of Ps.) |
|
| (in percentages) |
| ||||||||||||||
Energía Base (1) |
|
| 23,816,074 |
|
|
| 26,375,183 |
|
|
| 56,261,695 |
|
| (9.70 | %) |
| (53.12 | %) | ||
Sales under contracts(2) |
|
| 30,115,202 |
|
|
| 27,766,903 |
|
|
| 15,105,173 |
|
|
| 8.46 | % |
|
| 83.82 | % |
Steam sales(3) |
|
| 1,715,963 |
|
|
| 1,607,183 |
|
|
| 893,170 |
|
|
| 6.77 | % |
|
| 79.94 | % |
Resale of gas transport and distribution capacity |
|
| 307,995 |
|
|
| 595,979 |
|
|
| 588,289 |
|
| (48.32 | %) |
|
| 1.31 | % | |
Revenues from CVO thermal plant management |
|
| 1,124,105 |
|
|
| 1,175,831 |
|
|
| 1,048,505 |
|
| (4.40 | %) |
|
| 12.14 | % | |
Total revenues from ordinary activities |
|
| 57,079,339 |
|
|
| 57,521,079 |
|
|
| 73,896,832 |
|
| (0.77 | %) |
| (22.16 | %) | ||
____________
(1) | Includes (i) sales of energy and power to CAMMESA remunerated under Resolution No. 95, Resolution No. 19/2017, Resolution No. SE 1/2019, Resolution No.SE 31/2020 and Resolution No. 440/21 (ii) spot sales of energy and power to CAMMESA not remunerated under Resolution No. 95 (as amended), (iii) remuneration under Resolution No. 724/2008 relating to agreements with CAMMESA to improve existing Argentine power generation capacity and (iv) income under Res. SEE 70/18 (see “Item 4.B. Business Overview—The Argentine Electric Power Sector—Remuneration Scheme—The Previous Remuneration Schemes—Resolution SEE 70/18—Option to purchase fuel for units under Energía Base Regulatory Framework.”). |
(2) | Includes (i) term market sales under contracts and, (ii) energy sold under the Energía Plus, (iii ) contracts under the MATER framework and (iv) RenovAr Program sales under contracts (for further information regarding term market sales under contract, see “Item 4.B. Business Overview—Our Customers”) . |
(3) | Includes steam sold under steam sale contract with YPF from the Luján de Cuyo Plant and Terminal 6 cogeneration plant. |
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|
| Year ended December 31, |
|
| Change December 31, |
| ||||||||||||||
|
| 2021 |
|
| 2020 |
|
| 2019 |
|
| 2021/2020 |
|
| 2020/2019 |
| |||||
|
| (in thousands of Ps.) |
|
| (in percentages) |
| ||||||||||||||
Electric power generation from conventional sources |
|
| 44,300,944 |
|
|
| 44,876,174 |
|
|
| 66,001,178 |
|
| (1.28 | %) |
| (32.01 | %) | ||
Electric power generation from renewable sources |
|
| 11,346,295 |
|
|
| 10,873,096 |
|
|
| 6,258,860 |
|
|
| 4.35 | % |
|
| 73.72 | % |
Others(1) |
|
| 1,432,100 |
|
|
| 1,771,809 |
|
|
| 1,636,794 |
|
|
| (19.17 | %) |
|
| 8.25 | % |
Total revenues |
|
| 57,079,339 |
|
|
| 57,521,079 |
|
|
| 73,896,832 |
|
| (0.77 | %) |
| (22.16 | %) | ||
____________
(1) Includes resale of gas transport and distribution capacity and management and operation of thermal plant CVO.
2021 Compared to 2020
Revenues in 2021 totaled Ps.57.08 billion, a 0.77% decrease from Ps. 57.52 billion in 2020. This decrease was primarily attributable to:
| 1. | a 9.7% decrease in spot sales/Energía Base, which amounted to Ps.23.82 billion during 2021, as compared to Ps. 26.38 billion in 2020, mainly due to the decrease in energy generation from our Piedra del Águila hydroelectric plant. |
partially offset by:
| 1. | a 8.46% rise in sales under contracts, which amounted to Ps. 30.12 billon in 2021, compared to Ps. 27.77 billion in 2020 due to the commencement of operations of Terminal 6 and full-year operation of La Genoveva I, Manque and Los Olivos wind farms. |
| 2. | a 6.77% increase in steam sales, which totaled Ps. 1.72 billion in 2021, compared to Ps. 1.61 billion in 2020, due to a 12% increase in production as a result of the production good performance of our operations in the Province of Mendoza and the commencement of operations of Terminal 6, which was partially offset by the fact that inflation’s adjustment surpassed the peso’s depreciation in the period. |
Revenues attributable to electric power generation from conventional sources in the year ended December 31, 2021 totaled Ps.44.30 billion, a 1.28% decrease from Ps.44.88 billion in the year ended December 31, 2020. This decrease is mainly attributable to the decrease in spot sales/Energía Base described above, which was partially offset by the rise in sales under conctracts due to the commencement of operations of Terminal 6 and the increase in steam sales also described above.
Revenues attributable to electric power generation from renewable sources in the year ended December 31, 2021 totaled Ps.11.35 billion, a 4.35% increase from Ps.10.87 billion in the year ended December 31, 2020. This increase is mainly attributable to the full-year operation of La Genoveva I, Manque and Los Olivos wind farms.
2020 Compared to 2019
Revenues in 2020 totaled Ps. 57.52 billion, a 22.16% decrease from Ps. 73.9 billion in 2019. This decrease was primarily attributable to:
| 1. | the abrogation of Resolution No. 70/2018, on December 30, 2019, which resulted on less fuel remuneration for units under the Energía Base regulatory framework . Also, revenues were negatively impacted by a price reduction due to Resolution SE No. 31/2020. |
Excluding fuel remuneration, revenues for 2020 would have been Ps. 55.6 billion, an 8.09% increase compared to Ps. 51.44 billion for 2019. This increase was mainly due to:
| 1. | An 83.82% increase in sales under contracts, which amounted to Ps.27.77 billion during 2020, as compared to Ps. 15.11 billion in 2019, mainly due to the operation during all of 2020 of La Castellana II (15.2 MW), La Genoveva II (41.8 MW) wind farms that commenced their commercial operations during the third quarter of 2019, and Manque (57 MW), Los Olivos (22.8 MW) and La Genoveva I (88.2 MW), which started operations during December 2019 (partially), February 2020, and November 2020, respectively. To a lesser extent, the increase was also due to Brigadier Lopez and Lujan de Cuyo’s COD. |
| 2. | A 79.94% increase in steam sales, mainly due to the new Luján de Cuyo cogeneration unit, which totaled Ps.1.61 billion during 2020, as compared to Ps. 0.89 billion in 2019. |
| 3. | This increase was partially offset by a decrease in spot sales/Energía Base (Revenues from Resolution 1, Resolution 31, Resolution No.19, SGE Resolution No.70/2018 and amendments), which, without considering the remuneration associated to the self-procured fuel under Resolution SE. No. 70/18 mentioned above, were Ps. 24.5 billion in 2020 as compared to Ps. 33.8 billion in 2019, mainly due to the a decrease in prices for units under the Energía Base Regulatory framework established by Resolution SE No. 31/2020, in force since February 1, 2020, and the suspension of the monthly price adjustment procedure under Annex VI of such resolution which was instructed by the Secretariat of Energy to CAMMESA on April 8, 2020. |
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| 4. | To a lesser extent, spot sales/Energía Base were also affected by (i) a decrease in machine availability for thermal units which was 89% during 2020, compared to 93% in 2019, mainly due to (w) a failure in the main transformer of the Siemens branded combined cycle which returned to service on July 16, 2020, (x) some steam turbines from Lujan de Cuyo operated most of the year with power limitation and (y) certain failures in the combined cycle of Puerto’s complex during June and October 2020, and (z) the unavailability for some of the steam turbines of the Puerto complex; and (ii) a 12% decrease in energy generation from the hydro plant Piedra del Águila due to lower waterflow in the Limay and Collón Curá rivers. |
Revenues attributable to electric power generation from conventional sources in the year ended December 31, 2020, totaled Ps.44.88 billion, a 32.01% decrease from Ps.66.00 billion in the year ended December 31, 2019. This decrease is mainly explained by the abrogation of Resolution No. 70/2018 mentioned above and by the decrease in prices for units under the Energía Base Regulatory framework established by Resolution SE No. 31/2020, in force since February 1, 2020, and the suspension of Annex VI of such resolution (monthly price adjustment procedure) instructed by the Secretariat of Energy to CAMMESA on April 8, 2020.
Revenues attributable to electric power generation from renewable sources in the year ended December 31, 2020, totaled Ps.10.87 billion, a 73.72% increase from Ps.6.26 billion in the year ended December 31, 2019. This increase is mainly explained by the operation during all of 2020 of La Castellana II (15.2 MW) and La Genoveva II (41.8 MW) wind farms that commenced their commercial operations during the third quarter of 2019, and Manque (57 MW), Los Olivos (22.8 MW) and La Genoveva I (88.2 MW) wind farms, which started operations during December 2019 (partially), February, and November 2020, respectively.
Cost of Sales
|
| Year ended December 31, |
|
| Change December 31, |
| ||||||||||||||
|
| 2021 |
|
| 2020 |
|
| 2019 |
|
| 2021/2020 |
|
| 2020/2019 |
| |||||
|
| (in thousands of Ps.) |
|
| (in percentages) |
| ||||||||||||||
Inventories at the beginning of the year |
|
| 2,207,300 |
|
|
| 1,647,569 |
|
|
| 934,386 |
|
|
| 33.97 | % |
|
| 76.33 | % |
Purchases |
|
| 6,174,758 |
|
|
| 5,510,012 |
|
|
| 21,349,001 |
|
|
| 12.06 | % |
| (74.19 | %) | |
Operating expenses: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Compensation to employees |
|
| 4,333,694 |
|
|
| 4,363,107 |
|
|
| 4,869,264 |
|
| (0.67 | %) |
| (10.39 | %) | ||
Other long-term employee benefits |
|
| 205,817 |
|
|
| 157,574 |
|
|
| 141,432 |
|
|
| 30.62 | % |
|
| 11.41 | % |
Depreciation of property, plant and equipment |
|
| 7,637,642 |
|
|
| 5,465,104 |
|
|
| 4,047,123 |
|
|
| 39.75 | % |
|
| 35.04 | % |
Amortization of intangible assets |
|
| 3,073,753 |
|
|
| 3,523,429 |
|
|
| 2,920,414 |
|
| (12.76 | %) |
|
| 20.65 | % | |
Purchase of energy and power |
|
| 192,977 |
|
|
| 216,503 |
|
|
| 192,451 |
|
| (10.87 | %) |
|
| 12.50 | % | |
Fees and compensation for services |
|
| 1,401,161 |
|
|
| 1,417,559 |
|
|
| 875,922 |
|
| (1.16 | %) |
|
| 61.84 | % | |
Maintenance expenses |
|
| 3,635,639 |
|
|
| 2,660,334 |
|
|
| 2,698,995 |
|
|
| 36.66 | % |
| (1.43 | %) | |
Consumption of materials and spare parts |
|
| 1,152,038 |
|
|
| 773,063 |
|
|
| 969,451 |
|
|
| 49.02 | % |
| (20.26 | %) | |
Insurance |
|
| 1,283,956 |
|
|
| 1,081,107 |
|
|
| 709,193 |
|
|
| 18.76 | % |
|
| 52.44 | % |
Levies and royalties |
|
| 384,896 |
|
|
| 676,828 |
|
|
| 789,808 |
|
| (43.13 | %) |
| (14.30 | %) | ||
Taxes and assessments |
|
| 89,104 |
|
|
| 77,810 |
|
|
| 69,807 |
|
|
| 14.51 | % |
|
| 11.46 | % |
Taxes on bank account transactions |
|
| 9,180 |
|
|
| 9,881 |
|
|
| 10,119 |
|
| (7.09 | %) |
| (2.35 | %) | ||
Other |
|
| 13,174 |
|
|
| 8,865 |
|
|
| 24,808 |
|
|
| 48.61 | % |
| (64.26 | %) | |
Transfers to property, plant and equipment |
|
| (403,609 | ) |
|
| ― |
|
|
| ― |
|
|
| ― |
|
|
| ― |
|
Inventories at the end of the year |
|
| (1,828,892 | ) |
|
| (2,207,300 | ) |
|
| (1,647,569 | ) |
| (17.14 | %) |
|
| 33.97 | % | |
Total cost of sales |
|
| 29,562,588 |
|
|
| 25,381,445 |
|
|
| 38,954,605 |
|
|
| 16.47 | % |
| (34.84 | %) | |
| 137 |
| Table of Contents |
|
| Year ended December 31, |
|
| Change December 31, |
| ||||||||||||||
|
| 2021 |
|
| 2020 |
|
| 2019 |
|
| 2021/2020 |
|
| 2020/2019 |
| |||||
|
| (in thousands of Ps.) |
|
| (in percentages) |
| ||||||||||||||
Electric power generation from conventional sources |
|
| 25,186,092 |
|
|
| 21,434,437 |
|
|
| 36,244,484 |
|
|
| 17.50 | % |
| (40.86 | %) | |
Electric power generation from renewable sources |
|
| 3,378,745 |
|
|
| 2,845,346 |
|
|
| 1,496,052 |
|
|
| 18.75 | % |
|
| 90.19 | % |
Others(1) |
|
| 997,751 |
|
|
| 1,101,662 |
|
|
| 1,214,069 |
|
| (9.43 | %) |
| (9.26 | %) | ||
Total cost of sales |
|
| 29,562,588 |
|
|
| 25,381,445 |
|
|
| 38,954,605 |
|
|
| 16.47 | % |
| (34.84 | %) | |
____________
(1) Includes resale of gas transport and distribution capacity and management and operation of thermal plant CVO.
2021 Compared to 2020
Cost of sales during the year ended December 31, 2021 totaled Ps.29.56 billion, a 16.47% increase from Ps.25.38 billion in 2020. This increase was mainly the result of:
| 1. | (i) a 12.06% increase in purchases of fuel and spare parts, which totaled Ps. 6.17 billion in 2021 and (ii) a 14.59% increase in costs of production, mainly due to (x) an increase in depreciations, (y) a rise in maintenance expenses and (z) to a lesser extent, an increase in consumption of materials and spare parts. |
Cost of sales attributable to electric power generation from conventional sources in the year ended December 31, 2021, totaled Ps.25.19 billion, a 17.50% increase from Ps.21.43 billion in the year ended December 31, 2020. This increase is mainly attributable to the increase in purchases of fuel and spare parts and the increase in costs of production, as described above.
Cost of sales attributable to electric power generation from renewable sources in the year ended December 31, 2021, totaled Ps.3.38 billion, a 18.75% increase from Ps.2.85 billion in the year ended December 31, 2020. This increase was mainly attributable to the full-year operation of La Genoveva I, Manque and Los Olivos wind farms.
2020 Compared to 2019
Cost of sales during the year ended December 31, 2020, totaled Ps.25.38 billion, a 34.84% decrease from Ps.38.95 billion during the year ended December 31, 2019. This decrease was mainly the result of:
| 1. | a 74.19% decrease in purchases of fuel and spare parts by Central Puerto, which amounted to Ps.5.51 billion during 2020, as compared to Ps. 21.35 billion in 2019. |
Cost of sales attributable to electric power generation from conventional sources in the year ended December 31, 2020, totaled Ps. 21.43 billion, a 40.86% decrease from Ps.36.24 billion in the year ended December 31, 2019. This decrease was mainly attributable to the decrease in purchases of fuel and spare parts as described above.
Cost of sales attributable to electric power generation from renewable sources in the year ended December 31, 2020, totaled Ps.2.85 billion, a 90.19% increase from Ps.1.50 billion in the year ended December 31, 2019. This increase was mainly attributable to the operation during all of 2020 of La Castellana II (15.2 MW) and La Genoveva II (41.8 MW) wind farms that commenced their commercial operations during the third quarter 2019, and Manque (57 MW), Los Olivos (22.8 MW) and La Genoveva I (88.2 MW) wind farms, which started operations during December 2019 (partially), February 2020, and November 2020, respectively.
Gross Income
2021 Compared to 2020
Gross income during the year ended December 31, 2021 totaled Ps.27.52 billion, a 14.38% decrease from Ps.32.14 billion during the year ended December 31, 2020, due to the reasons mentioned above. Gross margin for the year ended December 31, 2021 was 48.21%, compared to a gross margin of 55.87% during the same period in 2020.
| 138 |
| Table of Contents |
2020 Compared to 2019
Gross income during the year ended December 31, 2020 totaled Ps.32.14 billion, a 8.02% decrease from Ps. 34.94 billion during the year ended December 31, 2019, due to the reasons mentioned above. Gross margin for the year ended December 31, 2020 was 55.87%, compared to a gross margin of 47.29% during the same period in 2019.
Administrative and Selling Expenses
|
| Year ended December 31, |
|
| Change December 31, |
| ||||||||||||
|
| 2021 |
|
| 2020 |
|
| 2019 |
|
| 2021/2020 |
| 2020/2019 |
| ||||
|
| (in thousands of Ps.) |
|
| (in percentages) |
| ||||||||||||
Electric power generation from conventional sources |
|
| 3,612,032 |
|
|
| 3,857,347 |
|
|
| 4,856,894 |
|
| (6.36 | %) | (20.58 | %) | |
Electric power generation from renewable sources |
|
| 539,591 |
|
|
| 629,549 |
|
|
| 554,564 |
|
| (14.29 | %) |
| 13.52 | % |
Total administrative and selling expenses |
|
| 4,151,623 |
|
|
| 4,486,896 |
|
|
| 5,411,458 |
|
| (7.47 | %) | (17.09 | %) | |
____________
2021 Compared to 2020
Administrative and selling expenses during the year ended December 31, 2021 totaled Ps.4.15 billion, a 7.47% decrease from Ps.4.49 billion during the year ended December 31, 2020. This decrease was primarily the result of a reduction in taxes on bank account transactions and other taxes during the year ended December 31, 2021.
2020 Compared to 2019
Administrative and selling expenses during the year ended December 31, 2020 totaled Ps.4.49 billion, a 17.09% decrease from Ps.5.41 billion during the year ended December 31, 2019. This decrease was primarily the result of:
| 1. | a 47.49% decrease in taxes on bank account transactions as a result of the revenue drop during the year ended December 31, 2020; and |
|
|
|
| 2. | a 21.24% decrease in fees and compensation for services. |
Impairment of property, plant and equipment and intangible assets
|
| Year ended December 31, |
|
| Change December 31, | ||||||||||||||
|
| 2021 |
|
| 2020 |
|
| 2019 |
|
| 2021/2020 |
|
| 2020/2019 | |||||
|
| (in thousands of Ps.) |
|
| (in percentages) | ||||||||||||||
Electric power generation from conventional sources |
|
| 7,765,017 |
|
|
| 6,062,276 |
|
|
| 9,050,812 |
|
|
| 28.09 | % |
| (33.02 | %) |
Total impairment of property, plant and equipment and intangible assets |
|
| 7,765,017 |
|
|
| 6,062,276 |
|
|
| 9,050,812 |
|
|
| 28.09 | % |
| (33.02 | %) |
____________
2021 Compared to 2020
In 2021, we recorded a Ps. 7.77 billion impairment of property, plant and equipment and intangible assets charge, related to a reduction in the assessed value-in-use of the following assets that exceeded their previously recorded book value: Thermal Station Brigadier López, Luján de Cuyo Combined Cycle Power Plant, Nuevo Puerto combined cycle power plant and Terminal 6 San Lorenzo cogeneration unit . Some of the factors that influenced this reduction were the limited useful life of some of these assets, the current economic uncertainties, and the effects from the repeal of the spot market price update mechanism established by Resolution 440.For further information, see “Item 5.A. Operating Results Critical Accounting Policies Impairment of property, plant and equipment and intangible assets.”
In 2020, we recorded a Ps. 6.06 billion impairment of property, plant and equipment and intangible assets charge, mainly related to a reduction in the assessed value-in-use of certain assets that exceeded their previously recorded book value, related to our Brigadier López plant and our Lujan de Cuyo Combined Cycle plant and also related to the assessed fair value less cost of sales of some of the gas turbines that the Company holds for potential new projects. Some of the factors that influenced this reduction were the limited useful life of these assets, the drop in the Company’s stock price, the current economic uncertainties, the suspension of the spot market price update mechanism established by Resolution SE No.31/2020, and in the particular case of the Company’s gas turbines, the uncertainty about the feasibility of new projects that would enable the use of the acquired turbines. For further information, see “Item 5.A. Operating Results Critical Accounting Policies Impairment of property, plant and equipment and intangible assets.”
| 139 |
| Table of Contents |
2020 Compared to 2019
In 2020, we recorded a Ps. 6.06 billion impairment of property, plant and equipment and intangible assets charge, mainly related to a reduction in the assessed value-in-use of certain assets that exceeded their previously recorded book value, mainly related to our Brigadier López plant and our Lujan de Cuyo Combined Cycle plant and also related to the assessed fair value less cost of sales of some of the gas turbines we hold for potential new projects. Some of the factors that influenced this reduction were the limited useful life of these assets, the drop in our stock price, the current economic uncertainties, the suspension of the spot market price update mechanism established by Resolution SE No. 31/2020, and in the particular case of our gas turbines, the uncertainty about the feasibility of new projects that would enable the use of the acquired turbines. For further information, see “Item 5.A. Operating Results Critical Accounting Policies Impairment of property, plant and equipment and intangible assets.”
In 2019, we recorded a Ps. 9.05 billion impairment of property, plant and equipment and intangible assets charge, mainly related to a reduction in the assessed value-in-use of certain assets that exceeded their previously recorded book value, related to our Brigadier López plant and also related to the assessed fair value less cost of sales of some of the gas turbines we hold for potential new projects. Some of the factors that influenced this reduction were the limited useful life of these assets, the drop in our stock price, the current economic uncertainties, the conversion of the electric and power spot market tariff into Argentine pesos, and in the particular case of our gas turbines, the uncertainty about the feasibility of new projects that would enable the use of the acquired turbines. For further information, see “Item 5.A. Operating Results Critical Accounting Policies Impairment of property, plant and equipment and intangible assets.”
Other Operating Income
|
| Year ended December 31, |
|
| Change December 31, |
| ||||||||||||||
|
| 2021 |
|
| 2020 |
|
| 2019 |
|
| 2021/2020 |
|
| 2020/2019 |
| |||||
|
| (in thousands of Ps.) |
|
| (in percentages) |
| ||||||||||||||
Electric power generation from conventional sources |
|
| 10,476,409 |
|
|
| 20,621,029 |
|
|
| 37,496,269 |
|
| (49.20 | %) |
| (45.01 | %) | ||
Electric power generation from renewable sources |
|
| 422,821 |
|
|
| 659,470 |
|
|
| 173,699 |
|
| (35.88 | %) |
|
| 279.66 | % | |
Others(1) |
|
| 19,831 |
|
|
| - |
|
|
| 44,550 |
|
|
| 100.00 | % |
| (100.00 | %) | |
Total other operating income |
|
| 10,919,061 |
|
|
| 21,280,499 |
|
|
| 37,714,518 |
|
| (48.69 | %) |
| (43.57 | %) | ||
____________
(1) Includes management and operation of thermal plant CVO..
2021 Compared to 2020
Other operating income in the year ended December 31, 2021 totaled Ps. 10.92 billion, a 48.69% decrease from Ps. 21.28 billion in the year ended December 31, 2020. This decrease was primarily the result of a decrease in foreign exchange rates difference, net, mainly due to a 22.07% devaluation of the peso with respect to the U.S. dollar in 2021 while during 2020 the foreign exchange rate increased 40.67%, and a decrease in interest earned from customers.
2020 Compared to 2019
Other operating income in the year ended December 31, 2020 totaled Ps.21.28 billion, a 43.57% decrease from Ps. 37.71 billion in the year ended December 31, 2019. This decrease was primarily the result of:
| 1. | a 32.47%, decrease in foreign exchange gains from trade payables and receivables, net denominated in U.S. dollars mainly due to a 40.67% devaluation of the peso with respect to the U.S. dollar in 2020 while during 2019 the foreign exchange rate increased 59.07%; and |
|
|
|
| 2. | a 64.53%, decrease in interests from trade payables and receivables. |
| 140 |
| Table of Contents |
Other Operating Expenses
|
| Year ended December 31, |
|
| Change December 31, |
| ||||||||||||||
|
| 2021 |
|
| 2020 |
|
| 2019 |
|
| 2021/2020 |
|
| 2020/2019 |
| |||||
|
| (in thousands of Ps.) |
|
| (in percentages) |
| ||||||||||||||
Electric power generation from conventional sources |
|
| 818,208 |
|
|
| 486,902 |
|
|
| 28,105 |
|
| (68.04 | %) |
|
| 1,632.44 | % | |
Electric power generation from renewable sources |
|
| (10,573 | ) |
|
| 195,408 |
|
|
| 520,801 |
|
| (105.41 | %) |
| (62.48 | %) | ||
Others(1) |
|
| — |
|
|
| 7,620 |
|
|
| 7,474 |
|
| (100.00 | %) |
|
| 1.95 | % | |
Total other operating expenses |
|
| 807,635 |
|
|
| 689,930 |
|
|
| 556,380 |
|
|
| 17.06 | % |
|
| 24.00 | % |
____________
(1) Includes management and operation of thermal plant CVO.
2021 Compared to 2020
Other operating expenses in the year ended December 31, 2021 totaled Ps. 807.64 million, a 17.06% increase from Ps.689.93 million in the year ended December 31, 2020.This increase was primarily the result of an increase of Ps. 43.78 million in the net charge related to the provision for lawsuits and claims, and an increase of Ps. 61.23 million of trade and tax interests.
2020 Compared to 2019
Other operating expenses in the year ended December 31, 2020 totaled Ps.689.93 million, a 24.00% increase from Ps.556.38 million in the year ended December 31, 2019. This increase was primarily the result of an increase of Ps. 563.16 million in interest, which was partially offset by a Ps. 414.49 million decrease in charges related to discount of tax credits.
Operating Income
|
| Year ended December 31, |
|
| Change December 31, |
| ||||||||||||
|
| 2021 |
|
| 2020 |
|
| 2019 |
|
| 2021/2020 |
| 2020/2019 |
| ||||
|
| (in thousands of Ps.) |
|
| (in percentages) |
| ||||||||||||
Electric power generation from conventional sources |
|
| 17,396,004 |
|
|
| 33,656,241 |
|
|
| 53,317,152 |
|
| (48.31 | %) | (36.88 | %) | |
Electric power generation from renewable sources |
|
| 7,861,353 |
|
|
| 7,862,263 |
|
|
| 3,861,142 |
|
| (0.01 | %) |
| 103.63 | % |
Others(1) |
|
| 454,180 |
|
| 662.527, |
|
|
| 459,801 |
|
| (31.45 | %) |
| 44.09 | % | |
Total operating income |
|
| 25,711,537 |
|
|
| 42,181,031 |
|
|
| 57,638,095 |
|
| (39.04 | %) | (26.82 | %) | |
____________
(1) Includes resale of gas transport and distribution capacity and management and operation of thermal plant CVO.
2021 Compared to 2020
For the reasons explained above, operating income in the year ended December 31, 2021 totaled Ps.25.71 billion, a 39.04% decrease from Ps.42.18 billion in the year ended December 31, 2020. This is mainly explained by a decrease in CVO and FONI receivables and minor currency exchange differences of those receivables and an increase in the costs of sales, primarily driven by an increase in purchases of fuel and spare parts and an increase in costs of production, mainly due to (i) an increase in depreciations (ii) a rise in maintenance expenses and, (iii) to a lesser extent, an increase in consumption of materials and spare parts.
2020 Compared to 2019
For the reasons explained above, operating income in the year ended December 31, 2020 totaled Ps.42.18 billion, a 26.82% decrease from Ps.57.64 billion in the year ended December 31, 2019. This is mainly explained by a decrease in CVO and FONI receivables and minor currency exchange differences of those receivables.
| 141 |
| Table of Contents |
Finance Income
2021 Compared to 2020
Finance income in the year ended December 31, 2021 totaled Ps.1.94 billion, a 75.06% decrease from Ps.7.79 billion in the year ended December 31, 2020. This decrease was primarily the result of a decrease in net income on financial assets at fair value.
2020 Compared to 2019
Finance income in the year ended December 31, 2020 totaled Ps.7.79 billion, a 5.26% increase from Ps.7.4 billion in the year ended December 31, 2019. This increase was primarily the result of
| 1. | an increase in net income on financial assets at fair value through profit or loss, totaling Ps.7.6 billion in the year ended December 31, 2020, compared to Ps. 7.34 million in the year ended December 31, 2019; and |
|
|
|
| 2. | an increase in interest gains, totaling Ps.194.24 million in the year ended December 31, 2020, compared to Ps. 60.59 million in the year ended December 31, 2019. |
Finance Expenses
2021 Compared to 2020
Finance expenses in the year ended December 31, 2021 totaled Ps.17.82 billion, a 47.07% decrease from Ps.33.66 billion in the year ended December 31, 2020. This decrease was primarily the result of a lower foreign exchange difference, which decreased from Ps. 26.14 billion in 2020 to Ps. 12.36 billion in 2021, mainly due to a lower U.S. dollar-denominated debt balance and a lower depreciation of the Argentine peso.
2020 Compared to 2019
Finance expenses in the year ended December 31, 2020 totaled Ps.33.66 billion, a 2.85% increase from Ps.32.72 billion in the year ended December 31, 2019. This increase was primarily the result of foreign exchange differences on loans and borrowings, a 5.76% increase compared to the year ended December 2019, partially offset by a decrease in interest on loans, totaling Ps. 5.5 billion in 2020, compared to Ps. 6.6 billion in 2020, driven by a decrease in financial loans.
Share of the Profit of Associates
2021 Compared to 2020
Share of the profit of associates in the year ended December 31, 2021 totaled a Ps.0.56 billion loss during 2021 compared to a gain of Ps. 0.16 billion in 2020, mainly due to the loss resulting from the operations of Ecogas in 2021.
2020 Compared to 2019
Share of the profit of associates in the year ended December 31, 2020 totaled a gain of Ps.0.16 billion, a 92.82% decrease from Ps.2.29 billion in the year ended December 31, 2019. This decrease was primarily the result of (a) a profit of Ps. 149 million from our interest in Ecogas through IGCE, DGCE and IGCU in the year ended December 31, 2020, as compared to Ps.2.1 billion in the year ended December 31, 2019 and (b) a loss of Ps.24 million from our interest in TGM in the year ended December 31, 2020, as compared to a loss of Ps.14 million in the year ended. December 31, 2019.
Income Tax
2021 Compared to 2020
Income tax in the year ended December 31, 2021 totaled Ps.8.27 billion, a 7.03% increase from Ps.7.73 billion in the year ended December 31, 2020. Our effective tax rate for the year ended December 31, 2021 and 2020 was 108.5% and 42.38%, respectively. This increase was mainly due to the changes in tax rate of the corporate income tax and the no recognition of the deferred tax assets related to a portion of tax loss carryforward for which there is no certainty about the existence of future taxable income against which it could be applied.
2020 Compared to 2019
Income tax in the year ended December 31, 2020 totaled Ps.7.73 billion, a 34.57% decrease from Ps.11.81 billion in the year ended December 31, 2019. This decrease was primarily the result of decreased taxable income in the year ended December 31, 2020. Our effective tax rate for 2020 and 2019 was 42.38% and 39.88%, respectively.
| 142 |
| Table of Contents |
Net (loss) Income for the Year
2021 Compared to 2020
For the reasons described above, net loss for the year ended December 31, 2021 totaled Ps.0.65 billion, compared to a gain of Ps.10.50 billion in the year ended December 31, 2020.
2020 Compared to 2019
For the reasons described above, net income for the year ended December 31, 2020 totaled Ps.10.5 billion, a 40.99% decrease from Ps. 17.8 billion in the year ended December 31, 2019.
Item 5.B Liquidity and Capital Resources
As of December 31, 2021, we had cash and cash equivalents of Ps.0.28 billion, and other current financial assets of Ps19.84 billion. See Note 15 and 13.6 to our Audited Consolidated Financial Statements.
Our primary sources of liquidity have been cash flows from operating activities, cash flows from the proceeds of the sale of our temporary investments, and financing provided by equipment suppliers or service providers.
Our receivables from CAMMESA also are an important source of liquidity for us. As of December 31, 2021, our current trade and other receivables from CAMMESA and other customers totaled Ps.22.75 billion.
Our primary cash requirements have been in connection with payments under loans and other financing agreements, employees’ salaries, operating and maintenance expenses and fixed assets investments, taxes, and other overhead expenses. See “Item 5.A.—The State of Emergency of the Argentine Electricity Sector—Expansion of our Generating Capacity.”
Our loans and other borrowings contain customary covenants for facilities of each type, including: (i) certain limitations on consolidations, mergers, and sales of assets; (ii) restrictions on incurring additional indebtedness; (iii) restrictions on paying dividends; (iv) limitations on making capital expenditures and (v) restrictions on the incurrence of liens. Certain events of default and covenants are subject to certain thresholds and exceptions. We do not expect these restrictions to have a material impact on our ability to meet our cash obligations. As of the date of this annual report, we are in compliance with all of our debt covenants.
The Company does not discard the option to pursue potential financing alternatives, if the conditions are favorable.
As of the date of this annual report, we also have uncommitted lines of credit with commercial banks, totaling approximately Ps. 8.95 billion.
As discussed in Note 13.3 to our financial statemens, we have no significant payments related to loans and borrowings scheduled for 2022. During 2023 we will need to make payments of installments under the Citibank N.A., JP Morgan Chase Bank N.A. and Morgan Stanley Senior Funding INC. loan and CP Manque S.AU. and CP Los Olivos S.A.U. corporate bonds. We expect to make the aforementioned payments mainly with liquity from our operations.
We believe that our sources of liquidity, which are mainly the result of operations, will be sufficient to meet our debt service and working capital requirements for the foreseeable future. Also, given that the Company’s expansion plan has been completed in 2021, we do not expect to have any material requirements regarding capital expenditures except for the requirements for Brigadier Lopez close cycle project that has not yet a defined date for commencement.
However, any further deterioration of the current economic situation may result in a deterioration of the Company’s finances, in a context of lack of access or substantial reduction of credit availability in the financial markets, which could affect our financial condition and results of operation. See “Item 3.D Risk Factors—Risk Relating to Our Business—An outbreak of a disease, including COVID-19, may have material adverse consequences on our operations including new projects”.
Receivables from CAMMESA
We hold receivables in the form of LVFVD for the unpaid balances from CAMMESA relating to the sale of electric power to CAMMESA from 2008 to 2011. For further information, see “Item 4.B. Business Overview—FONINVEMEM and Similar Programs.” Under the FONINVEMEM and similar arrangements, we are entitled to collect our receivables, including interest, in monthly installments over ten years starting from, the commercial launch date of the CVOSA combined cycle. For further information, see “Item 4.B. Business Overview—FONINVEMEM and Similar Programs.”
Following the commercial authorizations granted to the Manuel Belgrano power plant (on January 7, 2010) and the San Martín power plant (on February 2, 2010), we started to collect monthly payments of the receivables relating to the sale of electric power to CAMMESA from January 2004 through December 2007. As of December 31, 2020, there was no balance owed to us under the FONINVEMEM arrangement relating to the sale of electric power to CAMMESA from 2004 through 2007 During the year ended December 31, 2020, we received Ps. 0.5 billion (US$3.98 million in U.S. dollar-denominated payments) in principal and interest for these receivables (including VAT).
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As of March 20, 2018, CAMMESA granted the CVO Commercial Approval in the WEM, as a combined cycle, of the thermal plant Central Vuelta de Obligado, which entitled us to receive the collection of the trade receivables under the CVO Agreement. A PPA between the CVO Trust and CAMMESA, through which the CVO Trust makes energy sales and, consequently, receives the cash flow to pay the trade receivables, had to be signed in order to start the collections. The PPA agreement was signed on February 7, 2019, with retroactive effect to March 20, 2018. As a result, the original amortization schedule from the CVO Agreement is in full force and effect. As of December 31, 2021, the CVO “LVFVD 2008-2011 receivables” totaled Ps.36.05 billion.
After the CVOSA power plant became operational, in the case of receivables accrued between 2008 and September 2010, the amount due was converted into U.S. dollars at the exchange rate effective at the date of the CVO Agreement (i.e., November 25, 2010), which was Ps.3.97 per U.S. dollar. Additionally, certain receivables that accrued after September 2010 and that were also included in the CVO Agreement, were converted into U.S. dollars at the exchange rate effective at the due date of each monthly sale transaction. The total estimated amount due was US$548 million plus accrued interests after the CVO Commercial Approval. The U.S. denominated monthly payments under the CVO Agreement are payable in pesos, converted at the applicable exchange rate in place at the time of each monthly payment.
During 2020, we collected Ps. 9.5 billion in CVO receivables, measured in current amounts as of December 31, 2021. During 2021, we collected Ps.8.2 billion in CVO receivables, measured in current amounts as of December 31, 2021.
Additionally, we held receivables in the form of LVFVD for the unpaid balances from CAMMESA relating to the sale of electric power to CAMMESA under the additional trust remuneration concept since 2012. On September 3, 2019, CAMMESA and Central Puerto (in accordance with a general offer made to all generators) entered into a final agreement to settle the LVFVD receivables balance. As a result, a 18% reduction of principal amount and accrued interest as of such date was achieved. Moreover, the Company waived any complaint related to such receivables. Pursuant to the agreement, during September 2019, the Company collected Ps. 3,730 million and booked a net profit of Ps. 8,039 million, which was recognized in “Interest earned from customers” under the item “Other operating income” of the 2019 annual consolidated income statement.
For further information regarding sales relating to additional trust remuneration and non-recurring maintenance, see “Item 5.A. Operating Results—Our Revenues—The Energía Base” and “Item 4.B. Business Overview—The Argentine Electric Power Sector—Remuneration Scheme—The Previous Remuneration Schemes.”
Cash Flows
The following table sets forth our cash flows from our operating, investing and financing activities for the periods indicated:
|
| Year ended December 31, |
| |||||||||
|
| (in thousands of Ps.) |
| |||||||||
|
| 2021 |
|
| 2020 |
|
| 2019 |
| |||
Net cash flows provided by operating activities |
|
| 26,035,917 |
|
|
| 29,122,100 |
|
|
| 24,605,353 |
|
Net cash flows used in investing activities |
|
| (6,924,183 | ) |
|
| (26,095,028 | ) |
|
| (57,341,352 | ) |
Net cash provided by (used in) financing activities |
|
| (19,166,890 | ) |
|
| (5,559,727 | ) |
|
| 35,205,631 |
|
Increase (Decrease) in cash and cash equivalents, net |
|
| (55,156 | ) |
|
| (2,532,655 | ) |
|
| 2,469,632 |
|
Net Cash Provided by Operating Activities
2021 Compared to 2020
Net cash provided by operating activities decreased by 10.6% to Ps.26.04 billion for the year ended December 31, 2021, from Ps.29.12 billion for the year ended December 31, 2020. The decrease was primarily driven by (i) a decrease of Ps. 3.65 billion of the stock of trade receivables, mainly related to the FONI collections, (ii) a decrease of Ps. 3.52 billion in collection of interests from clients, including the ones from FONI and (iii) a decrease of Ps. 7.77 billion non-cash impairment of property, plant and equipment and intangible assets charge included in the operating income, which was partially offset by (iv) an increase of Ps. 6.88 billion non-cash foreign exchange difference on trade receivables, (v) a decrease of Ps. 4.41 billion from income tax paid, and (vi) a Ps. 6.89 billion reduction in trade and other payables, other non-financial liabilities and liabilities from employee benefits.
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2020 Compared to 2019
Net cash provided by operating activities increased by 18.36% to Ps.29.12 billion for the year ended December 31, 2020, from Ps.24.61 billion for the year ended December 31, 2019. The increase was primarily driven by (i) increased revenues as a result of an increase in the exchange rate for 2020, which impacted directly on tariffs set in U.S. dollars, an increase in our revenues from sales under contracts and an increase in our revenues from steam sales; and (ii) a decrease in interest collected from clients and a decrease in the income tax paid in 2020 as compared to income tax paid in 2019.
Net Cash Used in Investing Activities
2021 Compared to 2020
Net cash used in investing activities decreased by 73.47% to Ps.6.92 billion for the year ended December 31, 2021, from Ps.26.10 billion for the year ended December 31, 2020. The decrease was primarily driven by (i) Ps. 5.37 billion in payments for the purchase of property, plant, and equipment mainly related to the construction of Terminal 6 thermal project that were lower than during 2020, (ii) Ps. 5.34 billion from the acquisition of short-term financial assets, net, that also were lower than during 2020; which was partially offset by (iii) Ps. 3.64 billion obtained in the sale of property, plant, and equipment and (iv) Ps. 0.14 billion in dividends collected.
2020 Compared to 2019
Net cash used in investing activities decreased by 54.49% to Ps.26.10 billion for the year ended December 31, 2020, from Ps.57.34 billion for the year ended December 31, 2019. The decrease was primarily driven by a decrease in payments for purchases of property, plant and equipment used primarly for the construction of the wind farms La Genoveva I, Manque, Los Olivos and Terminal 6 San Lorenzo cogeneration plants, compared to the payments of 2019.
Net Cash (Used in) provided by Financing Activities
2021 Compared to 2020
Net cash used in financing activities totaled Ps. 19.17 billion for the year ended December 31, 2021, compared to Ps.5.56 billion in net cash provided by financing activities during the year ended December 31, 2020. This variation was primarily driven by (i) an increase in bank and investment accounts overdrafts paid, and (ii) an increase in loans paid, mainly related to the loans received for the expansion projects
2020 Compared to 2019
Net cash used in financing activities totaled Ps.5.56 billion for the year ended December 31, 2020, compared to Ps. 35.21 billion in net cash provided by financing activities during the year ended December 31, 2019. This variation was primarily driven by (i) long-term loans received and (ii) an increase in interest and other financial costs paid in 2020 as compared to 2019 and (iii) an increase in long-term loans paid.
Capital Expenditures
The following table sets forth our capital expenditures for the years ended December 31, 2021, 2020 and 2019.
|
| Year ended December 31, |
| |||||||||
|
| (in thousands of Ps.) |
| |||||||||
|
| 2021 |
|
| 2020 |
|
| 2019 |
| |||
Land and buildings |
|
| 5,018 |
|
|
| 7,796 |
|
|
| 2,174,921 |
|
Electric power facilities |
|
| - |
|
|
| 157,259 |
|
|
| 17,417,558 |
|
Gas turbines |
|
| 1,448 |
|
|
| - |
|
|
| - |
|
Construction in progress |
|
| 5,071,193 |
|
|
| 16,941,084 |
|
|
| 36,403,516 |
|
Other |
|
| 120,019 |
|
|
| 180,187 |
|
|
| 128,530 |
|
Total |
|
| 5,197,678 |
|
|
| 17,286,326 |
|
|
| 56,124,525 |
|
____________
In the year ended December 31, 2021, we made total capital expenditures of Ps.5.2 billion, compared to Ps. 17.29 billion in 2020. During these years, the main additions to fixed assets and land were in connection with proposed projects for the expansion of our installed capacity. During the year ended December 31, 2021, our main capital expenditure was the construction of Terminal 6-San Lorenzo thermal project.
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In the year ended December 31, 2020, we made total capital expenditures of Ps.17.29 billion, compared to Ps. 56.12 billion in 2019. During these years, the main additions to fixed assets and land were in connection with proposed projects for the expansion of our installed capacity. During the year ended December 31, 2020, our main capital expenditure was the construction of Terminal 6-San Lorenzo thermal project, and the renewable projects, Manque, Los Olivos and La Genoveva I.
We have funded our capital expenditures with proceeds from debt issuances and cash generated from our operations.
Additionally, capital expenditures estimated for our projects under development are approximately US$130 million for the expansion of the Brigadier López plant. However, due to the uncertainties mentioned in this report we cannot estimate when these capital expenditures will be made. Depending on the timing for the construction of these projects, we may finance these capital expenditures using cash flows from our operations and/or using external financing sources. See “Item 3D. Risk Factors—Risks Relating to our Business— Factors beyond our control may affect or delay the completion of the awarded projects, or alter our plans for the expansion of our existing plants.”
Equity interests in DGCU and DGCE
In addition to the expenditures on physical assets, on July 23, 2014, we executed agreements to purchase, directly and indirectly, subject to certain conditions, equity interests in DGCU and DGCE, jointly with an investment consortium. On January 7, 2015, all acquisition-related conditions established in the agreement were met, and the shares were transferred to us.
Taking into account both direct and indirect interests involved, we acquired (i) an interest equivalent to 21.58% of DGCU’s capital stock and (ii) an interest equivalent to 40.59% of DGCE’s capital stock.
In addition, as provided for by Argentine Capital Markets Law and CNV regulations, and given our controlling interest in DGCU shared with the consortium of buyers described above, our Board of Directors decided to proportionally participate in a tender offer by the consortium of buyers for all of DGCU’s outstanding shares issued and not owned, directly or indirectly, by us or by of any of the members of the consortium of buyers. On October 30, 2015, the board of directors of the CNV approved the tender offer. Upon termination of the tender offer in January 2016, since no acceptances were tendered, no shares were acquired in this tender offer.
At a meeting of our shareholders on December 16, 2016, in accordance with the strategic objective of focusing on assets within the energy industry, the shareholders considered a potential sale of our equity interests in Ecogas, but voted to postpone the decision. We are currently assessing various strategic opportunities regarding DGCU and DGCE, including a possible partial or total sale of our equity interest in them. On January 26, 2018, the shareholders of DGCE approved the admission of DGCE to the public offering regime in Argentina. On March 14, 2018, the Company authorized the offer of up to 10,075,952 common class B shares of DGCE, in a potential public offering authorized by the CNV, subject to market conditions. This authorization was encompassed within the February 23, 2018 authorization of the Board of Directors for the sale of up to 27,597,032 common B shares of DGCE. However, due to market conditions, DGCE shareholders decided to postpone the offer. On October 24, 2019, the CNV notified DGCE the cancellation of the authorization for the public offering.
Indebtedness
As of December 31, 2021, our total indebtedness was Ps. 43 billion of which 100% was denominated in U.S. dollars. The following table shows our indebtedness as of such date:
|
| December 31, |
| |||||
|
| 2021 |
| |||||
|
| (in thousands of US$) |
|
| (in thousands of Ps.) |
| ||
Current debt |
|
| 66,340 |
|
|
| 6,814,403 |
|
Non-Current debt |
|
| 352,241 |
|
|
| 36,182,243 |
|
____________
Borrowing from Kreditanstalt für Wiederaufbau (“KfW”)
On March 26, 2019 the Company entered into a loan agreement with KfW for an amount of US$56 million in relation to the acquisition of two gas turbines, equipment and related services relating to the Luján de Cuyo project described in Note 20.7 to our Audited Consolidated Financial Statements. In accordance with the terms of the agreement, the loan accrues an annual interest equal to LIBOR plus 1.15% and it is amortizable quarterly in 47 equal and consecutive installments as from the day falling six months after the commissioning of the gas turbines and equipment, which occurred on October 5, 2019.
Pursuant to the loan agreement, among other obligations, Central Puerto has agreed to maintain a debt ratio of (a) as of December 31, 2019 of no more than 4.00:1.00 and (b) as from that date, no more than 3.5:1.00. As of December 31, 2021, the Company has complied with that requirement.
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During fiscal year 2019, the planned disbursements for this loan were completed for a total of US$ 55.2 million.
As of December 31, 2021, the balance of this loan, amounts to US$ 45.59 million, approximately equivalent to Ps. 3.69, net of transaction costs.
Loan from Citibank N.A., JP Morgan Chase Bank N.A. and Morgan Stanley Senior Funding INC.
On September 12, 2019, the Company entered into a loan agreement with Citibank N.A., JP Morgan Chase Bank N.A. and Morgan Stanley Senior Funding INC. for US$180 million to fund the acquisition of the Thermal Plant Brigadier (the “Brigadier Lopez Loan”).
Pursuant to the agreement, Brigadier Lopez Loan accrues an adjustable annual interest rate based on LIBOR plus margin.
Pursuant to the loan agreement, among other obligations, Central Puerto has agreed to maintain (i) a debt ratio of no more than 2.25:1.00; (ii) an interest coverage ratio of no more than 3.50:1.00 and (iii) and a minimum equity of US$500 million. As of December 31, 2021, the Company complied with such obligations.
On September 15, 2020, BCRA issued Communication “A” 7106 (“FX Regulatory Restrictions 7106”) pursuant to which any Argentine debtor that has scheduled principal payments of indebtedness due between October 15, 2020 and March 31, 2021 and payable in foreign currency (subject to certain exceptions), is required, in order to access to the official exchange market, to file with the BCRA a refinancing plan in respect of such indebtedness, which shall fulfill certain conditions established in the regulation, such as the following (i) the net amount for which the debtor shall have access to the official foreign exchange market to meet its foreign currency denominated payments of principal shall not exceed 40% of the aggregate principal amount due between October 15, 2020 and March 31, 2021 and (ii) the remaining principal amount is required to be deferred such that the repayment of the deferred principal amounts is due on average two years later than the originally scheduled principal amortization payments. The installments under Brigadier Lopez Loan becoming due between December 2020 and March 2021 were under the scope of such regulation.
In compliance with FX Regulatory Restrictions 7106, the Company presented to the BCRA a new repayment schedule for the Brigadier Lopez Loan, which included the refinancing of the first two principal installments, each for a sum of US$ 36 million,which were payable on December 14, 2020 and March 12, 2021. On December 14, 2020, the Company entered into a forbearance agreement with the creditors of the Brigadier Lopez Loan by means of which the creditors agreed not to take any judicial or extrajudicial action to claim their rights of collection under the such loan and to negotiate in good faith certain modifications. On December 22, 2020, the Company signed a waiver and amendment to the Brigadier Lopez Loan, modifying, among others, the amortization schedule so as to comply with the requirements established by Communication “A” 7106, partially postponing installments becoming due in December 2020 and March 2021, extending the final payment term to June 2023, including monthly amortizations as from January 2021 until January 2022, and keeping the amortizations in the initial schedule for June, September and December 2021, each of them equal to 20% of capital. In December 2020, 40% of the installment for such month was paid, complying with the regulations in force and the abovementioned amendment. Amongst others, the amendment involves a 200 basis points increase in the interest rates as from December 12, 2020.
The amendment of the Brigadier Lopez Loan contains a more restrictive covenant package than under the original loan, which includes a prohibition to make dividends payment during 2021 and a US$ 25 million maximum allowed for dividends payment in 2022. Moreover, a collateral agreement was signed, which includes the pledge on turbines of Brigadier López Thermal Station, a mortgage on the land in which such power station is located and a LVFDV passive collection collateral assignment.
FX Regulatory Restrictions 7106 were extended until December 31, 2021 by Communication “A” 7230. The installments under the Brigadier Lopez Loan due in June, September and December 2021 were under the scope of the provisions of such regulation. As a consequence, the Company signed a new amendment, which changed the amortization schedule, rescheduling 60% of installments, whose original maturity date operated in June, September and December 2021, and extending the loan’s final term up to January 2024. The schedule in force, which includes this amendment and the one dated December 22, 2020, foresees monthly amortizations until January 2022, one amortization in June 2023 for the amount of U.S.$34.128 million and the last amortization in January 2024 for the amount of U.S.$55.1 million. Moreover, the financial commitments and obligations undertaken in the first amendment remained unchanged.
This new amendment also implied a 125 basis pointst increase in the applicable interest rate as from June 12, 2021 and the dividend payment restriction was maintained until 2021, as well as the U.S.$ 25 million limitation for 2022. During 2023, the maximum dividend payment allowed is U.S.$20 million.
As of the date of this annual report, all payments provided in the amendments have been made.
As of December 31, 2021, the balance of the loan, amounts to US$ 90.5 million, approximately equivalent to Ps.9.21 billion net of transaction costs.
See “Item 3.D. Risk Factors—Risks Relating to Argentina—Exchange controls and restrictions on capital inflows and outflows could limit the availability of international credit and could threaten the financial system, adversely affecting the Argentine economy and, as a result, our business” and “ —Risks Relating to Our Business—We may be unable to refinance our outstanding indebtedness, or the refinancing terms may be materially less favorable than their current terms, which would have a material adverse effect on our business, financial condition and results of operations.”
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Brigadier López Financial Trust
On June 14, 2019 we purchased the Brigadier López Plant from IEASA. As part of the deal, Central Puerto replaced IEASA as the trustor of the Brigadier López Financial Trust Agreement. The trustee of the Brigadier López Financial Trust Agreement is BICE Fideicomisos.
Under the terms of the trust agreement, the financial debt accrues interest at an annual rate equal to the greater of (i) LIBOR plus 5% or (ii) 6.25%. BICE Fideicomisos as the trustee, is in charge of the administration, and pays such debt, using for that purpose the proceeds from certain components of the sales of Brigadier Lopez power plant that were assigned to the Brigadier López Financial Trust Agreement and are paid monthly directly by CAMMESA to the Brigadier López Financial Trust Agreement. Additionally, there is a reserve account, for a total amount equivalent to two monthly debt services. In case of insolvency of the Brigadier López Financial Trust, creditors have no recourse against the assets of Central Puerto other than the components of the sales of Brigadier Lopez power plant that were assigned to the Trust.
The financial debt balance of the trust as of December 2021 amounts to US$32.08 million, approximately equivalent to Ps. 3.3 billion.
As of the date of this annual report, this financial debt has been cancelled.
Loans from the IIC—IFC Facilities
CP La Castellana
On October 20, 2017, CP La Castellana entered into a common terms agreement with (i) the Inter-American Investment Corporation, (ii) the Inter-American Investment Corporation, acting as agent for the Inter-American Development Bank, (iii) the Inter-American Investment Corporation, as agent of the Inter-American Development Bank, in its capacity as administrator of the Canadian Climate Fund for the Private Sector of the Americas, and (iv) the International Finance Corporation (collectively, the “senior lenders”) to provide loans for a total amount of up to US$100,050,000 (the “IIC—IFC Facility I”), from which US$5 million will accrue interest at an annual rate equal to LIBOR plus 3.5% and the rest at LIBOR plus 5.25%, and shall be repaid in 52 quarterly equal installments. Several other agreements and related documents, such as the guarantee and sponsor support agreement, where we will fully, unconditionally and irrevocably guarantee, as primary obligor, all payment obligations assumed and/or to be assumed by CP La Castellana until the project reaches the commercial operation date (the “Guarantee and Sponsor Support Agreement I”), hedge agreements, guarantee trust agreements, a share pledge agreement, an asset pledge agreement over the wind turbines, direct agreements and promissory notes have been executed.
Pursuant to the Guarantee and Sponsor Support Agreement I, among other customary covenants for this type of facilities, we committed, until the La Castellana project completion date, to maintain (i) a leverage ratio of (a) until (and including) December 31, 2018, not more than 4.00:1.00; and (b) thereafter, not more than 3.5:1.00; and (ii) an interest coverage ratio of not less than 2.00:1.00. In addition, our subsidiary, CP Renovables, and we, upon certain conditions, agreed to make certain equity contributions to CP La Castellana.
We also agreed to maintain, unless otherwise consented to in writing by each senior lender, ownership and control of the CP La Castellana as follows: (i) until the La Castellana project completion date, (a) we shall maintain (x) directly or indirectly, at least seventy percent (70%) beneficial ownership of CP La Castellana; and (y) control of CP La Castellana; and (b) CP Renovables shall maintain (x) directly, ninety-five percent (95%) beneficial ownership of CP La Castellana; and (y) control of CP La Castellana. In addition, (ii) after La Castellana project completion date, (a) we shall maintain (x) directly or indirectly, at least fifty and one tenth percent (50.1%) beneficial ownership of each of CP La Castellana and CP Renovables; and (y) control of each of CP La Castellana and CP Renovables; and (b) CP Renovables shall maintain control of CP La Castellana
On August 18, 2018, La Castellana I wind farm reached the commercial operation date. La Castellana “project completion date” is defined in the common terms agreement as the date in which the commercial operation date has occurred and certain other conditions have been met, which is expected to occur several months after the commercial operation date. For further information on La Castellana project see “Item 5.A. Operating Results—Factors Affecting Our Results of Operations—Expansion of Our Generating Capacity.”
As of the date of this annual report, the IIC-IFC Facility disbursements have been fully received.
CP Achiras
On January 17, 2018, CP Achiras entered into a common terms agreement with (i) the Inter-American Investment Corporation, (ii) the Inter-American Investment Corporation, acting as agent for the Inter-American Development Bank, (iii) the Inter-American Investment Corporation, as agent of the Inter-American Development Bank, in its capacity as administrator of the Canadian Climate Fund for the Private Sector of the Americas, and (iv) the International Finance Corporation (collectively, the “senior lenders”) to provide loans for a total amount of up to US$50,700,000 (the “IIC—IFC Facility II” and together with the IIC—IFC Facility I, the “IIC—IFC Facilities”). In accordance with the terms of the agreement entered into by CP Achiras, US$ 40.7 million accrue a fixed annual interest rate equal to 8.05%, and the rest accrue a 6.77% fixed annual interest rate. The loan is amortizable quarterly in 52 equal and consecutive installments as from May 15, 2019 Several other agreements and related documents, such as the guarantee and sponsor support agreement, where we will fully, unconditionally and irrevocably guarantee, as primary obligor, all payment obligations assumed and/or to be assumed by CP Achiras until the project reaches the commercial operation date (the “Guarantee and Sponsor Support Agreement II” and together with Guarantee and Sponsor Support Agreement I, the “Guarantor and Sponsor Support Agreements”), guarantee trust agreements, a share pledge agreement, a mortgage, an asset pledge agreement over the wind turbines, direct agreements and promissory notes have been executed.
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Pursuant to the Guarantee and Sponsor Support Agreement II, among other customary covenants for this type of facilities, we committed, until the Achiras project completion date, to maintain (i) a leverage ratio of (a) until (and including) December 31, 2018, not more than 4.00:1.00; and (b) thereafter, not more than 3.5:1.00; and (ii) an interest coverage ratio of not less than 2.00:1.00. In addition, our subsidiary, CP Renovables, and we, upon certain conditions, agreed to make certain equity contributions to CP Achiras.
We also agreed to maintain, unless otherwise consented to in writing by each senior lender, ownership and control of the CP Achiras as follows: (i) until the Achiras project completion date, (a) we shall maintain (x) directly or indirectly, at least seventy percent (70%) beneficial ownership of CP Achiras; and (y) control of CP Achiras; and (b) CP Renovables shall maintain (x) directly, ninety-five percent (95%) beneficial ownership of CP Achiras; and (y) control of CP Achiras. In addition, (ii) after Achiras project completion date, (a) we shall maintain (x) directly or indirectly, at least fifty and one tenth percent (50.1%) beneficial ownership of each of CP Achiras and CP Renovables; and (y) control of each of CP Achiras and CP Renovables; and (b) CP Renovables shall maintain control of CP Achiras.
On September 20, 2018, the Achiras wind farm reached the commercial operation date. The Achiras “project completion date” is defined in the common terms agreement as the date in which the commercial operation date has occurred and certain other conditions have been met, which is expected to occur several months after the commercial operation date. For further information on the Achiras project see “Item 5.A. Operating Results—Factors Affecting Our Results of Operations—Expansion of Our Generating Capacity.”
As of the date of this annual report, the IIC-IFC Facility disbursements have been fully received.Our loans under the IIC—IFC Facilities (see “Item 5.B.—Loans from the IIC—IFC Facilities”) contain customary covenants for facilities of this type, including: (i) certain limitations on consolidations, mergers and sales of assets; (ii) restrictions on incurring additional indebtedness; (iii) restrictions on paying dividends; (iv) limitations on making capital expenditures and (v) restrictions on the incurrence of liens. Certain events of default and covenants in the IIC—IFC Facilities are subject to certain thresholds and exceptions described in the agreements relating to the IIC—IFC Facilities. We do not expect these restrictions to have a material impact on our ability to meet our cash obligations. As of the date of this annual report, we are in compliance with all of our debt covenants.
As of December 31, 2021, the balance under the CP Achiras and CP La Castellana Loans from the IIC—IFC Facilities, was US$ 118 million, approximately equivalent to Ps.11.79 billion, net of transaction costs.
Loan from the IFC to the subsidiary Vientos La Genoveva S.A.U.
On June 21, 2019, Vientos La Genoveva S.A.U., a subsidiary of the Company, entered into a loan agreement with IFC on its own behalf, as Eligible Hedge Provider and as an implementation entity of the Managed Co-Lending Portfolio Program (MCPP) administered by IFC, for the construction of the wind Farm La Genoveva I, for a principal amount of US$76.1 million.
Pursuant to the terms of the agreement, the loan accrues interest at an annual rate equal to LIBOR plus 6.50%,and amortizes quarterly in 55 installments from November 15, 2020.
Other related agreements and documents, such as the Guarantee and Sponsor Support Agreement (the “Guarantee Agreement” by which Central Puerto completely, unconditionally and irrevocably guarantees, as the main debtor, all payment obligations undertaken by Vientos La Genoveva S.A.U until the project reaches the project completion date) hedging agreements, guarantee trusts, guarantee agreements on shares, guarantee agreements on wind turbines, direct agreements and promissory notes have been signed.
Pursuant to the Guarantee Agreement, among other customary covenants for this type of facilities, Central Puerto has committed, until the project completion date, to maintain (i) a leverage ratio of not more than 3.5:1.00; and (ii) an interest coverage ratio of not less than 2.00:1.00. In addition, Central Puerto, upon certain conditions, agreed to make certain equity contributions to Vientos La Genoveva S.A.U. As of December 31, 2021, the Company has met the requirements described in (i) and (ii) above.
On November 22, 2019, Vientos La Genoveva S.A.U. received a disbursement of US$76.1 million for the total amount of the loan.
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As of December 31, 2021, balance of this loan, was US$ 71.71 million, approximately equivalent to Ps.7.10 billion, net of transaction costs.
Loan from Banco de Galicia y Buenos Aires S.A. to CPR Energy Solutions S.A.U. (wind farm La Castellana II)
On May 24, 2019, CPR Energy Solutions S.A.U. (subsidiary of the Company) entered into a loan agreement with Banco de Galicia y Buenos Aires S.A. to fund the construction of the wind farm “La Castellana II” for a principal amount of US$12.5 million.
According to the agreement, the loan accrues interest at an annual fixed rate equal to 8.5% during the first twelve months, and has a 0.5% step-up each year, up to 11% on the 61st monthly interest payment date, where it remains until maturity, and it is amortizable in 25 quarterly installments as from May 24, 2020. Other agreements and related documents, like the Collateral (in which Central Puerto totally, unconditionally and irrevocably guarantees, as main debtor, all the payment obligations assumed by CPR Energy Solutions S.A.U. until total fulfillment of the guaranteed obligations or until the project reaches the commercial operation date, what happens first), guarantee agreements on shares, guarantee agreements on wind turbines, promissory notes and other agreements have been executed.
Pursuant to the Collateral, among other obligations, Central Puerto has agreed to maintain a debt ratio of no more than 3.75:1.00 until the date of completion of the project. In addition, Central Puerto, under certain conditions, agreed to make capital contributions, directly or indirectly, to subsidiary CPR Energy Solutions S.A.U. Moreover, Central Puerto has agreed to maintain, unless otherwise consented to in writing by the lender, the ownership (directly or indirectly) and control over CPR Energy Solutions S.A.U. As of September 3, 2021, CPR Energy Solutions S.A.U. has fulfilled all the requirements and conditions to achieve project’s completion date. As a result, the collateral posted by the Company was released and CPSA is no longer subject to the obligations previously described.
On May 24, 2019, the loan was fully disbursed. As of December 31, 2021, the balance of this loan was US$ 9.38 million, approximately equivalent to Ps. 0.94 million, net of transaction costs.
Loan from Banco Galicia y Buenos Aires S.A. to subsidiary Vientos La Genoveva II S.A.U.
On July 23, 2019, subsidiary Vientos La Genoveva II S.A.U. entered into a loan agreement with Banco de Galicia y Buenos Aires S.A. for the construction of the La Genoveva II wind farm for a principal amount of US$37.5 million.
According to the agreement, the loan accrues interest at an annual rate of LIBOR plus 5.95% and amortizes in 26 quarterly installments beginning on April 23, 2020.
Other agreements and related documents, like the Collateral (in which Central Puerto totally, unconditionally and irrevocably guarantees, as main debtor, all the payment obligations assumed by Vientos La Genoveva II S.A.U. until total fulfillment of the guaranteed obligations or until the project reaches the commercial operation date, what happens first), guarantee agreements on shares and promissory notes have been signed, while guarantee agreements on wind turbines and direct agreements are in the process of being issued, as per the terms defined by the loan agreement.
Pursuant to the Collateral, among other obligations, Central Puerto has agreed, until the project termination date, to maintain a debt ratio of no more than 3.75:1.00. Moreover, Central Puerto, under certain conditions, agreed to make capital contributions to subsidiary Vientos La Genoveva II S.A.U. Moreover, Central Puerto has agreed to maintain, unless otherwise consented to in writing by the lender, the ownership (directly or indirectly) and control over Vientos La Genoveva II S.A.U. As of September 3, 2021, Vientos La Genoveva II S.A.U. has fulfilled all the requirements and conditions to achieve the project’s completion date.As a result, the Collateral posted by the Company was released and CPSA is no longer subject to the obligations previously described.
On July 23, 2019, the loan was fully disbursed. As of December 31, 2021, the balance of this loan, was US$ 27.19 million, approximately equivalent to Ps.2.73 billion, net of transaction costs.
CP Manque S.AU. and CP Los Olivos S.A.U. Program of Corporate Bond
On August 26, 2020, under Resolution No. RESFC-2020 - 20767 - APN.DIR#CNVM, the public offering of the Global Program for the Co-Issuance of Simple Corporate Bonds (not convertible into shares) by CP Manque S.A.U. and CP Los Olivos S.A.U. (both subsidiaries of CPR, and together the “Co-issuers”) for the amount of up to US$ 80,000,000 was authorized. By virtue of such program, the Co-Issuers may issue corporate bonds, of different class and/or series, that may qualify as social, green and sustainable marketable securities under the criteria established by CNV in that regard.
Within the framework of the mentioned program, dated September 2, 2020, Corporate Bonds Class I were issued for an amount of US$ 35.160.000 at a fix 0% interest rate expiring on September 2, 2023; and Corporate Bonds Class II were issued for 1.109.925 at a variable interest rate equivalent to BADLAR rate, plus an applicable margin of 0.97% expiring on September 2, 2021, which was fully cancelled on that date.
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On June 24, 2020, the Board of Directors of CPSA decided to guarantee unconditionally the co-emission of corporate bonds of its subsidiaries CP Manque S.A.U. and CP Los Olivos S.A.U. (the “Guarantee”). The Guarantee is an obligation with a common guarantee, not subordinated and unconditional of the Company, and shall have at all times, the same priority rank regarding the non-guaranteed and unsubordinated obligations, present and future, of the Company. The Guarantee was instrumented through the signature of the Company in its capacity as co-signer of the permanent global certificates deposited in Caja de Valores S.A., in which the Corporate Bonds Class I and Corporate Bonds Class II of CP Manque S.AU. and CP Los Olivos S.AU. are represented.
Cybersecurity
As of the date of this annual report, the Company has not suffered any material cybersecurity incidents. We have, and continue to implement several controls and procedures to avoid, reduce and mitigate the potential exposure to such risk including:
| · | Certain controls on users regarding specific systems and apps that can potentially affect the company; |
| · | Training programs about risks related to technology and software and potential impact for all personnel of the company; |
| · | Periodic software and apps update issued by developers and software suppliers; |
| · | Security events monitoring to identify potential outbreaks or suspicios actions or non authorized actiones; |
| · | Perimetral portection mechanisms like UTM Fortinet, VPN, MFA, antimalware among others; |
| · | Periodic seurity evaluations through vulnerability analysisand ethical hacking; and |
| · | Information and data access controlled by setting roles and acces profiles. |
For further information relating to risks relating to cybersecurity, see “Item 3.D.—Risk Factors—Risks relating to Our Business—A cyberattack, could adversely affect our business, balance sheet, results of operations and cash flow.”
Item 5.C Research and Development, patents and licenses, etc.
We do not have any significant policies or projects relating to research and development, and we own no patents or licenses.
Item 5.D Trend Information
The following discussion includes forward-looking statements based on our management’s current beliefs, expectations and estimations. Forward-looking statements involve inherent risks and uncertainties. Our future operating and financial performance may differ materially from these forward-looking statements, including due to many factors outside of our control. We do not undertake any obligation to update forward-looking statements in the event of changed circumstances or otherwise. For further information, see “Forward-Looking Statements” and “Item 3.D.—Risk Factors” in this annual report.
We expect that our operating and financial performance in the future will benefit from the increases we expect in our power generation capacity. We have been awarded three wind farm projects under the RenovAr Program (Achiras with 48 MW of awarded electric capacity, La Castellana with 99 MW of awarded electric capacity and La Genoveva I with 86.6 MW of awarded electric capacity) and two co-generation projects (Terminal 6 San Lorenzo with an awarded electric capacity of 330 MW and 317 MW for the winter and summer, respectively, and Luján de Cuyo with an awarded electric capacity of 93 MW and 89 MW for the winter and summer, respectively). Two of our wind farms, Achiras and La Castellana, commenced their operations in September and August 2018, respectively, while La Genoveva I commenced its operation in November 2020. Additionally, on July 2019, September 2019, December 2019/January 2020/March 2020, and February 2020, the wind farms La Castellana II (developed by CP Energy Solutuons S.A.U.), La Genoveva II (developed by Vientos La Genoveva II S.A.U.), Manque (CP Manque S.A.U.), and Los Olivos (CP Los Olivos S.A.U.), respectively, reached their COD. As of the date of this annual report, we have already entered into long-term PPA contracts with private customers for 100% of the estimated energy generation capacity of our term market renewable energy projects developed under Resolution No. 281-E/17 regulatory framework. (see “Item 4.B. Business Overview—The Argentine Electric Power Sector—Resolution No. 281-E/17: The Renewable Energy Term Market in Argentina”).
Regarding cogeneration projects, Luján de Cuyo cogeneration project commenced its operations during October 2019. While on August, 15 2021, the COD for the Terminal 6 San Lorenzo cogeneration project was accomplished. On June 14, 2019, Central Puerto, in the context of a local and foreign public tender called by IEASA, which had been awarded to the Company, purchased the Brigadier López Plant which was transferred on that date. The Brigadier López Plant currently has a Siemens gas turbine of 280.5 MW. According to the tender specifications and conditions, it is expected to supplement the gas turbine with a boiler and a steam turbine to reach the closing of the combined cycle, which is expected to generate 420 MW in total. The works for the closing of the combined cycle are pending. However, the effects of the COVID-19 crisis pose challenges to our expansion plans for the Brigadier López plant not only because of the restrictions to the construction, but also due to difficulties to obtain the necessary financing for the projects in the current market situation. As of the date of this annual report, the continued impact of the COVID-19 crisis in the development of our projects is uncertain, and it may result in us not being able to construct or develop such projects. See “Item 3D. Risk Factors—Risks Relating to our Business— The novel coronavirus couldAn outbreak of a disease may have anmaterial adverse effectconsequences on our business operations and financial conditions.”
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The following new projects have their prices set in US dollars, providing a protection against the depreciation of the argentine currency: a) plants under RenovAR regulatory framework, La Castellana I, Achiras, and La Genoveva I , b), Terminal 6-San Lorenzo and the cogeneration of the Luján de Cuyo plant under Res. 287/17, and c) the Brigadier López plant, have PPAs with CAMMESA. The steam sales from the units, Terminal 6-San Lorenzo and the cogeneration of the Luján de Cuyo plant under Res. 287/17, have long term contracts with private offtakers. Furthermore, the PPAs under the MATER regulatory framework, La Castellana II, Manque, Los Olivos, and La Genoveva II, also have PPAs with private offtakers.Furthermore, several factors have affected our plans for the project currently under development, Brigadier López : a) the effects of the outbreak of COVID-19, b) the economic recession in Argentina, c) the decrease in demand of electric energy, d) the lack of available financing, and e) the reduction in the prices of electric energy for power units under Energía Base beginning in February 2020 (Resolution No. 440/21, among others). The same factors have affected, and may continue to affect, the possibility of new expansion projects and opportunities, for which the company had purchased one General Electric gas turbine with a capacity of 373 MWand 130 hectares of land in the north of the Province of Buenos Aires. See “Item 5.A Operating Results—Factors Affecting our Results from Operations—Expansion of Our Generating Capacity.” Regarding the GE gas turbine, it is uncertain whether there will be new projects or other prospects that would enable us to use the GE gas turbine. We have recorded a charge for the impairment of the GE gas turbine in the consolidated income statement for the year ended December 31, 2021. For more information, see Note 2.5 to our Audited Consolidated Financial Statements and “Item 5.A. Operating Results—Critical Accounting Policies—Impairment of Property, Plant and Equipment”.In terms of energy tariffs, the Argentine Government has announced that it will keep the energy tariffs without significant changes. We believe that the possibility to see changes in these tariffs in order to cut off subsidies and narrow the gap between the whole price of generating electric energy and the price paid by the demand after that date is highly dependent on the outcome of the COVID-19 pandemic crisis, and the path of the recovery of economic activity . In February 2020, Energía Base tariffs were reduced significantly by Res. 31/20 compared to the tariffs in effect at the beginning of the year, and prices for this segment were set in Argentine pesos. Although Resolution No. 31/20 included a monthly update mechanism taking into account a mix between CPI and WPI, on April 8, 2020, the Secretary of Energy instructed CAMMESA to postpone until further notice the application of Annex VI, related to the price update mechanism described under “Item 4.B. Business Overview—The Argentine Electric Power Sector—Remuneration Scheme—The Current Remuneration Scheme”. In February 2021, Resolution No. 440/21 was issued amending Resolution No. 31/20 and increasing prices for generators, among other modifications. Under the Energía Base, the fuel required to produce the energy we generate is supplied by CAMMESA free of charge, and the price we receive as generators, for sales not made under term contracts, is determined by the Resolution SE No. 440/2021 without accounting for the fuel CAMMESA supplies.
The changes made to the Enegía Base Regulatory Framework may help the Argentine Government’s fiscal deficit reduction, since it may reduce the subsidies needed for the sector. We have no control over these tariffs and cannot assure that the Argentine Government will restore term market sales under contracts for conventional energy. See “Item 3.D. Risk Factors—Risks Relating to the Electric Power Sector in Argentina—The Argentine Government has intervened in the electric power sector in the past, and is likely to continue intervening” and “Item 3.D.—Risk Factors—Risks Relating to Our Business—Our results depend largely on the compensation established by the Secretariat of Electric Energy and received from CAMMESA”.
In terms of the performance of our plants, we estimate that our existing plants will achieve availability factors consistent with their average historical performances over the past ten years and in the case of our expansion co-generation and potential combined cycle projects that the plants will achieve availability factors consistent with the assurances provided by our vendors. We also estimate that the capacity factor of our hydro plant will be consistent with its historical average performance since the plant was awarded its concession in 1994 and that the capacity factor of our wind farm projects will be consistent with our wind studies that have been certified by renowned international experts. However, we cannot assure you that the expected availability factors and capacity factor will be consistent with past performance or with the assurances provided by vendors.
A substantial portion of our remuneration is currently based on fixed capacity and not generation levels. Our power plants are subject to the risk of mechanical or electrical failures due to natural disasters. Catastrophic accidents or terrorist attacks and any resulting unavailability may affect our ability to fulfill our contractual and other commitments and thus adversely affect our business and financial performance”.
Additionally, our steam production, which was affected by the La Plata Plant Sale, was affected by Terminal 6-San Lorenzo COD delays, originally scheduled for September 2020 but started operations on August, 15 2021. This was partillay offset with the steam production from our Luján de Cuyo plant which started operations in October 2019.
The concession for our hydro plant expires in December 2023 and we believe that we are well-positioned to achieve the extension of this concession. However, since the HPDA Concession Agreement does not contain a clause for an automatic renewal, we cannot assure you that we will achieve the extension of the concession or be awarded with a new concession, for our operation of the Piedra del Águila plant (“Item 3.D.—Risk Factors—Risks Relating to Our Business—The non-renewal or early termination of the HPDA Concession Agreement would adversely affect our results of operations”).
Regarding the collections from CAMMESA, from September 2016 to November 2017 CAMMESA has paid without delays, and since then, there were periods in which CAMMESA experienced certain delays in paying up to 90 days (for further information on the duration of these delays see “Item 11. Quantitative and Qualitative Disclosures about Market Risk—Credit Risk”)..For these delays, we are entitled to receive interests from CAMMESA. Payments related to PPAs under the Renovar Regulatory Framework have not suffered delays. CAMMESA may once again be unable to make payments to generators both in respect of energy dispatched and generation capacity availability on a timely basis or in full, which may substantially and adversely affect our financial position and the results of our operations.
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As of March 20, 2018, CAMMESA granted the CVO Commercial Approval in the WEM, as a combined cycle, of the thermal plant Central Vuelta de Obligado, which entitled us to receive the collection of the trade receivables under the CVO Agreement. A PPA between the CVO Trust and CAMMESA, through which the CVO Trust makes energy sales and, consequently, receives the cash flow to pay the trade receivables, had to be signed in order to start the collections. The PPA agreement was signed on February 7, 2019, with retroactive effect to March 20, 2018.
In terms of our main costs, on November 7, 2018, pursuant to Res. SEE 70/18, the Argentine Government authorized generators to purchase their own fuel for assets under the Energía Base Regulatory framework. However, prior commitments assumed by generators with CAMMESA for energy supply contracts are not altered by this new regulation. If generation companies opted to take this option, CAMMESSA will value and pay the generators their respective fuel costs in accordance with the Variable Costs of Production (CVP) declared by each generator to CAMMESA.
In accordance to Res. SEE 70/18, in November 2018, we started purchasing fuel for our Luján de Cuyo combined cycle, and in December 2018, for all our thermal units. During 2019 we were able to obtain a positive gross margin on these fuel purchases since we were able to benefit from better fuel prices than the reference pass-through values provided by CAMMESA, given our scale as one of the largest private sector power companies in Argentina, as measured by generated power, according to data from CAMMESA, and the diverse and strategic location of our power sector assets (see “Item 4.A. History and development of the Company—Our Competitive Strengths”).
On December 27, 2019, the Ministry of Productive Development issued Resolution MDP No. 12/2019, repealing Resolution SGE No. 70/2018 and restoring Art. 8 of Res. SE 95/2013. Beginning January 2020, CAMMESA became the only fuel supplier for generation companies, except for (i) thermal units that had prior commitments with CAMMESA for energy supply contracts with their own fuel management and (ii) thermal units under the Energía Plus regulatory framework, authorized under Resolution SE No.1281/05 to supply energy to large private users.
We also assume an increase in our number of employees related to our new projects, but we believe that salaries will remain in line with current levels. We cannot assure you that our operating or other costs will not increase at higher rates. See “Item 3.D. Risk Factors—Risks Relating to Argentina—Government measures, as well as pressure from labor unions, could require salary increases or added benefits, all of which could increase companies’ operating costsOur Business— We could be affected by material actions taken by the trade unions”, “Item 3.D.—Risk Factors—Risks Relating to the Electric Power Sector in
Argentina—We operate in a heavily regulated sector that imposes significant costs on our business, and we could be subject to fines and liabilities that could have a material adverse effect on our results of operations” and “Item 3.D.—Risk Factors—Risks Relating to Our Business—Our ability to generate electricity at our thermal generation plants partially depends on the availability of natural gas and, to a lesser extent, liquid fuel.”
Item 5.E Critical Accounting Estimates
Not applicable.
Item 6. Directors, Senior Management and Employees
Item 6.A Directors and senior management
Board of Directors
We are managed by our Board of Directors in accordance with the Argentine Corporate Law. Our Board of Directors makes management decisions, as well as those expressly set forth in the Argentine Corporate Law, our bylaws and other applicable regulations. In addition, our Board of Directors is responsible for carrying out shareholders’ resolutions and fulfilling particular tasks expressly delegated by the shareholders.
According to our bylaws, our Board of Directors must be composed of 11 directors, and our shareholders may also appoint an equal or lesser number of alternate directors. As of the date of this annual report, our Board of Directors is composed of 11 directors and 11 alternate directors. All of our directors reside in Argentina.
Directors and their alternates are appointed for a term of one year by our shareholders during our annual shareholders’ meetings. Directors may be reelected. Shareholders are entitled to elect up to one-third of the vacant seats by cumulative voting pursuant to Section 263 of the Argentine Corporate Law. Pursuant to Section 257 of the Argentine Corporate Law, the directors maintain their positions until the following annual ordinary shareholders’ meeting where directors are appointed.
The latest election relating to our Board of Directors took place at the ordinary shareholders’ meeting held on April 30, 2021.
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During the first board meeting after directors have been appointed, they must appoint a chairman and vice-chairman of the board. The vice-chairman would automatically and temporarily replace the chairman in the event that the chairman is absent, resigns, dies, is incapacitated or disabled, removed or faces any other impediment to serve as chairman. A new chairman must be elected within ten days from the seat becoming vacant. The election of a new chairman must take place only if the situation that gives rise to the re-election is expected to be irreversible during the remaining term of office.
According to Section 26 of our bylaws, our Board of Directors has the broadest powers and authorities in connection with our direction, organization and administration, with no limitations other than those set forth by the applicable laws and regulations. The chairman is our legal representative.
The following table sets forth the current composition of our Board of Directors:
Name |
| Title |
| Date of first appointment to the board |
| Date of expiration of current term |
| Date of birth |
Osvaldo Arturo Reca |
| Chairman of the Board |
| April 5, 2011 |
| December 31, 2021 |
| December 14, 1951 |
Guillermo Rafael Pons* |
| Director |
| April 30, 2020 |
| December 31, 2021 |
| September 22, 1964 |
Miguel Dodero |
| Director |
| September 21, 2015 |
| December 31, 2021 |
| February 16, 1955 |
José Luis Morea* |
| Director |
| April 30, 2019 |
| December 31, 2021 |
| October 19, 1954 |
Juan José Salas* |
| Director |
| September 21, 2015 |
| December 31, 2021 |
| February 23, 1960 |
Diego Gustavo Petracchi |
| Director |
| April 27, 2018 |
| December 31, 2021 |
| July 17, 1972 |
Tomas Peres |
| Director |
| April 27, 2018 |
| December 31, 2021 |
| December 31, 1983 |
Tomás José White* |
| Director |
| April 27, 2018 |
| December 31, 2021 |
| May 18, 1957 |
Soledad Reca |
| Director |
| April 30, 2021 |
| December 31, 2021 |
| February 22, 1990 |
Jorge Eduardo Villegas* |
| Director |
| April 28, 2017 |
| December 31, 2021 |
| January 9, 1949 |
Marcelo Atilio Suvá |
| Director |
| July 22, 2008 |
| December 31, 2021 |
| July 27, 1948 |
Oscar Luis Gosio* |
| Alternate Director |
| July 11, 2007 |
| December 31, 2021 |
| August 17, 1954 |
Fernando Bonnet |
| Alternate Director |
| April 30, 2021 |
| December 31, 2021 |
| March 25, 1977 |
Justo Pedro Sáenz |
| Alternate Director |
| April 10, 2008 |
| December 31, 2021 |
| May 2, 1958 |
Adrián Gustavo Salvatore |
| Alternate Director |
| April 27, 2018 |
| December 31, 2021 |
| April 26, 1967 |
Javier Alejandro Torre |
| Alternate Director |
| April 27, 2018 |
| December 31, 2021 |
| April 19, 1967 |
Rubén Omar López |
| Alternate Director |
| April 27, 2018 |
| December 31, 2021 |
| April 17, 1964 |
José Manuel Pazos |
| Alternate Director |
| September 21, 2015 |
| December 31, 2021 |
| September 14, 1971 |
Enrique Gonzalo Ballester* |
| Alternate Director |
| April 28, 2017 |
| December 31, 2021 |
| January 19, 1954 |
Gabriel Enrique Ranucci* |
| Alternate Director |
| April 30, 2020 |
| December 31, 2021 |
| April 7, 1974 |
Enrique Terraneo |
| Alternate Director |
| April 30, 2021 |
| December 31, 2021 |
| October 10, 1974 |
Alejo Villegas* |
| Alternate Director |
| April 30, 2021 |
| December 31, 2021 |
| February 16, 1980 |
* Independent directors according to CNV rules, which differ from NYSE requirements for U.S. issuers.
Note: Notwithstanding expiration of current term, under the company, bylaws, directors continue to serve in their capacity until the next shareholders’ meeting.
The following are the academic and professional backgrounds of the members of our Board of Directors. The business address of each of the members of our Board of Directors is Avda. Thomas Edison 2701, Buenos Aires, Argentina.
Osvaldo Arturo Reca holds a degree in Engineering from the Universidad Católica Argentina. He also received an advanced degree in 1977 from North Carolina State University in the United States. He has been a member of our Board of Directors since 2011. From 1980 to 1984, he was a shareholder and director of Ingeniería de Avanzada S.A., a company engaged in the deployment of sanitary and gas facilities for housing developments. From 1984 to 1989, he served as general manager of Dufalp S.A., a leading company within the clothing industry (“Dufour” was its principal brand). From 1989 to 2002, Mr. Reca served as commercial, operating and planning manager of Alpargatas S.A., a leading company in the clothing and footwear industry. He then developed an agricultural project for cereal and oilseeds production. He also served as vice chairman of HPDA from 2012 to 2015 and as a director of Transportadora de Gas del Norte S.A., Edesur S.A. and PB Distribución S.A. In addition, he currently serves as chairman of the board of directors of DGCE, DGCU, IGCE and Energía Sudamericana S.A. He also serves as director of Coyserv S.A.
Guillermo Rafael Pons hold a degree in Accounting from the National University of Comahue, completed a Master in Business Administration at the International Business School, and has a postgraduate degree in Comprehensive Risk Management at the University of San Andres. He served as Secretary of Finance of the Municipality of Neuquén and was Director General of Administration of the Ministry of Government and Justice of Neuquén and Administrative Manager of the Executing Unit of External Financing, in the Province of Neuquén. He was hired as a Consultant by the Superintendency of Economic Management of the Province of Rio Negro, by the IDB, Aguas Rionegrinas, Legislature of Rio Negro, UNDP, and was an Accounting Advisor at Banco Provincia del Neuquén S.A. He was Director of the Pension Fund for Professionals in Economic Sciences and Vice President of the College of Accountants of Cipolletti, both in the Province of Rio Negro. He joined Banco Provincia del Neuquén S.A. in 2012, as Assigned to the General Management, and in 2013 he was appointed Deputy General Manager of Risk Management and Regulatory Compliance. On December 10, 2019, he was appointed Minister of Economy and Infrastructure of the Province of Neuquén.
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Miguel Dodero holds a degree in Business Administration from the Universidad de Buenos Aires. He has been a member of our Board of Directors since 2015. He has previous work experience at Agencia Marítima Dodero S.A. and Compañía Argentina de Navegación Intercontinental S.A. He served as chairman of Dodero Inmobiliaria y Mandataria S.A. from 1990 to September 2014. Mr. Dodero has been chairman of M. Dodero Compañía de Servicios S.A. since 1989 and of Full Logistics S.A. since 2008, as well as a shareholder of both companies. In addition, he currently serves as a director of IGCE, DGCU and DGCE.
José Luis Morea holds a degree in Political Science from the Universidad Católica Argentina. He completed postgraduate studies in SME Management at IAE. Between 1980 and 1990 he held executive positions in communication companies, mainly in Editorial Atlántida and Videomega. From 1990 to 1995 he served as Executive Director in San Ciriaco, with operations in the agricultural sector, and later as General Manager of Espro S.A., a company dedicated to the production and export of agriculture products. From 1999 to 2001 he became General Manager of Tecnovital S.A., a fruit export company. In 2001, he founded North Bay Argentina S.A., a company in which he serves as Chairman and General Manager. North Bay S.A. has become one of the main blueberry exporters and producers in Argentina. Together with other partners, he created Servifrío Ezeiza SA, a logistics and cold storage company in which he serves as Director. He is also Director of North Bay Peru S.A. and of North Bay Produce Inc. in the United States. He served in this group until 2013. In 2014 he joins La Gloriosa SA as Blueberries Project Manager, developing a high-tech enterprise in Virasoro, Corrientes, until December 2018. Between 2016 and 2018 he served as Director of Transportadora de Gas Cuyana. He has been a member of our Board of Directors since 2019. Since 2020, he has been a consultor in projects and high-tech agricultural developments for Adblick Hidroponia S.A. and Club Agtech S.A.
Juan José Salas holds a degree in Engineering from the Universidad de La Plata. He has been a member of our Board of Directors since 2015. From 1983 to 1984, he completed postgraduate studies at the Instituto de Altos Estudios Empresariales. From 2010 to 2015, Mr. Salas has also served as operations and information systems manager of Autopistas del Sol S.A.
Diego Gustavo Petracchi holds a degree in Economics from the Universidad Católica Argentina and a Master in Science of Management (Sloan Program) from Stanford University. He is currently developing a project in the senior living (residences for adults) business. He is the founder and currently serves as Chief Executive Officer of Yugen S.A. From 2006 to 2015, he was a director of NDM Holding (Valle de las Leñas S.A.), a Company engaged in tourism, real state and agribusiness. He has also served as a director of Nieves de Mendoza S.A., Santa Rosa del Monte S.A., Rio Lobo S.A., Valles Mendocinos S.A. In addition, from 1995 to 2006, he worked in different positions, including Vice President, in Prefinex S.A., a company that provides financial advisory services.
Tomas Peres holds a degree in Business Administration from the Universidad de San Andrés. From 2007 to 2009 he worked in the audit department of KPMG. From 2009 to 2015 he worked at Ultrapetrol American Barge Line, first as bunker responsible, and then as chief of commercial planning. He served as an advisor of the Ministry of Transport of the Republic of Argentina Director of Inversora de Gas del Centro S.A. and Energía Sudamericana S.A until 2021 and currently acts as an independent consultant.
Tomás José White holds a degree in Accounting from the Universidad Católica Argentina. From 1977 to 1984 he served as director in several private companies in the construction industry, such as Bemba S.A., Sumarge S.A. and Din S.A. From 1996 to 1998 he also served as a director of Empresa Amanco SA. Since 2000 he is the chairman of Celestal SAIC. Since 2019 he owns interests and is the chairman of BEP SRL, a company involved in the plastic industry.
Soledad Reca holds a degree in organization and production of events from Ott College. She currently acts as independent event planner. Between 2018 and 2020 she served as Director of DGCE.
Marcelo Suvá holds a degree in Economics from the Universidad Católica Argentina. He has served as alternate director of our Board of Directors since 2008. Since 2020 he serves as vice president of CPSA. He was shareholder of Coinvest SA, a private equity company, as well as of MBA Banco de Inversiones S.A. (currently known as Lazard Argentina SA), a leading Argentine investment bank, where he was also member of its Board of Directors and took part in various MA transactions. He also served as Director of HNQ. Distrilec Inversora S.A. He also serves as director of Distrilec Inversora S.A and alternate Director of IGCE SA, DGCU SA, DGCE SA and RPS Consultores S.A.. He currently serves as chairman of the Governing Board at Universidad Austral.
Jorge Eduardo Villegas holds a degree in law from the Universidad de Buenos Aires. Since his graduation, he has worked as a lawyer in the private sector, independently through his own law firm, Estudio Jorge Villegas Asociados. Mr. Villegas also currently serves as the chairman of Agropecuaria Los Potros S.A.
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Oscar Luis Gosio holds a degree in Accounting from the Universidad de Buenos Aires. He has served as alternate director of our Board of Directors since 2007. He is currently the principal partner at Gosio, Medina Asociados, a company that provides audit, accounting and tax services. He is also the chairman and partner of Agropecuaria Huen Loo S.A. since 2008, a company engaged in the agriculture business, as well as the President of the Instituto de Hermanos Cristianos, which is focused on education (Colegio Cardenal Newman) since 2014. Mr. Gosio also serves as a director of Asociación Argentina de Criadores de Corriedale. In addition, he is syndic in several companies of the agriculture industry.
Fernando Roberto Bonnet holds a degree in Accounting from the Universidad Nacional de Buenos Aires. In addition, from 2009 to 2010, he took a graduate level course in Executive Business Administration in IAE Business School, Universidad Austral. Since April 1, 2021, he serves as the Chief Executive Officer of our company. From March 2020 to March 2021, he served as the Chief Operating Officer of our company. From 2010 to March 2020, he served as the Chief Financial Officer of our company and from 2008 to 2010, he also served as tax manager. He served as tax manager of Ernst Young Argentina. Mr. Bonnet currently serves as vice-chairman of Proener S.A.U. and CP Renovables S.A He currently serves as an alternate director of CP Achiras S.A.U., CPR Energy Solutions S.A.U., CP La Castellana S.A.U., CP Patagones S.A.U., Vientos La Genoveva S.A.U., Vientos La Genoveva II S.A.U., CP Manques S.A.U. and CP Los Olivos S.A.U.
Justo Pedro Sáenz completed the “Advanced Management Program” at The Wharton School, University of Pennsylvania in the United States. He has served as alternate director of our Board of Directors since 2008. From 2007 to 2016, he served as administration and human resources manager of Central Puerto, and since 2016 he serves as administration manager of Central Puerto. From 2005 to 2007, he worked at Cima Investments in the new business area. From 2003 to 2005, he served as Chief Financial Officer of Banco de Servicios y Transacciones S.A. In 2002, he co-founded Idun Inversiones S.A. From 2000 to 2001, he held the position of partner and finance manager of Softbank Latin America Ventures, Venture Capital Fund. From 1984 to 2000, he worked at Merchant Bankers Asociados, MBA Banco de Inversiones and MBA Sociedad de Bolsa. He has been a partner of Merchant Bankers Asociados since 1992, which was affiliated with Salomon Brothers and the investment company of Nicholas Brady, former U.S. Secretary of Treasury. In addition, he currently serves as a director of Proener S.A.U., Vientos La Genoveva S.A.U. and Vientos La Genoveva II S.A.U., and as an alternate director of IGCE, DGCU, DGCE, CP Renovables S.A., CP Patagones S.A.U., CP Achiras S.A.U., CP La Castellana S.A.U., CPR Energy Solutions S.A.U., CP Manque S.A.U. y CP Los Olivos S.A.U.
Adrián Gustavo Salvatore holds a degree in law from the Universidad de Buenos Aires and an MBA in a joint degree from the Universidad del Salvador (Argentina) and the Universidad de Deusto (Spain). From 1993 to 1997 he worked at the legal and regulatory department of ESEBA, where he was in charge of the process of privatizing the company. From 1997 to 2003, he worked as legal manager at COMESA, Comercializadora de Energía, and in 2003 he joined the law firm Bruchou, Fernández Madero, Lombardi Mitrani, as part of their regulatory and public services department. He has worked in the regulatory department of Central Puerto since 2008, and he currently serves as Institutional Relations Director. He also serves as a director in Termoeléctrica José de San Martín S.A. and as alternate director of Termoeléctrica Manuel Belgrano S.A., Inversora de Gas del Centro S.A., Distribuidora de Gas Cuyana S.A. and Distribuidora de Gas del Centro S.A. He is also the chairman of Proener S.A.U., and vice-chairman of Central Vuelta de Obligado S.A.
Javier Alejandro Torre holds a degree in Human Resources from the University of Buenos Aires and a Master in Business Administration from the University of Buenos Aires. From 2011 to 2016, he was human resources manager of Argentine operations in LyondellBasell. He has been our human resources manager since 2016. He previously worked at ExxonMobil for almost 20 years, where he held different positions in the commercial and human resources areas.
Rubén Omar López holds a degree in Electrical Engineering from the Universidad Tecnológica Nacional. He also holds a postgraduate degree in Business Management from Universidad de Buenos Aires. From 2013 to 2019, he was our planning and regulation manager, from 2019 to April 2020 he was our Strategic Planning Director. Since April 2020, he is our Renewable Energy Manager. He has more than 30 years of experience in the utilities sector, where he has held different positions both in technical and commercial areas. In addition, he currently serves as director of EDESUR S.A. and alternate director of Distrilec Inversora S.A. He currently serves as Chairman of: CP Achiras S.A.U., CP La Castellana S.A.U., CPR Energy Solutions S.A.U., , Vientos La Genoveva S.A.U., Vientos La Genoveva II S.A.U., CP Manque S.A.U. and CP Los Olivos S.A.U., In addition, he has been a director in Compañía Administradora del Mercado Mayorista Eléctrico (CAMMESA) since 2015 to August 2019.
José Manuel Pazos holds a degree in law from the Universidad Católica Argentina. He also holds a postgraduate degree in Utilities’ Economic Regulation from the Universidad Austral. He has served as General Counsel, Head of Legal Area and alternate director of our Board of Directors since 2015. From 1997 to 2002, he served as lawyer of the Argentine Secretariat of Energy and Emprendimientos Binacionales S.A. (EBISA), and, from 2003 to 2014, he worked for the law firm, Bruchou, Fernández Madero Lombardi. Between 2007 and 2008, he worked for Simpson Thacher Bartlett LLP in New York. Currently he serves as alternate director of Distrilec Inversora S.A., CP Renovables S.A., CP Achiras S.A.U., CPR Energy Solutions S.A.U., CP La Castellana S.A.U., CP Patagones S.A.U., Vientos La Genoveva S.A.U., Vientos La Genoveva II S.A.U., CP Manques S.A.U. and CP Los Olivos S.A.U.
Enrique Gonzalo Ballester holds a degree in Economics from the Universidad Católica Argentina and a Master of Science (MSc) of the University of London. From 1995 to 2016, he served as senior operator in the department of finance of Banco de Galicia y Buenos Aires S.A. Since 1990, he has served as director of various companies. He currently serves as an alternate director of Quenuma S.A., Lanceros Civicos S.A. and Guardia Cívica S.A.
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Gabriel Enrique Ranucci holds a Law degree received from the University of Belgrano in 1999. Since 2001 he joined as Legal Advisor of the Subsecretariat of Public Revenues of the Province of Neuquén, until 2012. From 2012 to 2015 he was appointed Director General of Legal of the Provincial Directorate of Revenues of the Province of Neuquén. From 2015 to 2017 he was appointed Provincial Director of Legal Affairs and Concessions dependent on the Subsecretariat of Public Revenues of the Province of Neuquén. From December 10, 2017 to the present, he has been appointed as Administrative Technical Coordinator of the Ministry of Energy and Natural Resources of the Province of Neuquén.
Enrique Terraneo holds a degree in Accounting from the Universidad Nacional de Buenos Aires. In addition, from 2009 to 2010, he took a graduate level course in Executive Business Administration in IAE Business School, Universidad Austral. Since April 2021, he serves as Chief Financial Officer of our company. Previously, he served as new business manager in Lartirigoyen y Cia. From 2019 to 2020, he served as CFO of Banco de Inversion y Comercio Exterior. Between 2006 and 2019, he served as finance managerof our company. He served as audit manager of Ernst Young Argentina.
Alejo Villegas is a lawyer graduated from the Universidad Católica Argentina in 2006. Since then, he has worked as an independent professional advising clients in the private sector. He has been part of the Jorge Eduardo Villegas Law Firm since 2002, specializing in advising on Civil and Commercial Law. He is registered with the Federal Capital Bar Association and with the San Isidro Bar Association. He is currently a member of the Directory of commercial companies that develop activities related to agriculture and tourism.
Family Relationships
Mr. Juan Antonio Nicholson is the father of Lucas Nicholson, and serve as Syndic and Alternate Syndic, respectively, on our Supervisory Committee.Mr. Diego Gustavo Petracchi and Tomas Peres are cousins, ans serve as Directors, on our Board of Directors. Mr. Osvaldo Reca is the uncle of Mrs. Soledad Reca.
Duties and Liabilities of Directors
Directors have the obligation to perform their duties with the loyalty and the diligence of a prudent businessperson. Under Section 274 of the Argentine Corporate Law, directors are jointly and severally liable to the company, the shareholders and third parties for the improper performance of their duties, for violating any law or the bylaws or regulations, if any, and for any damage to these parties caused by fraud, abuse of authority or gross negligence. The following are considered integral to a director’s duty of loyalty: (i) the prohibition on using corporate assets and confidential information for private purposes; (ii) the prohibition on taking advantage, or allowing another to take advantage, by action or omission, of the business opportunities of the corporation; (iii) the obligation to exercise board powers only for the purposes for which the law, the corporation’s bylaws or the shareholders’ or the board of directors’ resolutions were intended; and (iv) the obligation to take strict care so that acts of the board do not go, directly or indirectly, against the corporation’s interests. A director must inform the board of directors and the Supervisory Committee of any conflicting interest he or she may have in a proposed transaction and must abstain from voting thereon.
In general, a director will not be held liable for a decision of the board of directors, even if that director participated in the decision or had knowledge of the decision, if (i) there is written evidence of the director’s opposition to the decision and (ii) the director notifies the Supervisory Committee of that opposition. However, both conditions must be satisfied before the liability of the director can be contested before the board of directors, the Supervisory Committee or the shareholders or relevant authority or the commercial courts.
Section 271 of the Argentine Corporate Law allows directors to enter into agreements with the company that relate to such director’s activity and under arms’ length conditions. Agreements that do not satisfy any of the foregoing conditions must have prior approval of the board of directors (or the Supervisory Committee in the absence of board quorum), and must be notified to the shareholders at a shareholders’ meeting. If the shareholders reject the agreement, the directors or the members of the supervisory committee, as the case may be, shall be jointly and severally liable for any damages to the company that may result from such agreement. Agreements that do not satisfy the conditions described above and are rejected by the shareholders are null and void, without prejudice to the liability of the directors or members of the Supervisory Committee for any damages to the company.
The acts or agreements that a company enters into with a related party involving a relevant amount shall fulfill the requirements set forth in Section 72 and 73 of Argentine Capital Markets Law. Under Section 72, the directors and syndics (as well as their ascendants, descendants, spouses, brothers or sisters and the companies in which any of such persons may have a direct or indirect ownership interest) are deemed to be a related party. A relevant amount is considered to be an that which exceeds 1.00% of the net worth of the company as per the latest balance sheet. The board of directors or any of its members shall require from the audit committee a report stating if the terms of the transaction may be reasonably considered adequate in relation to normal market conditions. The company may proceed with the report of two independent evaluating firms that shall have informed them about the same matter and about the other terms of the transaction. The board of directors shall make available to the shareholders the report of the audit committee or of the independent evaluating firms, as the case may be, at the main office on the business day after the board’s resolution was adopted and shall communicate such fact to the shareholders of the company in the respective market bulletin. The vote of each director shall be stated in the minutes of the board of directors approving the transaction. The transaction shall be submitted to the approval of the shareholders of the company when the audit committee or both evaluating firms have not considered the terms of the transaction to be reasonably adequate in relation to normal market conditions. In the case where a shareholder demands compensation for damages caused by a violation of Section 73, the burden of proof shall be placed on the defendant to prove that the act or agreement was in accordance market conditions or that the transaction did not cause any damage to the company. The transfer of the burden of proof shall not be applicable when the transaction has been approved by the board of directors with the favorable opinion of the audit committee or the two evaluating firms.
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We may initiate causes of action against directors if so decided at a meeting of the shareholders. If a cause of action has not been initiated within three months of a shareholders’ resolution approving its initiation, any shareholder may start the action on behalf of and on the company’s account. A cause of action against the directors may be also initiated by shareholders who object to the approval of the performance of such directors if such shareholders represent, individually or in the aggregate, at least 5.00% of the company’s capital stock.
Except in the event of our mandatory liquidation or bankruptcy, shareholder approval of a director’s performance, or express waiver or settlement approved by the shareholders’ meeting, terminates any liability of a director vis-à-vis the company, provided that shareholders representing at least 5.00% of the company’s capital stock do not object and provided further that such liability does not result from a violation of law or the company’s bylaws.
Under Argentine law, the board of directors is in charge of the company’s management and administration and, therefore, makes any and all decisions in connection therewith, as well as those decisions expressly provided for in the Argentine Corporate Law, the company’s bylaws and other applicable regulations. Furthermore, the board of directors is responsible for the execution of the resolutions passed in shareholders’ meetings and for the performance of any particular task expressly delegated by the shareholders.
Meetings, Quorum, Majorities
Pursuant to Section 23 of our bylaws, our Board of Directors’ meetings require a quorum of an absolute majority of its members. Our Board of Directors functions and acts upon the majority vote of its members present at its meetings either physically or via videoconferencing.
Our Board of Directors’ minutes must be drafted and signed by directors and syndics who are present at the meeting within five days from the date on which it was held. Members of our Supervisory Committee must register in the minutes the names of the directors who have participated in the meeting remotely and that the decisions made therein were made in accordance with the law. The minutes must include the statements from directors participating in person and remotely and must state their respective votes on each decision made.
The chairman, or the individual acting in lieu of the chairman pursuant to applicable law, may call meetings when deemed convenient, or when so required by any director or the supervisory committee. The meeting must be called within five days from the request; otherwise, the meeting may be called by any of the directors. Our Board of Directors’ meetings must be called in writing and notice thereof must be given to the address reported by each director. The notice must indicate the date, time and place of the meeting and the meeting agenda. Business that is not included in the notice may be discussed at the meeting only to the extent all permanent directors are present and have cast their unanimous vote.
Independence Criteria of Directors
In accordance with the provisions of Section 4, Chapter I, Title XII “Transparencia en el Ámbito de la Oferta Pública” and Section 11, Chapter III, Title II “Órganos de Administración y Fiscalización, Auditoría Externa” of the CNV rules, we are required to report to the shareholders’ meeting, prior to vote the appointment of any director, the status of such director as either “independent” or “non-independent.” At present José Luis Morea, Juan José Salas, Tomas José White, Jorge Eduardo Villegas, Oscar Luis Gosio, Guillermo Rafael Pons, Gonzalo Ballester, Alejo Villegas and Gabriel Enrique Ranucci are independent members of our Board of Directors according to the criteria established by the CNV, which may differ from the independence criteria of the NYSE and NASDAQ. See “Item 6.—Audit Committee” for further details about independence requirements of the members of our Audit Committee at the time of the offering.
Corporate Governance
We have adopted a corporate governance code to put into effect corporate governance best practices, which are based on strict standards regarding transparency, efficiency, ethics, investor protection and equal treatment of investors. The corporate governance code follows the guidelines established by the CNV. We have also adopted a Code of Business Conduct designed to establish guidelines with respect to professional conduct, morals and employee performance.
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Senior Officers
The following table sets forth the current composition of our management team:
Name |
| Title |
| Date of first appointment to position |
| Date of Birth |
Fernando Roberto Bonnet |
| CEO |
| 2021 |
| March 23, 1977 |
Enrique Terraneo |
| CFO |
| 2021 |
| October 13, 1974 |
Eduardo Nitardi |
| Engineering Director |
| 2016 |
| July 18, 1955 |
Alberto Francisco Minnici |
| Production and Combined Cycle Plant Manager |
| 2015 |
| April 14, 1965 |
José María Saldungaray |
| Fuel Supply Planning Manager |
| 2014 |
| February 18, 1967 |
Justo Pedro Sáenz |
| Administration Manager |
| 2007 |
| May 2, 1958 |
José Manuel Pazos |
| General Counsel, Head of Legal Area |
| 2015 |
| September 14, 1971 |
Rubén Omar López |
| Renewable Energy Manager |
| 2019 |
| April 17, 1964 |
Gabriel Omar Ures |
| Commercial Director |
| 2018 |
| December 31, 1978 |
Leonardo Marinaro |
| Legal Affairs Manager |
| 2007 |
| April 25, 1963 |
Javier Alejandro Torre |
| Human Resources Manager |
| 2016 |
| April 19, 1967 |
Adrián Gustavo Salvatore |
| Institutional Relations Director |
| 2019 |
| April 26, 1967 |
Martín Fernández Barbiero |
| Compliance and Internal Audit Manager |
| 2009 |
| April 28, 1971 |
Leonardo Katz |
| Director de Planificación Estratégica |
| 2020 |
| March 24, 1970 |
____________
The following are the academic and professional backgrounds of our senior management. The business address of each of the members of our senior management team is Avda. Thomas Edison 2701, Buenos Aires, Argentina.
Eduardo Luis Nitardi holds a degree in Mechanical-Electric Engineering from the Universidad Nacional de Córdoba. In addition, from March 1999 to November 2000, he took a graduate level course of Master in Administration of the WEM in Instituto Tecnológico de Buenos Aires. From March 2002 to November 2002, Mr. Nitardi took a graduate level course in Direction Development in IAE Business School, Universidad Austral. Mr. Nitardi has 39 years of experience in the electric power industry both in the transmission and electric power generation segments. He has served as Central Puerto’s Engineering Director since 2016. Previously, he served as CEO of CVOSA from 2012 to 2015, planning and works manager of Central Puerto since 2011 to 2012, and Technical Director in Transener S.A. since 2008 to 2011. He served as technical manager in the same company since 1997 to 2008.
Alberto Francisco Minnici holds a degree in Electrical Engineering from the Universidad Tecnológica Nacional. Mr. Minnici has 31 years of experience in the electric power industry. He has served as Central Puerto’s Production and Combined Cycle Plant Manager since 2015. Previously, he served as Plant Operations Manager of the Puerto Complex from 2012 to 2015 and as Plant Operations Manager of the combined cycle plant of the Puerto Complex located in the City of Buenos Aires from 2008 to 2012, among other positions within Central Puerto.
José María Saldungaray holds a degree in Electrical Engineering from the Universidad Nacional del Sur, Bahía Blanca, Argentina. He has been our planning manager since 2014. He currently serves as alternate director of Proener S.A.U., Vientos la Genoveva S.A.U. and Vientos La Genoveva II S.A.U. He also served as commercial manager of HPDA and was a member of the board of directors of Centrales Térmicas Mendoza S.A. and LPC.
Gabriel Omar Ures holds a degree in Systems Engineering from the Universidad Abierta Interamericana. He also holds a Postgraduate degree in Gas and Electricity Administration in Instituto Tecnológico de Buenos Aires (ITBA) and a Management Program from the Darden Business School of the University of Virginia, United States. He started his professional career in 1997 and has over 24 years of experience working in the Argentine power sector. Among other positions, he held managerial positions in Hidroeléctrica Alicura, was commercial director of AES Argentina Generación, General Manager of Termoeléctrica Manuel Belgrano (from 2013 to 2018), Commercial Manager in Central Dock Sud (YPF EE). Additionally, he was a director of various companies and industry chambers, including AGEERA (Asociación de Generadores de Energía Eléctrica de la República Argentina) where he has been elected as President for 5 consecutive terms (2012/2017) after holding the Vice Presidency. He currently serves as director of CAMMESA and Termoeléctrica Manuel Belgrano S.A.
Leonardo Marinaro holds a degree in law from the Universidad Católica Argentina. He has been our legal affairs manager since 2007. Mr. Marinaro has served as director of LPC, CTM and Edesur S.A. He is currently a director of CP Renovables S.A., Vientos La Genoveva S.A.U. and Vientos La Genoveva II S.A.U., and alternate director of Proener S.A.U., Central Vuelta de Obligado S.A., TMB, TJSM, Distrilec Inversora S.A.,., DGCE, IGCE, and Energía Sudamericana S.A.
Martín Fernández Barbiero holds a degree in Accounting from the Universidad Nacional de Buenos Aires and a Master in Business Administration (MBA) from Universidad de San Andrés. He also completed an international certification program in Compliance from the Universidad Austral (IAE). He has served as Internal Auditor Manager of Central Puerto since 2008 and since 2018, he was also appointed as Compliance Officer. Before Central Puerto he worked for CMS Energy as Internal Auditor Manager and SOX Compliance Manager among other positions between 1999 and 2007.
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Leonardo Katz holds a degree in Industrial Engineering from the Universidad Nacional de Salta. He also received an MBA degree in 2001 from Universidad del CEMA. He has more than 20 years of experience in the Generation sector. He has been the General Manager of Central Vuelta de Obligado S.A., in charge of the completion of the project and the closing of commercial litigation, currently remain as a Chairman. Previously Mr Katz served in Central Puerto as Planning and Investments Manager (Dec’15 to Dec’19), Head of Internal Investment Planning (Apr’07-Dec’15). He served as Latam Senior Market Analyst since Set’97 in CMS Energy an American company who used to have assets in Argentina and Latam. He is a Director in the FONINVEMEN Projects since its completion.
For the biography of Mr. Fernando Roberto Bonnet, Enrique Terraneo Justo Pedro Sáenz, José Manuel Pazos, Rubén Omar López, Javier Alejandro Torre and Adrián Salvatore see “Item 6.—Board of Directors.”
Item 6.B Compensation
Compensation of our Board of Directors
Our shareholders fix our directors’ compensation, including their salaries and any additional wages arising from the directors’ permanent performance of any administrative or technical activity. Compensation of our directors is regulated by the Argentine Corporate Law and the CNV regulations. Any compensation paid to our directors must have been previously approved at an ordinary shareholders’ meeting. Article 261 of the Argentine Corporate Law provides that the compensation paid to all directors and syndics in a year may not exceed 5.00% of net income for such year, if the company is not paying dividends in respect of such net income. The Argentine Corporate Law increases the annual limitation on director compensation to up to 25.00% of net income based on the amount of dividends, if any, that are paid. In the case of directors that perform duties at special commissions or perform administrative or technical tasks, the aforementioned limits may be exceeded if a shareholders’ meeting so approves, such issue is included in the agenda, and is in accordance with the regulations of the CNV. In any case, the compensation of all directors and members of the Supervisory Committee requires shareholders’ ratification at an ordinary shareholders’ meeting. Certain of our directors perform managerial, technical and administrative functions. We compensate directors who perform such functions for their roles both as directors and as executive officers.
During the annual ordinary shareholders’ meeting convened for April 29, 2022, the shareholders will consider the approval of the directors’ fees that amounted to a total of Ps.23,094,000 for services rendered in 2021, which were paid in 2021. As of the date of this annual report, neither we, nor any of our affiliates, have entered into any agreement that provides for any benefit or compensation to any director after expiration of his or her term.
Compensation of our Senior Officers
In 2021, our management received compensation and fees totaling Ps. 215.3 million (in nominal values), of which Ps. 34.67 million consisted of an annual bonus. The annual bonus to management is normally between three and four times their salaries and is based on certain performance thresholds related to the amount of work performed and the importance of such work to our business. We also compensate directors who perform managerial, technical and administrative functions for their roles both as directors and as executive officers.
Compensation of our Supervisory Committee
During the annual ordinary shareholders’ meeting convened for April 29, 2022, the shareholders will consider the approval of the Supervisory Committee’s fees of Ps.1,665,000 (in nominal terms) for services rendered in 2021.
Item 6.C Board practices
As of the date of this annual report, the Company does not have contracts with its directors providing benefits upon termination of employment.
Audit Committee
Under the SEC rules applicable to corporate governance, we are required to maintain an audit committee.
Pursuant to Argentine Capital Markets Law and its implementing regulations, we are required to have an audit committee consisting of at least three members of our Board of Directors with experience in business, finance, accounting, banking and audit matters. Under CNV regulations, at least a majority of the members of the audit committee must be independent directors under CNV standards.
On April 16, 2017, CNV issued Resolution No. 730/2018, which modified the criteria and requirements applicable for directors of companies admitted to the public offering regime of its shares. The main changes introduced by Resolution No. 730/2018 are as follows:
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Independent directors will cease to be independent after 10 years of holding a position of director but will be eligible to return to their independent status three years after leaving office.
The threshold constituting a “significant participation” has been reduced from a 15% holding of capital stock to a 5% holding of capital stock;
The following criteria preclude a person from being considered “independent”: (i) being connected with the company or the company´s shareholders that have (direct or indirect) significant participations, or being connected with companies in which the aforementioned shareholders have (direct or indirect) significant participations; (ii) maintaining a frequent professional relation, of relevant nature and volume, with, or receiving remuneration or fees from, the company, its shareholders who have a (direct or indirect) significant participation, or companies in which the aforementioned shareholders have (direct or indirect) significant participations; (iii) maintaining a significant participation, through the possession of shares of the capital stock and/or the votes, in the company and/or in another company in which the company has a significant participation; (iv) on a regular basis, selling and/or providing goods and/or services of relevant nature and volume (directly or indirectly) to the company or to shareholders that have (direct or indirect) significant participations; (v) being the director, CEO, administrator or principal executive for a non-profit organization which has received funds in amounts exceeding those established by Resolution No. 30/2011 of the UIF (currently equivalent to Ps. 300,000) from the company or its parent company; (vi) receiving any payments from the company or companies of the same group other than fees as a director or dividends as shareholder; and (vii) being a member of the administrative or supervisory committee and/or holding a significant participation (directly or indirectly) with respect to one or more companies that are registered as Agente de Negociación, Agente de Liquidación y Compensación y/o Agente de Corretaje de Valores Negociables.
It is necessary to comply with all the conditions of independence set forth above for at least three years before the appointment. Our Audit Committee is composed of three members designated by our Board of Directors. Mr. Juan José Salas, Mr. José Luis Morea and Mr. Tomas White are independent under Rule 10A-3 of the Exchange Act (“Rule 10A-3”) and applicable NYSE standards, which are different from the general test for independence of board and committee members. Our board of directors has determined that Mr. Tomas White qualifies as a financial expert within the meaning of the rules adopted by the Commission relating to the disclosure of financial experts on audit committees in periodic filings pursuant to the Exchange Act.
Independence Requirements under Commission Rule 10-A3
Pursuant to NYSE Rule 303A.06, we are required to have an audit committee that complies with Rule 10-A3. Under rule 10-A3, we are required to comply with certain independent standards. Each member of the audit committee must be independent and a member of the board of directors. Pursuant to Rule 10-A3, in order to be considered “independent”, a member of an audit committee of a listed issuer may not, other than in his or her capacity as a member of the audit committee, the board of directors, or any other board committee:
| · | accept directly or indirectly any consulting, advisory, or other compensatory fee from the issuer or any subsidiary thereof. Compensatory fees do not include the receipt of fixed amounts of compensation under a retirement plan (including deferred compensation) for prior service with the listed issuer (provided that such compensation is not contingent in any way on continued service); or |
| · | be an affiliated person of the issuer or any subsidiary thereof. |
Additionally, as of the date of this annual report, all members of our Audit Committee satisfy the independence requirements of the Commission and NYSE applicable to the audit committees of foreign private issuers. The members of our Audit Committee are entitled to annual compensation in the form of a fixed salary. Our Audit Committee also has two alternate members, and both are independent under Rule 10A-3 and applicable NYSE standards.
A quorum for a decision by the Audit Committee will require the presence of a majority of its members and matters will be decided by the vote of a majority of those present at the meeting. A chairman of the committee must be appointed during the first meeting after members of the committee have been appointed. The chairman of the committee may cast two votes in the case of a tie. Pursuant to our bylaws, the committee will pass resolutions by the affirmative vote of the majority of members present. Decisions of the Audit Committee will be recorded in a special corporate book and will be signed by all members of the committee who were present at the meeting. Pursuant to Section 17 Chapter III Title II of the CNV rules, the Audit Committee must hold at least one regularly scheduled meeting every three months.
Pursuant to Argentine Capital Markets Law, the Audit Committee, among other things:
| · | advises on the Board of Directors’ proposal for the designation of external independent accountants and ensure their independence; |
| · | oversees our internal control mechanisms and administrative and accounting procedures and assesses the reliability of all financial and other relevant information filed with the CNV and other entities to which we report; |
| · | oversees our information policies concerning risk management; |
| · | provides the market with complete information on transactions in which there may be a conflict of interest with members of our various corporate bodies or controlling shareholders; |
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| Table of Contents |
| · | advises on the reasonableness of fees or stock option plans for our directors and managers proposed by the Board of Directors; |
| · | advises on our fulfillment of legal requirements and the reasonableness of the terms of the issuance of shares or other instruments that are convertible into shares in cases of capital increase in which pre-emptive rights are excluded or limited; |
| · | verifies the fulfillment of any applicable rules of conduct; and |
| · | issues opinions on related-party transactions under certain circumstances and files such opinions with regulatory agencies as required by the CNV in the case of possible conflicts of interest. |
Additionally, the Audit Committee is required to prepare an annual working plan and present it to the Board of Directors and the Supervisory Committee. Members of the Board of Directors, members of the Supervisory Committee and external independent accountants are required to attend the meetings of the Audit Committee if the Audit Committee so requests it, and are required to grant the Audit Committee full cooperation and information. The Audit Committee is entitled to hire experts and counsel to assist it in its tasks and has full access to all of our information and documentation.
The following chart shows the members of our Audit Committee according to the resolution passed at the Board of Directors’ meeting held on May 12, 2021
Name |
| Title |
| Date of first appointment to position |
| Date of birth |
| Status(1) |
Juan José Salas |
| Chairman |
| May 6, 2016 |
| February 23, 1960 |
| Independent |
|
|
|
|
|
|
|
|
|
Tomás José White |
| Member |
| May 14, 2018 |
| May 18, 1957 |
| Independent |
|
|
|
|
|
|
|
|
|
José Luis Morea |
| Member |
| May 13, 2019 |
| October 19, 1954 |
| Independent |
Jorge Eduardo Villegas |
| Alternate Member |
| May 11, 2017 |
| January 9, 1949 |
| Independent |
Oscar Luis Gosio |
| Alternate Member |
| July 12, 2007 |
| August 17, 1954 |
| Independent |
(1) Status based on rules of the CNV and the Commission.
For the biographies of the members of our Audit Committee, see “Item 6.—Board of Directors.”
Supervisory Committee
We have a monitoring body called the supervisory committee (“Supervisory Committee”). Our Supervisory Committee consists of three syndics and three alternate syndics appointed by shareholders at our annual ordinary shareholders’ meeting. The syndics and their alternates are elected for a period of one year, and are vested with the powers set forth by the Argentine Corporate Law and other applicable legal provisions. Any compensation paid to our syndics must have been previously approved at an ordinary shareholders’ meeting. The term of office of the members of the Supervisory Committee expired on December 31, 2021
Members of our Supervisory Committee are also authorized to attend Board of Directors’ and shareholders’ meetings, call extraordinary shareholders’ meetings and investigate claims brought in writing by shareholders who own more than 2.00% of our outstanding shares. Pursuant to the Argentine Corporate Law, only lawyers and accountants admitted to practice in Argentina and domiciled in Argentina or civil partnerships composed of such persons may serve as syndics in an Argentine sociedad anónima, or limited liability corporation. Following the registration of the 2016 Merger, members of our Supervisory Committee may call for an ordinary shareholders’ meeting, in the specific cases provided by law, as deemed necessary by any of them, or otherwise when so required by shareholders representing no less than 5.00% of our capital stock. Pursuant to Section 294 of the Argentine Corporate Law, our Supervisory Committee must review our books and records, when deemed convenient and at a minimum on a quarterly basis.
Following the registration of the amendment to our bylaws dated June 3, 2015, our Supervisory Committee holds meetings and makes decisions with the presence and affirmative vote of at least two of its members, notwithstanding the rights granted by law to the dissenting syndic. Before the registration of the 2016 Merger, meetings of the Supervisory Committee could be called by any of its members, its meetings were held with the attendance of all of its members and decisions were adopted by a majority of votes, notwithstanding the rights granted by law to the dissenting syndic.
Our Supervisory Committee must hold meetings at least once a month. Meetings may also be called at the request of any of its members within five days from the date the request is submitted to the chairman of our Supervisory Committee or our Board of Directors, as the case may be. Notice of all meetings must be given in writing to the address indicated by each syndic at the time of holding office.
Our Supervisory Committee must be presided over by one of its members, elected by a majority of votes, at the first meeting held every year. At that time, the member who will act in lieu of the chairman in his or her absence shall also be elected. The chairman represents our Supervisory Committee before our Board of Directors.
| 162 |
| Table of Contents |
The following chart shows the members of our Supervisory Committee according to the resolution passed at the annual ordinary shareholders’ meeting held on April 30, 2021. According to Technical Resolution No. 15 of the Argentine Federation of Professional Counsel of Economic Sciences and Section III, Chapter III of Title II of the CNV rules, all of our syndics and alternate syndics are independent.
Name |
| Office |
| Date of first appointment to position |
| Profession |
| Date of birth |
Carlos C. Adolfo Halladjian. |
| Syndic |
| April 16, 2013 |
| Public Accountant |
| March 8, 1977 |
Eduardo Antonio Erosa |
| Syndic |
| April 16, 2013 |
| Public Accountant |
| October 6, 1958 |
Juan Antonio Nicholson |
| Syndic |
| April 27, 2018 |
| Lawyer |
| July 21, 1947 |
Cristina Margarita De Giorgio |
| Alternate Syndic |
| April 30, 2021 |
| Public Accountant |
|
|
Carlos Adolfo Zlotnitzky |
| Alternate Syndic |
| September 21, 2015 |
| Public Accountant |
| April 4, 1981 |
Lucas Nicholson |
| Alternate Syndic |
| April 27, 2018 |
| Lawyer |
| October 9, 1985 |
____________
The following are the academic and professional backgrounds of our Supervisory Committee members:
Carlos C. Adolfo Halladjian holds a degree in Accounting, magna cum laude, from the Universidad de Buenos Aires. He has served as a syndic of our Supervisory Committee since 2013. He has been a partner of the Halladjian y Asociados accounting firm since 2010. He serves as syndic of the following companies: Proener S.A.U., CVOSA, TJSM, Empresa Distribuidora Sur Sociedad Anónima (EDESUR S.A), CP Renovables, CP La Castellana S.A.U., CP Achiras S.A.U., CPR Energy Solutions S.A.U., Distrilec Inversora S.A., Hidrodistribución S.A, PB Distribución S.A, RPE Distribución S.A., CP Patagones S.A.U., Estudio Halladjian SRL, Vientos La Genoveva S.A.U. and Vientos La Genoveva II S.A.U., as well as an alternate syndic of the following companies: DGCU, CP Manque S.A.U. and CP Los Olivos S.A.U.
.Eduardo Antonio Erosa holds a degree in Accounting from the Universidad Católica Argentina in 1985. He has served as a syndic of our Supervisory Committee since 2013. He currently is President of the Board of Directors of Compañía Argentina de Navegación de Ultramar S.A. In addition, he is an alternate syndic of LE Capital S.R.L
Juan Antonio Nicholson holds a degree in law from the Universidad de Buenos Aires, where he also was adjunct professor of Commercial Law. He is partner at the law firm Nicholson y Cano Abogados. He served as a director and syndic of several companies. Since 2005 he has been a syndic of HSBC Bank Argentina. He is also president of el Tunalito S.A. Since 2018 he serves as a member of our Supervisory Committee
Cristina Margarita De Giorgio holds a degree in Accounting from the Universidad Católica Argentina in 1985. She also holds postgraduate degrees in Management of Small and Medium Enterprises, Ontological Coaching, Human Resources and Leadership from Universidad Católica Argentina, Universidad de Belgrano, Universidad del Salvador and IAE, respectively. She worked as Head of Accounting in a private firm, and from 1983 to 1988 she worked at Balzarotti and Associates Studio (Touch Ross International) Small and Medium Enterprises Subdivision. From 1985 to 2005 she served as Professor of Accounting I and II at Universidad Católica Argentina, and, from 1985 to 1990, as Professor of Ethics at Universidad Católica Argentina .
Carlos Adolfo Zlotnitzky holds a degree in Accounting from the Universidad de Buenos Aires. He has served as an alternate syndic of our Supervisory Committee since 2015. He works as an independent accountant and tax and accounting advisor for both legal entities and individuals. He currently serves as alternate syndic of DGCE, DGCU, IGCE, . ESSA, CP Manques S.A.U. and CP Los Olivos S.A.U.
Lucas Nicholson holds a degree in law from the Universidad del Salvador. In addition, he took a graduate level course in legal framework of agribusiness in the Universidad Austral. From 2011 to 2016, he worked at the law firm Nicholson Cano in their corporate and competition law departments. In 2016, together with Santiago Williams and Agustín Ibarzábal, he founded WIN Abogados. In addition, he currently serves as syndic of IGCE, Energía Sudamericana S.A., DGCE, COyServ S.A., and, since 2018, alternate syndic of Central Puerto S.A.
| 163 |
| Table of Contents |
Item 6.D Employees
We had 861 employees ad of December 31, 2021, 885 employees as of December 31, 2020, and 894 employees as of December 31, 2019. The following table breaks down the number of our employees and their affiliation with unions for the periods indicated:
Year |
| Union |
| Puerto Complex |
|
| La Plata |
|
| Luján de Cuyo |
|
| Piedra del Águila |
|
| Brigadier López |
|
| Terminal 6-San Lorenzo |
|
| CP Renovables |
|
| CP La Castellana |
|
| CP Achiras |
|
| VientosLa Genoveva |
|
| Manque |
|
| CVOSA |
| ||||||||||||
2017 |
| Subtotal outside CBA |
|
| 68 |
|
|
| 3 |
|
|
| 10 |
|
|
| 4 |
|
|
| — |
|
|
| — |
|
|
| 1 |
|
|
| 3 |
|
|
| 3 |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| APSEE |
|
| 104 |
|
|
| 2 |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| LYF |
|
| 360 |
|
|
| 23 |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| FATLYF |
|
| — |
|
|
| — |
|
|
| 89 |
|
|
| 47 |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| APUAYE |
|
| — |
|
|
| — |
|
|
| 16 |
|
|
| 5 |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| Subtotal under CBA |
|
| 464 |
|
|
| 25 |
|
|
| 105 |
|
|
| 52 |
|
|
| — |
|
|
| — |
|
|
| 1 |
|
|
| 5 |
|
|
| 5 |
|
|
| — |
|
|
| — |
|
|
| 40 |
|
|
| Total |
|
| 532 |
|
|
| 28 |
|
|
| 115 |
|
|
| 56 |
|
|
| — |
|
|
| — |
|
|
| 1 |
|
|
| 5 |
|
|
| 5 |
|
|
| — |
|
|
| — |
|
|
| 78 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| — |
|
2018 |
| Subtotal outside CBA |
|
| 116 |
|
|
| — |
|
|
| 11 |
|
|
| 4 |
|
|
| — |
|
|
| — |
|
|
| 1 |
|
|
| 5 |
|
|
| 5 |
|
|
| — |
|
|
| — |
|
|
| 38 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| APJAE |
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| 6 |
|
|
| APSEE |
|
| 100 |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| LYF |
|
| 336 |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| FATLYF |
|
| — |
|
|
| — |
|
|
| 83 |
|
|
| 43 |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| 34 |
|
|
| APUAYE |
|
| — |
|
|
| — |
|
|
| 16 |
|
|
| 5 |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| Subtotal under CBA |
|
| 436 |
|
|
| — |
|
|
| 99 |
|
|
| 48 |
|
|
| — |
|
|
| — |
|
|
| 1 |
|
|
| 5 |
|
|
| 5 |
|
|
| — |
|
|
| — |
|
|
| 40 |
|
|
| Total |
|
| 552 |
|
|
| — |
|
|
| 110 |
|
|
| 52 |
|
|
| — |
|
|
| — |
|
|
| 1 |
|
|
| 3 |
|
|
| 5 |
|
|
| — |
|
|
| — |
|
|
| 78 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2019 |
| Subtotal outside CBA |
|
| 119 |
|
|
| — |
|
|
| 9 |
|
|
| 4 |
|
|
| 0 |
|
|
| 11 |
|
|
| 1 |
|
|
| 6 |
|
|
| 4 |
|
|
| — |
|
|
| — |
|
|
| 31 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| — |
|
|
| 6 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| — |
|
|
|
|
|
|
|
|
|
|
| APJAE |
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| 6 |
|
|
| APSEE |
|
| 91 |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| LYF |
|
| 327 |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| FATLYF |
|
| — |
|
|
| — |
|
|
| 81 |
|
|
| 41 |
|
|
| 71 |
|
|
| 21 |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| 34 |
|
|
| APUAYE |
|
| — |
|
|
| — |
|
|
| 16 |
|
|
| 5 |
|
|
| — |
|
|
| 2 |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| 8 |
|
|
| Subtotal under CBA |
|
| 418 |
|
|
| — |
|
|
| 97 |
|
|
| 46 |
|
|
| 71 |
|
|
| 29 |
|
|
| 0 |
|
|
| 0 |
|
|
| 0 |
|
|
| — |
|
|
| — |
|
|
| 48 |
|
|
| Total |
|
| 537 |
|
|
| — |
|
|
| 106 |
|
|
| 50 |
|
|
| 71 |
|
|
| 40 |
|
|
| 1 |
|
|
| 6 |
|
|
| 4 |
|
|
| — |
|
|
| — |
|
|
| 79 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2020 |
| Subtotal outside CBA |
|
| 107 |
|
|
| - |
|
|
| 9 |
|
|
| 4 |
|
|
| - |
|
|
| 16 |
|
|
| - |
|
|
| 6 |
|
|
| 4 |
|
|
| 1 |
|
|
| — |
|
|
| 31 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| APJAE |
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| 6 |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| 6 |
|
|
| APSEE |
|
| 92 |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| - |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| - |
|
|
| LYF |
|
| 322 |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| - |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| - |
|
|
| FATLYF |
|
| — |
|
|
| — |
|
|
| 80 |
|
|
| 43 |
|
|
| 71 |
|
|
| 21 |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| 34 |
|
|
| APUAYE |
|
| — |
|
|
| — |
|
|
| 16 |
|
|
| 5 |
|
|
| - |
|
|
| 2 |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| 8 |
|
|
| Subtotal under CBA |
|
| 414 |
|
|
| — |
|
|
| 96 |
|
|
| 48 |
|
|
| 71 |
|
|
| 29 |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| 48 |
|
|
| Total |
|
| 521 |
|
|
| — |
|
|
| 105 |
|
|
| 52 |
|
|
| 71 |
|
|
| 45 |
|
|
| — |
|
|
| 6 |
|
|
| 4 |
|
|
| 1 |
|
|
| — |
|
|
| 79 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2021 |
| Subtotal outside CBA |
|
| 116 |
|
|
| — |
|
|
| 9 |
|
|
| 4 |
|
|
| 1 |
|
|
| 11 |
|
|
| — |
|
|
| 1 |
|
|
| 1 |
|
|
| 1 |
|
|
| 2 |
|
|
| 31 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| APJAE |
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| 6 |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| 6 |
|
|
| APSEE |
|
| 89 |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| LYF |
|
| 302 |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| FATLYF |
|
| — |
|
|
| — |
|
|
| 82 |
|
|
| 43 |
|
|
| 67 |
|
|
| 25 |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| 34 |
|
|
| APUAYE |
|
| — |
|
|
| — |
|
|
| 16 |
|
|
| 5 |
|
|
| — |
|
|
| 2 |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| 7 |
|
|
| Subtotal under CBA |
|
| 391 |
|
|
| — |
|
|
| 98 |
|
|
| 48 |
|
|
| 67 |
|
|
| 33 |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| — |
|
|
| 47 |
|
|
| Total |
|
| 507 |
|
|
| — |
|
|
| 107 |
|
|
| 52 |
|
|
| 68 |
|
|
| 44 |
|
|
| — |
|
|
| 1 |
|
|
| 1 |
|
|
| 1 |
|
|
| 2 |
|
|
| 78 |
|
____________
Note: APSEE: Asociación del Personal Superior de Empresas de Energía
| 164 |
| Table of Contents |
LYF: Luz y Fuerza
FATLYF: Federación Argentina de Trabajadores de Luz y Fuerza
APUAYE: Asociación de Profesionales del Agua y la Energía Eléctrica
The CBA entered into with the several unions that have members working at our sites include the terms and conditions that govern the employment contracts of the workers affiliated with each of these unions. Some of the most relevant terms and conditions of these agreements include the positions that are included in and excluded from bargaining, work schedules, salary levels and additional amounts payable on the basis of the worker’s job, working days and leaves, among other things.
Matters that are not specifically agreed upon in collective bargaining are governed by the applicable labor laws in Argentina.
The CBAs are entered into for a specific term and may be renewed by the parties. If not renewed, they may remain in place under the principle of survival of repealed laws set forth in the CBA Law No. 14,250.
Item 6.E Share Ownership
Share Ownership
The table below sets forth information concerning the share ownership of our directors and members of our administrative, supervisory or management bodies as of April 22, 2022
Name |
| Title |
| Shares |
| % of shares |
Marcelo Suvá |
| Alternate Director and Vice President |
| 1,500,000 |
| 0.10% |
Fernández Barbiero, Martín |
| Compliance and Internal Audit Manager |
| 285 |
| 0.00% |
Leonardo Katz |
| Director de Planificación Estratégica |
| 2,675 |
| 0.00% |
Enrique Terraneo |
| CFO and Alternate Director |
| 4,000 |
| 0.00% |
Item 7. Major Shareholders and Related Party Transactions
Item 7.A. Major Shareholders
As of April 28, 2022, we had 1,514,022,256 outstanding shares of common stock with a par value of Ps.1.00 per share. Each share of common stock is entitled to one vote. We do not have any preferred shares outstanding and only have one class of common shares outstanding. 8,851,848, or 0.58%, of our common shares are held by our subsidiary, Proener S.A.U.
The following table sets forth certain information known to us concerning the beneficial ownership over 5% or more of our common shares as of April 22, 2022 (except as set forth below).
Beneficial Owner |
| Shares |
|
| % of shares |
| ||
Plusener S.A.(1) |
|
| 158,073,984 |
|
|
| 10.44 | % |
Argentine Government |
|
| 124,949,112 |
|
|
| 8.25 | % |
Guillermo Pablo Reca(2) |
|
| 172,737,169 |
|
|
| 11.41 | % |
Eduardo José Escasany(3) |
|
| 77,643,863 |
|
|
| 5.13 | % |
Senior Management and Directors** |
|
| 1,506,960 |
|
|
| 0.10 | % |
Other Shareholders(4) |
|
| 979,111,141 |
|
|
| 64.67 | % |
Total |
|
| 1,514,022,256 |
|
|
| 100.00 | % |
____________
** | Marcelo Suvá Enrique Terraneo, Leonardo Katz and Martín Fernández Barbiero each own less than 1% of the outstanding common stock. |
(1) | According to Schedules 13G filed with the Commission by Plusener S.A. on February 6, 2020. |
(2) | According to Schedules 13G filed with the Commission by Guillermo Pablo Reca on February 9, 2022. |
(3) | According to Schedules 13G filed with the Commission by Eduardo José Escasany on February 14, 2021. |
(4) | No other shareholder has beneficial ownership of more than 5% of our common shares. None of our senior officers own any of our common shares. |
As of April 22, 2022, we had approximately 33,658,656 ADSs outstanding.
We are not able to determine the number of record holders of our ADSs as of such date, as we are only aware of the Depositary Trust Company and its nominee as record holders. In addition, it is not practicable for us to determine the number of our ADSs or common shares beneficially owned in the United States. Likewise, we cannot readily ascertain the domicile of the final beneficial holders represented by ADS record holders in the United States or the domicile of any of our foreign shareholders who hold our common shares, either directly or indirectly.
As of the date of this annual report, there are no agreements in place which, if enforced on a subsequent date, may result in a change of control.
| 165 |
| Table of Contents |
On December 16, 2016, at a meeting of our shareholders, our shareholders decided to reduce the voluntary reserve by Ps.1,324,769,474 and capitalize such funds through the payment of a dividend in shares of seven new shares of common stock with a par value of Ps.1.00 per share for each outstanding share of common stock. Following such capitalization and dividend of shares, and as of the date of this annual report, we have 1,514,022,256 outstanding shares of common stock with a par value of Ps.1.00 per share.
The table below represents the evolution of our capital stock since January 1, 2015:
Date |
| Capital stock (Ps.) |
|
| Event |
| Controlling shareholders |
| ||
March 11, 2016 |
|
| 189,252,782 |
|
| 2016 Merger (and related capital decrease) |
|
| N/A |
|
December 16, 2016 |
|
| 1,514,022,256 |
|
| Capital Increase and Share Dividend Distribution |
|
| N/A |
|
Item 7.B Related Party Transactions
Argentine corporate law permits directors of a corporation to enter into transactions with such corporation provided that any such transactions are consistent with prevailing market practice. The Argentine Securities Law provides that corporations whose shares are publicly listed in Argentina must submit to their respective audit committees for approval of any transaction with a related party involving an amount that exceeds 1.00% of the corporation’s net worth.
On June 24, 2020, our Board of Directors authorized the purchase of 30% of the capital stock of the subsidiary CP Renovables S.A. from Mr. Guillermo Pablo Reca. On June 24, 2020, we acquired 993,993,952 shares, at a value of US Dollars 0.034418 per share, which were fully paid through the transfer of financial assets. Based on the Audit Committee’s report, the Board of Directors determined that such transaction was an arm´s length transaction.
As a result of this transaction, as of the date of this annual report, the Company´s consolidated interest in the subsidiary CP Renovables S.A. amounts to 100% of its capital stock.
This transaction was accounted as a transaction with non-controlling interest in accordance with IFRS 10. Consequently, the difference of 2,967,736 between the book value of the non-controlling interest at the transaction date and the fair market value of the consideration paid was directly recognized in equity and attributed to holders of the parent.
Except as set forth below and as otherwise permitted under applicable law, we are currently not party to any transactions with, and have not made any significant loans to, any of our directors, key management personnel or other related persons, and have not provided any guarantees for the benefit of such persons, nor are there any such transactions contemplated with any such persons.
Management Assistance Agreement
RMPE (formerly known as SADESA Servicios S.A.) provides certain administrative, financial, commercial, human resources and general management services to us under the terms of the management assistance proposal dated November 30, 2007, as amended and assigned (the “Assistance Proposal”). Guillermo Pablo Reca currently serves as regular director and chairman of RMPE and holds equity therein. The Assistance Proposal was valid for five years as of December 1, 2007 and was automatically extended for two additional periods. We must pay a fee equal to one and a half percent (1.50%) of our annual gross sales revenues carried out as a result of our main activities. The amounts accrued under this agreement in years ended December 31, 2021, 2020, and 2019 were Ps. 848 million, Ps. 821.7 million, and Ps. 738.3 million, respectively.
Other than the management assistance services, we receive from RMPE, a lease between us, as lessor, and RMPE, as lessee, involving a monthly payment of Ps.18,000.
For more information on the related party transactions, see Note 18 to our Audited Consolidated Financial Statements.
CP Renovables Stock Option Agreement
On January 18, 2017, CP Renovables entered into a stock option agreement with its then chairman and general manager (or CEO), Guillermo Pablo Reca (“the minority shareholder”), pursuant to a stock option plan approved by CP Renovables’ shareholders on April 28, 2016. Under the stock option agreement, the minority shareholder had the obligation, for a three-year term, to (i) develop the CP Renovables business by, among other things, facilitating investments, proposing acquisitions and business opportunities for the expansion of renewable energy projects, and (ii) lead the development of the existing projects of CP Renovables. In addition, the minority shareholder has the right to purchase up to 10% of the fully diluted capital stock of CP Renovables, in whole or in part, in one or more acquisitions, at any time prior to the seventh anniversary of the date of execution of the stock option agreement. This latter right to purchase up to 10% of the fully diluted capital stock of CP Renovables is composed by the right to acquire (y) 63,058,342 class B shares of CP Renovables (the “Initial Option Shares”), and (z) an additional number of class B shares equal to 10% of any increase in capital stock made since the execution of the stock option agreement (the “Additional Option Shares”). The aggregate price for the Initial Option Shares (assuming all are purchased) has been agreed in US$3,963,690, while the purchase price of any Additional Option Shares will be the U.S. dollar equivalent (based on the exchange rate at the time of the relevant capital increase) of the subscription price per share paid for the shares of CP Renovables issued pursuant to such capital increase. The stock option agreement includes adjustments and anti-dilution protections, including with respect to in-kind capital increases and dividend distributions by CP Renovables, and other transactions such as stock splits and redenomination of par value. In addition, the minority shareholder can assign his rights under the stock option agreement without the consent of CP Renovables. As of the date of this annual report, the option, although fully vested, has neither been exercised nor assigned.
GESER S.A.U.
On March 24, 2022, we acquired an 8.599% interest in the related company GESER S.A.U., an entity controlled by IGCE. The purchase price was Ps. 2,631 thousand. GESER S.A.U. is a private unlisted company which is engaged in providing administrative services.
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| Table of Contents |
Item 7.C Interests of experts and counsel
Not applicable.
Item 8. Financial Information
Item 8.A. Consolidated Statements and Other Financial Information.
See Item 18 and our Audited Consolidated Financial Statements as of December 31, 2021 and for the years ended December 31, 2021, 2020, and 2019 included in this annual report.
Legal Proceedings
Income Tax for Fiscal Year 2014
In February 2015 the Company filed income tax returns for the nine-month period ended September 30, 2014, applying the adjustment for inflation mechanism established by the Argentine Income Tax Law. In addition, the Company filed its income tax return for the three-month period ended December 31, 2014, applying the same adjustment for inflation mechanism.
On July 27, 2021, the Argentine Tax Authorities issued a resolution through which it implemented an infringement investigation in relation to the income tax for the irregular fiscal periods ended September 30, 2014 and December 31, 2014, for the alleged omission included in Section 45, Law No. 11,683. On September 8, 2021, the Company submitted the corresponding deposition and the corresponding evidence. As of the date of this annual report, the proceedings are under review of the Argentine Tax Authorities.
Based on the opinion of legal counsel and on the IFRIC 23 accounting guidelines, we concluded that it is probable that the Argentine tax authority may accept the Company’s interpretation, thus not requiring to register a liability under such item with respect to income tax determination for fiscal year 2014.
Action for Recovery—Income Tax Refund for Fiscal Period 2010.
In December 2014, the Company, as merging company and continuing company of HPDA, filed action for recovery with the tax authorities regarding the income tax for the fiscal period 2010, which was incorrectly entered by HPDA. This recourse action seeks to recover the income tax entered by HPDA in accordance with the lack of application of the inflation- adjustment mechanism established by the Income Tax Law. In December 2015, since the term stated by Law no. 11,683 elapsed, the Company brought a contentious- administrative claim before the National Court to ask for its right to obtain the income tax recovery.
In October 2018, the Company was served notice of the judgment issued by the Federal Contentious- Administrative Court No. 5, which granted the right to recourse. The judgment ordered tax authorities to return the amount of Ps. 67,612 thousand (at historical values) to the Company plus the interest stated in the Central Bank Communication 14290 and ordered that legal cost must be borne by the defendant. Such judgment was appealed by the National Tax Administration, and on September 9, 2019, Division I of the National Court of Appeals of the Federal Contentious- Administrative Court (“CNACAF”) confirmed the appealed judgment. On September 24, 2019, the National Tax Administration raised Federal Extraordinary Appeal (“REF”) against CNACAF judgment, which was replied by the Company. On October 29, 2019, CNACAF granted the REF and sent the file to the Argentine Supreme Court, which remains under analysis as of the date of this annual report.
Action for recovery - Income Tax Refund for Fiscal Years 2009, 2011 and 2012
In December 2015, the Company filed a claim before the Argentine Tax Authorities for the recovery of income tax for the fiscal year 2009, in the amount of Ps. 20,395 thousand at historical values which had been incorrectly paid by the Company in excess of our income tax liability. By filling such action, the Company sought to recover the excess amounts we paid due to the non application of the inflation adjustment as set forth in the Argentine Income Tax Law. On April 22, 2016, after the term required by Law No. 11,683 expired, the Company filed an action for recovery for the amount claimed with the Argentinean Tax Court. On September 27, 2019, the first instance court rendered a judgment rejecting the complaint filed by the Company. Such judgment was appealed by the Company on October 4, 2019 and, on March 11, 2020, the CNACAF revoked the first instance tax court judgment, in favor of the Company’s claim. Upon this resolution, the Argentine Tax Authorities raised an Extraordinary Appeal, which was granted by CNACAF on September 1, 2020.
In December 2017, the Company, as merging and continuing company of HPDA, filed a claim before the Argentine Tax Authorities for the recovery of Ps. 52,783 thousand at historical values paid in excess by HPDA on its 2011 fiscal year Income Tax fiscal period. By filling such action, HPDA intends to recover the excess amounts paid due to the non application of the inflation adjustment set forth in the Argentine Income Tax Law. On April 1, 2019, such claim was rejected by Argentine Tax Authorities. Therefore, the Company filed an administrative and legal action on April 25, 2019.
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In December 2018, the Company brought two administrative complaints of recovery before the Argentine Tax Authorities: the first one was filed by the Company, as merging company and continuing company of HPDA, regarding the income tax for the fiscal period 2012 that amounted to 62,331 at historical values, which was entered in excess by HPDA. The second complaint was filed by the Company regarding the income tax for the same fiscal period that amounted to 33,265 at historical values, which was entered in excess by the Company. These recourse actions seek to recover the income tax entered by HPDA and the Company in accordance with the lack of application of the inflation-adjustment mechanism aforementioned. On September 12, 2019, the Company filed both recourse actions before the Federal Contentious- Administrative Court against the Argentine Tax Authorities in accordance with Section 82, paragraph “c” of Law no. 11,683 (restated text 1998 as amended), as the term established in the second paragraph of Section 81 of such law had elapsed.
Action for recovery - Income Tax Refund for Fiscal Year 2015
On December 23, 2020, the Company submitted a claim before the Argentine Tax Authorities in relation to income tax for the fiscal year 2015, for the amount of Ps. 129,231 thousands at historical values. The purpose of the claim for recovery is to obtain reimbursement of the income tax paid by the Company due to the non application of the inflation adjustment mechanism set forth in the Argentine Income Tax Law. On April 22, 2021, the Company filed a recovery lawsuit before the Court for Contentious Administrative Matters against the Argentine Tax Authorities pursuant to the provisions of Section 82, subsection c of Law No. 11683 (restated and amended 1998), on the grounds that the term established in the second paragraph of Section 81 of that body of rules had elapsed.
Action for recovery - Income Tax Refund for Fiscal Year 2016
On January 24, 2022, the Company filed before the tax authorities a recovery action of the income tax for the fiscal year 2016, for the amount of 189,376 (at historical values) unduly paid by CPSA. Such recovery action is aimed at obtaining the reimbursement of the income tax paid by CPSA based on the non application of the inflation adjustment mechanism set forth in the Argentine Income Tax Law.
Based on the opinion of legal counsel and on the IFRIC 23 accounting guidelines, we concluded that it is probable that the the Company’s interpretation with respect to its income tax refund claims detailed above, will be accepted in court, with the only exception of the claim brought by HPDA on its 2011 fiscal year income. Thus, we registered an asset under item “Other non-financial assets” of non Current Assets under “Income Tax Credits” of our financial statements and it amounts to Ps. 277.1 million and Ps. 291.7million as of December 31, 2021, and 2020, respectively.
Dividends and Dividend Policy
The holders of ADSs are entitled to receive dividends to the same extent as the owners of our common shares. In August 2017, we declared dividends of Ps. 0.85 per ordinary share in cash. In April 2018, we declared dividends of Ps. 0.70 per ordinary share in cash. In November 2019, we paid Ps. 0.71 per ordinary share in dividends in cash.
In the future, we could decide to pay dividends in accordance with applicable law and based on various factors then existing, including:
| · | our financial condition, operating results and current and anticipated cash needs; |
| · | our strategic plans, business prospects and expansion capital expenditures; |
| · | general economic and business conditions; |
| · | our strategic plans and business prospects; |
| · | legal, contractual and regulatory restrictions on our ability to pay dividends; and |
| · | other factors that our Board of Directors may consider to be relevant. |
Under the Argentine Corporate Law, the declaration and payment of annual dividends, to the extent that the company presents retained earnings in accordance with IFRS and CNV regulations, are determined by shareholders at the annual ordinary shareholders’ meeting. In addition, under the Argentine Corporate Law, 5% of the net income for the fiscal year calculated in accordance with IFRS and CNV regulations must be appropriated by resolution adopted at shareholders’ meetings to a legal reserve until such reserve equals 20% of the capital stock. This legal reserve is not available for distribution.
According to the amendments introduced to the Income Tax Law by means of the current laws and regulations, the taxation applicable on the distribution of dividends from Argentine companies would be as follows:
1. Dividends originated in profits obtained during fiscal years initiated on or after January 1, 2018 and up to December 31, 2020: dividends on Argentine shares paid to Argentine resident individuals and/or non-Argentine residents would be subject to a 7% income tax withholding on the amount of such dividends (“Dividend Tax”). Note that according to Section 48 of Law No. 27,541, the application of the corporate 25% rate was suspended for one tax period; thus the 7% rate would also apply for dividend distributions involving profits obtained during fiscal years initiated on or after January 1, 2018 and up to December 31, 2021. However, if dividends are distributed to Argentine Entities (in general, entities organized or incorporated under Argentine law, certain traders and intermediaries, local branches of non-Argentine entities, sole proprietorships and individuals carrying on certain commercial activities in Argentina), no Dividend Tax should apply. Equalization Tax (as defined below) is not applicable.
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Argentine individuals and undivided estates located in Argentina are not allowed to offset income arising from the distribution of dividends on Argentine shares with other losses arisen in other type of operations.
2. Dividends originated in profits obtained during fiscal years initiated on or after January 1, 2021 onward: due to the amendments introduced by Law 27,630; dividends on Argentine shares paid to Argentine resident individuals and/or non-Argentine residents would be subject to a 7% income tax withholding on the amount of such dividends. However, if dividends are distributed to Argentine Entities, no Dividend Tax should apply. Equalization Tax is not applicable.
3.Dividends originated in profits obtained during tax periods before those contemplated above: no Argentine income tax withholding would apply on dividend distributions except for the application of the Equalization Tax.
The equalization tax (the “Equalization Tax”) is applicable when the dividends distributed are higher than the “net accumulated taxable income” of the immediate previous fiscal period from when the distribution is made. In order to assess the “net accumulated taxable income” from the income calculated by the Income Tax Law, the income tax paid in the same fiscal period should be subtracted and the local dividends received in the previous fiscal period should be added to such income. The Equalization Tax would be imposed as a 35% withholding tax on the shareholder receiving the dividend. Dividend distributions made in property (other than cash) would be subject to the same tax rules as cash dividends. Stock dividends on fully paid shares (“acciones liberadas”) are not subject to Equalization Tax.
For Argentine individuals and undivided estates not registered before the Argentine tax authorities as taxpayers for income tax purposes as well as for non-Argentine residents, the Dividend Tax withholding will be considered a final payment. Argentine individuals and undivided estates are not allowed to offset income arising from the distribution of dividends on Argentine shares with losses from other types of operations.
Pursuant to the terms of the amendment to the Brigadier Lopez Loan between the Company and Citibank N.A., JP Morgan Chase Bank N.A. and Morgan Stanley Senior Funding INC. dated December 22, 2020, the Company is precluded from making dividends payment during 2021 and limited to a maximum of US$ 25 million and USD 20 million in dividends payment for 2022 and 2023, respectively.
As of the date of this report, in accordance to the Central Bank regulations, we are required to obtain a prior authorization in order to have access to the FX Market to purchase the foreign currency (a step necessary to make international transfers) to pay dividends. However, as of the date of this annual report, there are no restriction fom Central Bank to use the cash and equivalents in foreign currency that the company may hold in order to pay dividends to its shareholders.
Furthermore, as from January 17, 2020, in accordance with Central Bank regulations, access is granted to the FX Market exchange market to pay dividends to non-resident shareholders, subject to the requirement that the total amount of transfers executed through the FX Market for payment of dividends to non-resident shareholders may not exceed 30% of the total value of any new capital contributions made in the Company that had been entered and settled through such exchange market. The total amount paid to non-resident shareholders may not exceed the corresponding amount denominated in Argentine Pesos that was determined by the related shareholders' meeting.
Amount Available for Distribution
Dividends may be lawfully declared and paid only out of our earnings stated in our annual financial statements approved by the annual ordinary shareholders’ meeting. Under the Argentine Corporate Law, listed companies (such as ourselves) may distribute provisional dividends or dividends in advance resulting from interim financial statements.
Under the Argentine Corporate Law and our bylaws, our annual net income (as adjusted to reflect changes in prior years’ results) is allocated in the following order: (i) to comply with our legal reserve requirement of 5% of our net income until such reserve equals 20% of the capital stock; (ii) for voluntary or contingent reserves, as may be resolved from time to time by our shareholders at the annual ordinary shareholders’ meeting; (iii) the remainder of the net income for the year may be distributed as dividends on common shares; and/or (iv) as otherwise decided by our shareholders at the annual ordinary shareholders’ meeting.
Our Board of Directors submits our financial statements for the preceding fiscal year, together with reports thereon by our Supervisory Committee and the independent accountants, at the annual ordinary shareholders’ meeting for approval. Within four months of the end of each fiscal year, an ordinary shareholders’ meeting must be held to approve our annual financial statements and determine the appropriation of our net income for such year.
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Under applicable CNV regulations, cash dividends must be paid to shareholders within 30 days of the shareholders’ meeting approving such dividends. In the case of stock dividends, shares are required to be delivered within three months of our receipt of notice of the authorization by the CNV for the public offering of the shares relating to such dividends. The statute of limitations in respect of the right of any shareholder to receive dividends declared by the shareholders’ meeting is three years from the date on which it has been made available to the shareholder.
Item 8.B Significant Changes
The main subsequent events occurred after the closing date of the annual financial statements (December 31, 2021) are the following:
Resolution SE N°238/2022
On April 21, 2022, the Secretariat of Energy issued Resolution SE No. 238/2022, which updates remuneration prices for energy and capacity of generation units not committed on a PPA. Resolution SE No. 238/2022 replaces Annex I to V of the former Resolution SE No. 440/2021 and eliminates section 4 of the Resolution SE No. 1037/2021, which provided for a transitional additional revenue to generators. Resolution SE No. 238/2022 also removes the “Use Factor” from the capacity payment calculation, improving revenue performance.
Resolution SE No. 238/2022 increases by 30% the remuneration values retroactively to February 2022 and provides for an additional 10% above the new values, which will become effective in June 2022.
Item 9. The Offer and Listing
Item 9.A. Offer and listing details
Our shares are listed on the BYMA and, since February 2, 2018, have been listed on the NYSE under the symbol “CEPU.”
Item 9.B. Plan of Distribution
Not applicable.
Item 9.C. Markets
Our common shares are listed on the BYMA under the symbol “CEPU.” During 2021, the volume traded on the BYMA amounted to 145,075,204 shares. The total number of shares subscribed and integrated on December 31, 2021 was 1,514,022,256, of which 100% were listed and available to trade on the Buenos Ares Stock Exchange.
On February 1, 2018, we completed our IPO and on February 2, 2018, our ADSs representing our common shares began to trade on the NYSE under the symbol “CEPU.” From January 1, 2021 to December 31, 2021 the volume of ADRs traded on the NYSE amounted to 70,090,836, equivalent to 700,908,360common shares.
Consequently, the total trading volume of our common shares during 2021 was 845,983,564.
Item 9.D. Selling Shareholders
Not applicable.
Item 9.E. Dilution
Not applicable.
Item 9.F. Expenses of the issue
Not applicable.
Item 10. Additional Information
Item 10.A. Share capital
Not applicable.
Item 10.B. Memorandum and articles of association
Below we provide certain information on our capital stock and a brief summary of certain significant provisions of our bylaws and the applicable laws and regulations in Argentina. This summary is not intended to be comprehensive and is qualified in its entirety by our bylaws and the applicable laws and regulations in force in Argentina.
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Capital Stock
As of the date of this annual report, our capital stock amounts to Ps.1,514,022,256 and is represented by 1,514,022,256 common shares with a par value of Ps.1.00 and one voting right each, all of them having been fully paid in and admitted to public offering
On December 16, 2016, at a meeting of our shareholders, our shareholders decided to reduce the voluntary reserve by Ps.1,324,769,474 and capitalize such funds through the payment of a dividend in shares of seven new shares of common stock with a par value of Ps.1.00 per share for each outstanding share of common stock. Following such capitalization and dividend of shares, and as of the date of this annual report, we have 1,514,022,256 outstanding shares of common stock with a par value of Ps.1.00 per share.
As of the date of this annual report, one of our subsidiaries holds 8,851,848 of our common stock.
As of the date of this annual report, we are not aware of any individuals who hold, or who have agreed to hold, conditionally or otherwise, stock options, with respect to our common shares
Articles of Incorporation and Bylaws
We are a corporation (sociedad anónima) organized and existing pursuant to the laws of Argentina. Our registered offices are domiciled in the City of Buenos Aires, Argentina. Central Puerto was created through Executive Decree No. 1222/92 dated February 26, 1992, in connection with the privatization process of SEGBA, and was registered with the Public Registry of Commerce on March 13, 1992 under No. 1,855 of Book 110, Volume A (Sociedades Anónimas). Central Puerto was created for a term of ninety-nine years as from its registration with the Public Registry of Commerce.
Corporate Purpose
Pursuant to Section 4 of our bylaws, Central Puerto was created to be engaged in any of the following activities, either on its own account, or through or in association with third parties, in Argentina or abroad:
(a) producing, transforming, carrying, distributing and selling electric power in any of its forms, including, but not limited to, thermoelectric power from non-renewable sources (coal, oil derivatives, natural gas, uranium) and renewable sources, or from usable waste, hydroelectric power (including mini and micro power plants), thermonuclear power, wind power, geothermal power, offshore energy (tidal power, wave power, ocean currents, ocean-thermal energy, osmosis energy), solar energy (photovoltaic and thermal power) and bioenergy (plant and animal biomass);
(b) producing, storing and using hydrogen technologies in any of its available forms of energy;
(c) engaging in the exploration, exploitation, processing, purification, transformation, refining, industrialization, storage, sale, transportation, distribution, import and export of liquid (such as oil) and/or gaseous hydrocarbons (such as natural gas), minerals (such as mineral coal) and metals (such as uranium and lithium, among others) and their respective direct or indirect derivatives;
(d) engaging in the production and exploitation of raw materials for biofuel production (biodiesel and bioethanol), including their manufacturing, storage, sale, distribution and transportation;
(e) engaging in the processing, storage, sale, distribution and transportation and/or use of: (i) agricultural waste and urban solid waste as a renewable energy source and (ii) ordinary and special waste (solid, semisolid and liquid) as a source of energy;
(f) obtaining, storing, selling, distributing, carrying and/or using biogas as a renewable energy source;
(g) processing raw materials from fossil fuels (natural gas, raw gasoline) to obtain basic (synthesis gas, benzene, toluene, etc.), intermediate (ammoniac, ethanol, methanol, ethyl-benzene, etc.) and final petrochemicals (fertilizers, resins, polyurethanes, detergents, PET, etc.;) and
(h) engaging in the research and development of energy technologies.
With respect to the activities described in (a), (b), (c), (d), (e), (f), (g) and h) above, and within the limitations set forth in our corporate purpose, we have full legal capacity to (i) acquire rights, assume obligations, and carry out any kind of acts that are not otherwise prohibited by the applicable laws or by our bylaws; (ii) establish, incorporate, partner with, or hold interests in legal entities of whatsoever nature incorporated in Argentina or abroad (we may do so by any available means, including but not limited to, capital contributions, purchase of shares, bonds, debentures, notes or other debt or equity securities, whether publicly or privately held); and (iii) render services and/or undertake representations, commissions, consignments, services and/or agencies for our benefit or for the benefit of third parties, always within the scope of the permitted activities under our corporate purpose as described in (a), (b), (c), (d), (e), (f), (g) and (h) above.
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Statutory Provisions concerning our Board of Directors
Our board of directors is comprised by eleven permanent directors, and an equal or lower number of alternate directors. Directors will hold office for one fiscal year and will be appointed at the shareholders’ meeting. Shareholders are entitled to elect up to one third of vacant seats on the board of directors by cumulative voting as set forth in Section 263 of the Argentine Corporate Law. The outcome of such voting will be computed per candidate, specifying the number of votes for each of them.
At the first meeting held following the shareholders’ meeting at which the members of the Board of Directors are renewed, the Board of Directors will elect a chairman and a vice-chairman from among its members. The vice-chairman will act in lieu of the chairman upon the latter’s resignation, death, incapacity, disability, removal or temporary or definitive absence, with a new chairman having to be elected within ten days from the seat becoming vacant. The election of a new chairman will take place only if the situation that gives rise to the reelection is expected to be irreversible during the remaining term of office. Pursuant to Section 23 of our bylaws, Board of Directors’ meetings will be held with the presence of an absolute majority of its members and decisions will be made by majority of present votes. Board of Directors’ meetings may also be held by videoconferencing, in which case directors participating in person and remotely will be computed in the calculation of the required quorum. Minutes of Board of Director’s meetings will be drafted and signed by directors and statutory auditors who were present at the meeting within five days from the date in which it was held. Members of our Supervisory Committee will register in the minutes the names of the directors who have participated in the meeting remotely, and that the decisions made therein were passed in accordance with the law. The minutes will include the statements from directors participating in person and remotely and will state their respective votes on each decision made. If a Board of Director’s meeting cannot be validly held because of the number of vacant seats, even with the attendance of all deputy directors of the same class, the Supervisory Committee will designate substitutes to hold office until the election of permanent members takes place, to which end an ordinary or class shareholders’ meeting will be called for, as the case may be, within ten days from the Supervisory Committee having made the designations.
There are no requirements as to the minimum number of meetings to be held by the Board of Directors.
The chairman, or the individual acting in lieu of the chairman pursuant to the law, may call for meetings when so deemed convenient, or when so required by any director or the supervisory committee. The meeting will be called for within five days from the request; otherwise, the meeting may be called for by any of the directors. The Board of Director’s meetings will be called for in writing and notice thereof must be given to the address reported by each director. The notice will indicate the date, time and place of the meeting and the meeting agenda. Business that is not included in the notice may be discussed at the meeting only to the extent all permanent directors are present and have cast their unanimous vote.
Our Board of Directors may hold meetings with the attendance of its members in person or by videoconference or other simultaneous sound, imaging or voice broadcasting media. The Board of Directors may hold meetings with the attendance of its chairman or its substitute. Our Board of Directors’ meetings will be held with the presence of an absolute majority of its members and decisions will be made by majority of present votes.
According to Section 26 of our bylaws, our Board of Directors has the broadest powers and authority in connection with the Company’s direction, organization and administration, with no limitations other than those set forth in the applicable laws and regulations. The chairman is the legal representative of the Company.
Statutory Provisions concerning our Supervisory Committee
The Company’s oversight shall be in charge of a Supervisory Committee to be comprised by three (3) permanent and three (3) alternate statutory auditors. Statutory auditors will be elected for one (1) fiscal year and will be vested with the powers set forth by Argentine Corporate Law and other applicable legal provisions.
Our Supervisory Committee holds meetings and adopts decisions with the presence and favorable vote of, at least, two of its members, notwithstanding the rights granted by law to the dissenting statutory auditor. Meetings of our Supervisory Committee may be called for by any of its members. Prior to the registration of the amendments to the bylaws of June 3, 2015, meetings of our Supervisory Committee were held with the attendance of all of its members, and decisions were adopted by majority of votes, notwithstanding the rights granted by law to the dissenting statutory auditor.
Members of our Supervisory Committee are also authorized to attend Board of Director’s and shareholders’ meetings, call for extraordinary shareholders’ meetings and investigate written claims brought by shareholders who own more than two percent (2%) of our outstanding shares. In accordance with the applicable laws, members of the Supervisory Committee are required to be certified public accountants or lawyers. Members of our Supervisory Committee may call for an ordinary shareholders’ meeting, in the specific cases provided by law, at any time at their discretion, or otherwise when so required by shareholders representing no less than five percent (5%) of our capital stock.
Members of our Supervisory Committee are designated at the annual ordinary shareholders’ meeting and will remain in office for one (1) year. Pursuant to Section 294 of the Argentine Corporate Law, our Supervisory Committee is required to review our books and records, when deemed convenient and, at least, on a quarterly basis.
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Our Supervisory Committee will hold meetings at least once a month; meetings may be also called for at the request of any of its members, within five (5) days from the date the request is submitted to the Chairman of the Supervisory Committee or the Board of Directors, as the case may be. Notice of all meetings shall be given in writing to the address indicated by each Statutory Auditor at the time of holding office.
Our Supervisory Committee shall be presided over by one of its members, elected by majority of votes, at the first meeting held every year. At that time, the member who will act in lieu of the chairman in his/her absence will also be elected. The chairman represents our Supervisory Committee before the Board of Directors.
Rights, Preferences and Restrictions attached to our Shares
According to our bylaws, realized and liquid profits will be allocated in the following order: (i) 5% to the legal reserve until reaching at least 20% of our subscribed capital; (ii) Directors’ fees, within the amounts set forth by Section 261 of the Argentine Corporate Law, which may not be exceeded, and Statutory Auditors’ fees; (iii) payment of dividends in connection with the employee stock ownership plan; (iv) optional reserves and provisions, at the discretion of the shareholders’ meeting; and (v) the remaining balance shall be distributed as dividends among shareholders, regardless of their class.
Shareholders’ Meetings
Shareholders’ meetings will be called for by publishing notices in the Official Gazette and in one of Argentina’s major newspapers for five (5) days, no less than twenty (20) and no more than forty five (45) days in advance of the scheduled date for the meeting. The notice will include the type of meeting, as well as the date, time and place where it will be held and the agenda. Ordinary and extraordinary shareholders’ meetings are subject to the quorum and majorities required by Section 79 of the Capital Market Law and Sections 243 and 244 of the Argentine Corporate Law.
Shareholders’ Liability
In conformity with Argentine law, shareholders’ liability for a company’s losses is limited to the payment of their subscribed equity holdings. However, shareholders who voted for a decision that was then rendered null by a court for its being inconsistent with the Argentine laws or the corporate bylaws (or operating agreement, if any) might be held personally and jointly and severally liable for the damages that may arise from such decision.
Conflicts of Interest
Under the Argentine laws, if a shareholder casts a vote in connection with a matter in which it may have, directly or indirectly, interests that are contrary to ours, such shareholder will be liable for damages, but only to the extent such matter had not been approved but for the vote of such shareholder. The Argentine laws also set forth that if a member of our Board of Directors has interests in a business operation that are contrary to our interests, such director will report so to the Board of Directors and the Supervisory Committee and will refrain from engaging in the discussion of that issue. If that director acts in a manner that is contrary to the law, it will be held personally and jointly and severally liable for the damages that may arise from such director’s acts or omissions.
Preemptive and Accretion Rights
Pursuant to Section 194 of the Argentine Corporate Law, upon a potential capital increase, each holder of common shares will be entitled to preemptive rights in respect of the newly issued common shares on a proportional basis to the number of shares already held. Preemptive rights can be exercised beginning on the last notice posted in the Official Gazette and in a major Argentine newspaper thirty (30) days; provided, however, that such 30-day period may be reduced to no less than ten (10) days, if so approved at an extraordinary shareholders’ meeting.
Liquidation
Pursuant to our bylaws, liquidation will be carried out by our Board of Directors or the liquidators appointed at the shareholders’ meeting, under the oversight of the Supervisory Committee.
Once liabilities have been settled, including the expenses incurred in the liquidation, the remaining balance will be distributed among shareholders on a proportional basis to their respective holdings, without regard to classes or categories.
Neither Argentine law, our bylaws nor other corporate documents provide limitations as to share ownership that might apply to us.
Term
According to our bylaws, our company was created for a term of ninety-nine (99) years since the registration date with the Public Registry of Commerce. Such term may be extended by a decision made at an extraordinary shareholders’ meeting.
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Mandatory Tender Offer Regime
We are subject to the mandatory tender offer rules set forth in Argentine Capital Markets Law, which provide that in certain circumstances a mandatory tender offer (“OPA”) must be launched at an equitable price with respect to some or all of a company’s outstanding shares. Such circumstances giving rise to an OPA include instances where a person individually or through concerted action, has effectively acquired a controlling interest in a company whose shares are admitted to the public offering regime. The Argentine Capital Markets Law also provides that a person acquires a controlling interest, individually or in concert with other persons when (i) directly or indirectly reaches a percentage of voting rights equal to or greater than 50% of the company, excluding from the basis of calculation the shares that belong, directly or indirectly, to the offeree company; or (ii) has reached a shareholding of less than 50% of the voting rights of a company, but acts as a controlling shareholder (a controlling shareholder being understood as one that directly or indirectly, individually or jointly, holds a shareholding that grants it the necessary votes to form the corporate will in ordinary meetings or to elect or revoke the majority of the directors or supervisory directors).
In line with the above CNV regulations set forth that an OPA applies in case of a person effectively acquiring, individually or in concert with other persons, a controlling interest in a listed company whether:
| · | through the acquisition of shares or subscription rights or options granted by the issuing company itself on those shares, convertible securities or other similar securities which, directly or indirectly, may give the right to the subscription and/or acquisition of securities, or conversion of those shares with voting rights in that company; |
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| · | through agreements with other holders of securities that, in a concerted manner, grant the necessary votes to form the corporate will in ordinary meetings or to elect or revoke the majority of the directors or members of the supervisory committee, as well as any other agreement that, for the same purpose, regulates the exercise of voting rights in the administrative organ or to whom the latter delegates the management. The CNV regulations clarifys that (a) this assumption will be applicable when (i) the parties to the agreement have acquired the voting shares of the company, acting individually or in concert within the 12 months prior to the signing of the agreement; or (ii) when a new shareholder promotes and subscribes an agreement with others in order to establish joint control of the affected company by reason of its entry as a shareholder; and (b) this situation shall not apply when a shareholding of less than 50% is acquired in a controlling company of a listed company and there is a prior agreement to which the new shareholder adheres, occupying the position held by the selling shareholder, without any change in the controlling company's shareholding in the target company; or |
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| · | in an indirect or supervening manner, including the cases of mergers or other corporate reorganizations. |
In accordance with the above, CNV regulations further provide that once the controlling interest is reached such situation must be immediately disclosed to the market by the affected company.
| · | The Argentine Capital Markets Law provides that the OPA procedure must be carried out after the takeover and the the deadline for submitting the tender offer documents is one month from the moment the controlling interest is reached. Accordingly the OPA must be made within 90 calendar days from the date it becomes mandatory |
Determination of the OPA Price
For an OPA in the case of a change in control, the Argentine Capital Markets Law and CNV regulations establish that the "equitable price" to be offered will be determined as the higher of the following:
| a) | the highest price that the offeror has paid or agreed for the marketable securities subject to the offer during the 12 months prior to the date of the agreement or payment that allowed reaching the controlling interest, without considering acquisitions of not significant volumes ─5 % or less of the total trading volume on the trading floor of the day of arrangement─, made at the quoted price, and including any other additional consideration paid or agreed in relation to such securities. For this assumption, the CNV regulations clarify that, in case the final price is increased by subsequent adjustments, the offered price must be recalculated and adjusted if it yields a higher value. When such adjustment occurs after the end of the offer period, the difference must be paid to those who accepted the offer within 10 calendar days from the effective payment of the increase and the average price of the marketable securities must be adjusted. |
| b) | the average price of the marketable securities subject to the offer during the six-month period immediately prior to the date on which the offeror is obliged to publish the announcement of the OPA by which the change in the controlling interest is agreed. This last guideline will not apply when the percentage of shares listed in a market authorized by the CNV represents at least 25% of the issuer's capital stock and the liquidity conditions set forth in CNV regulations are met. |
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In the event of a public offer for residual shareholdings due to near total control or withdrawal of the public offer, the Argentine Capital Markets Law establishes that the following price criteria must be considered:
| a) | the highest price that the offeror has paid or agreed to pay for the marketable securities subject to the offer during the 12 months prior to the intimation of the minority shareholder or the unilateral declaration of acquisition in the cases of companies subject to near-total control or since the agreement to withdraw the public offer; |
| b) | the average price of the marketable securities subject to the offer during the six-month period immediately preceding the intimation of the minority shareholder or the unilateral declaration of acquisition in the case of companies subject to near-total control or since the agreement to withdraw the public offer; |
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| c) | the equity value of the shares, considering a special delisting balance sheet, as the case may be; |
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| d) | the value of the company valued according to discounted cash flow criteria and/or indicators applicable to comparable companies or businesses; and |
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| e) | the liquidation value of the company. |
In these cases, the "equitable price" offered may not be lower than the highest of those indicated in points (a) and (b) of this paragraph.
The CNV has a period of 20 business days to decide on the request for authorization of the OPA and to object to the price offered. This period will be counted from the date all the documentation is gathered and no new observations and requests for information are made. The refusal of authorization and/or objection to the offered price by the CNV may be challenged by the offeror by means of a direct appeal before the Federal Courts of Appeals with jurisdiction over commercial matters within 30 business days of notification of the refusal. Minority shareholders may also object to the price from the date of the announcement of the offer or the filing of the withdrawal request and until the CNV's objection period described above.
The offeror must publish the OPA prospectus within 5 calendar days after the CNV's formal approval of the tender offer. The period granted to investors to accept or not the offer will be set between a minimum of 10 business days and a maximum of 20 business days. In addition, the offeror may grant an additional term of not less than 5 business days to the general closing date of the offer.
Penalties for Breach
The Argentine Capital Markets Law provides that purchases in violation of such regime will be declared irregular and ineffective for administrative purposes by the CNV and cause the auction of the shares acquired in violation of the applicable regulation, without prejudice to the penalties that may correspond under CNV regulations, such as restriction in the use of political rights derived from its shares in the company.
Tender Offer Regime in the Case of a Voluntary Withdrawal from the Public Offering and Listing System in Argentina
Argentine Capital Markets Law and CNV regulations also established that when a company whose shares are publicly offered and listed in Argentina agrees to withdraw voluntarily from the public offering and listing system in Argentina, it must follow the procedures provided for in the CNV’s regulations and it must likewise launch an OPA for its aggregate shares or subscription rights or securities convertible into shares of stock options under the terms provided for in such regulation. It is not necessary to extend the public offering to those shareholders that voted for the withdrawal at the shareholders’ meeting.
The acquisition of one’s own shares must be made with liquid and realized profits or with free reserves, whenever paid up in full, and for the amortization or disposition thereof, within the term set forth in Section 221 of the Argentine Corporate Law and the company must present the CNV with evidence that it has the necessary solvency to effect such purchase and that the payment for the shares will not affect its solvency.
According to Section 98 of Argentine Capital Markets Law the price offered in the case of a voluntary withdrawal from the public offering and listing system in Argentina should be “equitable value” as described above and take into account the relevant criteria of Section 88 of Argentine Capital Markets Law.
Mandatory or Voluntary Tender Offer in the Case of Near-total Control
When a publicly traded Argentine company becomes subject to near-total control any minority shareholder may, at any time, request the controlling person to make a tender offer to all the minority shareholders at an “equitable price” under the terms of Section 88 of this Argentine Capital Markets Law for near-total control scenarios. In addition, within six (6) months from the date on which the company has come under the near-total control of another person, the latter may issue a unilateral declaration of willingness to acquire all the remaining capital stock held by third parties.
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For the purposes of the above, “near-total control” shall mean a shareholder (or group of shareholders) becomes holder, directly or indirectly, of 95% or more of the outstanding capital stock of a publicly traded Argentine company, and “minority shareholder” shall mean the holders of shares of any kind or class, as well as the holders of all other securities convertible into shares other than those of the controlling person(s). For voluntary offers the price offered may be set by the offeror at its discretion, but the guidelines and criteria applied for its determination must be disclosed and, in such case, the valuation report(s) taken into account must be published. The CNV shall not issue an opinion in relation to the offered price, but shall only formally approve the offer if it complies with the requirements established by CNV regulations.
Item 10.C Material contracts
For information concerning our material contracts, see “Item 4. Information on the Company,” “Item 7.B. Related Party Transactions” and “Item 5. B. Liquidity and Capital Resources.”
Item 10.D Exchange Controls
On September 1, 2019, after the market disruptions caused by the results of the primary elections, with the purpose of strengthening the normal functioning of the economy, fostering a prudent administration of the exchange market, reducing the volatility of financial variables and containing the impact of the variations of financial flows on the real economy, the Argentine government issued Decree No. 609/2019 whereby foreign exchange controls were temporarily reinstated. The decree: (i) reinstated, originally until December 31, 2019, the exporters’ obligation to repatriate the proceeds from exports of goods and services in the terms and conditions set forth by the Central Bank’s implementing regulations and settle for Pesos through the FX Market; and (ii) authorized the Central Bank to (a) regulate access to the FX Market for the purchase of foreign currency and outward remittances; and (b) set forth regulations to avoid practices and transactions aimed to circumvent, through the use of securities and other instruments, the measures adopted through the decree. On the same date, the Central Bank issued Communication “A” 6770, which was subsequently amended and supplemented by further Central Bank communications.
At present, foreign exchange regulations have been consolidated in a single regulation, Communication “A” 7490, as subsequently amended and supplemented from time to time by Central Bank’s communications (the “FX Regulations”). Below is a description of the main exchange control measures implemented by the FX Regulations:
Specific provisions for inward remittances
Repatriation and settlement of the proceeds of exports of goods.
In accordance with section 7.1 of the FX Regulations, exporters must repatriate, and settle in Argentine Pesos through the FX Market, the proceeds of their exports of goods cleared through customs as from September 2, 2019. Notwithstanding the maximum terms established in section 7 of the FX Regulations, export proceeds must be entered and settled through in the FX Market within 5 business days following payment thereof.
Exporters who carried out operations with related counterparties (the importer is a company controlled by the Argentine exporter) may request their respective monitoring entities to extend the entry period: (A) up to 120 calendar days in cases where exports of more than US$ 50,000,000 have been registered and the goods correspond to the positions detailed in said standard (mainly related to the meat industry); and (B) up to 180 calendar days when exports of more than US$ 50,000,000 have not been registered by the exporter in the immediate previous calendar year.
Exceptionally, exports made under the “Exporta Simple” special regime must be entered and settled through the FX Market within 365 days as of the date of the issuance of the certificate of shipping, regardless of the type of goods exported.
Any foreign currency amounts derived from insurance claims, to the extent that they cover the value of the exported goods, are subject to the obligation to repatriate and convert said amounts into pesos by means of settlement in the FX Market within the applicable term for the underlying export.
According to section 7.5.5. of the FX Regulations, when upon expiration of the term for the repatriation and settlement requirement it has not been made for reasons beyond the exporter’s control, the monitoring entity may extend the term up to 120 calendar days as from the date of the date of the issuance of the certificate of shipping stated in the provisional shipment permit. For this purpose, the monitoring entity shall verify compliance with the following conditions: (i) the exporter has registered charges by the admitted concepts for at least 85% of the value of the provisional shipping permit, and (ii) the exporter has submitted an affidavit stating the reasons beyond its control for which it has not been possible to determine the definitive price of the goods included in the export operation.
Moreover, through section 8 of the FX Regulations, the Argentine Central Bank reinstated the export proceeds monitoring system, setting forth rules governing such monitoring process and exceptions thereof. Exporters will need to appoint a financial entity in charge of monitoring compliance with the aforementioned obligations.
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Export advances, and pre-export and export financings
Export advances, pre-financing and post-financing of exports from abroad must be repatriated and settled in the FX Market within 5 business days following payment thereof. Likewise, pre-financing, post-financing and financing to foreign importers granted by local financial institutions must be settled through the FX Market at the payment.
Section 7.5.2. of the FX Regulations provides that when the amount pending payment of the transactions has been prefinanced in full and the funds settled through the FX Market as prefinancing of local and/or foreign exports, the term for the settlement of foreign currency of the shipment may be extended until the maturity date of the corresponding financing.
On the other hand, in case the exporter proves to have settled in the exchange market the amount received under post-financing of exports covering the totality of the amount pending repatriation of the permit, and as long as no restriction for the issuance of the use of proceeds certification is met, the term for the foreign currency settlement of the shipment may be extended until the maturity date of the longer term credit discounted and/or assigned by the exporter. This shall also apply when the exporter has partially prefinanced the operation and proves to have settled through the FX Market, prior to maturity, post-financing of exports covering the rest of the amount pending repatriation
Use of exports proceeds
FX Regulations authorize the use of export proceeds to the repayment of: (i) pre-export financings and export financings granted or guaranteed by local financial entities; (ii) foreign pre-export financings and export advances settled in the FX Market, provided that the relevant transactions were entered into through public deeds or public registries; (iii) financial indebtedness under contracts executed prior to August 31, 2019 providing for cancellation thereof through the application abroad of export proceeds; (iv) financings granted by local financial entities to foreign importers; (v) foreign financial indebtedness and debt securities denominated in foreign currency publicly registered in Argentina, as admitted by Sections 7.9. or 7.10 of the FX Regulations; and (vi) foreign direct investment, as admitted by Sections 7.9. or 7.10 of the FX Regulations. All other uses of export proceeds shall be subject to Argentine Central Bank prior approval.
FX Regulations authorize the use of export proceeds if the following requirements are complied with:
(a) Payment of principal and interest services on foreign financial indebtedness whose funds have been repatriated and settled through the FX Market as from October 2, 2020 and destined to the financing of projects that meet the conditions set forth in Section 7.9.1.1. of the FX Regulations, to the extent that their average life is not less than 1 (one) year, considering the payments of principal and interest services.
(b) Repatriation of direct investments of non-residents in companies that are not controlling companies of local financial entities whose funds have been repatriated and settled through the FX Market as from October 2, 2020, and destined to the financing of projects that meet the conditions set forth in Section 7.9.1.2. of the FX Regulations, to the extent that the repatriation takes place after the date of completion and implementation of the investment project and, at least, 1 (one) year after the capital contribution was deposited in the exchange market.
(c) Payment of principal and interest services of debt securities issuances with public registration in Argentina denominated in foreign currency that comply with the conditions set forth in Section 3.6.1.3. of the FX Regulations, whose funds have been settled through the FX Market as from October 16, 2020 and destined to the financing of projects that comply with the conditions set forth in Section 7.9.2. of FX Regulations, to the extent that their average life is not less than 1 (one) year considering the maturities of capital and interest.
(d) Payment of principal and interest services on issuances of debt securities with public registration in Argentina, denominated in foreign currency and whose services are payable in foreign currency in the country or issuances of debt securities with public registration abroad, made as from October 9, 2020, with an average life of not less than 2 (two) years and whose delivery to creditors has allowed reaching the refinancing parameters set forth in Section 3.17 of the FX Regulations.
(e) Payment of principal and interest services of foreign financial indebtedness whose funds have been repatriated and settled through the FX Market as from October 16, 2020 and have allowed reaching the refinancing parameters set forth in Section 3.17 of FX Regulations.
(f) Payment of principal and interest services of debt securities issuances with public registry in Argentina denominated in foreign currency that comply with the conditions set forth in Section 3.6.1.3. of the FX Regulations whose funds have been settled through the FX Market as from October 16, 2020 and have allowed reaching the refinancing parameters set forth in Section 3.17 of the FX Regulations.
(g) Payment of principal and interest services on issuances of debt securities with public registration in Argentina denominated in foreign currency and whose services are payable in foreign currency in Argentina or issuances of debt securities with public registration abroad, arranged between January 7, 2021 and March 31, 2021, made within the framework of debt securities exchange transactions or refinancing of interest services and/or capital amortization of foreign financial indebtedness with maturity until December 31, 2022 for transactions whose final maturity was after March 31, 2021, to the extent that considering the whole transaction the average life of the new debt implies an increase of no less than 18 months with respect to the refinanced maturities.
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The transactions detailed in a), b) and c) above will be eligible to the extent that the settled funds are used to finance investment projects in the country that generate: (i) an increase in the production of goods that, for the most part, will be placed in foreign markets and/or that will allow the substitution of imports of goods. The preceding condition will be deemed to be met when it is reasonably demonstrated that at least two thirds of the increase in the production of goods as a result of the project will be destined for foreign markets and/or the substitution of imports within three (3) years following the completion of the project, with a positive effect on the exchange balance of goods and services, and/or (ii) an increase in the transportation capacity of exports of goods and services with the construction of infrastructure works in ports, airports and land terminals for international transport.
The amount by which importers can access the FX Market for payment of imports of goods by accessing the FX Market until June 30, 2022, will be increased by the equivalent of 50% of the amounts that the importer settles through the FX Market as export advances or pre-financing of exports from abroad with a minimum term of 180 days, as of October 2, 2020. Access for the remaining 50% will also be admitted to the extent that the additional part corresponds to payments for imports of capital goods and/or goods that qualify as necessary inputs for the production of exportable goods. In the latter case, the entity must have an affidavit from the client regarding the type of good involved and its status as an input in the production of goods to be exported.
Payment of export advances or other export financings without the use of export proceeds
As a general rule, these operations must be paid with funds from the payment of goods exports, unless the client can demonstrate that it cannot do so for reasons beyond its control, in which case access to the FX Market to pay export advances or other foreign financing of exports without the settlement of foreign currency from exports of goods payments will be governed by the rules for the payment of principal services of financial indebtedness.
Local collections for exports of on-board supplies to foreign flagged means of transport (regimen de ranchos)
On February 5, 2021, the Argentine Central Bank issued Communication “A” 7217, incorporated to the FX Regulations in Section 8.5.18 establishing that, regarding local collections for exports of on-board (regimen de ranchos) supplies to foreign flagged means of transport, it shall be considered that the follow-up of the shipment permit is totally or partially complied with, for an amount equivalent to the amount paid locally in Pesos and/or in foreign currency to the exporter by a local agent that owns the foreign flagged means of transport, as long as the following conditions are met:
A) The documentation allows to verify that the delivery of the exported merchandise has taken place in the country, that the local agent of the company that owns the foreign flagged means of transport made the payment to the exporter locally and in which currency the payment was made.
B) An entity shall issue a certification stating that the company that owns the foreign flagged means of transport would have had access to the FX Market pursuant to Section 3.2.2. of the FX Regulations for the equivalent amount in foreign currency which is intended to be computed to the shipment permit.
The entity which states the precedent shall previously verify compliance with all the other requirements stablished in Section 3.2.2. of the FX Regulations except for provisions of Section 3.16.13. and the local agent of the company that owns the foreign flagged means of transport shall have filed an affidavit stating that it has not transferred or will transfer funds abroad for the proportional amount of the operations included in the certification.
C) In the event that the funds have been received in the country in foreign currency, a certification that the settlement of the funds through the FX Market has been made is needed.
The local agent of the company that owns the foreign flagged means of transport shall not have used this mechanism for an amount greater than US$250,000 in the calendar month.
Repatriation and settlement of the proceeds of exports of services
Section 2.2 of the FX Regulations imposes to exporters the obligation to repatriate and settle in the FX Market, the proceeds from exports of services within 5 business days following payment thereof.
In case funds received or credited abroad, the repatriation and settlement requirement for the amount equivalent to the usual expenses debited by foreign financial entities for the transfer of funds to Argentina may be considered complied with.
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In case said collections are entered through the local currency system, the settlement requirement shall be considered complied with for the amount credited in local currency in the exporter’s account. In the case of services rendered to Paraguayan residents invoiced in guaraníes, the equivalent in such currency of the amount credited shall be computed.
FX Regulations allows the use of export of services proceeds to cancel principal and interest services of foreign financial indebtedness or debt securities denominated in foreign currency publicly registered in Argentina and whose services are payable in foreign currency in Argentina or to the repatriation of foreign direct investments, to the extent that the requirements set forth in section 7.9 of the FX Regulations are complied with.
Likewise, to the extent that the requirements set forth in sections 3.11.3 and 7.9.5. of the FX Regulations are complied with, FX Regulations allows for proceeds from exports of goods and services held in local or foreign financial institutions to guarantee payment of new indebtedness entered into. Funds in these accounts shall not exceed at any time 125% of the principal and interest to be paid in the current month and the following six calendar months, in accordance with the scheduled of payments as agreed upon with the creditors. Funds exceeding such amount must be repatriated and settled through the FX Market subject to the applicable foreign exchange rules.
Sale of non-financial non-produced assets
Pursuant to section 2.3 of the FX Regulations, the proceeds in foreign currency of the sale of non-financial non-produced assets must be repatriated and settled in Pesos in the FX Market within 5 business days following either the perception of funds in the country or abroad, or their accreditation in foreign accounts.
In the case of proceeds received or credited abroad, the repatriation and settlement may be considered fulfill for the amount equivalent to the usual expenses debited by the financial entities abroad for the transfer of funds to Argentina
Foreign financial indebtedness
Section 2.4 of the FX Regulations have reinstated the requirement to repatriate and settle in Argentine Pesos through the FX Market the proceeds of new financial indebtedness disbursed from and after September 1, 2019 as a condition for accessing the FX Market to make debt service payments thereunder. Although the regulations do not establish a specific term for repatriation, this requirement shall be met any time prior to accessing the FX Market. The reporting of the debt under the External Assets and Liabilities Reporting Regime is also a condition to accessing the FX Market to repay debt service.
Subject to compliance with the aforementioned obligations, access to the FX Market is granted for the prepayment of debt services at maturity or up to 3 business days in advance. In addition, as set forth by section 3.5 of the FX Regulations, access to the FX Market for prepayments will be granted, provided all of the following conditions are met: (i) the prepayment is simultaneous with the conversion of the new financial indebtedness to Pesos disbursed as from October 17, 2019; (ii) the new indebtedness has a higher average life than the outstanding of the current debt being prepaid; and (iii) the first principal payment under the new indebtedness is (a) at a later date and (b) for an amount not greater than, the scheduled principal payment under the existing debt being prepaid.
Moreover, section 3.11 of the FX Regulations authorizes (1) local borrowers under (A) foreign financial indebtedness with non-related creditors and (B) foreign indebtedness to finance the import of goods granted by foreign financial entities or official credit agencies, and (2) Argentine security trusts created to guarantee indebtedness detailed in (1)(A) and (1)(B) above, to access the FX Market to purchase foreign currency to constitute the guarantees for the amounts required under the relevant loan agreements, subject to compliance with the following conditions: (a) the relevant indebtedness grants the relevant borrower access to the FX Market for repayment and the agreements provide for debt service guarantee accounts; (b) the funds are transferred to accounts opened in local financial entities; credit into offshore accounts shall only be admitted if that is the only alternative set forth under the financing documents provided that such financing documents were entered into before August 31, 2019; (c) the amount accumulated in guarantee accounts does not exceed the amount of the next debt service payment; (d) the daily purchases do not exceed 20% of the maximum amount mentioned in (c); and (e) the bank must review the financing documents and confirm that the aforementioned conditions are met. Any funds not applied to cancel debt services must be settled through in Pesos in the FX Market within 5 business days from the corresponding debt service payment date.
Payments of local debt securities denominated in foreign currency among residents
In accordance with section 3.6 of the FX Regulations, access to the FX Market for the payment of foreign currency denominated obligations between Argentine residents executed from September 1, 2019 is subject to prior approval from the Argentine Central Bank. With regard to existing transactions as of such date, access is authorized; provided that the relevant transactions were entered into through public deeds or public registries. These prohibitions do not apply to loans in foreign currency granted by local financial entities, including payments of credit cards.
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Additionally, section 3.3 of the FX Regulations states that the Central Bank’s prior approval will be required to access the FX Market for the repayment of debts for imports of goods and services
Exceptions to the repatriation and settlement requirement
Although the FX Regulations maintain the obligation to repatriate export proceeds to Argentina through the FX Market, in accordance with section 2.6, exporters are authorized to avoid the settlement in Argentine Pesos to the extent that: (a) the funds are credited to foreign-denominated accounts in the name of the exporter, opened at local banks; (b) the funds are brought to Argentina within the applicable period established; (c) the funds are simultaneously applied to conduct payments for which the regulations grant access to the FX Market, subject to any applicable caps; (d) if the funds correspond to the proceeds of new external financial indebtedness and are applied to the prepayment of foreign currency-denominated loans with local banks, the new indebtedness must have a longer average life than the local indebtedness, and (e) the mechanism is tax-neutral
Specific provisions regarding access to the FX Market
In the case of certain outflows made through the FX Market (i.e., payments of imports and other purchases of goods abroad; payment of services rendered by non-residents; remittances of profits and dividends; payment of principal of and interest on external indebtedness; payments of interest on debts for the import of goods and services; payments of indebtedness in foreign currency owed by residents made through trusts organized in Argentina to secure the provision of services; payments under foreign currency-denominated debt securities publicly registered in Argentina and liabilities in foreign currency owed by residents; purchases of foreign currency by resident individuals for the purpose of forming external assets, providing family assistance and entering into derivative transactions (other than those made by individuals on account of the formation of external assets), purchase of foreign currency by individuals to be simultaneously used to purchase real estate in Argentina with a mortgage loan; purchase of foreign currency by other residents (excluding financial institutions) to form external assets and in connection with derivative transactions; other purchases of foreign currency by residents for specific uses and under interest rate hedge agreements in connection with liabilities incurred by residents that have been reported and validated under the External Assets and Liabilities Reporting Regime), the financial institution shall obtain the Argentine Central Bank’s prior approval before processing the transaction, unless it has obtained an affidavit executed by the legal entity or individual stating that, at the moment of accessing the local exchange market:
a) Holding foreign currency in Argentina and non-holding of available external liquid assets. The customer shall certify that all foreign currency in Argentina is available in accounts with financial institutions and that the customer had no external liquid assets available at the beginning of the day when access to the market was requested in an amount higher than the equivalent to US$ 100,000.
FX Regulations provides a merely illustrative list of liquid external assets including, among others, holdings of foreign currency bills and coins, holdings of coined gold or gold bars for good delivery, demand deposits with financial institutions abroad and other investments that allow for immediate availability of foreign currency including, for example, investments in external government securities, funds held in investment accounts with investment managers abroad, crypto-currency, funds in payment service providers’ accounts, etc.
Available liquid external assets are not understood to include those funds deposited abroad that may not be used by the legal entity or individual as they are reserve or security funds set up in compliance with the requirements under borrowing agreements abroad or funds set up as collateral under derivative transactions consummated abroad.
If the legal entity or individual had liquid external assets available in an amount higher than the sum specified in the first paragraph, the financial institution may also accept an affidavit provided it is satisfied that such amount shall not be exceeded on the grounds that, either partially or totally, such assets:
| i. | were used during such day to make payments that would have required access to the local exchange market; |
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| ii. | were transferred to the legal entity or individual to a correspondent account of a local institution licensed to deal in foreign exchange; |
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| iii. | are funds deposited in bank accounts abroad from collections of exports of goods and/or services or advances, pre- or post-export financing of goods by non-residents, or from the disposal of non-financial non-produced assets in respect of which the term of 5 business days after collection has not yet expired; or |
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| iv. | are funds deposited in bank accounts abroad from financial indebtedness abroad and the amount thereof does not exceed the equivalent amount payable as principal and interest within the next 120 calendar days. |
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The affidavit filed by legal entities or individuals shall expressly indicate the value of their liquid external assets available as of the beginning of the day as well as the amounts allocated to each of the situations described in paragraphs i) through iv), as applicable.
b) New inflows and settlement of foreign currency from collections of loans granted to third parties and time deposits or sales of any asset, provided same were purchased and granted after May 28, 2020. Customers’ affidavits shall include a commitment to settle in the FX Market, within a term of five business days upon being made available, those funds received from abroad from the collection of loans granted to third parties, the collection of a time deposit or the sale of any asset, provided the asset had been purchased, the time deposit had been made or the loan had been granted after May 28, 2020.
The filing of this affidavits shall not be required for outflows through the FX Market in the following cases: (1) client transactions made in the framework of sections 3.8, 3.13 and 3.14.1 to 3.14.5 of the FX Regulations; (2) the exchange institution’s own transactions, acting as customer; (3) payment of financing in foreign currency granted by local financial institutions in connection with purchases in foreign currency using credit or shopping cards; and (4) payments abroad by credit card companies that are not financial institution in connection with the use of credit, shopping, debit or pre-paid cards issued in Argentina.
c) Affidavit regarding securities transactions. On the date of the access to the FX Markat, the client shall sign an affidavit, stating: (i) not to have carried out any blue chip swap transaction, exchanged securities for other external assets, or transferred securities to a foreign broker for the prior 90-calendar day period; (ii) undertaking the obligation not to carry out any blue chip swap transactions, exchange securities for other external assets, or transfer securities to a foreign brokerage house for a 90-calendar day period; (iii) stating the detail of the human or legal entities that exercise a direct control over the company, as described in Section 1.2.2.1 of the rules of "Large exposures to credit risk"; and (iv) that on the day on which access to the FX Market is required and in the previous 90-calendar days, the company has not delivered funds in local currency or other liquid local assets to any human or legal person exercising a direct control in the country on it, except those directly associated with normal operations for the acquisition of goods and / or services.
Also, Section 13.6.6 of the FX Regulations established that, prior to allowing any outflow of funds abroad, financial institutions are required to check the online system implemented by the Argentine Central Bank to verify if the customer that intends to access the FX Market is included in the list of CUITs (Tax Identification Numbers) showing inconsistent foreign exchange transactions.
Foreign financial indebtedness
Section 3.17 of FX Regulations establishes that those who have principal maturities between October 15, 2020, and June 31, 2022, in order to access the FX Market, they shall file within the Argentine Central Bank a refinancing plan for the following transactions: (a) foreign financial indebtedness of the non-financial private sector with a creditor that is not a related counterparty of the debtor; (b) foreign financial indebtedness regarding own operations of the entities, or (c) issuances of debt securities publicly registered in Argentina denominated in foreign currency of private sector clients or of the entities themselves. The refinancing plan shall follow this criteria: (a) the net amount for which the access to the FX Market will not exceed 40% of the principal amount maturing, and (b) the remaining principal has been, at least, refinanced with new foreign indebtedness with an average life of 2 years.
In addition to the refinancing granted by the original creditor, the refinancing scheme will be deemed completed when the debtor accesses the FX Market to pay off principal for an amount greater than 40% of the principal amount that was due, to the extent that the debtor settles through the FX Market as from October 9, 2020 an amount equal to or greater than the excess over 40%, in respect of: (i) issuances of debt securities public registered abroad or other foreign financial indebtedness; (ii) issuances of debt securities publicly registered in Argentina denominated in foreign currency that meet the conditions set forth in section 3.6.1.3 of the FX Regulations.
However, the foregoing shall not apply when: (i) the indebtedness are granted by international organizations or their associated agencies or guaranteed by them; (ii) the indebtedness are granted by official credit agencies or guaranteed by them; (iii) the indebtedness originated as from January 1, 2020, and whose funds have been repatriated and settled through the FX Market; (iv) the indebtedness originated on or after January 1, 2020, and constitutes refinancing of principal maturities subsequent to that date, to the extent that the refinancing has made it possible to reach the parameters set forth in section 3.17.3 of the FX Regulations; (v) the remaining portion of maturities already refinanced to the extent that the refinancing has allowed reaching the parameters set forth in section 3.17.3 of the FX Regulations; and (vi) the debtor that will access the FX Market for the cancellation of the principal does not exceed the equivalent of US$2,000,000 (two million U.S. dollars) in the calendar month and in the group of entities.
Section 3.16.4 of the FX Regulations establishes that financial entities will be required to obtain the prior consent of the Central Bank to provide their clients with access to the FX Market for payments, with regards to payment operations included in Sections 3.1. to 3.11. and 4.4.2. of the FX Regulations (including those that are specified through exchanges or arbitrations), to individuals or entities included by the AFIP in the database of “false” invoices or equivalent documents established by such Agency. This requirement will not be applicable to access the FX Market for the payment of financing in foreign currency granted by local financial entities, including payments in foreign currency made through credit or purchase cards.
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Payments of principal and interest of foreign financial indebtedness
Section 3.5 of the FX Regulations allows the access to the FX Market for the payment of principal and interest on financial indebtedness, establishing as requirements:
a) The debtor proves the repatriation and settlement of foreign currency in the FX Market for an amount equivalent to the nominal value of the foreign financial indebtedness, which shall be considered fulfilled in the following cases:
| (i) | The funds disbursed as from September 1, 2019, have been repatriated and settled in the FX Market. Such requirement shall not apply in the case of indebtedness abroad originating on or after September 1, 2019, which do not generate disbursements because they are refinancings of foreign financial indebtedness that have had access to the FX Market and to the extent that such refinancings do no anticipate the maturity of the original debt; |
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| (ii) | for the amount of the applicable granting and/or issuance expenses and other expenses debited abroad for the banking operations involved; |
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| (iii) | for the difference between the effective issue value and the nominal value in issues of debt securities with foreign public registration placed under par; |
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| (iv) | for the portion corresponding to a capitalization of interest provided for in the debt contract; |
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| (v) | for the portion of the issues of debt securities with foreign public registration made as from October 9, 2020, with an average life of not less than 2 (two) years that were delivered to creditors of foreign financial indebtedness and/or debt securities with local public registration denominated in foreign currency with maturities between October 15, 2020 and June 30, 2022, which have allowed reaching the refinancing parameters set forth in Section 3.17 of the FX Regulations; |
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| (vi) | for the portion of the issuances of debt securities with foreign public registration made on or after January 7, 2021 that were delivered to creditors to refinance pre-existing financial indebtedness with an average life extension, when applicable to the principal amount refinanced, the interest accrued up to the refinancing date and, to the extent that the new debt securities have no principal maturities during the first 2 years, the amount equivalent to the interest that would accrue during the first 2 years for the indebtedness that is refinanced early and/or for the deferral of the refinanced principal and/or for the interest that would accrue on the amounts so refinanced; |
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| (vii) | for the portion subscribed with foreign currency in the country of issues of debt securities with foreign public registration made as from February 5, 2021, to the extent that all of the following conditions are met: (i) that the debtor proves to have registered exports prior to the issuance of the debt securities or that the proceeds of the placement were destined to face foreign commitments. If at least one of the two conditions is not met, the issue has the prior approval of the BCRA; (ii) the average life of the debt securities is not less than five (5) years; (iii) the first principal payment is not made before three (3) years from the issue date; (iv) the local subscription does not exceed 25% of the total subscription of the issue in question; and (v) at the access date, all the funds subscribed abroad and in the country have been settled in the FX Market. |
b) It must be demonstrated, if applicable, that the operation has been declared in the last overdue presentation of the External Assets and Liabilities Reporting Regime.
c) That access to the FX Market takes place no more than three (3) business days prior to the due date of the principal or interest to be paid. Access to the FX Market with a longer period of time will require the prior approval of the BCRA unless the debtor is in one of the following situations and all the conditions stipulated in each case are met:
| i. | Prepayment of principal and interest simultaneously with the settlement of the new foreign financial indebtedness. |
| a. | Such prepayment be made simultaneously with the settled funds of a new financial indebtedness disburse as of the date. |
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| b. | The new indebtedness has an average life greater than the remaining balance of the prepaid debt. |
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| c. | The first principal service maturity of the new debt is at a later date and in an amount not greater than the next principal service maturity of the prepaid debt. |
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| ii. | Prepayment of interest in the context of a debt security swap process: |
| a. | The prepayment takes place within the context of a swap process of debt securities issued by the client. |
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| b. | The amount paid before maturity corresponds to the interest accrued at the closing date of the swap; |
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| c. | The average life of the new debt securities is greater than the average remaining life of the exchanged security; and |
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| d. | The aggregate principal maturities of the new securities may at no time exceed the aggregate principal maturities of the exchanged security. |
| iii. | Prepayment within the framework of a refinancing process in accordance with the provisions of Section 3.17 of the FX Regulations: |
| a. | Prepayment of capital and/or interests within the framework of a refinancing process in accordance with the provisions of Section 3.17 of the FX Regulations. |
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| b. | The access to the FX Market occurs no more than 45 (forty-five) days prior to the maturity date; |
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| c. | The amount of interest paid does not exceed the amount of interest accrued on the refinanced indebtedness up to the date on which the refinancing was closed; |
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| d. | The access to the FX Market occurs no more than 45 days prior to the maturity date. |
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| e. | The accumulated amount of the principal maturities of the new indebtedness may not exceed the amount of the accumulated principal maturities of the refinanced debt. |
d. To the extent that the BCRA's prior approval requirement is in force for access to the FX Market for the cancellation at maturity of principal of non-financial private sector foreign financial indebtedness when the creditor is a counterparty related to the debtor, this requirement shall not be applicable to the extent that all of the following conditions are met:
| i. | The funds have been repatriated and settled through the FX Market as of October 2, 2020; |
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| ii. | The indebtedness has an average life of no less than 2 years. |
e. To the extent that the BCRA's prior approval requirement is in force for access to FX Market for the cancellation at maturity of principal and interest on foreign financial indebtedness, this requirement shall not apply to the extent that all of the following conditions are met:
| i. | the funds have been used to finance projects within the framework of the Plan Gas.Ar |
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| ii. | the funds have been repatriated and settled through the FX Market as from November 16, 2020; and |
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| iii. | the average life of the indebtedness is not less than 2 (two) years. |
f. Foreign financial indebtedness shall be entitled to cancel its principal and interest services as from its maturity through the application of collections of exports of goods and services, to the extent that the requirements set forth in section 7.9 of the FX Regulations are complied with.
g. Until June 30, 2022, the prior approval of the BCRA will be required for access to the FX Market for the cancellation of capital services of foreign financial indebtedness when the creditor is a counterparty related to the debtor, notwithstanding the fact that this requirement will not be applicable to local financial entities' own transactions. This requirement shall also not be applicable when the client has a "Certification of increase of exports of goods" issued within the framework of the provisions of item 3.18 of the FX Regulations.
h. In the event that the debtor has scheduled capital maturities up to June 30, 2022 for indebtedness included in this item, the provisions of item 3.17 of FX Regulations shall be complied with.
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In line with the Argentine Central Bank, the CNV issued General Resolution No. 861 to facilitate the refinancing of debt through the capital markets. In this regard, the CNV provided that whenever the issuer intends to refinance debt through an exchange offer or new issues of debt securities, in both cases in exchange for or to be paid with debt securities previously issued by the company and placed privately and/or with preexisting credits against such company, the requirement of placement through public offering will be regarded as met if the new issue is underwritten in this way by the creditors of the company whose debt securities without public offering and/or preexisting credits represent a percentage that does not exceed thirty percent (30%) of the aggregate amount actually placed, and the remaining percentage is underwritten and paid in cash or in kind by tendering debt securities originally placed through public offering, or other debt securities publicly offered and listed and/or traded on markets authorized by the CNV, issued by the same company, by persons who are domiciled in Argentina or in countries that are not included in the list of non-cooperative jurisdictions for tax purposes, listed in section 24 of the Annex to Decree No. 862/2019 or anyone that may replace it in the future. Additionally, General Resolution No. 861provided for mandatory compliance with certain conditions to consider that the public offering requirement has been met.
Section 3.19 of the FX Regulations provides:
a) those clients who register settlements of new foreign financial indebtedness and who have a certification issued by an entity that establishes their compliance with the requirements of item b are exempted from the requirement of prior conformity of the BCRA to access the FX Market until December 31, 2021, for the cancellation as from the maturity of the principal of commercial debts for the importation of goods and services in force as of June 30, 2021.
In all cases, compliance with the remaining general and specific requirements applicable under the foreign exchange regulations must be evidenced.
b) The entity by which the settlement of the funds of the new financial indebtedness has taken place may issue the certification to the extent that when it verifies the following conditions:
| i. | The new foreign financial indebtedness has an average life of not less than two years and no capital maturities are recorded at least three months after its liquidation. |
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| ii. | The certified amount must not exceed the amount repatriated and settled in the FX Market as of August 27, 2021. |
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| iii. | The entity has a sworn statement from the client stating that a) It has not used this mechanism for an amount higher than the equivalent of USD 5 million (USD 10 million as of January 3, 2022), including the requested certification, and b) the new foreign financial indebtedness is not received within items 3.5.3.1., 3.6.4.2., 3.17.3., 7.9. and 7.10 of the FX Regulations. |
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| iv. | The certification may be used within five working days of the liquidation of funds. |
Additionally, local financial entities may access the FX Market to meet their obligations with non-residents for financial guarantees granted as from October 1, 2021, as long as all of the following conditions are met:
| i. | The granting of the guarantee was a requirement for the completion of a contract for works or provision of goods and/or services that involved, directly or indirectly, the performance of exports of goods and/or services by Argentine residents. |
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| ii. | The guarantee is issued at the request of the resident that will provide the goods or services and is associated with the performance of the works contracts or provision of goods and/or services by the resident or by a non-resident company under its control that will be in charge of the execution of the contract. |
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| iii. | The counterparty of the mentioned contract is a nonresident not related to the resident that will export the goods and/or services. |
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| iv. | The beneficiary of the payment is the nonresident counterparty or a foreign financial institution that has granted guarantees for the faithful performance of works contracts or provision of goods and/or services by the exporter or a nonresident company it controls. |
| v. | The amount of the guarantee granted by the local financial institution does not exceed the value of the exports of goods and/or services to be made by the resident from the execution of the contract for works or provision of goods and/or services. |
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| vi. | The term of the guarantee does not exceed 180 calendar days from the date of shipment of local goods or completion of the provision of services related to the contract covered by the guarantee. |
(i) | foreign financial indebtedness of the non-financial private sector with a creditor who is not a counterparty related to the debtor; |
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(ii) | foreign financial indebtedness on account of transactions of the debtor and/or |
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(iii) | issuances of debt securities publicly registered in Argentina, denominated in foreign currency, of private sector customers or of the financial entities themselves, |
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Prepayment of financing denominated in foreign currency granted by local financial institutions
The Argentine Central Bank’s prior approval shall be required to access the FX Market to prepay foreign currency financing granted by local financial institutions, unless they relate to payments of credit card purchases made in foreign currency.
Payments of local debt securities denominated in foreign currency among residents
In accordance with section 3.6 of the FX Regulations, establishes the prohibition of access to the FX Market for the payment of debts and other obligations in foreign currency between residents, entered into as from September 1, 2019. However, it sets as exceptions the cancellation as from their maturity of principal and interest of:
| - | Financing in foreign currency granted by local financial entities (including payments for consumption in foreign currency through credit cards). |
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| - | Obligations in foreign currency between residents instrumented through public registries or deeds as of August 30, 2019. |
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| - | Issuances of debt securities made on or after September 1, 2019, for the purpose of refinancing foreign currency obligations between residents instrumented through public registers or deeds as of August 30, 2019, and that entail an increase in the average life of the obligations. |
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| - | Payment, at maturity, of principal and interest services under new issues of debt securities made as of November 29, 2019, with public registration in the country, denominated and payable in foreign currency in the country, to the extent that: (i) they are denominated and subscribed in foreign currency, (ii) the respective principal and interest services are payable in the country in foreign currency and (iii) the totality of the funds obtained with the issuance are settled through the foreign exchange market. |
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| - | The issues made as from October 9, 2020, of debt securities with public registration in the country, denominated in foreign currency and whose services are payable in foreign currency in the country, to the extent that their average life is not less than 2 (two) years and their delivery to creditors has allowed reaching the refinancing parameters set forth in Section 3.17 of the FX Regulations. |
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| - | The issues made as from January 7, 2021 of debt securities with public registration in the country denominated in foreign currency and whose services are payable in foreign currency in the country, to the extent that they were delivered to creditors to refinance pre-existing debts with an extension of the average life, when it corresponds to the amount of capital refinanced, interest accrued up to the refinancing date and, to the extent that the new debt securities do not mature before 2023, the amount equivalent to the interest that would accrue until December 31, 2022 on the indebtedness that is refinanced early and/or on the deferral of the refinanced principal and/or on the interest that would accrue on the amounts so refinanced. |
Payments of principal under debts with related counterparties until June 30, 2022
The Argentine Central Bank’s prior approval is required to access the FX Market to make payments abroad of principal of financial debts when the creditor is a counterparty related to the debtor. This requirement is applicable until June 30, 2022, pursuant to Section 3.5.7 of the FX Regulations. Such requirement shall not apply to the local financial institutions’ own transactions.
Section 3.5.4 of the FX Regulations establishes that, for as long as the requirement to obtain prior approval to access the FX Market to pay, at maturity, principal of foreign financial indebtedness of the non-financial private sector when the creditor is a counterparty related to the debtor continues to be in place, such requirement will not be applicable if the funds have been entered and settle through the FX Market as of October 2, 2020 and the average life of the indebtedness is not less than 2 (two) years.
Access to the FX Market for the payment of new issuances of debt securities
New duly registered issuances of foreign-denominated debt securities, issued as of January 7, 2021, intended to refinance pre-existing debt, when seeking access to the FX Market for the payment of principal and interest under such new indebtedness, shall be considered to have complied with the obligation to mandatory settle through foreign currency for an amount equivalent to the refinanced principal, the interest accrued up to the date the refinancing was settled and, to the extent that the new debt securities do not schedule principal maturities before 2023, the interest that would accrue until December 31, 2022 by the indebtedness which is refinanced in advance and/or by the deferment of the refinanced principal and/or by the interest which would accrue on the amounts so refinanced.
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Duly registered securities that are denominated and payable in foreign currency in Argentina
In accordance with section 2.5 of the FX Regulations issued by the Argentine Central Bank, resident debt issuers are granted access to the FX Market for the payment at maturity of principal and interest under new duly registered issuances of debt securities that are denominated and payable in foreign currency in Argentina, to the extent they (i) are fully subscribed in foreign currency, and (ii) the proceeds from the issuance are settled through the FX Market. However, the settlement of the proceeds from the issuance shall not be required for the future access to the FX Market for repayment of domestic issuances as provided in (ii) above, provided that certain conditions are met (i.e., the proceeds are deposited in a local foreign currency-denominated bank accounts and are simultaneously applied to transactions having access to the FX Market, and the mechanism is tax neutral, among others).
Payment of principal and interest on registered debt securities with foreign clearing
On February 4, 2021, the Argentine Central Bank issued Communication “A” 7218, which provides access to the FX Market to Argentine residents for the payment of principal and interest on notes registered with foreign clearing and central securities depository agencies issued as from February 5, 2021, which have been partially settled with foreign currency in Argentina, to the extent that all of the following conditions are met, (i) the borrower provides evidence of exports made prior to the issuance of the notes, or that the proceeds of the issuance of such notes were used for making payments abroad; provided that one of the two (2) conditions is met, access to the FX Market shall not require the prior approval of the Argentine Central Bank; (ii) the average life of the notes shall not be less than five (5) years; (iii) the first payment of principal under the notes shall not occur before three (3) years as from the issue date; (iv) the notes subscribed locally in Argentina and settled locally with foreign currency shall not exceed 25% of the aggregate amount of notes subscribed; and (v) all of the funds of the offering shall be settled through the FX Market prior to the borrower accessing the FX Market for the first time for paying interest and/or principal under the notes.
Extension of the term for outflows through the FX Market in connection with the sale of securities to be settled in foreign currency or transfers to foreign depositaries
In the case of outflows through the FX Market, including by means of swap or arbitrage transactions, in addition to the requirements that apply to each particular case, financial institutions shall request the filing of an affidavit certifying that:
a) on the day when access to the market is requested and within the prior 90 calendar days no sales of securities have been made via settlement of foreign currency or transfers thereof to foreign depositaries; and
b) the customer filing the affidavit undertakes to refrain from selling securities to be settled in foreign currency or transferring same to foreign depositaries since the day access is requested and during a term of 90 calendar days.
The filing of the affidavit shall not be required in case of outflows through the FX Market in the following circumstances: 1) Transfer of foreign currency abroad by individuals from their local accounts in foreign currency to their own bank accounts abroad, to the extent that it corresponds to the transfer abroad of funds remaining in a "Caja de ahorro para turistas" at the time of closing.; 2) client operations in accordance to sections 3.14.2 to 3.14.5 of the FX Regulations; 3) payment of financing in foreign currency granted by local financial institutions, including payments for purchases made in foreign currency using credit or shopping cards; and 43) remittances abroad in the name of individuals who are the recipients of retirement and/or pension benefits paid by ANSES.
Access to the FX Market by non-residents
In accordance with section 3.13 the FX Regulations, prior approval by the Argentine Central Bank will be required for access to the FX Market by non-residents for the purchase of foreign currency, except for the following operations: (a) international organizations and institutions that perform functions of official export credit agencies, (b) diplomatic representations and consular and diplomatic personnel accredited in the country for transfers made in the exercise of their functions, (c) representatives of courts, authorities or offices, special missions, commissions or bilateral bodies established by Treaties or International Agreements, in which the Argentine Republic is part, to the extent that transfers are made in the exercise of their functions, (d) foreign transfers in the name of individuals who are beneficiaries of retirement and/or pensions paid by the ANSES, for up to the amount paid by said agency in the calendar month and to the extent that the transfer is made to a bank account owned by the beneficiary in its registered country of residence, (e) purchase of foreign currency (in cash) by non-resident individuals for tourism and travel expenses, up to a maximum amount of U$S100 dollars, to the extent the financial entity can verify in the online system implemented by the Argentina Central Bank that the client has settled an amount equal or higher than the sum to be purchased within 90 days prior to the operation; (f) transfers to offshore bank accounts by individuals that are beneficiaries of pensions granted by the National Government pursuant to Laws Nos. 24,043, 24,411 and 25,914, as supplemented; and (g) repatriations of direct investments of non-residents in companies that are not controlling companies of local financial entities, to the extent that the capital contribution has been entered and settled through the FX Market as of October 2, 2020 and the repatriation tales place at least two years after its entry.
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Access to the FX Market for savings or investments purposes of individuals
Pursuant to section 3.8 of the FX Regulations, Argentine residents may access the FX Market for the purposes of external assets’ formation, family assistance or derivative operations (with some exceptions expressly set forth) for up to U$S 200 (through debits to local bank accounts) or U$S 100 (in cash) per person per month through all authorized exchange entities. If the access entails a transfer of the funds abroad, the destination account must be an account owned by the same person.
In all cases, the person shall be obligated to submit a sworn statement expressing that the funds shall not be used for the secondary purchase of securities within the following five (5) business days. In addition, if an individual purchases securities through payment in foreign currency, the same must have been held by the client for at least 5 business days since the settlement of the transaction before their subsequent sale or transfer to another depositary. This minimum holding period shall not apply if the sale of the securities is carried out in the same jurisdiction and the settlement of the transactions is made in the same foreign currency.
Effective as of September 16, 2020, the Argentine Central Bank ordered under Communication “A” 7106 (now reflected in Section 3.8 of the FX Regulations) that purchases in pesos made abroad with a debit card and amounts in foreign currency acquired by individuals in the FX Market as of September 1, 2020, for the payment of obligations between residents under section 3.6 of the FX Regulations, including payments for credit card purchases in foreign currency, will be deducted, as from the subsequent calendar month, from the US$ 200 monthly quota. If the amount of such purchases exceeds the quota available for the following month or such quota has been already absorbed by other purchases made since September 1, 2020, such deduction will be made from the quotas of the following months until completing the amount of those purchases.
In addition, pursuant to Section 3.8.4 of the FX Regulations and effective as of September 16, 2020, in order to allow access to the FX Market for the formation of external assets, the relevant institution must be provided with a customer’s affidavit whereby the customer undertakes not to enter into securities transactions in Argentina to be settled in foreign currency as from the time the customer requests access to the FX Market and for 90 calendar days thereafter.
The relevant institution shall check the online system implemented by the Argentine Central Bank to verify whether the person has not reached the limits set for the applicable calendar month or has not exceeded them in the previous calendar month and is thus entitled to enter into the foreign exchange transaction, and shall request the customer to provide an affidavit stating that such person is not a beneficiary of any “Zero Interest-Rate Loans” contemplated in section 9 of Decree No. 332/2020, as amended, “Subsidized Loans for Companies” and/or “Zero Interest-Rate Loans for Independent Workers Engaged in Cultural Activities.”
In addition, for the purpose of entering into derivative transactions relating to the payment of premiums, creation of guarantees and payments of futures, forwards, options and other derivatives, to the extent they imply a payment in foreign currency, individuals shall be required to obtain the Argentine Central Bank’s prior approval.
Access to the local exchange market is also allowed for the payment of premiums, creation of guarantees and payment of interest rate hedge agreements under obligations by residents vis-à-vis foreign creditors that are reported and validated, as applicable, under the External Assets and Liabilities Reporting Regime, provided that it does not cover risks higher than the external liabilities actually incurred by the debtor at the interest rate of the risk being hedged through such transaction. The customer who accesses the local market using this mechanism shall designate an institution authorized to deal in the FX Market which shall follow up the transaction and shall sign an affidavit committing to enter and settle the funds payable to the local customer as a result of such transaction or as a result of the release of the collateral money, within 5 business days following the date such payment or release.
Access to the FX Market by other residents -excluding entities- for the formation of external assets and for derivatives transactions
Section 3.10 of the FX Regulations sets forth that access to the FX Market for the build-up of foreign assets and for derivatives transactions by local governments, mutual funds, other universalities established in Argentina, requires prior authorization by the Argentine Central Bank.
Access to the FX Market by security trusts for principal and interest payments.
Pursuant to section 3.7 of the FX Regulations, Argentine security trusts created to guarantee principal and interest payments by resident debtors may access the FX Market in order to make such payments at their scheduled maturity, to the extent that, pursuant to the current applicable regulations, the debtor would have had access to the FX Market to make such payments directly. Also, subject to certain conditions, a trustee may access the FX Market to guarantee certain capital payments and interest on financial debt abroad and anticipate access to it.
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Derivatives transactions
Section 3.12 of the FX Regulations requires that derivatives transactions, including payment of premiums, constitution of collateral and settlement of futures, forwards, options and other derivatives, shall, as of September 11, 2019, be made in local currency (i.e., Pesos).
Likewise, access to the FX Market is granted for the payment of premiums and settlements, margins and other collateral in connection with interest rate hedge agreements for foreign debt declared and validated, if applicable, in the External Assets and Liabilities Reporting Regime, as long as such agreements do not cover higher risks than external liabilities of the recorded debtor’s interest rate risk being covered.
An entity authorized to operate in the FX Market must be designated by the debtor to track the operation and an affidavit must be provided in which the debtor undertakes to repatriate and settle the funds that are in favor of the local client as a result of such operation, or as a result of the release of the funds of the constituted as collateral, in Pesos within the following five (5) business days.
Payment of Imports
Residents are authorized to access the FX Market for the payment of import of goods in accordance with section 10.1 of the FX Regulations. This regulation sets forth different requirements depending on whether it relates to the payment of imports of goods with customs clearance or the payments of import of goods pending customs clearance. Also, the imports and import payments monitoring system (SEPAIMPO) has been reinstated, setting forth rules governing such monitoring process and exceptions thereof.
Pursuant to the FX Regulations, the local importer must appoint a local financial entity to act as a monitoring bank, which will be responsible for verifying compliance with the applicable regulations, including, among others, the liquidation of import financing and the entry of imported goods.
Payment of services provided by non-residents
Pursuant to section 3.2 of the FX Regulations, residents may access the FX Market for payment of services provided by non-residents (provided that the are unrelated entities, except for expressly provided exceptions among which the payment of reinsurance premiums abroad, whose beneficiary has been admitted by the Superintendencia de Seguros de la Nación and payments for operating leases of vessels that have the authorization of the Ministry of Transportation of the Nation and are used to provide services exclusively to another unrelated resident, to the extent that the amount to be paid abroad does not exceed the amount paid by the latter net of commissions, reimbursement of expenses or other items that may be retained by the resident making the payment abroad except affiliates), as long as there is documentation to support the existence of the service, and it is verified that the operation has been declared, if applicable, in the last presentation of the External Assets and Liabilities Reporting Regime.
They must also verify that the client has the declaration made through the Integral Monitoring System for Foreign Payments of Services (SIMPES) in "APPROVED" status, with the exception of operations corresponding to services provided under concept codes S02, S03, S06, S25, S26 and S27.
The preceding requirement shall not apply in the case of payment by: i) the public sector, ii) all business organizations, regardless of their corporate form, in which the National State has a majority participation in the capital or in the formation of corporate decisions, iii) trusts constituted with contributions from the national public sector, iv) financial entities for their own imports of services performed by the same entity, or v) entities for the cancellation of letters of credit or guaranteed letters issued or granted up to and including January 6, 2022.
In the case of letters of credit or guaranteed letters issued or granted as from January 7, 2022, the entity must have documentation proving that, at the time of opening or issuance by the entity, the client had the declaration made through the Integral Monitoring System for Foreign Payments of Services (SIMPES) in "APPROVED" status, with the exceptions already indicated.
Access to the FX Market for the prepayment of debts for services requires prior authorization by the Argentine Central Bank. Such approval will be also required to pay services rendered by foreign affiliates, provided, however, that the following transactions will be exempted:
Through Communication “A” 7301, as from June 14, 2021, clients will have access to make service payments to related counterparties abroad without the prior approval of the BCRA when they possess a "Certification of increase of exports of goods in 2021".
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Through Communication "A" 7348, as from August 26, 2021, clients will have access to make service payments to related foreign counterparties as from the maturity of the principal of debts outstanding as of June 30, 2021 without the prior approval of the BCRA when it has a certification from an entity in accordance with item 3.19 of FX Regulations, for the equivalent of the amount to be paid.
Access to the FX Market for payment of imports of goods while submission of import clearance is pending
Section 10.4.2.8 of the FX Regulations stablishes that to access the FX Market for the payment of imports of goods pending customs clearance, importers are required (in addition to the other requirements in force under the FX Regulations) to file a declaration through the Integral Import Monitoring System (Sistema Integral de Monitoreo de Importaciones or SIMI) showing the “SALIDA” status in connection with the imported goods to the extent that such declaration is required for the registration of the application for import of goods for consumption.
In accordance with Section 10.4.2.6 of the FX Regulations, payments for imports of goods pending customs clearance made between September 2, 2019 and October 31, 2019 will be considered in default if they (A) relate to (i) payments on demand upon presentation of shipping documents; (ii) payments of commercial debts abroad; and (iii) payment of commercial guarantees for imports of goods granted by local institutions, and (B) are not regularized, that is, the customer failed to furnish evidence to the institution in charge of monitoring such payment (up to the amount paid) of the existence of (i) import clearance in its name or in the name of a third party; (ii) the settlement on the FX Market of currency associated with the return of the payment made; (iii) other forms of regularization permitted under the FX Regulations; and/or (iv) the Argentine Central Bank’s acceptance of the total or partial regularization of the transaction.
Importers will not be allowed access to the FX Market to make new prepayments of imported goods until such defaulted transactions are not regularized.
Payment of imports of goods by accessing the FX Market until June 30, 2022.
Section 10.11 of the FX Regulations sets forth that, for the purposes of accessing the FX Market to pay imports of goods or the principal amount of debts arising from the import of goods, legal entities and individuals shall obtain the Argentine Central Bank’s prior approval, unless any of the following situations occurs:
a) The entity has received an affidavit from the client stating that the total amount of payments associated with its imports of goods processed through the exchange market since January 1, 2020, including the payment whose course is being requested, does not exceed in more than US$250,000, the amount that arises from considering: 1) the amount by which the importer would have access to the exchange market when computing the imports of goods that appear in his name in the system for tracking payments of imports of goods (SEPAIMPO) and that were made between January 1, 2020 and the day prior to accessing the FX Market; 2) plus the amount of payments made through the FX Market as from July 6, 2020, corresponding to imports of goods entered by Particular Request or Courier or to operations included in Sections 10.9.1. to 10.9.3. of the FX Regulations that have been shipped as from July 1, 2020, or that having been shipped previously had not arrived in the country before that date; 3) plus payments made under Sections 10.11.3. to 10.11.6., 10.11.8 and 10.11.9. not associated with imports included in Sections 10.11.1.1. and 10.11.1.2 of the FX Regulations; 4) plus payments associated with goods donated to the Ministerio de Salud de la Nación to strengthen the country's medical or health care capacity, as provided for in 10.6.5 of the FX Regulations; 5) les the amount of pending regularization for payments of imports with pending customs registration made between January 1, 2019 and December 12, 2019. The entity shall, in addition to requesting the affidavit from the client, verify that such statement is compatible with the existing data in the BCRA from the online system implemented to such effect. The total amount of payments for imports of goods associated with the customer’s imports must also include payments for cancellations of credit lines and/or commercial guarantees that were made by the entities bye virtue of the customer’s imports.
b) In the case of a deferred payment or at sight payment of imports corresponding to operations that have been shipped as of July 1, 2020 or that, having been shipped previously, did not have arrived in the country before that date.
c) It is a payment associated with an operation not included in section b) above, to the extent that it is destined to the cancellation of a commercial debt for imports of goods with an export credit agency or a foreign financial entity or that was guaranteed by either of such entities, to the extent that the debt with such creditors arose prior to July 1, 2020 or arose from guaranteed contracts prior to that date. If the debt was acquired by such creditors after that date from a creditor other than those listed above, the payment will not be covered by the provisions of this item..
d) It is a payment made by: i) the public sector, ii) entities in which the Argentine State has a majority participation in the capital stock or in the making of major corporate decisions or iii) trusts constituted with contributions made by the national public sector.
e) It is an imports payment with pending customs entry registration, to be made by an entity in charge of the provision of critical drugs to be entered by private request by the beneficiary.
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f) It is an imports payment with pending customs entry registration made for the purchase of COVID-19 detection kits or other products with tariff positions that are included in the list included in Decree No. 333/2020 as amended.
g) The financial entity has received an affidavit from the client stating that, including the advanced import payment which is being requested, plus the amounts included in a), do not exceed US$ 3,000,000 (three million US dollars) and that these payments are related to imports of products related to the provision of medication or other goods related to medical assistance and/or health care directed to the population or supplies that are necessary for their local preparation.
Prior to authorizing payments for imports of goods, the intervening financial entity must, in addition to requesting the client's affidavit, verify that such statement is compatible with the existing data in the Argentine Central Bank from the online system implemented for this purpose.
h) It is an advance payment of imports for the purchase of capital goods and the entity has received an affidavit from the client stating that, including the advanced import payment, which is being requested, the amount pending regularization for payments made under this item as of January 1, 2021, does not exceed the equivalent of US$1,000,000 (one million US dollars). In the event that the amount indicated is exceeded, the following conditions must be verified: 1) the sum of the advance payments made under this item does not exceed 30% of the total amount of the goods to be imported; and 2) the sum of the advance payments, on demand and commercial debt without customs entry record made under this item does not exceed 80% of the total amount of the goods to be imported For this purpose, the tariff positions classified as BK (Capital Goods) in the MERCOSUR Common Nomenclature (Decree No. 690/02 and complementary regulations) shall be considered. If capital goods and other goods that are not capital goods are paid for in the same advance payment, the payment may be channeled through this item to the extent that the former represent at least 90% of the total value of the goods purchased from the supplier in the transaction and the entity has a sworn statement from the customer stating that the remaining goods are spare parts, accessories or materials necessary for the operation, construction or installation of the capital goods being purchased. The intervening entity must verify compliance with the remaining requirements established for the transaction by the exchange regulations in force.
i) It is the payment of the principal of commercial debts for the imports of goods and the client has a “Certificación de aumento de exportaciones de bienes en el año 2021” (Certification of increase of exports of goods in the year 2021), for the equivalent value of the amount to be paid.
j) The client has a certification issued within the previous 5 (five) working days by an entity within the framework of the provisions of Section 3.19 of the FX Regulations, for the equivalent of the amount to be paid.
k) It is a payment on demand or commercial debts without customs entry record and the following conditions are verified: 1) the operation corresponds to the importation of inputs to be used for the production of goods in the country; and 2) the payments made under this item do not exceed, in the current calendar month and for the entities as a whole, the amount obtained by considering the average amount of the imports of inputs computable for the purposes of item a) above, in the last twelve calendar months closed, net of the amount pending regularization for payments with customs entry registration pending in a situation of delay recorded by the importer. The entity must have an affidavit from the client evidencing compliance with the above conditions, the input nature of the imports computed and also verify that the declared amount is compatible with the existing data in the BCRA from the online system implemented for such purpose. The limit set forth in 2) above, shall not apply when the client is a trust set up by a provincial government for the purpose of facilitating the acquisition of inputs by producers of goods.
The amount by which importers can access the FX Market under the conditions established within the framework for payment of imports of goods by accessing the FX Market until June 30, 2022, will be increased by the equivalent of 50% of the amounts that, the importer settles through the FX Market as export advances or pre-financing of exports from abroad with a minimum term of 180 days.
Access for the remaining 50% will also be admitted to the extent that the additional part corresponds to payments for imports of capital goods and/or goods that qualify as necessary inputs for the production of exportable goods. In the latter case, the entity must have an affidavit from the client regarding the type of good involved and its status as an input in the production of goods to be exported.
Prior to authorizing payments for imports of goods, the intervening financial entity must, in addition to requesting the client's affidavit, verify that such statement is compatible with the existing data in the Argentine Central Bank from the online system implemented for this purpose.
The access to make the corresponding payment must be made within 5 (five) working days of the settlement of the advance or pre-financing from abroad. The entity through which the settlement was made may send the corresponding certification to the entity/s through which the client wishes to access the foreign exchange market.
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Payment of dividends and corporate profits
In accordance with section 3.4 of the FX Regulations, access is granted to the FX Market to pay dividends to non-resident shareholders, subject to the following conditions:
i. | Dividends must be the result of closed and audited balance sheets. |
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ii. | The total amount paid to non-resident shareholders shall not exceed the corresponding amount denominated in Pesos determined by the shareholders’ meeting to be distributed as dividends. |
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iii. | If applicable, the External Assets and Liabilities Reporting Regime shall have been complied with. |
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iv. | The company is in one of the following situations and meets all the conditions stipulated in each case: |
1) It records direct investment contribution settled as 17.1.2020. In this case, (i) the total amount of transfers made through the FX Market for payment of dividends to non-resident shareholders may not exceed the 30% of the total value of the capital contributions made in the relevant local company that entered and settled through the FX Market as of January 17, 2020; (ii) the access will only be granted after a period of not less than thirty (30) calendar days has elapsed as from the date of the settlement of the last capital contribution that is taken into account for determining the aforementioned 30% cap; and (iii) evidence of the definitive capitalization of capital contributions must be provided or, if not available, evidence of filing of the process of registration of the capital contribution before the Public Registry shall be provided. In this case, evidence of the definitive capitalization shall be provided within 365 calendar days from the date of the initial filing with the Public Registry.
2) Profits generated in project under the “PLAN GAS”. In this case, (i) profits generated by foreign direct investment contributions entered and settled through the FX Market as from November 16, 2020, destined to the financing of projects framed within the " Plan de promoción de la producción del gas natural argentino – Esquema de oferta y demanda 2020-2024" established in Section 2 of Decree No. 892/20; (ii) the access to the FX Market occurs no earlier than two years from the date of settlement in the FX Markat of the contribution that allows the framing in this item 2; and (iii) the client must submit documentation supporting the definitive capitalization of the contribution.
3) Have a certification of increased exports of goods. In this case, (i) the client has a “Certificación de aumento de exportaciones de bienes” (certification of increased exports of goods).
Other Specific Provisions
Swap, arbitrage and securities transactions
Financial institutions may carry out currency swap and arbitrage transactions with their customers in the following cases:
(i) transfer of foreign currency abroad by individuals from their local accounts denominated in foreign currency to bank accounts held by such individuals abroad.
(ii) transfer of foreign currency abroad by local common depositaries of securities in connection with proceeds received in foreign currency on account of services of principal and interest on Argentine Treasury bonds, when such transaction forms part of the payment procedure at the request of the foreign common depositaries;
(iii) transfers of foreign currency abroad made by individuals from their local accounts denominated in foreign currency to offshore collection accounts up to an amount equivalent to US$ 500 in any calendar month, provided that the individual provides an affidavit stating that the transfer is made to assist in the maintenance of Argentine residents who were forced to remain abroad in compliance with the measures adopted in response to the COVID-19 pandemic;
(iv) arbitrage transactions not originated in transfers from abroad may be made without any restrictions, to the extent that the funds are debited from an account in foreign currency held by the customer with a local financial institution. To the extent that the funds are not debited from an account denominated in foreign currency held by the customer, these transactions may be made by individuals, without the Argentine Central Bank’s prior approval, up to the amount allowed for the use of cash under items 3.8. and 3.13 of the FX Regulations;
(vi) swap and arbitrage transactions by non-residents individual may be made without restrictions to the extent that the fonds be credited in a “Caja de ahorro para turistas” in accordance with the “Despositos de ahorrro, cuenta sueldo y especiales” regulations;
(vi) all other swap and arbitrage transactions may be made by customers without the Argentine Central Bank’s prior approval to the extent that they would be allowed without need of such approval in accordance with other exchange regulations. This also applies to local common depositaries of securities with respect to the proceeds received in foreign currency as payments of principal of and interest on foreign currency securities paid in Argentina.
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If the transfer is made in the same currency as that in which the account is denominated, the financial institution shall credit or debit the same amount as that received from or sent abroad. When the financial institution charges a commission or fee for these transactions, it shall be instrumented under a specifically designated item.
In addition, (i) any beneficiaries of refinancing under point 1.1.1. of the rules on "Financial services in the context of a health emergency Financial Services within the framework of the sanitary emergency provided by Decree No. 260/2020 Coronavirus (COVID-19)", until their total cancellation; (ii) the beneficiaries of "Credits at Zero Rate", "Credits at Zero Rate 2021", "Credits at Zero Rate Culture" or "Credits at Subsidized Rate for Companies", provided for in points 1.1.2. and 1.1.3. of the rules on "Financial Services within the framework of the sanitary emergency provided for by Decree No. 260/2020 Coronavirus (COVID-19)", until their total cancellation; (iii) the beneficiaries of financing in pesos within Section 2 of Communication “A” 6937, Sections 2 and 3 of Communication “A” 7006, as supplemented; until their total cancellation; (iv) the beneficiaries of Section 2 of Decree 319/2020 and complementary and regulatory norms, for the duration of the benefit with respect to the update of the value of the installment; and (v) those persons covered by the Joint Resolution of the President of the Honorable Senado de la Nación and the President of the Honorable Cámara de Diputados de la Nación No. 12/2020 of October 1, 2020; will be prevented from selling securities issued by residents to be settled in foreign currency in Argentina or transferring such securities to foreign depositaries or swap securities issued by residents for foreign assets or the acquisition in the country with settlement in pesos of securities issued by nonresidents.
Use of export proceeds for the payment of new issuances of debt securities
Pursuant to Section 7.9.1.7 of the FX Regulations, as of January 7, 2021, proceeds in foreign currency from exports of goods and services may be used for the payment of principal and interest under new duly registered issuances of debt securities, to the extent that:
| · | such issuance corresponds to (i) an exchange of debt securities, or (ii) the refinancing of foreign financial indebtedness, concerning scheduled principal repayments maturing between March 31, 2021, and December 31, 2022; and |
| · | considering the transaction as a whole, the average life of new indebtedness is at least 18 months longer than the principal and interest payments being refinanced which should occur before December 31, 2022 |
Export proceeds to guarantee new indebtedness
Section 7.9.5 of the FX Regulations allows for proceeds from exports of goods and services held in local or foreign financial institutions to guarantee payment of new indebtedness that has complied with the mandatory repatriation and settlement obligation, as from January 7, 2021. Funds in these accounts shall not exceed at any time 125% of the principal and interest to be paid in the current month and the following six calendar months, in accordance with the scheduled of payments as agreed upon with the creditors. Funds exceeding such amount must be repatriated and settled through the FX Market subject to the applicable foreign exchange rules.
In the event the financial agreement entered into requires the funds to be deposited for a period exceeding that which has been established for its mandatory settlement, the exporter may request this latter period be extended up until five business day after the former.
Access to the FX Market for the constitution of guarantees
Residents may access the FX Market for the constitution of guarantees in connection to new indebtedness entered into as of January 7, 2021, in accordance with Section 7.9 of the FX Regulations, or in connection to local trusts created to guarantee principal and interest payments of such new indebtedness. Such guarantees are to be held in local financial institutions or, in the event of foreign indebtedness, in foreign financial institutions, in an amount equal to that established in the agreement, pursuant to the following conditions:
i. concurrently to such access, foreign currency-denominated funds are being repatriated and settled through the FX Market and/or funds credited to the correspondent account of a local financial institutions, and
ii. the guarantees shall not exceed at any time 125% of the principal and interest to be paid in the current month and the following six calendar months, in accordance with the scheduled of payments as agreed upon with the creditors.
Funds which are not applied to the payment of principal and interest or the conservation guarantee detailed herein must be settled through the FX Market within five business days from its maturity date.
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Special regime for financings under Plan Gas IV
Section 3.5.5 provides that to the extent that the Argentine Central Bank prior approval requirement is in force for access to the FX Market for the cancellation at maturity of principal and interest of financial indebtedness abroad, this requirement shall not apply to the extent that all of the following conditions are met:
(i) the destination of the funds has been the financing of projects framed in the "Plan de Promoción de la Producción del Gas Natural Argentino–Esquema de Oferta y Demanda 2020-2024" established in Section 2 of Decree No. 892/20;
(ii) the funds have been deposited and settled through the FX Market as from November 16, 2020; and
(iii) the indebtedness has an average life of not less than 2 (two) years.
Section 3.13.2 provides that entities may grant access to the FX Market, without the prior consent of the Argentine Central Bank, for the repatriation of direct investments made by non-residents up to the amount of direct investment contributions settled on the FX Market as of November 16, 2020 as long as all of the following conditions are met:
(i) the institution has documentation that proves the effective inflow of the direct investment in the resident company;
(ii) access occurs not earlier than two years from the date of settlement on the FX Market of the transaction that qualifies for inclusion in this point;
(iii) in case of a capital reduction and/or return of irrevocable contributions made by the local company, the institution has documentation that proves that the relevant legal mechanisms have been complied with and has verified that the external liability in pesos generated as from the date of the non-acceptance of the irrevocable contribution or the capital reduction, as applicable, has been disclosed in the last filing due under the External Assets and Liabilities Reporting Regime.
In all cases, the institution shall have documentation that allows it to verify the genuineness of the transaction to be processed, that the funds were used to finance projects falling under the scope of such plan and the fulfilment of the other requirements set forth in the FX Regulations.
Special regime under the investment promotion regime for exports set forth by Decree No. 234/21
On April 8, 2021, the Argentine Central Bank issued Communication “A” No. 7259, incorporated in the FX Regulations in Section 7.10, that states that proceeds of exports of goods under the investment promotion regime for exports set forth by Decree No. 234/21 (the “Promotion Regime”) might be applied, in the terms set by its regulators, to the following transactions: a) Payment of principal and interests of debts arising from import of goods and services as from the maturity date; b) Payment of principal and interests of debts connected to foreign financial debts as from the maturity date; c) Payment of profits and dividends corresponding to closed and audited balance sheets; and d) Repatriation of direct investments by non-residents in companies that are not controllers of local financial entities.
Such uses shall be admitted to the extent that the following conditions are met:
| 1. | The amount applied does not exceed 20% of the amount in foreign currency corresponding to the permit of export whose charges are applied. |
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| 2. | The amount does not exceed 25% of the gross amount of foreign currency settled through the FX Market for financing the project that generated the applied exports. This gross amount will be calculated based on the foreign currency settled through the FX Market as of April 7, 2021, as (i) foreign financial debts and (ii) foreign direct investments. The settlements through the FX Market can only be computed after a year has elapsed since such settlement was carried out. |
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| 3. | Exporters who opt for this mechanism must designate a local financial institution to monitor the project included in the Promotion Regime. |
Likewise, Section 7.10.3 sets forth that exports proceeds that being eligible, are not simultaneously applied to the admitted uses, may remain deposited until their application in foreign correspondent accounts of local financial entities and/or in local accounts in foreign currency of local financial entities. In the event that the application had not taken place at the time of expiration of the deadline for the settlement of exports proceeds of the corresponding export permit, the exporter may request to the monitoring entity the extension of the term until the date on which it estimates the application will take place.
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Section 7.10.4 states that the cases foreseen in point 1) of section 8º bis incorporated by Decree Nº 836/21 to Decree Nº 234/21, may apply during 2 consecutive calendar years for each calendar year in which the benefit was not used, up to 40% of the value of the permits shipped during the years in which the extended benefit is used, to the extent that the annual amount applied does not exceed the equivalent to 40% of the gross amount of the foreign currency entered to finance the development of the project that generates the exports applied. This option may be accessed after the second calendar year has elapsed from the first foreign currency inflow that initiates the project. Said period may be computed as part of the period of non-utilization that gives rise to the use of the extended benefit. In addition to the provisions of the first paragraph of point 7.10.3. the funds may also remain in bank accounts of foreign financial entities that are not incorporated in countries or territories where the recommendations of the Financial Action Task Force are not applied or are not sufficiently applied.
Section 7.10.5 sets forth that the cases foreseen in point 2) of section 8º bis incorporated by Decree Nº 836/21 to Decree Nº 234/21, may apply during 2 consecutive calendar years for each calendar year in which the benefit was not used, up to 60% of the value of the permits shipped during the years in which the extended benefit is used, to the extent that the annual amount applied does not exceed the equivalent to 60% of the gross amount of the foreign currency entered to finance the development of the project that generates the exports applied. This option may be accessed after the second calendar year has elapsed from the first foreign currency inflow that initiates the project. Said period may be computed as part of the period of non-utilization that gives rise to the use of the extended benefit. In addition to the provisions of the first paragraph of point 7.10.3. the funds may also remain in bank accounts of foreign financial entities that are not incorporated in countries or territories where the recommendations of the Financial Action Task Force are not applied or are not sufficiently applied.
Argentine Central Bank’s Reporting Systems
Advance information on foreign exchange transactions
On December 28, 2017, the BCRA replaced the reporting regimes set forth on Communications “A” 3602 and “A” 4237 with Communication “A” 6401 (and supplemental Communication “A” 6795), a unified regime applicable from December 31, 2017 (the “External Assets and Liabilities Reporting Regime”). Under such regime, Argentine residents whose foreign assets or debts flow or balance during the previous calendar year equal to or in excess of US$50 million in Argentine Pesos, are required to comply with these reporting obligations on a quarterly basis. From March 31, 2020, all residents with external liabilities at the end of any quarter, or residents who have cancelled any of its external liabilities during such period, must file the report within 45 calendar days from the end of the quarter.
Residents whose foreign assets or debts flow or balance equal to or in excess of the equivalent of US$50 million in Argentine Pesos at the end of each calendar year, are required to file within 180 calendar days from December 31, an annual report where supplements, amendments or confirmation of information contained in previously quarterly filings can be included.
Access to the FX Market for repayment of external financial indebtedness and other transactions are conditioned to the debtor’s compliance with the External Assets and Liabilities Reporting Regime. Please see “Additional Requirements Regarding Access to the Exchange Market” below
Moreover, the institutions authorized to deal in foreign exchange shall provide the Argentine Central Bank, at the end of each business day and two business days in advance, with information on transactions relative to outflows through the FX Market in daily amounts equal to or higher than the equivalent of US$ 50,000 (fifty thousand U.S. Dollars).
Customers of licensed institutions shall provide such institutions with information sufficiently in advance so that they may comply with the requirements under this reporting regime and, accordingly, to the extent any further requirements set forth in the exchange regulations are simultaneously satisfied, they may process the exchange transactions.
Registry of exchange information of exporters and importers.
On January 6, 2021, the Central Bank issued Communication “A” 7200, established a new “Registry of exchange information of exporters and importers.” Communication “A” 7273 was modified on April 29, 2021, establishing that exporters and importers who, due to their degree of significance of the volumes they operate, will have to be registered in before May 31, 2021; and beginning June 1, 2021, any payments done from Argentina through the FX Market, will require the Central Bank’s prior authorization if done by obligated entities that appear as “not registered” in the Registry of exchange information of exporters and importers.
Other foreign exchange regulations
Pursuant to General Resolution No. 836/20, the CNV provided that mutual investment funds in pesos shall invest at least 75% of their assets in financial instruments and marketable securities issued in Argentina exclusively in local currency. General Resolution No. 838/20 clarified that such requirement is not applicable to investments in assets issued or denominated in foreign currency that are made and paid in pesos and the interest and principal amounts whereof are exclusively paid in pesos.
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Under Interpretation Criterion No. 17 (referring to General Resolution No. 836/2020), the CNV established that new investments in assets issued in foreign currency may be made only if the aggregate of the assets listed in section 78, Article XV, Chapter III, Title XVIII of the CNV Rules plus the rest of the assets issued in a currency other than pesos does not exceed 25% of the assets of the relevant mutual investment fund.
Pursuant to General Resolution No. 878/2020, sales transactions of securities to be settled in foreign currency and in a foreign jurisdiction will be carried out provided that a minimum holding period of three business days is observed to be counted as from the date such securities are credited with the relevant depositary. As regards to sales of securities to be settled in foreign currency and in a local jurisdiction, the minimum holding period will be two business days to be counted as from the date such securities are credited with the relevant depositary. These minimum holding periods shall not be applicable in the case of purchases of securities to be settled in foreign currency.
In addition, transfers of securities acquired from foreign depositaries to be settled in pesos will be processed subject to a minimum holding period of three business days counted as from the crediting thereof with the depositary, unless such crediting results from a primary placement of securities issued by the National Treasury or refers to shares and/or Argentine deposit certificates (CEDEARs) traded on markets regulated by the CNV. Settlement and clearing agents and trading agents must verify compliance with the aforementioned minimum holding period of the securities.
As regards incoming transfers, General Resolution No. 878/2020 provided that securities transferred by foreign depositaries and credited with a central depositary may not be allocated to the settlement of transactions in foreign currency and in a foreign jurisdiction until three business days after such crediting into sub-account/s in the local custodian. If such securities are allocated to the settlement of transactions in foreign currency and in local jurisdiction, the minimum holding period will be two business days after such crediting into sub-account/s in the local custodian.
In addition, in the price-time priority order matching segment, transactions for the purchase and sale of fixed-income securities denominated and payable in US dollars issued by Argentina under local laws by sub-accounts subject to section 6 of the CNV Rules and that are also regarded as qualified investors, the following requirements must be observed:
| (i) | for the aggregate of such securities, the nominal amount of securities purchased and to be settled in pesos may not exceed the nominal amount of securities sold and to be settled in pesos, on the same trading day and for each customer sub-account; |
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| (ii) | for the aggregate of such securities, the nominal amount of securities sold and to be settled in foreign currency and in local jurisdiction may not exceed the nominal amount of securities bought and to be settled in such currency and jurisdiction, on the same trading day and for each customer sub-account; and |
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| (iii) | for the aggregate of such securities, the nominal amount of securities sold and to be settled in foreign currency and in a foreign jurisdiction may not exceed the nominal amount of securities bought and to be settled in such currency and jurisdiction, on the same trading day and for each sub-account. |
Pursuant to General Resolution No. 895/2021, the minimum holding period is reduced tot two business days for:
(i) Securities with settlement in foreign currency, prior to their sale in foreign jurisdiction.
ii) Securities acquired with settlement in local currency, prior to their transfer to foreign depository entities; and
iii) Securities from foreign depositary entities, prior to their sale with settlement in foreign currency and in a foreign jurisdiction.
In addition, the CNV added limits to the number of fixed income securities denominated and payable in U.S. dollars issued by the Argentine Republic sold with settlement in foreign currency and in foreign jurisdiction in the price-time priority bidding segment, for transactions that do not belong to the agents' own portfolio. It is clarified that by Interpretative Criterion No. 75, the CNV established that the Principal Sub-accounts on behalf of the sub-accounts covered by the provisions of Section 6 of Chapter V of Title VI ("own portfolio") of the CNV Rules and which are also qualified investors pursuant to Section 12 of Chapter VI of Title II of the CNV Rules, must comply with limits to the nominal amount of fixed income securities denominated and payable in US dollars issued by the Argentine Republic under foreign law sold with settlement in foreign currency and in foreign jurisdiction.
By means of the General Resolution No. 907/2021, the CNV substituted Section 6 above mentioned and incorporated Section 6 bis. Section 6 establishes that:
(i) In the transactions, in the segment of concurrence of offers with priority price time, of purchase and sale of fixed income securities nominated and payable in U.S. dollars issued by the Argentine Republic under Local Law, and for the set of all the principal sub-accounts and of such securities, at the closing of each calendar week it shall be observed that the amount of securities sold with settlement in foreign currency may not exceed fifty thousand (50.000) with respect to the amount of securities purchased with settlement in such currency, with this limit operating for each principal sub-account as well as for the set of principal sub-accounts owned or co-owned by the same subject; accounting the comparison between purchases and sales according to the settlement jurisdiction, local or foreign, and considering the limit established for the set of transactions with settlement in foreign currency.
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(ii) Settlement and Clearing Agents and Trading Agents must verify compliance with the limit per principal sub-account. Likewise, it eliminates the limit of fifty thousand (50,000) nominals with respect to the amount of securities, issued under foreign law, purchased with settlement in such currency and jurisdiction.
Section 6 bis provides that:
(i) As a prerequisite to enter into transactions with securities with settlement in foreign currency not covered by the provisions of Section 6 above, or to transfer securities from or to foreign depository entities, not to have made sales with settlement in foreign currency, in the segment of concurrence of offers with priority price time, of securities nominated and payable in US dollars, issued by the Argentine Republic under local law, in the previous 30 days and to undertake not to do so in the 30 subsequent running days.
(ii) Settlement and Clearing Agents and Trading Agents shall, prior to entering into the transactions referred to in the first paragraph of this section, require the submission of an affidavit evidencing compliance with this regulation.
In the same General Resolution 907/2021, the CNV issued Interpretative Criterion No. 76, by means of which certain guidelines were established.
First, in view of the provisions of Chapter V "Transitory Provisions" of Title XVIII of the CNV Rules, and considering that the limitation of Section 5 is applicable to fixed income securities denominated and payable in U.S. dollars issued by the Argentine Republic under Local Law, the Principal Subaccounts covered by the provisions of such Section must comply with the limits set forth in Article 6 and the restrictions contained in Section 6 bis above.
Finally, the restrictions set forth in Section 6 bis above, shall also apply prior to the execution of transactions with securities covered by the provisions of Section 6 above with settlement in foreign currency and in the bilateral trading segment.
Pursuant to General Resolution No. 911/2021, the CNV substituted Section 6 above mentioned and modifies the Interpretative Criterion No. 76 previously mentioned. Section 6 now establishes that:
(i) In transactions, in the time-priority bidding segment, for the purchase and sale of fixed-income securities denominated and payable in U.S. dollars issued by the Argentine Republic under Local Law, and for all the principal sub-accounts and such marketable securities, at the close of each calendar week, the total of sales with settlement in foreign currency shall not exceed FIFTY THOUSAND (50. 000) nominal; this limit shall apply to each principal sub-account as well as to all principal sub-accounts owned or co-owned by the same party and to all transactions settled in foreign currency.
(ii) The Settlement and Clearing Agents and the Trading Agents shall verify compliance with the limit per principal sub-account
Foreign Exchange Criminal Regime
Any operation that does not comply with the provisions of the FX Regulations is subject to Law No. 19,359 of Foreign Exchange Criminal Regime.
Notwithstanding the above mentioned measures adopted by the current administration, the Central Bank and the federal government in the future may impose additional exchange controls that may further impact our ability to transfer funds abroad and may prevent or delay payments that our Argentine subsidiaries are required to make outside Argentina.
Item 10.E Taxation
Certain United States Federal Income Tax Considerations
The following is a summary of certain U.S. federal income tax considerations that may be relevant to the purchase, ownership and disposition of common shares or ADSs by a U.S. Holder (as defined below).
This summary is based on provisions of the Internal Revenue Code of 1986, as amended (the “Code”), and regulations, rulings and judicial interpretations thereof, in force as of the date hereof. Those authorities may be changed at any time, perhaps retroactively, so as to result in U.S. federal income tax consequences different from those summarized below. In addition, this summary assumes that the deposit agreement, and all other related agreements, will be performed in accordance with their terms.
This summary is not a comprehensive discussion of all of the tax considerations that may be relevant to a particular investor’s decision to purchase, hold, or dispose of common shares or ADSs. In particular, this summary is directed only to U.S. Holders that hold common shares or ADSs as capital assets and does not address tax consequences to U.S. Holders who may be subject to special tax rules, such as banks, brokers or dealers in securities or currencies, traders in securities electing to mark to market, financial institutions, insurance companies, tax exempt entities, entities and arrangements treated as partnerships and the partners therein, holders that own or are treated as owning 10% or more of our shares by vote or value, persons holding common shares or ADSs as part of a hedging or conversion transaction or a straddle, nonresident alien individuals present in the United States for more than 182 days in a taxable year, or persons whose functional currency is not the U.S. dollar. Moreover, this summary does not address state, local or foreign taxes, the U.S. federal estate and gift taxes, or the Medicare contribution tax applicable to net investment income of certain non-corporate U.S. Holders, or alternative minimum tax consequences of acquiring, holding or disposing of common shares or ADSs.
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For purposes of this summary, a “U.S. Holder” is a beneficial owner of common shares or ADSs that is an individual citizen or resident of the United States or a U.S. domestic corporation or that otherwise is subject to U.S. federal income taxation on a net income basis in respect of such common shares or ADSs.
You should consult your own tax advisors about the consequences of the acquisition, ownership, and disposition of the common shares or ADSs, including the relevance to your particular situation of the considerations discussed below and any consequences arising under foreign, state, local or other tax laws.
ADSs
In general, if you are a U.S. Holder of ADSs, you will be treated, for U.S. federal income tax purposes, as the beneficial owner of the underlying common shares that are represented by those ADSs. Accordingly, deposits or withdrawals of common shares for ADSs will not be subject to U.S. federal income tax.
Taxation of Dividends
Subject to the discussion below under “—Passive Foreign Investment Company,” the gross amount of any distribution of cash or property with respect to common shares or ADSs (including any amount withheld in respect of Argentine withholding taxes) that is paid out of our current or accumulated earnings and profits (as determined for U.S. federal income tax purposes) will generally be includible in a U.S Holder’s taxable income as ordinary dividend income on the day on which the holder receives the dividend, in the case of common shares, or the date the ADS Depositary receives the dividends, in the case of ADSs, and will not be eligible for the dividends-received deduction allowed to corporations under the Code. To the extent that the amount of any distribution exceeds our current and accumulated earnings and profits for a taxable year, the distribution will first be treated as a tax-free return of capital, causing a reduction in the tax basis of the common shares or ADSs, and to the extent the amount of the distribution exceeds your tax basis, the excess will generally be taxed as capital gain recognized on a sale or exchange.
We do not expect to maintain calculations of our earnings and profits in accordance with U.S. federal income tax principles. U.S. Holders therefore should expect that distributions generally will be treated as dividends for U.S. federal income tax purposes.
Dividends paid in a currency other than U.S. dollars generally will be includible in a U.S. Holder’s income in a U.S. dollar amount calculated by reference to the exchange rate in effect on the day the holder receives the dividends, in the case of common shares, or the date the ADS Depositary receives the dividends, in the case of ADSs. Any gain or loss on a subsequent sale, conversion or other disposition of such non-U.S. currency (or on behalf of) by such U.S. Holder generally will be treated as ordinary income or loss and generally will be income or loss from sources within the United States. As indicated in “Item 3.D. Risk Factors—Risks Relating to our Shares and ADSs—Restrictions on transfers of foreign exchange and the repatriation of capital from Argentina may impair your ability to receive dividends and distributions on, and the proceeds of any sale of, shares underlying the ADSs”, in light of the current restrictions on conversion of Argentinean currency into foreign currency, the Depositary for the ADSs may hold the Argentine pesos it cannot convert for the account of the ADS holders for a significant period of time. The subsequent conversion of such Argentinean pesos into U.S. dollars may therefore result in such income or loss. U.S. Holders should consult their own tax advisors regarding the treatment of foreign currency gain or loss, if any, on any foreign currency received that is converted into U.S. dollars after it is received.
Subject to certain exceptions for short-term and hedged positions, the U.S. dollar amount of dividends received by a non-corporate U.S. Holder with respect to the common shares or ADSs will be subject to taxation at a preferential rate if the dividends are “qualified dividends” and certain other requirements are met. Dividends paid on the common shares or ADSs will be treated as qualified dividends if:
| · | the common shares or ADSs are readily tradable on an established securities market in the United States and |
| · | we were not, for the year prior to the year in which the dividend was paid, and are not, for the year in which the dividend is paid, a passive foreign investment company (a “PFIC”). |
Our ADSs are listed on the NYSE, and our ADSs will qualify as readily tradable on an established securities market in the United States so long as they are so listed and remain 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 2020 or 2021 taxable years. 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 our current taxable year or in the foreseeable future. U.S. Holders should consult their own tax advisors regarding the availability of the reduced dividend tax rate in light of their own particular circumstances.
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Because the common shares are not themselves listed on a U.S. exchange, dividends received with respect to common shares that are not represented by ADSs may not be treated as qualified dividends. U.S. Holders should consult their own tax advisors regarding the potential availability of the reduced dividend tax rate in respect of common shares.
U.S. Holders that receive distributions of additional common shares or ADSs or rights to subscribe for common shares or ADSs as part of a pro rata distribution to all of our shareholders generally will not be subject to U.S. federal income tax in respect of the distributions.
Taxation of Dispositions of Common Shares or ADSs
Subject to the discussion below under “—Passive Foreign Investment Company,” if a U.S. Holder realizes gain or loss on the sale, exchange or other disposition of common shares or ADSs, that gain or loss will be capital gain or loss and generally will be long-term capital gain or loss if the common shares or ADSs have been held for more than one year. Long-term capital gain realized by a non-corporate U.S. Holder generally is subject to taxation at a preferential rate. The deductibility of capital losses is subject to limitations.
Foreign Tax Credit Considerations
Dividend distributions with respect to the common shares or ADSs generally will be treated as “passive category” income from sources outside the United States for purposes of determining a U.S. Holder’s U.S. foreign tax credit limitation. Subject to the limitations and conditions provided in the Code and the applicable U.S. Treasury regulations, a U.S. Holder may be able to claim a U.S. foreign tax credit against its U.S. federal income tax liability in respect of any Argentine taxes withheld (to the extent not exceeding the withholding rate applicable to the U.S. Holder) from a dividend paid to such U.S. Holder if the tax is treated for U.S. federal income tax purposes as imposed on the U.S. Holder. Alternatively, the U.S. Holder may deduct such Argentine taxes from its U.S. federal taxable income, provided that the U.S. Holder elects to deduct rather than credit all foreign income taxes for the relevant taxable year.
Any gain realized on the sale or other disposition of common shares or ADSs will be treated as income from U.S. sources for purposes of determining a U.S. Holder’s U.S. foreign tax credit limitation. Therefore, an investor generally would not be able to use a foreign tax credit arising from any Argentine tax imposed on such disposition unless such credit could be applied (subject to applicable limitations) against tax due on other income treated as derived from foreign sources. Taxes are eligible for the foreign tax credit only if they are income taxes (or a tax paid in lieu of an income tax). As a result of recent changes to the foreign tax credit rules, any Argentine tax imposed on the sale or other taxable disposition of the shares by a U.S. Holder is unlikely to be treated as a creditable tax for taxable years beginning after December 28, 2021. For taxable years beginning fefore the effective date of the changes to the foreign tax credit rules, the Argentine capital gains tax is expected generally to be treated as an income tax (or a tax paid in lieu of an income tax) and thus potentially eligible for the foreign tax credit, provided the U.S. Holder has other income derived from foreign sources against which the credit could be used (as discussed above). Asset taxes, such as the Argentine personal assets tax (as described in “—Material Argentine Tax Considerations—Personal Assets Tax”), generally will not be treated as income taxes for U.S. federal income tax purposes. If the Argentine personal assets tax is not treated as an income tax for U.S. federal income tax purposes, a U.S. Holder generally would be unable to claim a foreign tax credit for any Argentine personal assets tax paid. A U.S. Holder may be able to deduct the Argentine taxes discussed in this paragraph in computing its U.S. federal income tax liability, subject to applicable limitations (including, in the case of income taxes, that the U.S. Holder elects to deduct rather than credit all foreign income taxes for the relevant taxable year).
The rules with respect to U.S. foreign tax credits are complex and involve the application of rules that depend on a U.S. Holder’s particular circumstances. Accordingly, U.S. Holders are urged to consult their tax advisors regarding the availability of the U.S. foreign tax credit under their particular circumstances.
Passive Foreign Investment Company
Special tax rules apply to U.S. Holders if we are a PFIC. In general, we will be a PFIC in a particular taxable year if, after applying certain look-through rules, either 75 percent or more of our gross income for the taxable year is passive income, or 50 percent or more of the value of our assets (determined on the basis of a quarterly average) is attributable to assets that produce or are held for the production of passive income. As discussed above, we believe that we were not treated as a PFIC for U.S. federal income tax purposes with respect to our 2021 taxable year, and we do not anticipate becoming a PFIC for our current taxable year or in the foreseeable future. The determination of whether we are a PFIC for any taxable year depends on the classification of our income and assets, our cash position and the nature of the activities performed by our officers and employees. Because this determination is made annually, it is possible that we may become a PFIC for the current taxable year or for any future taxable year due to changes in the composition of our income or assets.
If we are a PFIC for the current taxable year or for a future taxable year during which a U.S. Holder owns common shares or ADSs, the U.S. Holder will be subject to a special tax at ordinary income rates on certain “excess distributions” and on gain recognized on the sale or other disposition of such holder’s common shares or ADSs. For these purposes, distributions received in a taxable year will be treated as excess distributions to the extent that they are greater than 125% of the average annual distributions received during the shorter of the three preceding taxable years or the U.S. Holder’s holding period for the common shares or ADSs. In addition, the amount of income tax on any excess distributions or gains will be increased by an interest charge to compensate for tax deferral, calculated as if the excess distributions or gains were earned ratably over the period the U.S. Holder held the common shares or ADSs. Classification as a PFIC may also have other adverse tax consequences and subject a U.S. Holder to certain reporting requirements. If we are a PFIC for our current taxable year or in future taxable years, U.S. Holders may be able to make certain elections that would mitigate the consequences of our status as a PFIC, including by electing to mark common shares or ADSs to market annually. U.S. Holders should consult their own tax advisor regarding the U.S. federal income tax considerations discussed above.
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Specified Foreign Financial Assets
Certain individual U.S. Holders that own “specified foreign financial assets” with an aggregate value in excess of US$50,000 on the last day of the taxable year or $75,000 at any time during the taxable year are generally required to file an information statement along with their tax returns, currently on IRS Form 8938, with respect to such assets. “Specified foreign financial assets” include any financial accounts held at a non-U.S. financial institution, as well as securities issued by a non-U.S. issuer (which would include the common shares or ADSs) that are not held in accounts maintained by financial institutions. Higher reporting thresholds apply to certain individuals living abroad and to certain married individuals. Regulations extend this reporting requirement to certain entities that are treated as formed or availed of to hold direct or indirect interests in specified foreign financial assets based on certain objective criteria. U.S. Holders who fail to report the required information could be subject to substantial penalties. In addition, the statute of limitations for assessment of tax would be suspended, in whole or part. Prospective investors should consult their own tax advisors concerning the application of these rules to their investment in the common shares or ADSs, including the application of the rules to their particular circumstances.
Backup Withholding and Information Reporting
Dividends paid on, and proceeds from the sale, exchange or other disposition of, the common shares or ADSs to a U.S. Holder generally will be subject to the information reporting requirements of the Code and may be subject to backup withholding unless the U.S. Holder provides an accurate taxpayer identification number and makes any other required certification or otherwise establishes an exemption. Backup withholding is not an additional tax. The amount of any backup withholding from a payment to a U.S. Holder will be allowed as a refund or credit against the U.S. Holder’s U.S. federal income tax liability, provided the required information is furnished to the U.S. Internal Revenue Service in a timely manner.
Material Argentine Tax Considerations
The following discussion is a summary of the material Argentine tax considerations relating to the purchase, ownership and disposition of our common shares or ADSs. The following summary is based upon tax laws of Argentina as in effect on the date of this document and is subject to any change in Argentine law that may come into effect after such date any change could apply retroactively and could affect the continued validity of this summary.
This summary considers the most relevant aspects of Argentine tax law as of the date of this document, nevertheless, it does not include all of the tax considerations that may be relevant to you or your situation, particularly if you are subject to special tax rules.
This summary does not purport to be a comprehensive description of all the Argentine tax considerations that may be relevant to a holder of such securities. No assurance can be given that the courts or tax authorities responsible for the administration of the laws and regulations described in this report will agree with this interpretation. In this regard, due to recent nature of certain modifications to Argentine tax law, it is not possible to determine how the relatively new regulations will be applied and/or construed by the tax authorities of Argentina. Holders are encouraged to consult their tax advisors regarding the tax treatment of our ADSs or common shares as it relates to their particular situation.
Income Tax
Taxation on Dividends
Taxation applicable on the distribution of dividends from Argentine Companies would be as follows:
(i) Dividends originated in profits obtained during tax periods initiated before January 1, 2018: no Argentine income tax withholding (“ITW”) would apply except for the application of the “Equalization Tax” (as defined below).
(ii) Dividends originated in profits obtained during fiscal years initiated after January 1, 2018 and up to December 31, 2020:
-Non Argentine residents and Argentine resident individuals and undivided estates: dividends on Argentine shares would be subject to a 7% ITW on the amount of such dividends (“Dividend Tax”).
-Argentine Entities (in general defined as entities organized or incorporated under Argentine law, certain traders and intermediaries, local branches of non-Argentine entities, sole proprietorships and individuals carrying on certain commercial activities in Argentina, the “Argentine Entities”): no Dividend Tax should apply.
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(iii) Dividends originated in profits obtained during fiscal years initiated after January 1, 2021 onward:
-Non Argentine residents and Argentine resident individuals (and undivided estates): Due to the amendments introduced by Law N° 27,630, dividends on Argentine shares would be subject to a 7% ITW on the amount of such dividends...
-Argentine Entities: no Dividend Tax should apply.
The Income Tax Law provides a first in-first out rule pursuant to which distributed dividends correspond to the former accumulated profits of the distributing company.
Argentine individuals and undivided estates located in Argentina are not allowed to offset income arising from the distribution of dividends on Argentine shares with other losses arising from other type of operations. For Argentine individuals and undivided estates not registered before the Argentine tax authorities as taxpayers for income tax purposes as well as for non-Argentine residents, the Dividend Tax withholding will be considered a final payment.
The equalization tax (the “Equalization Tax”) is applicable, for income accrued in tax periods initiated before January 1st, 2018, when the dividends distributed are higher than the “net accumulated taxable income” of the immediate previous fiscal period from when the distribution is made. In order to assess the “net accumulated taxable income” from the income calculated by the Income Tax Law, the income tax paid in the same fiscal period should be subtracted and the local dividends received in the previous fiscal period should be added to such income. The Equalization Tax would be imposed as a 35% withholding tax on the shareholder receiving the dividend. Dividend distributions made in property (other than cash) would be subject to the same tax rules as cash dividends. Stock dividends on fully paid shares (“acciones liberadas”) are not subject to Equalization Tax.
Holders are encouraged to consult a tax advisor as to the particular Argentine income tax consequences derived from profit distributions made on ADSs or common shares.
Capital gains tax
According to Income Tax regulations, the results derived from the transfer of shares, quotas and other equity interests, titles, bonds and other securities, are subject to Argentine income tax (unless an exemption applies), regardless of the type of beneficiary who realizes the gain are subject to the following tax treatment:
-Argentine Entities: Capital gains obtained by Argentine Entities derived from the sale, exchange or other disposition of shares in Argentine entities are subject to income tax on the net income at the rate of 30% for fiscal years initiated after January 1, 2018 and up to December 31, 2020. As from fiscal periods initiated from January 1, 2021, the corporate income tax rate was amended, establishing a progressive tax rate system (rates from 25% to 35% depending on the net accumulated taxable income). The current progressive rates apply as indicated below:
Accumulated net taxable income | Shall pay ARS
| Plus %
| On the amount exceeding
| |
More than ARS | To ARS | |||
ARS 0 | ARS 5,000,000 | ARS 0 | 25% | ARS 0 |
ARS 5,000,000 | ARS 50,000,000 | ARS 1,250,000 | 30% | ARS 5,000,000 |
ARS 50,000,000 | Onwards | ARS 14,750,000 | 35% | ARS 50,000,000 |
The amounts stated in the chart above will be annually updated since January 1, 2022 based on an inflation index.
Losses arising from the sale of shares can only be offset against income derived from the same type of operations, for a five-year carryover period.
-Argentine Individuals and undivided estates: Starting in 2018, income obtained for the sale, exchange or other disposition of common shares is exempt from capital gains tax in the following cases: (i) when the shares are placed through a public offering authorized by the CNV; and/or (ii) when the shares are traded in stock markets authorized by the CNV, under segments that ensure priority of price-time and interference of offers; and/or (iii) when the sale, exchange or other disposition of shares is made through a tender offer regime and/or exchange of shares authorized by the CNV. In addition, Section 34 of Law N° 27,541, provides that since tax period 2020, in the case of securities under the provisions of Section 98 of the Income Tax Law, not included in the first paragraph of Section 26 subsection u) of the Income Tax Law, Argentine resident individuals and undivided estates located in Argentina are exempt from capital gains tax derived from their sale, exchange, or disposal to the extent said securities are listed on stock exchanges or securities markets authorized by the CNV, without being applicable the provisions of Section 109 of the Income Tax Law. In this sense, Section 109 of the Income Tax Law provides that the total or partial exemptions established or that will be established in the future by special laws regarding securities, issued by the National, Provincial, or Municipal States or the City of Buenos Aires, will not have effects on income tax for Argentine resident individuals and undivided estates located in Argentina.
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ADSs would not qualify for the capital gains tax exemption indicated above, since the referred conditions would not be met. If the exemption does not apply, the income derived from the sale, exchange or other disposition of ADSs (and shares, if applicable) is subject to income tax at a 15% rate on net income, calculated under the Argentine Income Tax Law rules. The acquisition cost may be updated pursuant to the IPC inflationary index rate to the extent the equity participation was acquired after January 1, 2018. Losses arising from the sale of non-exempt Argentine shares can only be offset by Argentine individuals and undivided estates located in Argentina against income derived from operations of the same source and type (understanding by “type” the different concepts of income included under each article of Chapter II, Title IV of the Income Tax Law), for a five-year carryover period.
If Argentine resident individuals and undivided estates located in Argentina perform a conversion procedure of securities representing shares, that do not meet the exemption requirements stated in the conditions mentioned in points (i), (ii) and (iii) above, to hold instead the underlying shares that do comply with said requirements, such conversion would be considered a taxable transfer of the securities representing shares for which the fair market value by the time the conversion takes place should be considered. The same tax treatment will apply if the conversion process involves shares that do not meet the exemption requirements stated above that are converted into securities representing shares to which the exemption is applicable. Once the underlying shares or securities representing shares are converted, the results obtained from the sale, exchange, swap or any other disposition thereof would be exempt from income tax provided that the conditions mentioned in points (i), (ii) and (iii) of the paragraph above are met. Pursuant to amendments introduced by Law N° 27,541, it could also be construed that a capital gains exemption could also apply for Argentine resident individuals and undivided estates located in Argentina if the securities involved are listed on stock exchanges or securities markets authorized by the CNV (although the matter is not free from doubt and further clarifications should be issued).
-Non Argentine Residents: Due to the amendments introduced to the Income Tax Law, as from 2018, non-Argentine resident individuals or legal entities (“Foreign Beneficiaries”) are also exempt from income tax on the capital gains derived from the sale of Argentine shares in the following cases: (i) when the shares are placed through a public offering authorized by the CNV; and/or (ii) when the shares are traded in stock markets authorized by the CNV, under segments that ensure priority of price-time and interference of offers; and/or or (iii) when the sale, exchange or other disposition of shares is made through a tender offer regime and/or exchange of shares authorized by the CNV. The exemption applies to the extent the Foreign Beneficiaries reside in a “cooperative jurisdiction” and, in accordance with Section 90 of the regulatory decree of the Income Tax Law, if their funds come from “cooperative jurisdictions” (as defined below). Capital gains obtained from the sale, exchange or other disposition of ADSs by Foreign Beneficiaries, provided that they reside in a cooperative jurisdiction and their funds come from cooperative jurisdictions, are exempt from income tax on capital gains, to the extent the underlying shares are authorized for public offering by the CNV. In case Foreign Beneficiaries conduct a conversion process of shares that do not meet the exemption requirements, into securities representing shares that are exempt from income tax pursuant to the conditions stated above, such conversion would be considered a taxable transfer for which the fair market value by the time the conversion takes place should be considered.
In case the exemption is not applicable and the Foreign Beneficiaries are resident in a cooperative jurisdiction and their funds were channeled through cooperative jurisdictions, the gain derived from the disposition of common shares or ADSs would be subject to Argentine income tax at a 15% rate on the net capital gain or at a 13.5% effective rate on the gross price.
For Foreign Beneficiaries resident in, or whose funds come from, non-cooperative jurisdictions, the tax rate applicable to the sales of shares and/or ADSs is assessed at 35% on a presumed net basis of 90% of the gross sale price.
General Resolution (AFIP) N°4227/2018 provides different payment mechanisms for the applicable tax on Foreign Beneficiaries, depending on the specific circumstances of the sale transaction. Pursuant to Section 252 of the regulatory decree of the Income Tax Law, in the cases included in the last paragraph of Section 98 of the Income Tax Law, (i.e. when the acquirer and the seller of the security involved are non-Argentine residents), the tax shall be paid by the foreign seller directly through the mechanism established for such purpose by the tax authorities, or (i) through an Argentine individual resident with sufficient mandate or (ii) by the foreign seller’s legal representative domiciled in Argentina.
Holders are encouraged to consult a tax advisor as to the particular Argentine income tax consequences derived from holding and disposing of ADSs or common shares and whether any different treatment under a treaty to avoid double taxation could apply.
Tax treaties
Argentina has signed tax treaties for the avoidance of double taxation with Australia, Belgium, Bolivia, Brazil, Canada, Chile, Denmark, Finland, France, Germany, Italy, Mexico, the Netherlands, Norway, Russia, Spain, Sweden, Switzerland, the UK the United Arab Emirates, Qatar and Uruguay.. The treaties signed with China, Luxembourg, Turkey, Austria and Japan are still undergoing the respective ratification procedures. There is no tax treaty for the avoidance of double taxation in effect between Argentina and the United States. Holders are encouraged to consult a tax advisor as to the potential application of the provisions of a treaty in their specific circumstances.
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Personal assets tax
Argentine entities, have to pay the personal assets tax corresponding to Argentine and foreign resident individuals and foreign resident entities for the holding of company shares by December 31 of each year. For Personal Assets Tax purposes, Law N° 27,541 (published in the Official Gazette on December 23, 2019) and Decree No. 99/2019 changed the “domicile” criterion for the “residence” criterion as stipulated under income tax rules. For tax period 2019, inclusive, and onwards the applicable tax rate is 0.50% and is levied on the proportional net worth value (“valor patrimonial proporcional”) by December 31st of each year, of the shares arising from the last balance sheet. Pursuant to the Personal Assets Tax Law, the Argentine company is entitled to seek reimbursement of such paid tax from the applicable Argentine resident individuals and/or foreign resident shareholders. The Argentine company may seek this reimbursement of Personal Assets Tax by setting off the applicable tax against any amount due to its shareholders or in any other way or, under certain circumstances, waive its right under Argentine law to seek reimbursement from the shareholders.
Holders are encouraged to consult a tax advisor as to the particular Argentine personal assets tax consequences derived from the holding of ADSs or common shares.
Value added tax
The sale, exchange or other disposition of our ADSs or common shares and the distribution of dividends are exempted from the value added tax.
Tax on debits and credits on Argentine bank accounts
All credits and debits originated in bank accounts held at Argentine financial institutions, as well as certain cash payments, are subject to this tax, which is assessed at a general rate of 0.6%. There are also increased rates of 1.2% and reduced rates of 0.075%. According to Section 45 of Law N° 27,541, the applicable rate of tax on debits and credits on Argentine bank accounts (the “TDC”) is doubled for certain cash withdrawals made by certain Argentine legal entities. Owners of bank accounts subject to the general 0.6% and taxpayers subject to the 1.2% tax rate may consider 33% of the tax paid as a credit for income tax and or for the special contributions on cooperatives capital. The remaining amount is deductible for income tax purposes. If lower rates were applied, the available credit would be reduced to 20%. Additionally, Law No. 27,264 establishes that the 100% of the tax paid may be considered as credit against income tax by entities that are characterized as “micro” and “small” and a 60% of the tax paid by those entities related to the manufacturing industry that are characterized as “medium - stage 1-” by means of section 1 of Law No. 25,300 and its complementary ones.
TDC has certain exemptions. Debits and credits in special checking accounts (created under Communication “A” 3250 of the Argentine Central Bank) are exempted from this tax if the accounts are held by foreign legal entities and if they are exclusively used for financial investments in Argentina. For certain exemptions and/or tax rate reductions to apply, bank accounts must be registered with the Tax Authority (AFIP-DGI) in accordance with General Resolution (AFIP) No.3900/2016.
Pursuant to Law No. 27,432 (published in the Official Gazette on December 29, 2017), the TDC shall apply until December 31, 2022, inclusive.
It is noted that according to Decree No. 796/2021, the TDC exemptions foreseen in Decree No. 380/2001 and other regulations of the same nature shall not be applicable in those cases where cash payments are related to the purchase, sale, exchange, intermediation and/or any other type of operation on crypto assets, cryptocurrencies, digital currencies or similar instruments, in the terms defined by the applicable rules.
Tax on minimum presumed income
Pursuant to Law No. 27,260, passed by the Argentine Congress on June 29, 2016, the tax on minimum presumed income was eliminated for tax periods beginning as of January 1, 2019.
PAIS Tax (“Impuesto para una Argentina inclusiva y solidaria”)
Law N° 27,541 establishes, on an emergency basis and for the term of five fiscal periods from the entry into force of said law (i.e. December 23,2019), a federal tax applicable to certain transactions for the purchase of foreign currency for saving purposes or without a specific destination and other operations of currency exchange and acquisition of services performed by Argentine tax residents (individuals, undivided estates, legal entities, among others). The applicable rate is, in general, 30%.
Investors should consider the provisions that apply to them according to their specific case.
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In addition, General Resolution (AFIP) N° 4815/2020 established on the operations subject to PAIS Tax and for the taxpayers defined in Article 36 of Law N° 27,541 that qualify as Argentine residents, in the terms of Article 116 and subsequent of the Income Tax Law, the application of a thirty-five percent (35%) collection on the amounts in Ps. that, for each case, are detailed in Article 39 of the Law 27,541. Said collection will have the character of payment on account and will be computable in the annual income tax return or, where appropriate, the annual personal assets tax return, corresponding to the fiscal period in which they were incurred.
Gross turnover tax
This tax is a provincial tax, which is also levied in the City of Buenos Aires, applicable to gross revenues resulting from the regular and onerous exercise of commerce, industry, profession, business, services or any other onerous activity conducted on a regular basis within the respective Argentine jurisdiction. Each of the provinces and the City of Buenos Aires apply different tax rates depending on the type of activity.
In addition, gross turnover tax could be applicable on the transfer of ADSs or common shares and on the perception of dividends to the extent, such activity is conducted on a regular basis within an Argentine province or within the City of Buenos Aires. However, under the Tax Code of the City of Buenos Aires, any transaction with shares as well as the perception of dividends are exempt from gross turnover tax.
In accordance with the stipulations of the Fiscal Consensus entered into by and amongst the Argentine Executive Branch, the representatives of the Provinces and the City of Buenos Aires on November 16, 2017 and approved by the Argentine Congress on December 21, 2017 (the so-called “Fiscal Consensus” and/or the “Consensus”), local jurisdictions took on certain commitments in connection with certain taxes that are within their powers. The Consensus shall be effective only in connection with the jurisdictions that have their legislative branches approve the Consensus and such effectiveness shall not commence if such approval has not been granted. When it comes to the impact of the Consensus on gross turnover tax, the Argentine provinces and the City of Buenos Aires agreed to grant exemptions and impose maximum tax rates on certain businesses and for certain periods.
However, the Argentine Executive Branch, the representatives of the Provinces and the City of Buenos Aires signed three agreements to suspend the Fiscal Consensus. Recently, Fiscal Consensus 2021 was signed between the Argentine Executive Branch and the representatives of the Provinces -except for the City of Buenos Aires- (the “Fiscal Consensus 2021”) in which it was agreed to suspend all the commitments made the parties by means of the previous Fiscal Consensus 2017, 2018, 2019 and 2020, maintaining only its enforcement those that have been complied with at the date of signing of the Fiscal Consensus 2021. These agreements shall be effective only in connection with the jurisdictions that have their legislative branches approve them and such effectiveness shall not commence if such approval has not been granted.
Holders of ADSs or common shares are encouraged to consult a tax advisor as to the particular gross turnover tax consequences of holding and disposing of ADSs or common shares in the involved jurisdictions.
Regimes for the Collection of Provincial Tax Revenues on the Amounts Credited to Bank Accounts
Different tax authorities (i.e., City of Buenos Aires, Corrientes, Córdoba, Tucumán, Province of Buenos Aires and Salta, among others) have established collection regimes for gross turnover tax purposes applicable to those credits verified in accounts opened at financial entities, of any type and/or nature and including all branch offices, irrespective of territorial location. These regimes apply to those taxpayers included in the lists provided monthly by the tax authorities of each jurisdiction. The applicable rates may vary depending on the jurisdiction involved. Collections made under these regimes shall be considered as a payment on account of the gross turnover tax. Note that certain jurisdictions have excluded the application of these regimes on certain financial transactions.
By means of Fiscal Consensus 2021, the parties assumed the commitment to take the necessary measures according to the procedures established in each jurisdiction with the aim to apply any turnover tax automatic refund or compensation mechanism for those taxpayers (either local or subject to the Multilateral Convention rules) that have outstanding balances in their favor generated by withholdings, collections and/or similar ones, to the extent certain specific requirements are met in each case
Holders of ADSs should consult a tax advisor regarding the potential application of this collection regime.
Stamp tax
Stamp tax is a provincial tax, which is also levied in the City of Buenos Aires, applicable to the execution of onerous transactions within an Argentine provincial jurisdiction or the City of Buenos Aires or outside an Argentine provincial jurisdiction or the City of Buenos Aires but with effects in such jurisdiction.
In the City of Buenos Aires, acts or instruments related to the negotiation of shares and other securities duly authorized for its public offering by the CNV are exempt from stamp tax to the extent their placement is made within a 180-days term counting as from such authorization is granted.
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Regarding the Fiscal Consensus, almost all the provinces in Argentina and the City of Buenos Aires have committed to establish for the stamp tax a maximum tax rate of 0.75% as from January 1, 2019, 0.5% as from January 1, 2020, 0.25% as from January 1,2021 and abrogate the stamp tax starting from January 1, 2022. However, such commitment was delayed by one calendar year pursuant Law No 27,469 “Fiscal Consensus 2018” (published in the Official Gazette on December 4, 2018). Fiscal Consensus 2018 shall be effective only in connection with the jurisdictions that have their legislative branches approve it and such effectiveness shall not commence if such approval has not been granted. However, later the Argentine Executive Branch, the representatives of the Provinces and the City of Buenos Aires signed Fiscal Consensus 2019 and 2020 to suspend the Fiscal Consensus 2017 and the Fiscal Consensus 2018. Recently, Fiscal Consensus 2021 was signed between the Argentine Executive Branch and the representatives of the Provinces -except for the City of Buenos Aires- in which it was agreed to suspend all the commitments made the parties by means of the previous Fiscal Consensus 2017, 2018, 2019 and 2020, maintaining only its enforcement those that have been complied with at the date of signing the Fiscal Consensus 2021. These agreements shall be effective only in connection with the jurisdictions that have their legislative branches approve them and such effectiveness shall not commence if such approval has not been granted.
Holders of ADSs or common shares are encouraged to consult a tax advisor as to the particular stamp tax consequences arising in the involved jurisdictions.
Other taxes
There are no federal inheritance or succession taxes applicable to the ownership, transfer or disposition of our ADSs or common shares.. However, it is noted that pursuant to the Fiscal Consensus 2021 signed between Argentine Executive Branch and the representatives of the Provinces -except for the City of Buenos Aires- by means of which the parties assumed the commitment to legislate during 2022 a tax applicable on any increase in wealth obtained as a result of any free transmission or act of such nature, which includes assets located in their territory and/or that benefits individuals or legal entities domiciled in them. Increasing marginal rates would be applicable as the amount transferred increases in order to grant progressiveness to the tax, reaching all transmissions that imply a patrimonial enrichment for free, including, but not limited to, inheritances, donations, legacies and inheritance advances.
At the provincial level, the province of Buenos Aires imposes a tax on free transmission of assets, including inheritance, legacies, donations, etc. For tax period 2021, any gratuitous transfer of property lower than or equal to Ps.468,060 is exempt. This amount is increased to Ps.1,948,800 in the case of transfers among parents, sons, daughters and spouses. The amount to be taxed, which includes a fixed component and a variable component that is based on differential rates (which range from 1.6026% to 9.5131%), varies according to the property value to be transferred and the degree of kinship of the parties involved. Free transmission of ADSs or common shares could be subject to this tax.
Holders of ADSs or common shares are encouraged to consult a tax advisor as to the particular tax consequences arising in the involved jurisdictions.
Court tax
In the event that it becomes necessary to institute enforcement proceedings in relation to our ADSs or common shares in the federal courts of Argentina or the courts sitting in the City of Buenos Aires, a court tax (currently at a rate of 3.0%) will be imposed on the amount of any claim brought before such courts. Certain court and other taxes could be imposed on the amount of any claim brought before the Province courts.
Non-cooperative jurisdictions and Low-or-nil-tax jurisdictions
According to Section 82 of Law No. 27,430, for fiscal purposes, any reference to “low tax or no tax countries” or “non-cooperative countries” should be understood to be “non-cooperative jurisdictions or low or nil tax jurisdictions,” as defined in Section 19 and Section 20 of the Income Tax Law.
Section 19 of the Argentine Income Tax Law defines non-cooperative jurisdictions as those countries or jurisdictions that do not have an agreement in force with the Argentine government for the exchange of information on tax matters or a treaty to avoid international double taxation with a broad clause for the exchange of information. Those jurisdictions that, having an agreement of this type in force, do not effectively comply with the exchange of information will also be considered as non-cooperative. The aforementioned treaties and agreements must comply with international standards of transparency and exchange of information on fiscal matters to which the Argentine Republic has committed. Section 24 of the regulatory decree of the Income Tax Law establishes the list of jurisdictions deemed as “non-cooperative” under Section 19 of the aforementioned law.
In turn, Section 20 of the Argentine Income Tax Law defines low or nil tax jurisdictions as those countries, domains, jurisdictions, territories, associated states or special tax regimes in which the maximum corporate income tax rate is lower than 60% of the corporate income tax rate established in the first paragraph of Section 73 of the Income Tax Law.
Pursuant to Section 25 of the regulatory decree of the Income Tax Law, for purposes of determining the taxation level referred to in Article 20 of the Income Tax Law, taxpayers should consider the aggregate corporate tax rate applicable in each jurisdiction, regardless of the governmental level in which the taxes were levied. In turn, “special tax regime” is understood as any regulation or specific scheme that departs from the general corporate tax regime applicable in said country and results in an effective rate below that stated under the general regime.
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Holders of ADSs or common shares are encouraged to consult a tax advisor as to the particular tax consequences arising for them related to non-cooperative jurisdictions or low-or-nil-tax jurisdictions.
Incoming Funds Arising from Non-Cooperative or Low or Nil Tax Jurisdictions
According to the legal presumption under Section 18.2 of Law No. 11,683, as amended, incoming funds from non-cooperative or low or nil jurisdictions could be deemed unjustified net worth increases for the Argentine party, no matter the nature of the operation involved. Unjustified net worth increases are subject to the following taxes:
| · | income tax would be assessed at 110% of the amount of funds transferred. |
| · | value added tax would be assessed at 110% of the amount of funds transferred. |
Although the concept of “incoming funds” is not clear, it should be construed as any transfer of funds:
(i) from an account in a non-cooperative/low or nil tax jurisdiction or from a bank account opened outside of a non-cooperative or low or nil tax jurisdiction but owned by an entity located in a non-cooperative or low or nil tax jurisdiction;
(ii) to a bank account located in Argentina or to a bank account opened outside of Argentina but owned by an Argentine party.
The Argentine party may rebut such legal presumption by duly evidencing before the Argentine tax authority that the funds arise from activities effectively performed by the Argentine party or by a third party in such jurisdiction, or that such funds have been previously declared.
THE ABOVE SUMMARY IS NOT INTENDED TO BE A COMPLETE ANALYSIS OF ALL ARGENINE TAX CONSEQUENCES RELATING TO THE OWNERSHIP OR DISPOSITION OF ADSs OR COMMON SHARES. HOLDERS ARE ENCOURAGED TO CONSULT THEIR TAX ADVISORS CONCERNING THE TAX CONSEQUENCES ARISING IN EACH PARTICULAR CASE.
Item 10.F Dividends and paying agents
Not applicable.
Item 10.G Statement by experts
Not applicable.
Item 10.H Documents on display
We are subject to the information requirements of the Securities Exchange Act of 1934, as amended, or the Exchange Act. In accordance with these requirements, we file reports and other information with the SEC. These materials, including this annual report and the accompanying exhibits, may be inspected and copied at the SEC’s Public Reference Room at 100 F Street, N.E., Room 1580, Washington, D,C, 20549. Copies of the materials may be obtained from the SEC’s Public Reference Room at prescribed rates. The public may obtain information on the operation of the SEC’s Public Reference Room by calling the SEC in the United States at 1-800-SEC-0330. In addition, the SEC maintains an internet website that contains filings, reports and other information regarding issuers who, like us, file electronically with the SEC. The address of that website is http://www.sec.gov.
We remind investors that we are required to file financial statements and other periodic reports with the CNV because we are a public company in Argentina. Investors can access our historical financial statements published in Spanish on the CNV’s website at www.cnv.gob.ar. The information found on the CNV’s website is not a part of this annual report. Investors are cautioned not to place undue reliance on our financial statements or other information not included in this annual report.
Item 10.I. Subsidiary Information
Not applicable.
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Item 11. Quantitative and Qualitative Disclosures about Market Risk
Financial Risk Management Goals and Policies
Our principal financial liabilities comprise of bank loans and borrowings from CAMMESA and trade and other payables. The main purpose of these financial liabilities is to finance our operations. We have trade and other receivables, and cash and cash equivalents that result directly from our operations. We also have financial assets at fair value through profit and loss.
Due to our business activity, we are exposed to the following financial risks: market risk, credit risk and liquidity risk. We continuously monitor these risks to minimize the potential negative impact they could have on our finances.
Market Risk
Market risk is the risk of changes in the fair value or the future cash flows of financial instruments due to fluctuations in market prices. The market risks affecting our business include interest rate risk, foreign currency risk and price risk.
Interest Rate Risk
See Note 19 to our audited and consolidated Financial Statements for the period ended December 31, 2021.
Interest rate sensitivity
See Note 19 to our audited and consolidated Financial Statements for the period ended December 31, 2021.
Foreign Currency Risk
See Note 19 to our audited and consolidated Financial Statements for the period ended December 31, 2021.
Foreign currency sensitivity
See Note 19 to our audited and consolidated Financial Statements for the period ended December 31, 2021.
Price Risk
See Note 19 to our audited and consolidated Financial Statements for the period ended December 31, 2021.
Credit Risk
See Note 19 to our audited and consolidated Financial Statements for the period ended December 31, 2021.
See “Item 3.D.—Risk Factors—Risks Relating to Our Business—Our results depend largely on the compensation established by the Secretariat of Electric Energy and received from CAMMESA” and “Item 3.D.—Risk Factors—Risks Relating to the Electric Power Sector in Argentina—We have, in the recent past, been unable to collect payments, or to collect them in a timely manner, from CAMMESA and other customers in the electric power sector.”
We are entitled to receive payments from CAMMESA under the Energía Base within 42 days after the date of billing. In recent years, due to regulatory conditions in Argentina’s electric power sector that affected the profitability and economic viability of power utilities, certain WEM agents defaulted on their payments to CAMMESA, which adversely affected CAMMESA’s ability to meet its payment obligations to electric power generators, including us. As a consequence, in the past, we have seen CAMMESA pay more than 90 days after month-end, rather than the required 42 days after the date of billing. Such payment delays would result in higher working capital requirements than we would typically have to finance with our own financing sources.
For these delays, we are entitled to receive interests from CAMMESA. Payments related to PPAs under the Renovar Regulatory Framework have not suffered delays. CAMMESA may once again be unable to make payments to generators both in respect of energy dispatched and generation capacity availability on a timely basis or in full, which may substantially and adversely affect our financial position and the results of our operations.
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The chart below shows the payment cycle of CAMMESA (for sales under the Energía Base) in terms of number of days after the due date that CAMMESA took to pay the balances each month from January 2018 to Novembre 2021.
Source: Central Puerto
Due to the COVID-19 pandemic crisis, we have experienced, and expect to continue experiencing, delays in certain payments from CAMMESA.
Under our contracts with YPF, we typically issue monthly invoices and YPF pays them within 35 to 45 days after they are issued. Our invoices are issued in U.S. dollars) and payments are made in pesos at the exchange rate as of the date of the payment.
Under our PPAs pursuant to Energía Plus, we typically issue monthly invoices and the off-taker pays them within 20 to 30 days after they are issued. The tariff for the energy sold is set in U.S. dollars. Our invoices can be issued in U.S. dollars or pesos converted into U.S.$ , and are payable in pesos at the exchange rate as of the date of the payment, with the off-taker in this second case typically covering any exchange rate fluctuations as a result of any payment delay through credit or debit payments.
With respect to the FONINVEMEM program, after commercial authorization was granted to the Manuel Belgrano power plant (on January 7, 2010) and the San Martín power plant (on February 2, 2010), we started to collect monthly partial payments of our outstanding receivables from electric power sales from January 2004 through December 2007. These receivables were denominated in U.S. dollars bearing interest at LIBOR plus 1% (for receivables paid from the proceeds of the Manuel Belgrano plant) and 2% (for receivables paid from the proceeds of the “San Martín” power plant), and payments were made in pesos at the exchange rate as of the date of the payment.
During January and February 2020 we collected the last installments from the total 120 installments that were established by TMB and TSM agreements, respectively.
Regarding the CVO Agreement, effective as of March 20, 2018, CAMMESA granted the CVO Commercial Approval in the WEM, as a combined cycle, of the thermal plant Central Vuelta de Obligado, which entitled us to receive the collection of the trade receivables under the CVO Agreement. A PPA between the CVO Trust and CAMMESA, through which the CVO Trust makes energy sales and, consequently, receives the cash flow to pay the trade receivables, had to be signed in order to start the collections. The PPA agreement was signed on February 7, 2019, with retroactive effect to March 20, 2018.
As a result, the original amortization schedule from the CVO Agreement is in full force and effect.
During 2020, we collected Ps. 9.5 billion in CVO receivables, measured in current amounts as of December 31, 2021.
During 2021, we collected Ps. 8.2 billion in CVO receivables, measured in current amounts as of December 31, 2021.
Liquidity Risk
See Note 19 to our audited and consolidated Financial Statements for the period ended December 31, 2021.
Item 12. Description of Securities Other Than Equity Securities
Item 12.A Debt Securities
Not applicable.
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Item 12.B Warrants and Rights
Not applicable.
Item 12.C Other Securities
Not applicable.
Item 12.D American Depositary Shares
Fees and Charges
As an ADS holder, you will be required to pay the following fees under the terms of the deposit agreement:
Service |
| Fees |
Issuance of ADSs (e.g., an issuance of ADS upon a deposit of common shares, upon a change in the ADS(s)-to-common share(s) ratio, or for any other reason), excluding ADS issuances as a result of distributions of common shares) |
| Up to U.S. 5¢ per ADS issued |
Cancellation of ADSs (e.g., a cancellation of ADSs for delivery of deposited property, upon a change in the ADS(s)-to-common share(s) ratio, or for any other reason) |
| Up to U.S. 5¢ per ADS cancelled |
Service |
| Fees |
Distribution of cash dividends or other cash distributions (e.g., upon a sale of rights and other entitlements) |
| Up to U.S. 5¢ per ADS held |
Distribution of ADSs pursuant to (i) stock dividends or other free stock distributions, or (ii) exercise of rights to purchase additional ADSs |
| Up to U.S. 5¢ per ADS held |
Distribution of securities other than ADSs or rights to purchase additional ADSs (e.g., upon a spin-off) |
| Up to U.S. 5¢ per ADS held |
ADS Services |
| Up to U.S. 5¢ per ADS held on the applicable record date(s) established by the depositary bank |
As an ADS holder you will also be responsible to pay certain charges such as:
| · | taxes (including applicable interest and penalties) and other governmental charges; |
| · | the registration fees as may from time to time be in effect for the registration of common shares on the share register and applicable to transfers of common shares to or from the name of the custodian, the depositary bank or any nominees upon the making of deposits and withdrawals, respectively; |
| · | certain cable, telex and facsimile transmission and delivery expenses; |
| · | the expenses and charges incurred by the depositary bank in the conversion of foreign currency; |
| · | the fees and expenses incurred by the depositary bank in connection with compliance with exchange control regulations and other regulatory requirements applicable to common shares, ADSs and ADRs; and |
| · | the fees and expenses incurred by the depositary bank, the custodian, or any nominee in connection with the servicing or delivery of deposited property. |
ADS fees and charges for (i) the issuance of ADSs, and (ii) the cancellation of ADSs are charged to the person for whom the ADSs are issued (in the case of ADS issuances) and to the person for whom ADSs are cancelled (in the case of ADS cancellations). In the case of ADSs issued by the depositary bank into DTC, the ADS issuance and cancellation fees and charges may be deducted from distributions made through DTC, and may be charged to the DTC participant(s) receiving the ADSs being issued or the DTC participant(s) holding the ADSs being cancelled, as the case may be, on behalf of the beneficial owner(s) and will be charged by the DTC participant(s) to the account of the applicable beneficial owner(s) in accordance with the procedures and practices of the DTC participants as in effect at the time. ADS fees and charges in respect of distributions and the ADS service fee are charged to the holders as of the applicable ADS record date. In the case of distributions of cash, the amount of the applicable ADS fees and charges is deducted from the funds being distributed. In the case of (i) distributions other than cash and (ii) the ADS service fee, holders as of the ADS record date will be invoiced for the amount of the ADS fees and charges and such ADS fees and charges may be deducted from distributions made to holders of ADSs. For ADSs held through DTC, the ADS fees and charges for distributions other than cash and the ADS service fee may be deducted from distributions made through DTC, and may be charged to the DTC participants in accordance with the procedures and practices prescribed by DTC and the DTC participants in turn charge the amount of such ADS fees and charges to the beneficial owners for whom they hold ADSs.
In the event of refusal to pay the depositary bank fees, the depositary bank may, under the terms of the deposit agreement, refuse the requested service until payment is received or may set off the amount of the depositary bank fees from any distribution to be made to the ADS holder. Certain of the depositary fees and charges (such as the ADS services fee) may become payable shortly after the closing of the ADS offering. Note that the fees and charges you may be required to pay may vary over time and may be changed by us and by the depositary bank. You will receive prior notice of such changes. The depositary bank may reimburse us for certain expenses incurred by us in respect of the ADR program, by making available a portion of the ADS fees charged in respect of the ADR program or otherwise, upon such terms and conditions as we and the depositary bank agree from time to time. Accordingly, on January 18, 2019, we received US$1,066,706.10 from the depositary bank.
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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
Evaluation of Disclosure Controls and Procedures
(a) Evaluation of Disclosure Controls and Procedures
Our company, under the supervision and with the participation of our chief executive officer and chief financial officer, has evaluated the effectiveness of the design and operation of the Company’s disclosure controls and procedures pursuant to 13a-15(e) of the Exchange Act, as of December 31, 2021.
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 effective disclosure controls and procedures can only provide reasonable assurance of achieving their control objectives. Based upon their evaluation, our company’s Chief Executive Officer and Chief Financial Officer concluded that as of December 31, 2021, our disclosure controls and procedures were effective to provide reasonable assurance of achieving their control objectives.
(b) Management’s 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 15d-15(f) under the Securities Exchange Act of 1934. The company’s internal control over financial reporting was designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with International Financial Reporting Standards (“IFRS”) as issued by the International Accounting Standards Board. The company’s internal control over financial reporting includes those policies and procedures that:
| (i) | pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; |
| (ii) | provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with IFRS, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and |
| (iii) | 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.
Management assessed the effectiveness of the company’s internal control over financial reporting as of December 31, 2021. In making this assessment, management used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission (COSO) in Internal Control-Integrated Framework (2013). Based on our assessment and those criteria, management believes that the company maintained effective internal control over financial reporting as of December 31, 2021.
(c) Attestation report of the registered public accounting firm
Reference is made to the report of Pistrelli, Henry Martin y Asociados S.R.L. (a member firm of Ernst Young Global) on page F-1 of this annual report.
(d) Changes in internal controls over financial reporting
There was no change in our internal control over financial reporting that occurred during the period covered by this annual report that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.
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Item 16.A Audit committee financial expert
Mr. Tomás José White is our audit committee’s financial expert. He is an independent member of the audit committee under Rule 10A-3 and applicable NYSE standards.
Item 16.B Code of Ethics
We have adopted a “Code of Business Conduct” (the “code”) designed to establish guidelines with respect to professional conduct, morals and employee performance. This code applies to all directors, managers, heads and employees of the Company. The code is posted on our website at http://investors.centralpuerto.com/govdocs. In 2018, the code was amended to comply with the requirements set forth in Argentine Law No. 27.401 (the “Corporate Criminal Liability Law”), which include that the Company’s employees while dealing with public sector officers or agencies on behalf of the Company shall act with due care and shall avoid, at all times, circumstances that may be considered contrary to the public duties of such public sector officers, illicit enrichment of such public sector officers, bribery and influence-peddling, extortion and preparation of false balance sheets and reports. On March 9, 2018, our Audit Committee approved the amendment. In addition, we did not grant any waivers to the code during the year ended December 31, 2021
Item 16.C Principal Accountant Fees and Services
Pistrelli, Henry Martin y Asociados S.R.L. (a member firm of Ernst Young Global) acted as our independent registered public accounting firm for the fiscal years ended December 31, 2021 and 2020. The following tables sets forth the total amount billed to us and our subsidiaries for the indicated fiscal years (stated in the current measurement unit as of December 31, 2021):
|
| 2021 |
|
| 2020 |
| ||
|
| (in thousands of Ps.) |
| |||||
Audit Fees |
|
| 54,400 |
|
|
| 47,548 |
|
Tax Fees |
|
| 1,800 |
|
|
| 1,909 |
|
All other fees |
|
| - |
|
|
| - |
|
Total |
|
| 56,200 |
|
|
| 49,457 |
|
Audit fees are fees billed for professional services rendered by the principal accountant for the audit of the registrant’s annual consolidated financial statements or services that are normally provided by the accountant in connection with statutory and regulatory filings or engagements for those fiscal years. It includes the audit of our annual consolidated financial statements, the reviews of our quarterly consolidated financial statements submitted to CNV and other services that generally only the independent accountant reasonably can provide, such as comfort letters, statutory audits, attestation services, consents and assistance with and review of documents filed with the SEC.
Tax fees are billed for professional services related to tax compliance and tax advice for fiscal years 2021 and 2020, respectively.
All other fees are billed for professional services related to assistance and training on the implementation of certain internal control procedures.
Audit Committee Pre-Approval Policies and Procedures
Consistent with SEC requirements regarding auditor independence, the Audit Committee pre-approves services prior to commencement of the specified service. Before any accountant is engaged to render audit or non-audit services, the engagement must be approved by the Audit Committee and the Audit Committee must pre-approve the provision of services by our principal auditor prior to commencement of the specified service. The Audit Committee has delegated the authority to grant pre-approvals to auditors’ services to its president. The decision of the president to pre-approve a service is presented to the full Audit Committee at each of its scheduled meetings.
All audit fees, audit-related fees, tax fees and other fees, if any, are submitted to our Audit Committee for prior approval. The Audit Committee evaluates the scope of the work to be performed by our accountants and the fees for such work prior to their engagement.
Consequently, 100% of the services and fees rendered by our principal accountants in 2021 were approved by the Audit Committee prior to their engagement to perform such work.
Item 16.D Exemptions from the Listing Standards for Audit Committees
Not applicable.
Item 16.E Purchases of Equity Securities by the Issuer and Affiliated Purchasers
None.
____________
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Item 16.F Change in Registrant’s Certifying Accountant
Not applicable.
Item 16.G Corporate Governance
NYSE Corporate Governance Rules
Under NYSE rules, foreign private issuers are subject to more limited corporate governance requirements than U.S. domestic issuers. As a foreign private issuer, we must comply with Sections 303A.06, 303A.11 and 303A.12(b) and (c) of the NYSE Listed Company Manual which set forth the following corporate governance rules: (i) we must satisfy the requirements of Rule 10A-3 of the Exchange Act relating to audit committees; (ii) our CEO must promptly notify the NYSE in writing after any executive officer becomes aware of any non-compliance with the applicable NYSE corporate governance rules; (iii) we must provide a brief description of any significant differences between our corporate governance practices and those followed by U.S. companies under NYSE listing standards; and (iv) we must provide the NYSE with annual and interim written affirmations as required under the NYSE corporate governance rules.
The table below briefly describes the significant differences between our Argentine corporate governance rules and the NYSE corporate governance rules:
Section |
| NYSE corporate governance rule for U.S. domestic issuers |
| Argentine corporate governance rules |
303A.01
|
| A listed company must have a majority of independent directors. “Controlled companies” are not required to comply with this requirement.
|
| A listed company must have at least two independent directors who form a majority of the Audit Committee.
|
303A. 02
|
| No director qualifies as “independent” unless the board of directors affirmatively determines that the director has no material relationship with the listed company (whether directly or as a partner, shareholder, or officer of an organization that has a relationship with the company), and emphasizes that the concern is independence from management. The board is also required, on a case by case basis, to express an opinion with regard to the independence or lack of independence, of each individual director.
|
| Pursuant to CNV Rules, a director is not independent if such director is:
(a) a member of management or an employee of shareholders who hold material holdings in the listed company or of other entities in which these shareholders have material holdings or over which these shareholders exercise a material influence;
(b) is currently an employee or has, in the last three years, been an employee of the listed company;
(c) a person who has a professional relationship or is part of a company or professional association that maintains professional relations with, or that receives remunerations or fees (other than directors’ fees) from, the listed company or from shareholders that have material holdings in the listed company, or with a company in which such shareholders have material holdings or exercise a material influence;
(d) a person who has material holdings in the listed company or in an entity that has material holdings in, or exercises a material influence over, the listed company;
(e) a person who directly or indirectly provides goods or services to the listed company or to shareholders that have material holdings in or exercise a material influence over the listed company and receives compensation for such services that is substantially higher than that received as director of the listed company; |
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| Table of Contents |
Section |
| NYSE corporate governance rule for U.S. domestic issuers |
| Argentine corporate governance rules |
|
|
|
|
(f) the member is married or is a family member to an individual who would not qualify as independent.
(g) the member is the director, CEO, administrator or principal executive from a non-profit organization which had received funds for amounts exceeding those established by Resolution No. 30/2011 of the UIF (currently equivalent to Ps.300,000), coming from the company, or a parent company;
(h) a person who receive any payments from the company or group companies other than fees as a director or dividends as shareholder; or
(i) a member of the administrative or supervisory committee and/or hold a significant participation (directly or indirectly) with respect to one or more companies that are registered as Agente de Negociación, Agente de Liquidación y Compensación y/o Agente de Corretaje de Valores Negociables.
It is necessary to comply with the conditions of independence for at least three years before the designation as a director.
The independent directors will cease to be independent after 10 years of holding its position of directors, and will be restored with its status of independent three years after leaving office.
“Material holdings” are shareholdings, either directly or indirectly, that represent at least 5% of the capital stock of the relevant entity, or a smaller percentage when the person has the right to elect one or more directors per class of shares or by having entered into agreements with other shareholders relating to the governance and the management of the relevant entity or of its controlling shareholders. |
|
|
|
|
|
303A.03 |
| The non-management directors of a listed company must meet at regularly scheduled executive sessions without management. |
| Neither Argentine law nor our bylaws require the holding of such meetings and we do not hold non-management directors meetings.
The Argentine Corporate Law provides, however, that the board shall meet at least once every three months, and according to our bylaws, whenever the chairman considers necessary to convene for a meeting. |
|
|
|
|
|
303A.04 |
| A listed company must have a nominating/corporate governance committee composed entirely of independent directors, with a written charter that covers certain minimum specified duties. “Controlled companies” are not required to comply with this requirement. |
| Neither Argentine law nor our bylaws require the establishment of a nominating/corporate governance committee. We do not have a nominating/corporate governance committee.
Directors are nominated and appointed by the shareholders. |
|
|
|
|
|
303A.05 |
| A listed company must have a compensation committee composed entirely of independent directors, with a written charter that covers certain minimum specified duties. “Controlled companies” are not required to comply with this requirement. |
| Neither Argentine law nor our bylaws require the establishment of a compensation committee. We do not have a compensation committee.
The compensation of our directors is determined at the annual ordinary shareholders’ meeting. Additionally, the audit committee must issue an opinion regarding the reasonableness and adequacy of such compensation. |
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| Table of Contents |
303A.06* |
| A listed company must have an audit committee with a minimum of three independent directors who satisfy the independence requirements of Rule 10A-3, with a written charter that covers certain minimum specified duties.
|
| Argentine law requires the audit committee be composed of three or more members from the board of directors (with a majority of independent directors), all of whom must be well-versed in business, financial or accounting matters. In addition, we are required to satisfy the audit committee requirements of Rule 10A-3.
The responsibilities of an audit committee, as provided in Law No. 26,831 and the CNV standards, are essentially the same as those provided for under Rule 10A-3, including, but not limited to, the following:
(a) advise on the board of directors’ proposal for the designation of external independent accountants and to ensure their independence;
(b) oversee our internal control mechanisms and administrative and accounting procedures and assess the reliability of all financial and other relevant information filed with the CNV and other entities to which we report;
(c) oversee our information policies concerning risk management;
(d) provide the market with complete information on transactions in which there may be a conflict of interest with members of our various corporate bodies or controlling shareholders;
(e) advise on the reasonableness of fees or stock option plans for our directors and managers proposed by the board of directors;
(f) advise on our fulfillment of legal requirements and the reasonableness of the terms of the issuance of shares or other instruments that are convertible into shares in cases of capital increase in which pre-emptive rights are excluded or limited;
(g) verify the fulfillment of any applicable rules of conduct; and
(h) issue grounded opinions on related-party transactions under certain circumstances and file such opinions with regulatory agencies as required by the CNV in the case of possible conflicts of interest. |
|
|
|
|
|
303A.08 |
| Shareholders must be given the opportunity to vote on all equity-compensation plans and material revisions thereto, with limited exemptions set forth in the NYSE rules.
|
| The basic terms for any equity-based compensation plan should be considered by the general shareholders’ meeting, notwithstanding its power to delegate any decision to the board of directors. We do not currently offer equity-based compensation to our directors, executive officers or employees, and have no policy on this matter. |
|
|
|
|
|
303A.09 |
| A listed company must adopt and disclose corporate governance guidelines that cover certain minimum specified subjects. |
| Neither Argentine law nor our bylaws require the adoption or disclosure of corporate governance guidelines. The CNV Rules contain a recommended Code of Corporate Governance for listed companies and the board of directors must include on its annual report, the degree of compliance of such code. We have adopted, as of May 26, 2011, a corporate governance manual. |
|
|
|
|
|
303A.10 |
| A listed company must adopt and disclose a code of business conduct and ethics for directors, officers and employees, and promptly disclose any waivers of the code for directors or executive officers. |
| Neither Argentine law nor our bylaws require the adoption or disclosure of a code of business conduct. We, however, have adopted a code of business conduct and ethics that applies to all of our employees. |
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| Table of Contents |
Section |
| NYSE corporate governance rule for U.S. domestic issuers |
| Argentine corporate governance rules |
|
|
|
|
|
303A.12 |
| a) Each listed company CEO must certify to the NYSE each year that he or she is not aware of any violation by the company of NYSE corporate governance listing standards.
b)* Each listed company CEO must promptly notify the NYSE in writing after any executive officer of the listed company becomes aware of any non-compliance with any applicable provisions of this Section 303A.
c)* Each listed company must submit an executed Written Affirmation annually to the NYSE. In addition, each listed company must submit an interim Written Affirmation as and when required by the interim Written Affirmation form specified by the NYSE. |
| The CNV Rules provide that each year the board of directors shall include in the annual report included in the financial statement, a report on the degree of compliance with the code of corporate governance for listed companies included in the CNV Rules. In such report, which shall be submitted to the CNV and published for the general public, the board of directors must:
(i) inform if it fully complies with the guidelines and recommendations of the aforementioned code of corporate governance; or (ii) explain the reasons for which it complies only partially or it does not comply with such principles and recommendations, and indicate if the company intends to incorporate the principles and guidelines it failed to adopt. To such end, the company must (a) adopt the principles as general corporate governance guidelines and the recommendations as a framework to adopt the principles within the company; (b) notify compliance with each of the recommendations included in the Corporate Governance Manual; (c) in case of compliance include the required information in accordance with CNV Rules; and (d) in case of partial or non-compliance, justify such event and indicate the action plan for future years, or an indication of the reasons for which the board of directors does not consider appropriate or applicable to follow the recommendations and guidelines provided in the CNV Rules. |
____________
* | We are required to comply with these rules under the NYSE Listed Company Manual |
* | We are required to conform the structure of the Board of Directors to the independence criteria established in article 11, Chapter III, Title II of the CNV Rules by the first shareholders meeting held after December 31, 2018. |
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Item 16.H. Mine Safety Disclosure
Not applicable.
Item 16.I. Disclosure Regarding Foreign Jurisdictions that Prevent Inspections
Not applicable.
Item 17. Financial Statements
The Company has responded to Item 18 in lieu of responding to this Item 17.
Item 18. Financial Statements
Our Audited Consolidated Financial Statements are included in this annual report beginning at Page F-1.
Item 19. Exhibits
EXHIBIT INDEX
Exhibit Number |
| Description |
| ||
|
|
|
2.1. |
| Form of deposit agreement among Central Puerto S.A., Citibank, N.A. and the holders and beneficial owners of ADSs issued thereunder (incorporated by reference to our registration statement on Form F-6 (File No. 333-222584) filed with the Commission on January 17, 2018). |
|
|
|
2.(d).
|
| Description of rights of the securities registered under Section 12 of the Securities Exchange Act of 1934 (incorporated by reference to Exhibit 2.(d) of our annual report on Form 20-F/A (File No. 001-38376), filed with the Commission on April 29, 2020). |
|
|
|
4.2.
|
| Guarantee and Sponsor Support Agreement, dated as of December 22, 2017, among CP La Castellana S.A.U., as Borrower, CP Renovables S.A., as Sponsor and Shareholder, Central Puerto S.A., as Sponsor Guarantor and Shareholder, the Inter-American Investment Corporation, the Inter-American Investment Corporation, acting as agent for the Inter-American Development Bank, the Inter-American Investment Corporation, in its capacity as administrator of the Canadian Climate Fund for the Private Sector of the Americas, the International Finance Corporation, as Senior Lenders, The Eligible Hedge Providers Listed Therein, and Citibank, N.A., as Offshore Collateral Agent (incorporated by reference to Exhibit 10.2 of our registration statement on Form F-1 (File No. 333-222402), as amended, filed with the Commission on January 3, 2018). |
|
|
|
4.3.
|
| Common Terms Agreement (the “Common Terms Agreement”), dated as of October 20, 2017, among CP La Castellana S.A.U., the Inter-American Investment Corporation, the Inter-American Investment Corporation, acting as agent for the Inter-American Development Bank, the Inter-American Investment Corporation, as agent of the Inter-American Development Bank, in its capacity as administrator of the Canadian Climate Fund for the Private Sector of the Americas, and the International Finance Corporation (incorporated by reference to Exhibit 10.3 of our registration statement on Form F-1 (File No. 333-222402), as amended, filed with the Commission on January 3, 2018). |
|
|
|
4.4.
|
| Amendment and Waiver to the Common Terms Agreement, dated as of December 22, 2017 (incorporated by reference to Exhibit 10.4 of our registration statement on Form F-1 (File No. 333-222402), as amended, filed with the Commission on January 3, 2018). |
|
|
|
4.5.
|
| Loan Agreement, dated as of October 20, 2017, among CP La Castellana S.A.U., the Inter-American Investment Corporation, the Inter-American Investment Corporation, acting as agent for the Inter-American Development Bank, and the Inter-American Investment Corporation, as agent of the Inter-American Development Bank, in its capacity as administrator of the Canadian Climate Fund for the Private Sector of the Americas (incorporated by reference to Exhibit 10.5 of our registration statement on Form F-1 (File No. 333-222402), as amended, filed with the Commission on January 3, 2018). |
|
|
|
4.6.
|
| Loan Agreement, dated as of October 20, 2017, among CP La Castellana S.A.U. and the International Finance Corporation (incorporated by reference to Exhibit 10.6 of our registration statement on Form F-1 (File No. 333-222402), as amended, filed with the Commission on January 3, 2018). |
|
|
|
4.7.
|
| English translation of Agreement for Project Management and Operation, Increase of Thermal Generation Availability and Adaptation of Remuneration for Generation 2008-2011, dated as of November 25, 2010, among the Secretary of Energy of the Ministry of Federal Planification, Public Investment and Services, and the generators named therein (the “FONINVEMEM Arrangement for CVOSA”) (incorporated by reference to Exhibit 10.7 of our registration statement on Form F-1 (File No. 333-222402), as amended, filed with the Commission on January 3, 2018). |
|
|
|
4.8.
|
| English translation of Addendum No. 1 to the Agreement for Project Management and Operation, Increase of Thermal Generation Availability and Adaptation of Remuneration for Generation 2008-2011, dated as of April 12, 2011, among the Secretary of Energy of the Ministry of Federal Planification, Public Investment and Services, and the generators named therein (incorporated by reference to Exhibit 10.8 of our registration statement on Form F-1 (File No. 333-222402), as amended, filed with the Commission on January 3, 2018). |
|
|
|
4.9.
|
| English translation of Addendum No. 2 to the Agreement for Project Management and Operation, Increase of Thermal Generation Availability and Adaptation of Remuneration for Generation 2008-2011, dated as of June 25, 2012, among the Secretary of Energy of the Ministry of Federal Planification, Public Investment and Services, and the generators named therein (incorporated by reference to Exhibit 10.9 of our registration statement on Form F-1 (File No. 333-222402), as amended, filed with the Commission on January 3, 2018). |
|
|
|
4.10.
|
| English translation of Final Agreement for the Management and Operation of Projects for the Reconversion of the MEM Under the Scope of Resolution 1427/2004 Issued by the Secretariat of Energy, as dated October 17, 2005, among the Argentine Secretary of Energy and the generators named therein (the “FONINVEMEM Arrangement for TJSM and TMB”) (incorporated by reference to Exhibit 10.10 of our registration statement on Form F-1 (File No. 333-222402), as amended, filed with the Commission on January 3, 2018). |
|
|
|
4.11.
|
| English translation of the Offer to Transfer the La Plata Steam and Electric Power Cogeneration Plant, dated as of December 15, 2017, from Central Puerto S.A. to YPF Energía Eléctrica S.A. (incorporated by reference to Exhibit 10.11 of our registration statement on Form F-1 (File No. 333-222402), as amended, filed with the Commission on January 3, 2018). |
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| Table of Contents |
4.12.
|
| Common Terms Agreement, dated as of January 17, 2018, among CP Achiras S.A.U., the Inter-American Investment Corporation, the Inter-American Investment Corporation, acting as agent for the Inter-American Development Bank, the Inter-American Investment Corporation, as agent of the Inter-American Development Bank, in its capacity as administrator of the Canadian Climate Fund for the Private Sector of the Americas, and the International Finance Corporation (incorporated by reference to Exhibit 10.12 of our registration statement on Form F-1 (File No. 333-222402), as amended, filed with the Commission on January 3, 2018). |
|
|
|
4.13.
|
| Loan Agreement, dated as of January 17, 2018, among CP Achiras S.A.U., the Inter-American Investment Corporation, the Inter-American Investment Corporation, acting as agent for the Inter-American Development Bank, and the Inter-American Investment Corporation, as agent of the Inter-American Development Bank, in its capacity as administrator of the Canadian Climate Fund for the Private Sector of the Americas (incorporated by reference to Exhibit 10.13 of our registration statement on Form F-1 (File No. 333-222402), as amended, filed with the Commission on January 3, 2018). |
|
|
|
4.14.
|
| Loan Agreement, dated as of January 17, 2018, among CP Achiras S.A.U. and the International Finance Corporation (incorporated by reference to Exhibit 10.14 of our registration statement on Form F-1 (File No. 333-222402), as amended, filed with the Commission on January 3, 2018). |
|
|
|
4.15.
|
| Guarantee and Sponsor Support Agreement, dated as of February 22, 2018, among CP Achiras S.A.U., as Borrower, CP Renovables S.A., as Sponsor and Shareholder, Central Puerto S.A., as Sponsor Guarantor and Shareholder, the Inter-American Investment Corporation, the Inter-American Investment Corporation, acting as agent for the Inter-American Development Bank, the Inter-American Investment Corporation, in its capacity as administrator of the Canadian Climate Fund for the Private Sector of the Americas, the International Finance Corporation, as Senior Lenders, and Citibank, N.A., as Offshore Collateral Agent (incorporated by reference to Exhibit 4.15 of our annual report on Form 20-F (File No. 001-38376), filed with the Commission on April 27, 2018). |
|
|
|
4.16.
|
| Wind Farm Omnibus Amendment and Agreement, dated March 16, 2018, among CP Achiras S.A.U., the Inter-American Investment Corporation, the Inter-American Investment Corporation, acting as agent for the Inter-American Development Bank, the Inter-American Investment Corporation, as agent of the Inter-American Development Bank, in its capacity as administrator of the Canadian Climate Fund for the Private Sector of the Americas, and the International Finance Corporation (incorporated by reference to Exhibit 4.16 of our annual report on Form 20-F (File No. 001-38376), filed with the Commission on April 27, 2018). |
|
|
|
4.18 |
| Brigadier López Power Plant transfer contract (incorporated by reference to Exhibit 4.18 of our annual report on Form 20-F/A (File No. 001-38376), filed with the Commission on April 29, 2020 ACTUALIZAR) |
|
|
|
| List of subsidiaries of Central Puerto S.A. as of the date of this annual report. | |
|
|
|
11.1. |
| Code of Ethics of Central Puerto S.A., as amended (incorporated by reference to Exhibit 11.1 of our annual report on Form 20-F (File No. 001-38376), filed with the Commission on April 27, 2018) |
|
|
|
| Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. | |
|
|
|
| Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. | |
|
|
|
| ||
|
|
|
15.2. |
| Consent of Vaisala, Inc. (incorporated by reference to Exhibit 23.5 of our registration statement on Form F-1 (File No. 333-222402), as amended, filed with the Commission on January 3, 2018). |
|
|
|
101 |
| XBRL Instance Document and related items. |
| 216 |
| Table of Contents |
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.
CENTRAL PUERTO S.A. |
| ||
|
|
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|
| By: | /S/ ENRIQUE TERRANEO |
|
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|
|
| Chief Financial Officer |
|
Date:April 28, 2022.
| 217 |
| Table of Contents |
INDEX TO THE FINANCIAL STATEMENTS
| Page |
Audited Consolidated Financial Statements of Central Puerto S.A. |
|
Report of the Independent Registered Public Accounting Firm (PCAOB ID | F-1 |
Consolidated Statement of Income for the years ended December 31, 2021, 2020, and 2019 | F-4 |
Consolidated Statement of Comprehensive Income for the years ended December 31, 2021, 2020, and 2019 | F-5 |
Consolidated Statement of Financial Position as of December 31, 2021 and 2020 | F-6 |
Consolidated Statement of Changes in Equity for the years ended December 31, 2021, 2020, and 2019 | F-7 |
Consolidated Statement of Cash Flows for the years ended December 31, 2021, 2020, and 2019 | F-8 |
Notes to the Consolidated Financial Statements | F-9 |
218 |
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Shareholders and Board of Directors of Central Puerto S.A.:
Opinion on the Financial Statements
We have audited the accompanying consolidated statements of financial position of Central Puerto S.A. (the “Company”) as of December 31, 2021 and 2020, the related consolidated statements of income, comprehensive income, changes in equity and cash flows for each of the three years in the period ended December 31, 2021, and the related notes (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, 2021 and 2020, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2021, in conformity with International Financial Reporting Standards as issued by the International Accounting Standards Board.
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, 2021, 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 28, 2022 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.
Critical Audit Matter
The critical audit matter communicated below is a matter arising from the current period audit of the consolidated financial statements that was communicated or required to be communicated to the audit committee and that relates to accounts or disclosures that are material to the financial statements, and involved our especially challenging, subjective, or complex judgments. The communication of the critical audit matter does not alter in any way our opinion on the financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.
Impairment of property, plant and equipment and intangible assets
Description of the Matter
As reflected in the Company´s consolidated financial statements, at December 31, 2021, the Company´s property, plant and equipment (“PPE”) and intangible assets were Argentine pesos (“Ps.”) 110,623 million and Ps. 6,040 million, respectively. As further described in Note 2.2.8 to the consolidated financial statements, PPE and intangible assets are tested for impairment when an existing event or one that took place after year end, and provides additional evidence of conditions that existed at the end of the reporting period, indicates than the recoverable value of the PPE and/or intangible assets amounts may be affected. For each individual asset or cash generating unit (“CGU”) for which impairment indicators are identified, management estimates the recoverable amount for the asset or CGU, which is the higher of the fair value less costs to sell and its value in use, and compares it to the respective carrying amount. The Company estimated the fair value less cost to sell of certain Turbine based on external specialist’s valuation. The value in use for the Company´s CGUs related to the Electric Power Generation from conventional sources operating segment, was estimated based on discounted future cash flows, which considered probability weighted scenarios. During 2021, the Company recorded a Ps. 6,696 million impairment loss on PPE related to the Thermal Station Brigadier López, the Luján de Cuyo Combined Cycle Power Plant, the Nuevo Puerto combined cycle power plant and the Terminal 6 San Lorenzo cogeneration unit, and a Ps. 1,069 million impairment loss on its intangible assets related to the Thermal Station Brigadier López.
| F-1 |
Auditing this area is especially challenging because it involves a high degree of auditor judgment in performing procedures to evaluate management assumptions to determine the fair value less cost to sell and value in use, such as prospective financial information (including market inputs used in the determination of certain assets’ fair value , expected inflation and exchange rates, the estimated growth in energy market, future electricity prices and developments in the regulatory framework), the use of different scenarios and the discount rate, which are forward-looking and based upon expectations about future economic and market conditions.
How We Addressed the Matter in our Audit
We obtained an understanding, evaluated the design, and tested the operating effectiveness of controls over the Group’s impairment assessment process, including controls over management’s review of the significant assumptions described above, the completeness and accuracy of the underlying data and over the consistency of the discounted cash flow model used by the Group.
To test management´s impairment evaluation, our audit procedures included, among others, assessing the methodologies used by management, testing the underlying data and involving our internal valuation specialists to assist in testing the significant assumptions discussed above and the valuation in which the Company based its determination of fair value less cost to sell. For example, we compared the significant assumptions used by management, such as expected inflation, exchange rates and future energy prices and costs, to current available economic trends data and known regulatory framework, and evaluated whether changes to the Group’s estimation model or other factors affected the significant assumptions. We also assessed historical accuracy of management’s estimates and performed sensitivity analysis to evaluate the changes in the value in use that would result from changes in the underlying assumptions and tested the arithmetical accuracy and internal logic of the discounted cash flows model. We also assessed related disclosures in the consolidated financial statements.
/s/
Member of Ernst Young Global
We have served as the Company’s auditor since 2002.
| F-2 |
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Shareholders and the Board of Directors of Central Puerto S.A.
Opinion on Internal Control Over Financial Reporting
We have audited Central Puerto S.A. internal control over financial reporting as of December 31, 2021, 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, Central Puerto S.A. (the Company) maintained, in all material respects, effective internal control over financial reporting as of December 31, 2021, 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 Central Puerto S.A. as of December 31, 2021 and 2020, the related consolidated statements of income, comprehensive income, changes in equity and cash flows for each of the three years in the period ended December 31, 2021, and the related notes, and our report dated April 28, 2022 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 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.
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.
/s/
Member of Ernst Young Global
| F-3 |
CENTRAL PUERTO S.A.
CONSOLIDATED STATEMENT OF INCOME
|
|
|
| For the years ended December 31, |
| |||||||||||
|
| Notes |
|
| 2021 |
|
| 2020 |
|
| 2019 |
| ||||
|
|
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| |||||
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
Revenues |
|
| 5 |
|
|
|
|
|
|
|
|
|
| |||
Cost of sales |
|
| 6.1 |
|
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Gross income |
|
|
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| |||
|
|
|
|
|
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|
|
|
|
|
|
|
|
|
|
|
Administrative and selling expenses |
|
| 6.2 |
|
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Other operating income |
|
| 7.1 |
|
|
|
|
|
|
|
|
|
| |||
Other operating expenses |
|
| 7.2 |
|
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Impairment of property, plant and equipment and intangible assets |
|
|
|
|
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Operating income |
|
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|
|
|
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|
|
|
| |||
|
|
|
|
|
|
|
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|
|
|
|
|
|
|
|
|
(Loss) Gain on net monetary position |
| 2.1.2 |
|
|
| ( | ) |
|
|
|
|
| ( | ) | ||
Finance income |
|
| 7.3 |
|
|
|
|
|
|
|
|
|
| |||
Finance expenses |
|
| 7.4 |
|
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Share of the profit of associates |
|
| 3 |
|
|
| ( | ) |
|
|
|
|
|
| ||
Income before income tax |
|
|
|
|
|
|
|
|
|
|
|
|
| |||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income tax for the year |
|
| 8 |
|
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Net (Loss) income for the year |
|
|
|
|
|
| ( | ) |
|
|
|
|
|
| ||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Attributable to: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
– Equity holders of the parent |
|
|
|
|
|
| ( | ) |
|
|
|
|
|
| ||
– Non-controlling interests |
|
|
|
|
|
|
|
|
|
|
|
| ( | ) | ||
Net income for the year |
|
|
|
|
|
| ( | ) |
|
|
|
|
|
| ||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic and diluted earnings per share (ARS) |
|
| 9 |
|
|
| ( | ) |
|
|
|
|
|
| ||
| F-4 |
CENTRAL PUERTO S.A.
CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME
|
|
|
| For the years ended December 31, |
| |||||||||||
|
| Notes |
|
| 2021 |
|
| 2020 |
|
| 2019 |
| ||||
|
|
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| |||||
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
Net (loss) income for the year |
|
|
|
|
| ( | ) |
|
|
|
|
|
| |||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |
Other comprehensive income for the year |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |
Other comprehensive income (loss) not to be reclassified to income in subsequent periods |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |
Remeasurement of losses from long-term employee benefits |
|
| 14.3 |
|
|
|
|
|
|
|
|
| ( | ) | ||
Income tax related to remeasurement of losses from long-term employee benefits |
|
| 8 |
|
|
| ( | ) |
|
| ( | ) |
|
|
| |
Other comprehensive income (loss) not to be reclassified to income in subsequent periods |
|
|
|
|
|
|
|
|
|
|
|
| ( | ) | ||
Other comprehensive income for the year |
|
|
|
|
|
|
|
|
|
|
|
| ( | ) | ||
Total comprehensive (loss) income for the year |
|
|
|
|
|
| ( | ) |
|
|
|
|
|
| ||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Attributable to: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
– Equity holders of the parent |
|
|
|
|
|
| ( | ) |
|
|
|
|
|
| ||
– Non-controlling interests |
|
|
|
|
|
|
|
|
|
|
|
| ( | ) | ||
|
|
|
|
|
|
| (647,611 | ) |
|
| 10,510,734 |
|
|
| 17,731,532 |
|
| F-5 |
CENTRAL PUERTO S.A.
CONSOLIDATED STATEMENT OF FINANCIAL POSITION
|
|
|
| 12-31-2021 |
|
| 12-31-2020 |
| ||||
|
| Notes |
|
| ARS 000 |
|
| ARS 000 |
| |||
|
|
|
|
|
|
|
|
|
| |||
Assets |
|
|
|
|
|
|
|
|
| |||
Non-current assets |
|
|
|
|
|
|
|
|
| |||
Property, plant and equipment |
|
| 11 |
|
|
|
|
|
|
| ||
Intangible assets |
|
| 12 |
|
|
|
|
|
|
| ||
Investment in associates |
|
| 3 |
|
|
|
|
|
|
| ||
Other financial assets |
|
| 13.6 |
|
|
|
|
|
| - |
| |
Trade and other receivables |
|
| 13.1 |
|
|
|
|
|
|
| ||
Other non-financial assets |
|
| 14.1 |
|
|
|
|
|
|
| ||
Inventories |
|
| 10 |
|
|
|
|
|
|
| ||
Deferred tax asset |
|
| 8 |
|
|
|
|
|
|
| ||
|
|
|
|
|
|
|
|
|
|
| ||
Current assets |
|
|
|
|
|
|
|
|
|
|
|
|
Inventories |
|
| 10 |
|
|
|
|
|
|
| ||
Other non-financial assets |
|
| 14.1 |
|
|
|
|
|
|
| ||
Trade and other receivables |
|
| 13.1 |
|
|
|
|
|
|
| ||
Other financial assets |
|
| 13.6 |
|
|
|
|
|
|
| ||
Cash and cash equivalents |
|
| 15 |
|
|
|
|
|
|
| ||
|
|
|
|
|
|
|
|
|
|
| ||
Property, plant and equipment available for sale |
|
| 20.5 |
|
|
| - |
|
|
|
| |
Total assets |
|
|
|
|
|
|
|
|
|
| ||
|
|
|
|
|
|
|
|
|
|
|
|
|
Equity and liabilities |
|
|
|
|
|
|
|
|
|
|
|
|
Equity |
|
|
|
|
|
|
|
|
|
|
|
|
Capital stock |
|
|
|
|
|
|
|
|
|
| ||
Adjustment to capital stock |
|
|
|
|
|
|
|
|
|
| ||
Legal reserve |
|
|
|
|
|
|
|
|
|
| ||
Voluntary reserve |
|
|
|
|
|
|
|
|
|
| ||
Other equity accounts |
|
|
|
|
|
| ( | ) |
|
| ( | ) |
Retained earnings |
|
|
|
|
|
| ( | ) |
|
|
| |
Equity attributable to holders of the parent |
|
|
|
|
|
|
|
|
|
| ||
Non-controlling interests |
|
|
|
|
|
|
|
|
|
| ||
Total equity |
|
|
|
|
|
|
|
|
|
| ||
|
|
|
|
|
|
|
|
|
|
|
|
|
Non-current liabilities |
|
|
|
|
|
|
|
|
|
|
|
|
Other non-financial liabilities |
|
| 14.2 |
|
|
|
|
|
|
| ||
Loans and borrowings |
|
| 13.3 |
|
|
|
|
|
|
| ||
Compensation and employee benefits liabilities |
|
| 14.3 |
|
|
|
|
|
|
| ||
Provisions |
|
| 17 |
|
|
|
|
|
|
| ||
Deferred income tax liabilities |
|
| 8 |
|
|
|
|
|
|
| ||
|
|
|
|
|
|
|
|
|
|
| ||
Current liabilities |
|
|
|
|
|
|
|
|
|
|
|
|
Trade and other payables |
|
| 13.2 |
|
|
|
|
|
|
| ||
Other non-financial liabilities |
|
| 14.2 |
|
|
|
|
|
|
| ||
Loans and borrowings |
|
| 13.3 |
|
|
|
|
|
|
| ||
Compensation and employee benefits liabilities |
|
| 14.3 |
|
|
|
|
|
|
| ||
Income tax payable |
|
|
|
|
|
|
|
|
|
| ||
Provisions |
|
| 17 |
|
|
|
|
|
|
| ||
|
|
|
|
|
|
|
|
|
|
| ||
Total liabilities |
|
|
|
|
|
|
|
|
|
| ||
Total equity and liabilities |
|
|
|
|
|
|
|
|
|
| ||
| F-6 |
CENTRAL PUERTO S.A.
CONSOLIDATED STATEMENT OF CHANGES IN EQUITY
|
| Attributable to holders of the parent |
|
|
|
|
| |||||||||||||||||||||||||||||
|
| Capital stock |
|
| Retained earnings |
|
|
|
|
|
|
|
|
|
|
|
| |||||||||||||||||||
|
| Face value |
|
| Adjustment to capital stock |
|
| Legal reserve |
|
| Voluntary reserve |
|
| Other equity accounts |
|
| Unappropriated retained earnings |
|
| Other accumulated comprehensive income (loss) |
|
| Non- controlling interests |
|
| Total |
| |||||||||
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| |||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||||
As of January 1, 2021 |
|
|
|
|
|
|
|
|
|
|
|
|
|
| ( | ) |
|
|
|
|
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| ||||||||
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|
|
|
|
|
|
|
|
|
|
Net (loss) income for the year |
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| ( | ) |
|
| ( | ) |
|
|
|
|
| ( | ) | |
Other comprehensive income for the year |
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
|
|
|
|
|
|
| - |
|
|
|
| |||
Total comprehensive (loss) income for the year |
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| ( | ) |
|
| ( | ) |
|
|
|
|
| ( | ) | |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Increase in legal reserve |
|
| - |
|
|
| - |
|
|
|
|
|
| - |
|
|
| - |
|
|
| ( | ) |
|
| - |
|
|
| - |
|
|
| - |
| |
Increase in voluntary reserve |
|
| - |
|
|
| - |
|
|
| - |
|
|
|
|
|
| - |
|
|
| ( | ) |
|
| - |
|
|
| - |
|
|
| - |
| |
Dividends in cash distributed by a subsidiary (2) |
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| ( | ) |
|
| ( | ) |
As of December 31, 2021 (1) |
|
|
|
|
|
|
|
|
|
|
|
|
|
| ( | ) |
|
| ( | ) |
|
|
|
|
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|
|
|
| |||||||
|
|
|
|
|
|
|
|
|
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|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
As of January 1, 2020 |
|
|
|
|
|
|
|
|
|
|
|
|
|
| - |
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||||
|
|
|
|
|
|
|
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|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income for the year |
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
Other comprehensive income for the year |
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
|
|
|
|
|
|
| - |
|
|
|
| |||
Total comprehensive income for the year |
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Increase in legal reserve |
|
| - |
|
|
| - |
|
|
|
|
|
| - |
|
|
| - |
|
|
| ( | ) |
|
| - |
|
|
| - |
|
|
| - |
| |
Increase in voluntary reserve |
|
| - |
|
|
| - |
|
|
| - |
|
|
|
|
|
| - |
|
|
| ( | ) |
|
| - |
|
|
| - |
|
|
| - |
| |
Dividends in cash distributed by a subsidiary (3) |
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| ( | ) |
|
| ( | ) |
Transaction with non-controlling interest (Note 18) |
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| ( | ) |
|
| - |
|
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Share-based payments |
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
|
|
|
|
| ||
As of December 31, 2020 (1) |
|
|
|
|
|
|
|
|
|
|
|
|
|
| ( | ) |
|
|
|
|
|
|
|
|
|
|
|
| ||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
As of January 1, 2019 |
|
|
|
|
|
|
|
|
|
|
|
|
|
| - |
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Effect of IFRIC 23 adoption |
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
|
|
|
|
|
|
| - |
|
|
|
| |||
As of January 1, 2019 (modified) |
|
|
|
|
|
|
|
|
|
|
|
|
|
| - |
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||||
|
|
|
|
|
|
|
|
|
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|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income for the year |
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
|
|
|
|
|
|
| ( | ) |
|
|
| |||
Other comprehensive income for the year |
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| ( | ) |
|
| ( | ) |
|
| - |
|
|
| ( | ) |
Total comprehensive income for the year |
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
|
|
|
|
|
|
| ( | ) |
|
|
| |||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Increase in legal reserve |
|
| - |
|
|
| - |
|
|
|
|
|
| - |
|
|
| - |
|
|
| ( | ) |
|
| - |
|
|
| - |
|
|
| - |
| |
Increase in voluntary reserve |
|
| - |
|
|
| - |
|
|
| - |
|
|
|
|
|
| - |
|
|
| ( | ) |
|
| - |
|
|
| - |
|
|
| - |
| |
Dividends in cash |
|
| - |
|
|
| - |
|
|
| - |
|
|
| ( | ) |
|
| - |
|
|
|
|
|
| ( | ) |
|
| - |
|
|
| ( | ) | |
Contributions from non-controlling interests |
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
|
|
|
|
| ||
Dividends in cash distributed by a subsidiary (4) |
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| ( | ) |
|
| ( | ) |
Share-based payments |
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
|
|
|
|
| ||
As of December 31, 2019 (1) |
|
|
|
|
|
|
|
|
|
|
|
|
|
| - |
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||||
(1) | A subsidiary holds 8,851,848 common shares. |
(2) | Distribution of dividends in cash approved by the Shareholders’ Meeting of the subsidiary Central Vuelta de Obligado S.A. held on April 28, 2021. |
(3) | Distribution of dividends in cash approved by the Shareholders’ Meeting of the subsidiary Central Vuelta de Obligado S.A. held on April 28, 2020. |
(4) | Distribution of dividends in cash approved by the Shareholders’ Meeting of the subsidiary Central Vuelta de Obligado S.A. held on April 23, 2019. |
| F-7 |
CENTRAL PUERTO S.A.
CONSOLIDATED STATEMENT OF CASH FLOWS
|
| For the years ended December 31, |
| |||||||||
|
| 2021 |
|
| 2020 |
|
| 2019 |
| |||
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| |||
|
|
|
|
|
|
|
|
|
| |||
Operating activities |
|
|
|
|
|
|
|
|
| |||
Income for the year before income tax |
|
|
|
|
|
|
|
|
| |||
|
|
|
|
|
|
|
|
|
|
|
|
|
Adjustments to reconcile income for the year before income tax to net cash flows: |
|
|
|
|
|
|
|
|
|
|
|
|
Depreciation of property, plant and equipment |
|
|
|
|
|
|
|
|
| |||
Amortization of intangible assets |
|
|
|
|
|
|
|
|
| |||
Impairment of property, plant and equipment and intangible assets |
|
|
|
|
|
|
|
|
| |||
Income from sale of property, plant and equipment |
|
| ( | ) |
|
| - |
|
|
| - |
|
(Recovery) discount of tax credits |
|
| ( | ) |
|
|
|
|
|
| ||
Interest earned from customers |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Trade and tax interests lost |
|
|
|
|
|
|
|
| - |
| ||
Finance income |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Finance expenses |
|
|
|
|
|
|
|
|
| |||
Share of the profit of associates |
|
|
|
|
| ( | ) |
|
| ( | ) | |
Material and spare parts impairments |
|
|
|
|
|
|
|
|
| |||
Share-based payments |
|
| - |
|
|
|
|
|
|
| ||
Movements in provisions, and long-term employee benefit plan expense |
|
|
|
|
|
|
|
|
| |||
Foreign exchange difference for trade receivables |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Loss on net monetary position |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
|
|
|
|
|
|
|
|
|
|
|
|
|
Working capital adjustments: |
|
|
|
|
|
|
|
|
|
|
|
|
Decrease in trade and other receivables |
|
|
|
|
|
|
|
|
| |||
(Increase) Decrease in other non-financial assets and inventories |
|
| ( | ) |
|
|
|
|
| ( | ) | |
Decrease in trade and other payables, other non-financial liabilities and liabilities from employee benefits |
|
| ( | ) |
|
| ( | ) |
|
|
| |
|
|
|
|
|
|
|
|
|
| |||
Trade and tax interests paid |
|
| ( | ) |
|
| ( | ) |
|
| - |
|
Interest received from customers |
|
|
|
|
|
|
|
|
| |||
Income tax paid |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Net cash flows provided by operating activities |
|
|
|
|
|
|
|
|
| |||
|
|
|
|
|
|
|
|
|
|
|
|
|
Investing activities |
|
|
|
|
|
|
|
|
|
|
|
|
Purchase of property, plant and equipment |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Sale of property, plant and equipment |
|
|
|
|
| - |
|
|
| - |
| |
Acquisition of thermal Station Brigadier López |
|
| - |
|
|
| - |
|
|
| ( | ) |
Dividends received |
|
|
|
|
|
|
|
|
| |||
Acquisition of financial assets, net |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Net cash flows used in investing activities |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
|
|
|
|
|
|
|
|
|
|
|
|
|
Financing activities |
|
|
|
|
|
|
|
|
|
|
|
|
Bank and investment accounts overdrafts received (paid), net |
|
| ( | ) |
|
| ( | ) |
|
|
| |
Loans paid |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Loans received |
|
| - |
|
|
|
|
|
|
| ||
Direct financing and loans refinancing costs |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Interest and other financial costs paid |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Contributions from non-controlling interests |
|
| - |
|
|
| - |
|
|
|
| |
Dividends paid |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Net cash flows (used in) provided by financing activities |
|
| ( | ) |
|
| ( | ) |
|
|
| |
|
|
|
|
|
|
|
|
|
|
|
|
|
(Decrease) Increase in cash and cash equivalents |
|
| ( | ) |
|
| ( | ) |
|
|
| |
Exchange difference and other financial results |
|
|
|
|
|
|
|
|
| |||
Monetary results effect on cash and cash equivalents |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Cash and cash equivalents as of January 1 |
|
|
|
|
|
|
|
|
| |||
Cash and cash equivalents as of December 31 |
|
|
|
|
|
|
|
|
| |||
| F-8 |
CENTRAL PUERTO S.A.
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
1. Corporate information and main business
Central Puerto S.A. (hereinafter the “Company”, ”we”, “us” or “CEPU”) and the companies that make up the business group (hereinafter the “Group”) form an integrated group of companies pertaining to the energy sector. The Group is mainly engaged in electric power generation.
CEPU was incorporated pursuant to Executive Order No. 122/92. We were formed in connection with privatization process involving Servicios Eléctricos del Gran Buenos Aires S.A. (“SEGBA”) in which SEGBA’s electricity generation, transportation, distribution and sales activities were privatized.
On April 1, 1992, Central Puerto S.A., the consortium-awardee, took possession over SEGBA’s Nuevo Puerto and Puerto Nuevo plants, and we began operations.
Our shares are listed on the BCBA (“Buenos Aires Stock Exchange”), and, since February 2, 2018, they are listed on the NYSE (“New York Stock Exchange”), both under the symbol “CEPU”.
In order to carry out its electric energy generation activity the Group owns the following assets:
– | Our Puerto complex is composed of two facilities, Central Nuevo Puerto (“Nuevo Puerto”) and Central Puerto Nuevo (“Puerto Nuevo”), located in the port of the City of Buenos Aires. Our Puerto complex’s facilities include steam turbines plants and a Combined Cycle plant and has a current installed capacity of 1,714 MW. |
|
|
– | Our Luján de Cuyo plants are located in Luján de Cuyo, Province of Mendoza and have an installed capacity of 571 MW and a steam generating capacity of 125 tons per hour. |
|
|
– | The Group also owns the concession right of the Piedra del Águila hydroelectric power plant located at the edge of Limay river in Neuquén province. Piedra del Águila has four 360 MW generating units. |
|
|
– | The Group is engaged in the management and operation of the thermal plants José de San Martín and Manuel Belgrano through its equity investees Termoeléctrica José de San Martín S.A. (“TJSM”) and Termoeléctrica General Belgrano S.A. (“TMB”). Those entities operate the two thermal generation plants with an installed capacity of 865 MW and 873 MW, respectively. Additionally, through its subsidiary Central Vuelta de Obligado S.A. (“CVO”) the Group is engaged in the operation of the thermal plant Central Vuelta de Obligado, with an installed capacity of 816 MW. |
|
|
– | The thermal station Brigadier López located in Sauce Viejo, Province of Santa Fe, with an installed power of 280.5 MW (open-cycle operation). |
|
|
– | The thermal cogeneration plant Terminal 6 - San Lorenzo located in Puerto General San Martín, Santa Fe Province, with an installed power of 330 MW and 340 tn/h of steam production. |
The Group is also engaged in the natural gas distribution public sector service in the Cuyo and Centro regions in Argentina, through its equity investees belonging to ECOGAS Group.
On July 19, 2018, the National Gas Regulation Entity (Enargas) filed the Company with the Registry of Traders and Trade Agreements of Enargas.
Moreover, through CP Renovables S.A. (“CPR”) and its subsidiaries, Vientos La Genoveva S.A.U. and Vientos La Genoveva II S.A.U. the Group takes part on the development and performance of energy projects based on the use of renewable energy sources. In this regard, as of the issuance date of these financial statements, the Group has a total installed capacity of 373.8 MW of commercially-authorized power from sources of renewable energy, which is distributed as follows: (i) wind farm La Castellana 100.8 MW; (ii) wind farm La Castellana II 15.2 MW; (iii) wind farm La Genoveva 88.2 MW; (iv) wind farm La Genoveva II 41.8 MW; (v) wind farm Achiras 48 MW; (iv) wind farm Los Olivos 22.8 MW and (vii) wind farm Manque 57 MW.
| F-9 |
CENTRAL PUERTO S.A.
1.1. Overview of Argentine Electricity Market
Transactions among different participants in the electricity industry take place through the wholesale electricity market (“WEM”) which is a market in which generators, distributors and certain large users of electricity buy and sell electricity at prices determined by supply and demand (“Term market”) and also, where prices are established on an hourly basis based on the economic production cost, represented by the short term marginal cost measured at the system’s load center (“Spot market”). CAMMESA (Compañía Administradora del Mercado Mayorista Eléctrico Sociedad Anónima) is a quasi-government organization that was established to administer the WEM and functions as a clearing house for the different market participants operating in the WEM. Its main functions include the operation of the WEM and dispatch of generation and price calculation in the Spot market, the real-time operation of the electricity system and the administration of the commercial transactions in the electricity market. Currently, the Term market has CAMMESA as sole seller, in accordance with Section 9 of SE Resolution No. 95/2013.
After the Argentine economic crisis in 2001 and 2002 and the Convertibility Law, the costs of generators increased as a result of the Argentine peso devaluation. In addition, the price of fuel for their generation increased as well. The increasing generation costs combined with the freezing of rates for the final user decided at the time by National Government led to a permanent deficit in CAMMESA accounts, which faced difficulties to pay the energy purchases to generators. Due to this structural deficit, the Secretariat of Energy issued a series of regulations to keep the electricity market working despite the deficit.
1.2. Amendments to WEM regulations
a) Resolution SE No. 406/03 and other regulations related to WEM generators’ receivables
Resolution 406/03 issued in September 2003 enforced priority payments of generator’s balances. Under the priority payment plan, generators only collected the variable generation costs declared and the payments for power capacity and the remaining payments on these plants were delayed as there were not sufficient funds as a result of the structural deficit. Resolution 406/03 established that the resulting monthly obligations to generators for the unpaid balance were to be considered payments without a fixed due date, or “LVFVD receivables” using the Spanish acronym. Although these obligations did not have a specified due date, the Resolution provided that they would earn interest at an equivalent rate to the one received by CAMMESA on its own cash investments, hereafter “the CAMMESA rate”.
As a result of this regulation, a portion of the invoices issued by Company’s plants were not paid in full beginning in 2004.
Between 2004 and 2007, the Argentine government issued a series of resolutions aimed at increasing thermal generation capacity while at the same time providing a mechanism for generators to collect their LVFVD receivables. These resolutions created funds called the “FONINVEMEM” which were administered by trusts (“the FONINVEMEM trust”) and made investments in two thermal generation plants within Argentina. All WEM creditor agents with LVFVD (including the Company) were invited to state formally their decision to participate in forming the FONINVEMEM. The Company, as most LVFVD generators, stated its decision to participate in the creation of the FONINVEMEM with the abovementioned receivables.
Within this framework, generators created the companies Termoeléctrica José de San Martín S.A. (“TSM”) and Termoeléctrica Manuel Belgrano S.A. (“TMB”), which were engaged in managing the purchase of equipment, and building, operating and maintaining each new power plant.
Under these Resolutions, the FONINVEMEM trusts are the owner of the Central Termoeléctrica San Martin and Central Termoeléctrica Belgrano plants during the first ten years of operations. Trusts are aimed at administrating, each of them, 50% of the resources accrued under FONINVEMEM and other funds for the purpose of financing the power stations. Under these agreements, CAMMESA acts as a Trustor, Banco de Inversión y Comercio Exterior (“BICE”) as Trustee, the Secretariat of Energy as regulatory authority and TSM and TMB as Trust Beneficiaries and the Company, with the remaining shareholders of TSM and TMB, as guarantors of the obligations of the latter.
| F-10 |
CENTRAL PUERTO S.A.
The trust agreements had to remain in force until the termination date of the supply agreement that the Trustee - in representation of the Trust - entered into with CAMMESA - as the purchasing party - that had to remain valid for 10 years as from the date of the commercial authorization of the power stations. Upon the termination of that term, the trust assets must be transferred to TSM and TMB provided that, prior to such transference, TSM and TMB and their shareholders perform all the corporate acts necessary to allow private contributors and/or the Argentine Government to receive their correspondent shares in the capital of the power stations pursuant to the terms of the agreement. Failure to comply with this condition, holders of interest certificates (Argentine Government) and the generators who are the current shareholders of TSM and TMB shall be deemed as trust beneficiaries.
The FONINVEMEM agreements established that the receivables mentioned above will be paid by CAMMESA in 120 equal, consecutive monthly installments commencing on the commercial operation date of the plants. Also, the agreements established that the LVFVD receivables would be collected converted to US dollar and began earning interest at LIBOR plus a spread of 1% and 2%.
Once Manuel Belgrano and San Martin plants were commissioned (on January 7, 2010 and February 2, 2010, respectively), CAMMESA began paying the LVFVD receivables. On May 2010, CAMMESA informed the Company of the payment plan, including the amount of accrued interest at the CAMMESA rate which was added to the principal to be repaid in monthly installments over a ten-year period. Upon receipt of the payment schedule, the Company recognized accrued interest (related to the CAMMESA rate). The Company also began recognizing LIBOR interest income based on the contractual rate provided in the Resolution and the conversion of the receivables into US dollar. Since achieving commercial operations in 2010, CAMMESA have made all scheduled contractual principal and interest payments in accordance with the installment plan.
On January 7, 2020, the supply agreement with TMB was terminated and on February 2, 2020, the supply agreement with TSM was terminated, therefore payments of the final installment of the 120 established in the agreement for each power stations ceased. As a result, the reimbursement for the LVFVD receivables is deemed completed.
Additionally, in 2010 the Company approved a new agreement with the former Secretariat of Energy (the “CVO agreement”). This agreement established, among other agreements, a framework to determine a mechanism to settle unpaid trade receivables as per Resolution 406/03 accrued over the 2008 - 2011 period by the generators (“CVO receivables”) and for that purpose, enabling the construction of a thermal combined cycle plant named Central Vuelta de Obligado. The CVO agreement established that the CVO receivables will be paid by CAMMESA in 120 equal and consecutive monthly installments. For the determination of the novation of CVO credits, the following mechanism was applied: the cumulative LVFVD (sale settlements with due date to be defined) were converted to USD at the exchange rate established in the agreement (ARS 3.97 per USD for the cumulative LVFVD until the execution date of the CVO Agreement and the closing exchange rate corresponding to each month for the LVFVD subsequently accumulated), the LIBOR rate was applied plus a 5% margin.
As from March 20, 2018, CAMMESA granted the commercial operation as a combined cycle of Central Vuelta de Obligado thermal power plant (the “Commercial Approval”). The financial impact of the Commercial Approval is described in Note 13.1.
Under the agreement mentioned above, generators created the company Central Vuelta de Obligado S.A., which was in charge of managing the purchase of equipment and construction of the Central Vuelta de Obligado thermal power plant and currently it is in charge of managing its operation and maintenance.
TSM and TMB
After termination of the supply agreements with TSM and TMB dated February 2, 2020 and January 7, 2020, respectively, trust agreements also terminated. As from those dates, a 90-day period commenced in which TSM and TMB and their shareholders had to perform all the company acts necessary to allow the Argentine Government to receive the corresponding shares in the capital of TSM and TMB that their contributions gave them rights to.
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CENTRAL PUERTO S.A.
On January 3, 2020, i.e. before the aforementioned 90-day period commenced, the Argentine Government (through the Ministry of Productive Development) served notice to the Company (together with TSM, TMB and their other shareholders and BICE, among others) stating that, according to the Final Agreement for the Re-adaptation of WEM, TSM and TMB shall perform the necessary acts to incorporate the Argentine Government as shareholder of both companies, acknowledging the following equity interest rights: 65.006% in TMB and 68.826% in TSM.
On January 9, 2020, the Company, together with the other generation shareholders of TSM and TMB, rejected such act understanding that the equity interest the Government claims does not correspond with the contributions made for the construction of power stations and that gave it right to claim such equity interest.
On March 4, 2020, the Company was notified on two notes sent by the Minister of Productive Development in response to the note sent by the Company on January 9, 2020 - mentioned above -, ratifying the terms of the note notified to the Company on January 3, 2020. In March 2020, the Company raised a reconsideration motion, with higher supplementary appeal, against the Argentine Government’s order for the acts mentioned above.
On May 4 and 8, 2020, the Company attended the Special Shareholder’s Meetings of TMB and TSM, respectively, in which the admission of the Argentine Government as shareholder of TSM and TMB was allowed, in accordance with the shareholding interest claimed by the Argentine Government. This with the sole purpose of complying with the precedent condition established in the respective Trust Agreements, which stated that for the trusted equity -comprised, among others, by the power plants- to be transferred to the companies TSM and TMB in a 90-day period counted as from the end of the supply agreements, such companies and their shareholders (among which the Company is included) had to allow the entrance of the Argentine Government in TSM and TMB, receiving the same amount of shares representing the contributions made by the Argentine Government for the construction of the plants and giving it the right to claim such interest.
In both cases, when the mentioned Shareholders’ Meetings were held, through which the Argentine Government was allowed as shareholder of TMB and TSM due to its interest claim, the Company made the corresponding reservation of rights so as to continue the abovementioned claims already commenced.
On November 19, 2020, BICE (in its capacity as trustee of both trust agreements) had the condition precedent established in the Trust Agreements fulfilled since the necessary corporate acts for the Argentine Government to be allowed as shareholder of TSM and TMB were performed. Finally, on March 11, 2021, the Argentine Government has subscribed its shares in TSM and TMB. This way, the Group´s equity interest in TSM and TMB was changed from 30.8752% to 9.6269% and from 30.9464% to 10.8312%, respectively. As of the date of these financial statements, the transference of power stations has not been made to TSM and TMB.
On the other hand, the Company, together with the other shareholders of TSM and TMB (as guarantor within the framework and the limits stated by the Final Agreement for the Re-adaptation of WEM, Note SE no. 1368/05 and trust agreements), BICE, TSM, TMB and SE signed: a) on January 7, 2020 an amendment addenda of the Operation and Maintenance (“OMA”) of Thermal Plant Manuel Belgrano and b) on January 9, 2020 an amendment addenda of the OMA of Thermal Plant San Martín, to extend the operating period until the effective transference of the trust’s liquidation equity.
The values recorded in these financial statements for the investments in TMB and TSM are included in non- current assets under other financial assets as of December 31, 2021, for an amount of
b) Resolution No. 95/2013, Resolution No. 529/2014, Resolution No. 482/2015 and Resolution No. 22/2016
On March 26, 2013, the former Secretariat of Energy released Resolution No. 95/2013 (“Resolution 95”), which affects the remuneration of generators whose sales prices had been frozen since 2003. This new regulation, which modified the current regulatory framework for the electricity industry, is applicable to generators with certain exceptions. It defined a new compensation system based on compensating for fixed costs, non-fuel variable costs and an additional remuneration. Resolution 95 converted the Argentine electric market towards an “average cost” compensation scheme. Resolution 95 applied to all Company’s plants, excluding La Plata plant, which also sells energy in excess of YPF’s demand on the Spot market pursuant to the framework in place prior to Resolution 95.
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CENTRAL PUERTO S.A.
In addition, Resolution 95 addressed LVFVD receivables not already included in any one of the FONINVEMEM trusts.
Thermal units must achieve an availability target which varies by technology in order to receive full fixed cost revenues. The availability of all Company’s plants exceeds this market average. As a result of Resolution 95, revenues to Company’s thermal units increased, but the impact on hydroelectric plant Piedra del Águila is dependent on hydrology. The new Resolution also established that all fuels, except coal, are to be provided by CAMMESA.
The resolution also established that part of the additional remuneration shall be not collected in cash rather it is implemented through LVFDV and will be directed to a “New Infrastructure Projects in the Energy Sector” which need to be approved by the former Secretariat of the Energy.
Finally, Resolution 95 suspended the inclusion of new contracts in the Term market as well as their extension or renewal. Notwithstanding the foregoing, contracts in force as at the effective date of Resolution 95 were continue being managed by CAMMESA upon their termination. As from such termination, large users should acquire their supplies directly from CAMMESA. Also, Resolution 95 temporarily suspended the acquisition of fuel by the generation agents. All fuel purchases for the generation of electric power are centralized through CAMMESA.
On May 23, 2014, the Official Gazzette published Resolution No. 529/2014 issued by the former Secretariat of Energy (“Resolution 529”) which retroactively updated the prices of Resolution 95 to February 1, 2014, changed target availability and added a remuneration for non-recurrence maintenance. This remuneration is implemented through LVFDV and is aimed to cover the expenses that the generator incurs when performing major maintenances in its units.
On July 17, 2015, the Secretariat of Electric Energy set forth Resolution No. 482/2015 (“Resolution 482”) which retroactively updated the prices of Resolution 529 to February 1, 2015, and created a new trust called “Recursos para las inversiones del FONINVEMEM 2015-2018” in order to invest in new generation plants. Company’s plants would receive compensation under this program.
Finally, on March 30, 2016, through Resolution No. 22/2016 (“Resolution 22”), the values set by Resolution 482 were updated to become effective as from the transactions of February 2016.
c) Resolution No. 19/2017
On January 27, 2017, the Secretariat of Electric Energy (“SEE”) issued Resolution SEE No. 19/17 (published in the Official Gazette on February 2, 2017) (Resolution 19), which replaced Resolution 95, as amended. This resolution changes electric energy generators remuneration methodology for transactions operated since February 1, 2017.
Resolution 19 substantially amended the tariff scheme applicable, which was previously governed by Resolution 22. Among its most significant provisions, such resolution established: (a) that generation companies would receive a remuneration of electric power generated and available capacity, (b) gradual increases in tariffs effective as of February, May and November 2017, (c) that the new tariffs would be denominated in U.S. dollars, instead of Argentine pesos, thus protecting generation companies from potential fluctuations in the value of the Argentine peso and (d) 100% of the energy sales are collected in cash by generators, eliminating the creation of additional LVFVD receivables.
Pursuant to this resolution, the Secretariat of Electric Energy established that electricity generators, co- generators and self-generators acting as agents in the WEM and which operate conventional thermal power plants, may make guaranteed availability offers (ofertas de disponibilidad garantizada) in the WEM. Pursuant to these offers, these generation companies may commit specific capacity and power output of the generation, provided that such capacity and energy had not been committed under other power purchase agreements. The offers must be accepted by CAMMESA (acting on behalf of the electricity demanding agents of the WEM), who will be the purchaser of the power under the guaranteed availability agreements (compromisos de disponibilidad garantizada). The term of the guaranteed availability agreements is 3 years, and their general terms and conditions are established in Resolution 19.
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CENTRAL PUERTO S.A.
Resolution 19 also establishes that WEM agents that operate hydroelectric power plants shall be remunerated for the energy and capacity of their generation units in accordance with the values set forth in such resolution.
d) SGE (Secretaría de Gobierno de Energía) Resolution No. 70/2018 and Ministry of Productive Development Resolution No. 12/2019
On November 6, 2018, Resolution No. 70/2018 of the SGE was published, which resolution replaces Article 8 of Resolution issued by former SE no. 95/2013. The new article allows MEM Generators, Autogenerators and Cogenerators to obtain their own fuel. This does not alter the commitments assumed by Generation Agents within the context of MEM supply agreements with CAMMESA. It is established that generation costs with their own fuel will be valued according to the recognition mechanism of Average Variable Costs (“CVP”) recognized by CAMMESA. The Resolution also establishes that regarding those Generators not purchasing their own fuel, CAMMESA will continue the commercial management and the fuel supply.
Regarding this matter, under Resolution No. 12/2019 by the Ministry of Productive Development (published in the Official Gazette on December 30, 2019) fuel purchase for the generation of electric power is once again centralized through CAMMESA, therefore repealing the effect of Resolution No. 70/2018 of the former Secretariat of Energy, and Section 8 of Resolution No. 95/2013 of the former Secretariat of Energy and Section 4 of Resolution No. 529/2014 of the former Secretariat of Energy are back in force.
e) Resolution of the Secretariat of Renewable Resources and Electricity Market no. 1/2019
On March 1, 2019 Resolution No. 1/2019 (“Resolution 1”) of the Secretariat of Renewable Resources and Electricity Market was published in the Official Gazette by virtue of which Resolution 19 was abolished. It establishes the new remuneration values of energy, power and associated services for the affected generators, as well as their application methodology. Its validity commences on the date of its publication in the Official Gazette.
According to Resolution 1, the approved remuneration system will be of transitional application and until the following are defined and gradually implemented: regulatory mechanisms aimed at reaching an autonomous, competitive and sustainable operation that allows for freedom of contract between supply and demand; and a technical, economical and operative functioning for the integration of different generation technologies so as to guarantee a reliable and cost effective system.
The following are the main changes introduced by Resolution 1 in connection with Resolution 19:
Energy Sale:
– | The price of energy generated by thermal power stations is reduced. Therefore, the price for energy generated with natural gas is of 4 USD/MWh and 7 USD/MWh for energy generated with liquid fuel. |
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– | The price of energy operated by thermal power stations is reduced. Therefore, the price for energy operated with any fuel is of 1.4 USD/MW. |
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– | The price for energy generated from non-conventional energy sources (renewable energies) is fixed at 28 USD/MWh. |
Power Sale:
– | DIGO price (established by Resolution 19) goes from 7,000 USD/MW-month during the twelve months of the year to 7,000 USD/MW-month the six months of higher seasonal demand for electrical energy (December, January, February, June, July and August) and to 5,500 USD/MW-month the remaining months of the year (March, April, May, September, October and November). |
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– | Some minimum values of offered availability are reduced. Its compliance is subject to the foregoing prices. |
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– | A weighting factor is fixed for foregoing prices, between 1 and 0.7, depending on the use factor of the twelve months previous to each month of the transaction. |
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CENTRAL PUERTO S.A.
f) Resolution No. 31/2020 of the Secretariat of Energy
On February 27, 2020, the Secretariat of Energy published in the Official Gazette Resolution No. 31 (“Resolution 31”) which sets forth the criteria to calculate the economic transactions of energy and power that the generating parties commercialize in the spot market, which is in force as from February 1, 2020.
This new regulation, contrary to Resolution 1, establishes all prices for the remuneration of energy and power in Argentine pesos, and it sets forth that the prices shall be adjusted on a monthly basis with a formula based on the evolution of Consumer Price Index (IPC) and the Domestic Wholesale Price Index (IPIM). New power prices are generally reduced in relation to the current prices as at January 2020, and the energy prices remain equivalent, expressed in Argentine pesos instead of US dollars. Finally, this regulation introduces a new remuneration component which applies to the energy generated during the first 50 hours of maximum thermal requirement of the month (MTR, which is determined by the sum of the hours of all the thermal generation of the system), it determines different remuneration prices based on the season of the year and the energy delivered during the first and second 25 hours of MTR.
On April 8, 2020, the Company learned that the Secretariat of Energy instructed CAMMESA to postpone until further notice the application of the price update mechanism described in the second paragraph of this note. Accordingly, CAMMESA did not apply the price update mechanism to the energy and power sold since March 2020.
g) Secretariat of Energy Resolution No. 440/2021
Through Resolution No. 440 (“Resolution 440”), published in the Official Gazette on May 21, 2021, the Secretariat of Energy established a new remuneration scheme for MEM generation agents. In this regard, Exhibits II, III, IV and V of Resolution 31 were replaced. Moreover, section 2 of Resolution 31, which established a system for the automatic updating of remuneration values, was repealed. In general terms, Resolution 440 increased the remuneration values of generation agents by 29% compared to Resolution 31.
It was established that for the application of what Resolution 440 set forth (collection of the new remuneration values as from February 2021 transactions, among others), MEM generation agents had to submit before CAMMESA a note -to CAMMESA’s satisfaction- stating full and unconditional withdrawal of any administrative complaint or ongoing judicial procedure against the National Government, the Secretariat of Energy and/or CAMMESA, related to section 2 of Resolution 31. Dated June 17, 2021, the Company submitted the requested withdrawal note.
In addition, on November 9, 2021, the Secretariat of Energy established that in order to determine the Power Availability Remuneration of thermal generators under Resolution 440, a constant Utilization Factor equal to 70% had to be considered until February 2022.
h) Secretariat of Energy Resolution No. 354/2020
This resolution established, among other things, that as from the effectiveness of Plan “GasAr” (Plan Gas 4), Generators of WEM may adhere to centralized dispatch, assigning CAMMESA such contracts entered into with producers or transporters of natural gas, so that such contracts are used by the Dispatch Entity (OED for its acronym in Spanish), based on dispatch criteria.
In addition, this resolution established that generation agents who, pursuant to Resolution No. 287/2017, have the obligation of self-procuring fuel are able to deem such obligations and the recognition of associated costs, but maintaining the transport capacity for centralized dispatch management, as long as CAMMESA determines its convenience.
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i) Secretariat of Energy Resolution No. 1037/2021
On November 2, 2021, Resolution No.1037/2021 was published in the Official Gazette, whereby the Secretariat of Energy, upon verifying a status of high energy demand in Brazil due droughts in the area, created an Exports Account where the revenue margins will be accumulated after such electric power export. Such amounts will be destined to financing energy infrastructure works.
In addition, through such Resolution, the Secretariat informed there will be an additional and temporary recognition in the remuneration of Generation Agents under the scope of Resolution 440, covering economic transactions between September 1, 2021 and February 28, 2022. Such recognition was established in an exported 1000 $/MWh additional amount during the month, which will be assigned in a proportional manner to the power generated on a monthly basis to each generating agent.
j) Secretariat of Energy Resolution No. 238/2022
On April 21, 2022, Resolution No. 238/2022 issued by the Secretariat of Energy was published in the Official Gazette. This resolution updates remuneration prices for energy and capacity of generation units not committed on a Purchase Power Agreement, it replaces Annex I to V of the former Resolution 440 and it eliminates section 4 of Resolution No. 1037/2021, which is described in Note 1.2.i). It also removes the Use Factor from the capacity payment calculation, improving revenue performance. In this way, this resolution increases by 30% the remuneration values starting February 2022, and it provides an additional 10% above the new values starting on June 2022.
2. Basis of preparation of the consolidated financial statements
2.1. Basis of preparation
The consolidated financial statements of the Group have been prepared in accordance with International Financial Reporting Standards (IFRS) as issued by the International Accounting Standards Board (IASB).
The attached financial statements have been prepared in order to be included in a Securities and Exchange Commission (“SEC”) filing and have been approved by the Company’s Board of Directors on April 28, 2022.
These consolidated financial statements provide comparative information in respect of the previous years.
In preparing these consolidated financial statements, the Group applied the significant accounting policies, estimates and assumptions described in Notes 2.2 and 2.3, respectively. Moreover, the Group has adopted the changes in accounting policies described in Note 2.4.
The Group’s consolidated financial statements are presented in Argentine pesos, which is the Group’s functional currency, and all values have been rounded to the nearest thousand (ARS 000), except when otherwise indicated.
2.1.1. Basis of consolidation
The consolidated financial statements as of December 31, 2021 and 2020 and for each of the years ended December 31, 2021, 2020 and 2019, include the financial statements of the Group formed by the parent company and its subsidiaries: Central Vuelta de Obligado S.A., Vientos La Genoveva S.A.U., Vientos La Genoveva II S.A.U., Proener S.A.U., CP Renovables S.A. and its subsidiaries.
Control is achieved when the investor is exposed or entitled to variable returns arising from its ownership interest in the investee, and has the ability to affect such returns through its power over the investee. Specifically, the investor controls an investee, if and only if it has:
– | Power over the investee (i.e. the investor has rights that entitle it to direct the relevant activities of the investee). |
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– | Exposure or right to variable returns arising from its ownership interest in the investee. |
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– | Ability to exercise its power over the investee to significantly affect its returns. |
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Restatement of the Statement of Cash Flows
IAS 29 sets forth that all the items of this section shall be restated in terms of the current measurement unit at the closing date of the reported period.
The monetary result generated by cash and equivalents to cash are stated in the Statement of Cash Flows separately from the cash flows resulting from operation, investment and financing activities as a specific item of the conciliation between the existence of cash and cash equivalents at the beginning and at the end of the period.
2.2. Summary of significant accounting policies
The following are the significant accounting policies applied by the Group in preparing its consolidated financial statements.
2.2.1. Classification of items as current and non-current
The Group classifies assets and liabilities in the consolidated statement of financial position as current and non-current. An entity shall classify an asset as current when:
– | it expects to realize the asset, or intends to sell or consume it, in its normal operating cycle; |
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– | it holds the asset primarily for the purpose of trading; |
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– | it expects to realize the asset within twelve months after the reporting period; or |
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– | the asset is cash or a cash equivalent unless the asset is restricted from being exchanged or used to settle a liability for at least twelve months after the reporting period. |
All other assets are classified as non-current. An entity shall classify a liability as current when:
– | it is expected to be settled in normal operating cycle; |
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– | It is held primarily for the purpose of trading; |
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– | it is due to be settled within twelve months after the reporting period; or |
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– | there is no unconditional right to defer the settlement of the liability for at least twelve months after the reporting period. |
All other liabilities are classified as non-current.
Deferred tax assets and liabilities are classified as non-current assets and liabilities, in all cases.
2.2.2. Fair value measurement
The Group measures certain financial instruments at their fair value at each reporting date. In addition, the fair value of financial instruments measured at amortized cost is disclosed in Note 13.5.
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 either:
– | in the principal market for the asset or liability, or |
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– | in the absence of a principal market, in the most advantageous market for the asset or liability. |
The principal or the most advantageous market must be accessible to the Group. 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, assuming that market participants act in their economic best interest.
A fair value measurement of a non-financial asset takes into account a market participant’s ability to generate economic benefits by using the asset in its highest and best use or by selling it to another market participant that would use the asset in its highest and best use.
The Group uses valuation techniques that are appropriate in the circumstances and for which sufficient data are available to measure fair value, maximizing the use of relevant observable inputs and minimizing the use of unobservable inputs.
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All assets and liabilities for which fair value is measured or disclosed in the consolidated financial statements are categorized within the fair value hierarchy, described as follows, based on the lowest level input that is significant to the fair value measurement as a whole:
– | Level 1 input data: quoted (unadjusted) prices in active markets for identical assets or liabilities. |
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– | Level 2 input data: valuation techniques with input data other than the quoted prices included in Level 1, but which are observable for assets or liabilities, either directly or indirectly. |
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– | Level 3 input data: valuation techniques for which input data are not observable for assets or liabilities. |
2.2.3. Transactions and balances in foreign currency
Transactions in foreign currencies are recorded by the Group at the related functional currency rates prevailing at the date of the transaction.
Monetary assets and liabilities denominated in foreign currencies are translated at the functional currency spot rate of exchange ruling at the reporting period-end.
All differences are taken to consolidated statement of income under other operating income or expenses, or under finance income or expenses, depending on the nature of assets or liabilities generating those differences.
Non-monetary items that are measured in terms of historical cost in a foreign currency are translated using the exchange rates as at the dates of the initial transactions. Non-monetary items measured by their fair value in foreign currency are converted using exchange rates at the date in which such fair value is determined.
2.2.4. Revenue recognition
2.2.4.1. Revenue from ordinary activities
IFRS 15 presents a five-step detailed model to explain revenue from contracts with customers. Its fundamental principal lies on the fact that an entity has to recognize revenue to represent the transference of goods or services promised to the customers, in an amount reflecting the consideration the entity expects to receive in exchange for those goods or services at the moment of executing the performance obligation. An asset is transferred when (or while) the client gets control over such asset, defined as the ability to direct the use and substantially obtain all the remaining benefits of the asset. IFRS 15 requires the analysis of the following:
– | If the contract (or the combination of contracts) contains more than one promised good or service, when and how such goods or services should be granted. |
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– | If the price of the transaction distributed to each performance obligation should be recognized as revenue throughout time or at a specific moment. According to IFRS 15, an entity recognizes revenue when the performance obligation is satisfied, i.e. every time control over those goods and services is transferred to the customer. The new model does not include separate guidelines for the “sale of goods” and the “rendering of services”; instead, it requires that entities should evaluate whether revenue should be recognized throughout time or at a specific moment, regardless of the fact that it includes “the sale of goods” or “the rendering of services”. |
– | When the price includes an estimation element of variable payments, how that will affect the amount and the time to recognize such revenue. The concept of variable payment estimation is broad. A transaction price is considered as variable due to discounts, reimbursement, credits, price concessions, incentives, performance bonus, penalties and contingency agreements. The new model introduces a big condition for a variable consideration to be considered as revenue: only as long as it is very unlikely for a significant change to occur in the cumulative revenue amount, when the uncertainties inherent to the variable payment estimation are solved. |
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– | When the incurred cost to close an agreement and the costs to comply with it can be recognized as an asset. |
The Company has a sole relevant revenue source, which consists on the commercialization of energy produced in the spot market and under the energy supply agreements, CAMMESA being its main customer.
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CENTRAL PUERTO S.A.
The Company recognizes its sales revenue in accordance with the availability of its machines’ effective power, the energy and steam supplied; and as balancing entry, a sales receivable is recognized, which represents the Company’s unconditional right to consideration owed by the customer. Billing for the service is monthly made by CAMMESA in accordance with the guidelines established by SEE; and compensation is usually received in a maximum term of 90 days. Therefore, no implicit financing components are recognized. The satisfaction of the performance obligation is done throughout time since the customer simultaneously receives and consumes the benefits given by the performance of the entity as the entity does it.
Revenues from energy, power and steam sales are calculated at the prices established in the respective contracts or at the prices prevailing in the electricity market, according to the regulations in force. These include revenues from the sale of steam, energy and power supplied and not billed until the closing date of the reported period, valued at the prices defined in the contracts or in the respective regulations.
Additionally, the Group recognizes the sales from contracts regarding the supplied energy and the prices established in such contracts, and as balancing entry it recognizes an account receivable. Such credit represents the unconditional right the Company has to receive the consideration owed by the customer. Billing for the service is monthly made by CAMMESA in the case of the contracts of the wind farms La Castellana and Achiras and for the Energía plus contract in accordance with the guidelines established by SEE; and compensation is received in a maximum term of 90 days. Therefore, no implicit financing components are recognized. For the rest of the clients, billing is also monthly and done by the Company; and compensation is received in a maximum term of 90 days. Therefore, no implicit financing components are recognized. The satisfaction of the performance obligation is done throughout time since the customer simultaneously receives and consumes the benefits given by the performance of the entity as the entity does it.
The Group recognizes revenues from resale and distribution of gas and revenues for the monthly management of the thermal power plant CVO in accordance with the monthly fees established in the respective contracts and as balancing entry, it recognizes a sale credit. Such credit represents the unconditional right the Company has to receive the consideration owed by the customer. Billing for the service is also monthly made by the Company and compensation is generally received in a maximum term of 90 days. Therefore, no implicit financing components are recognized.
The detail of revenues from ordinary activities of the Group is included in Note 5 to these consolidated financial statements.
2.2.4.2. Other income and expenses - Interest
For all financial assets and liabilities measured at amortized cost and interest bearing financial assets classified as available for sale, interest income or expense is recorded using the effective interest rate method, which is the rate that exactly discounts the estimated future cash payments or receipts through the expected life of the financial instrument or a shorter period, where appropriate, to the net carrying amount of the financial asset or liability. In general, interest income and expense are included in finance income and expenses in the consolidated statement of income, respectively, unless they derive from operating items (such as trade and other receivables or trade and other payables); in that case, they are booked under other operating income and expenses, as the case may be.
2.2.5 Taxes
Current income tax
Current income tax assets and liabilities for the year are measured at the amount expected to be recovered from or paid to the taxation authorities. The tax rates and tax laws used to compute those amounts are those that are enacted or substantively enacted, at the end of the reporting period. The statutory tax rate for the Group for the fiscal year 2021 is
Current income tax relating to items recognized directly in equity is recognized in equity and not in the consolidated statement of income.
Management periodically assesses the positions taken in each tax report regarding the situations in which the applicable tax regulations are subject to interpretation, and it determines whether they must be treated as uncertain tax treatment, and in such case, whether it must be treated independently or collectively with one or more tax treatments, pursuant to IFRIC 23. For these cases, we use the approach which better predicts uncertainty and applies criteria to identify and quantify uncertainties.
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CENTRAL PUERTO S.A.
Deferred income tax
Deferred income tax is provided using the liability method on temporary differences at the end of the reporting period between the tax bases of assets and liabilities and their related carrying amounts.
Deferred income tax liabilities are recognized for all taxable temporary differences, except:
– | where the deferred income tax liability arises from the initial recognition of goodwill or of an asset or liability in a transaction that is not a business combination and, at the time of the transaction, affects neither the accounting profit nor taxable profit or loss; |
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– | in respect of taxable temporary differences associated with investments in subsidiaries and associates, where the timing of the reversal of the temporary differences can be controlled and it is probable that the temporary differences will not reverse in the foreseeable future. |
Deferred income tax assets are recognized for all deductible temporary differences and tax carry forwards losses, to the extent that it is probable that taxable profit will be available against which the deductible temporary differences, and/or the tax losses carry forward can be utilized, except:
– | where the deferred income tax asset arises from the initial recognition of an asset or liability in a transaction that is not a business combination and, at the time of the transaction, affects neither the accounting profit nor taxable profit or loss; |
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– | in respect of deductible temporary differences associated with investments in subsidiaries, associates and interests in joint ventures, deferred income tax assets are recognized only to the extent that it is probable that the deductible temporary differences will reverse in the foreseeable future and taxable profit will be available against which those differences can be utilized. |
The carrying amount of deferred income tax assets is reviewed at each reporting period date and reduced against income or loss for the period or other comprehensive income, as the case may be, to the extent that it is no longer probable that sufficient taxable profit will be available to allow all or part of the deferred income tax asset to be utilized (recovered). Unrecognized deferred income tax assets are reassessed at each reporting period date and are recognized with a charge to income or other comprehensive income for the period, as the case may be, to the extent that it has become probable that future taxable profits will allow the deferred income tax asset not previously recognized to be recovered.
Deferred income tax assets and liabilities are measured at undiscounted nominal value at the tax rates that are expected to apply in the year when the asset is realized or the liability is settled, based on tax rates and tax laws that have been enacted or substantively enacted at the reporting period date.
Deferred income tax relating to items recognized outside profit or loss is recognized outside profit or loss. Deferred income tax items are recognized in correlation to the underlying transactions either in other comprehensive income or directly in equity.
Deferred income tax assets and deferred income tax liabilities are offset if a legally enforceable right exists to set off current income tax assets and liabilities and the deferred income taxes relate to the same taxable entity and the same taxation authority.
Uncertainties over income tax treatments
The Group determines whether each tax treatment should be considered independently or whether some tax treatments should be considered together and uses an approach that provides better predictions of the resolution of the uncertainty.
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CENTRAL PUERTO S.A.
The Group applies significant judgment when identifying uncertainties on the income tax treatment. The Group evaluated whether the Interpretation had an impact on its consolidated financial statements, especially within the framework of tax inflation adjustment in determining the tax income of mentioned periods:
a) Income tax return for fiscal year 2014
In February 2015 CPSA filed income tax returns for the nine-month period ended September 30, 2014, applying the adjustment for inflation mechanism established by the Argentine Income Tax Law. In addition, the Company filed its income tax return for the three-month period ended December 31, 2014, applying the same adjustment for inflation mechanism.
Later on, on July 27, 2021, the Argentine Tax Authorities issued a resolution through which it implemented an infringement investigation in relation to the income tax for the irregular fiscal periods ended September 2014 and December 31, 2014, for the alleged omission included in Section 45, Law No. 11,683. On September 8, 2021, CPSA submitted the corresponding deposition and the corresponding evidence. As the date of the issuance of these financial statements, the proceedings are kept by Argentine Tax Authorities.
b) Action for recovery - Income tax refund for fiscal period 2010
In December 2014, the Company, as merging company and continuing company of HPDA, raised a recourse action before fiscal authorities regarding the income tax for the fiscal period 2010, which was incorrectly entered by HPDA. This recourse action seeks to recover the income tax entered by HPDA in accordance with the lack of application of the inflation- adjustment mechanism established by the Law on Income Tax. In December 2015, since the term stated by Law no. 11,683 elapsed, the Company brought a contentious- administrative claim before the National Court to ask for its right to obtain the income tax recovery.
In October 2018, the Company was served notice of the judgment issued by the Federal Contentious- Administrative Court No. 5, which granted the right to recourse. The judgment ordered tax authorities to return the amount of 67,612 (at historical values) to the Company plus the interest stated in the BCRA Communication 14290 and ordered that legal cost must be borne by the defendant. Such judgment was appealed by the National Tax Administration, and on September 9, 2019, Division I of the National Court of Appeals of the Federal Contentious- Administrative Court (“CNACAF”) confirmed the appealed judgment. On September 24, 2019, the National Tax Administration raised Federal Extraordinary Appeal (“REF”) against CNACAF judgment, which was replied by the Company. On October 29, 2019, CNACAF granted the REF and sent the file to the Argentine Supreme Court.
c) Action for recovery - income tax refund for fiscal years 2009, 2011 and 2012
In December 2015, the Company filed a petition with the Argentine Tax Authorities for the recovery of income tax for the fiscal year 2009, in the amount of 20,395 at historical values which had been incorrectly paid by the Company in excess of our income tax liability. By filling such action, the Company seeks to recover the excess income tax paid by CPSA due to the failure to apply the adjustment for inflation set forth in the Argentine Income Tax Law. On April 22, 2016, after the term required by Law No. 11,683 expired, the Company filed an action for recovery for the amount claimed with the Argentinean Tax Court. On September 27, 2019, the judge entered judgment rejecting the complaint filed by the Company. Such judgment was appealed by the Company last October 4, 2019. Room I of CNACAF (Argentine Appeal Court for Federal Contentious Administrative Matters) granted the appeal presented by the Company on March 11, 2020. Upon this resolution, the Argentine Tax Authorities raised an Extraordinary Appeal, which was granted by CNACAF on September 1, 2020.
In December 2017, the Company, as merging company and continuing company of HPDA, filed a petition with the Argentine Tax Authorities for the recovery of 52,783 at historical values paid in excess by HPDA for payment of Income Tax for 2011 fiscal period. The purpose of such action is to recover the income tax paid by HPDA due to the failure to apply the adjustment for inflation mechanism aforementioned. On April 1, 2019 such claim was rejected by national fiscal authorities. Therefore, the Company filed an administrative and legal action on April 25, 2019.
In December 2018, the Company brought two administrative complaints of recovery before the Argentine Tax Authorities: the first one was filed by the Company, as merging company and continuing company of HPDA, regarding the income tax for the fiscal period 2012 that amounted to 62,331 at historical values, which was entered in excess by HPDA. The second complaint was filed by the Company regarding the income tax for the same fiscal period that amounted to 33,265 at historical values, which was entered in excess by the Company. These recourse actions seek to recover the income tax entered by HPDA and the Company in accordance with the lack of application of the inflation-adjustment mechanism aforementioned. On September 12, 2019, the Company filed both recourse actions before the Federal Contentious- Administrative Court against the Argentine Tax Authorities in accordance with Section 82, paragraph “c” of Law no. 11,683 (restated text 1998 as amended), as the term established in the second paragraph of Section 81 of such law had elapsed.
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CENTRAL PUERTO S.A.
d) Action for recovery - Income tax for the fiscal year 2015
On December 23, 2020, the Company submitted before the fiscal authorities an action for recovery of the income tax for the fiscal year 2015 for the amount of 129,231 (at historical values) unduly paid by CPSA. The purpose of the action for recovery is to obtain reimbursement of the income tax paid by CPSA based on the lack of application of the inflation adjustment mechanism set forth in the Argentine Income Tax Act. On April 22, 2021, the Company filed a recovery lawsuit before the Court for Contentious Administrative Matters against the Argentine Tax Authorities pursuant to the provisions of Section 82, subsection c of Law No. 11,683 (restated and amended 1998), on the grounds that the term established in the second paragraph of Section 81 of that body of rules had elapsed.
e) Action of recovery - Income tax for the fiscal year 2016
On January 24, 2022, the Company filed before the tax authorities a recovery action of the income tax for the fiscal year 2016, for the amount of 189,376 (at historical values) unduly paid by CPSA. Such recovery action is aimed at obtaining the reimbursement of the income tax paid by CPSA based on the lack of application of the inflation adjustment mechanism set forth by the Argentine Income Tax Act.
The Group considered, based on the opinion of its legal advisors and on the IFRIC 23 accounting guidelines: 1) regarding the income tax 2014 determination stated in a), that it is probable that tax authorities will accept the position and, therefore, it is not required to register a liability under such item, and 2) regarding recourse actions for income tax, except for the case of recourse action by HPDA for the fiscal period 2011, that it is also probable that the positions adopted by the Company will be accepted in court; therefore, an asset has been recognized for such recourse actions.
The corresponding asset is included in the item “Other non-financial assets” of Current Assets under “Income Tax Credits” and it amounts to
Other taxes related to sales and to bank account transactions
Revenues from recurring activities, expenses incurred and assets are recognized excluding the amount of sales tax, as in the case of value-added tax or turnover tax, or the tax on bank account transactions, except:
– | where the tax incurred on a sale or on a purchase of assets or services is not recoverable from the taxation authority, in which case the sales tax is recognized as part of the cost of acquisition of the asset or as part of the expense item as the case may be; |
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– | receivables and payables are stated including value-added tax. |
The charge for the tax on bank account transactions is presented in the administrative and selling expenses line within the consolidated statement of income.
The net amount of the tax related to sales and to bank account transactions recoverable from, or payable to, the taxation authority is included as a non-financial asset or liability, as the case may be.
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CENTRAL PUERTO S.A.
2.2.6. Property, plant and equipment
Property, plant and equipment are measured at the acquisition cost restated according to Note 2.1.2, net of the cumulative depreciation and/or the cumulative losses due to impairment, if any. This cost includes the cost of replacing components of property, plant and equipment and the cost for borrowings related to long-term construction projects, as long as the requirements for their recognition as assets are fulfilled.
When significant parts of property, plant and equipment are required to be replaced at intervals, the Group derecognizes the replaced part and recognizes the new part with its own associated useful life and depreciation. Likewise, when a major maintenance is performed, its cost is recognized as a replacement if the conditions for the recognition thereof as an asset are met. All other regular repair and maintenance costs are recognized in the consolidated statement of income as incurred.
Electric power facilities and materials and spare parts related to the Puerto Combined Cycle plant are depreciated on a unit-of-production basis.
Electric power facilities related to the Luján de Cuyo combined cycle plant and cogeneration unit, the Terminal 6 - San Lorenzo cogeneration unit and the Brigadier Lopez thermal station are depreciated on a straight-line basis over the total useful lives estimated.
Electric power facilities and auxiliary equipment of Piedra del Águila hydroelectric power plant are depreciated on a straight-line basis over the remaining life of the concession agreement of the mentioned power plant.
The depreciation of the remaining property, plant and equipment is calculated on a straight-line basis over the total estimated useful lives of the assets as follows:
– | Buildings: |
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– | Wind turbines: |
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– | Lands |
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– | Material and spare parts: |
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– | Furniture, fixtures and equipment: |
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– | Others: |
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– | Gas turbines and Construction in progress: |
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CENTRAL PUERTO S.A.
An item of property, plant and equipment and any significant part initially recognized is derecognized upon disposal or when no future economic benefits are expected from its use or disposal. Any gain or loss arising on derecognition of the asset (calculated as the difference between the net disposal proceeds and the carrying amount of the asset) is included in the consolidated statement of income when the asset is derecognized.
The residual values, useful lives and methods of depreciation are reviewed at each reporting period end and adjusted prospectively, if appropriate.
During year ended December 31, 2020 and 2019, the Group capitalized interest for an amount of
2.2.7. Intangible assets
Intangible assets acquired separately are measured on initial recognition at acquisition cost restated according to Note 2.1.2. The cost of the intangible assets acquired in a business combination is their fair value at the date of the acquisition. Following initial recognition, intangible assets are carried at cost less accumulated amortization (if they are considered as having finite useful lives) and accumulated impairment losses, if any.
The useful lives of intangible assets are assessed as either finite or indefinite. The useful lives of the intangible assets recognized by the Group are finite.
Intangible assets with finite useful lives are amortized over their useful economic lives. The amortization period and the amortization method for an intangible asset with a finite useful life are reviewed at least at the end of each reporting period. Changes in the expected useful life or the expected pattern of consumption of the asset is accounted for by changing the amortization period or method, as appropriate, and are treated prospectively as changes in accounting estimates. The amortization expense on intangible assets with finite lives is recognized in the consolidated statement of income in the expense category consistent with the function of the intangible assets.
The Group’s intangible assets are described in Note 12.
2.2.8. Impairment of property, plant and equipment and intangible assets
The Group assesses at each reporting period-end whether an existing event or one that took place after year end and provides additional evidence of conditions that existed at the end of the reporting period, indicates that an individual component or a group of property, plant and equipment and/or intangible assets with limited useful lives may be impaired. If any indication exists, the Group estimates the asset’s recoverable amount. An asset’s recoverable amount is the higher of the fair value less costs to sell, and the value-in-use. That amount is determined for an individual asset, unless the asset does not generate cash inflows that are largely independent of those from other assets or groups of assets; in which case, such assets are considered together as a cash-generating unit (“CGU”).
Where the carrying amount of an individual asset or CGU exceeds its recoverable amount, the individual asset or CGU, as the case may be, is considered impaired and is written down to its recoverable amount.
In assessing value in use of an individual asset or CGU, the estimated future cash flows are discounted to their present value using a pre-tax discount rate that reflects current market assessments of the time value of money and the risks specific to the individual asset or CGU, as the case may be.
In determining fair value less costs to sell, recent market transactions are taken into account, if available. If no such transactions can be identified, an appropriate valuation model is used including obtaining appraisals from valuation specialists. These calculations are verified by valuation multiples, quoted values for similar assets on active markets and other available fair value indicators, if any.
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CENTRAL PUERTO S.A.
The Group bases its impairment calculation on detailed budgets and forecast calculations which are prepared separately for each of the Group’s CGU to which the individual assets are allocated. These detailed budgets and forecast calculations generally cover a five-year period. For longer periods, if applicable, a long-term growth rate may be calculated and applied to project future cash flows after the fifth year. Budgets and calculations related to Complejo Hidroeléctrico Piedra del Águila are limited to the term of the concession contract.
Impairment losses of continuing operations are recognized in a specific line of the consolidated statement of income.
In addition, for the assets for which an impairment loss had been booked, as of each reporting period-end, an assessment is made whether there is any indication that previously recognized impairment losses may no longer exist or may have decreased.
Should there be such triggering event, the Group makes an estimate of the recoverable amount of the individual asset or of the cash generating unit, as the case may be.
A previously recognized impairment loss is reversed only if there has been a change in the assumptions used to determine the individual assets or CGU’s recoverable amount since the last impairment loss was recognized. The reversal is limited so that the carrying amount of the asset or CGU does not exceed its recoverable amount, nor exceed the carrying amount that would have been determined, net of the related depreciation or amortization, had no impairment loss been recognized for the asset or CGU in prior periods. Such reversal is recognized in the statement of income in the same line in which the related impairment charge was previously recognized (generally under the cost of sales or other operating expenses), unless the asset is carried at a revalued amount, in which case, the reversal is treated as a revaluation increase.
The Group has identified indicators of potential impairment of its property, plant and equipment and its intangible assets with limited useful life, affecting the CGUs related to the electric power generation from conventional sources operating segment, due to the repeal of the spot market price update mechanism established by Resolution 440, as described in Note 1.2.g)., combined with the current economic uncertainties. The Group has also identified indicators of potential impairment of the Company´s gas turbine due to the uncertainty about new projects that would enable the use of such turbine.
In order to measure the recoverability of its property, plant and equipment and its intangible assets with a limited useful life that present indicators of impairment, the Group estimated the value in use of such assets, except for the generating group classified as “Gas turbines”, for which the Group estimated the fair value less cost of sale. As a result of the recoverability analysis, the Group determined that the net book value of the assets related to the cogeneration unit Luján de Cuyo and hydroelectric power station Piedra del Águila and the generating group classified as " Gas Turbines", did not exceed their recoverable value as at December 31, 2021.
CGUs Thermal Station Brigadier López, Luján de Cuyo Combined Cycle Power Plant, Nuevo Puerto combined cycle power plant and Terminal 6 San Lorenzo cogeneration unit.
The Group estimated that the book value of the assets related to the Thermal Station Brigadier López exceeded its recoverable value by
In addition, the Group estimated that the book value of the assets related to Luján de Cuyo Combined Cycle Power Plant exceeded its recoverable value by
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CENTRAL PUERTO S.A.
Finally, the Group estimated that the book value of the assets related to Terminal 6 San Lorenzo cogeneration unit exceeded its recoverable value by
The Group estimated the recoverable value considering probability weighted scenarios in relation with the evolution of prices for energy and power. This approach required preparing scenarios with different estimations of the expected cash flows considering such variables and assigning occurrence probabilities, based on the experience and expectations of the Group about the outcome of the uncertainties involved.
Key assumptions to estimate the value in use are the following:
– | Gross margin: the margin has been determined for the budgeted period (5 years) based on the energy prices arising from Resolution 440 adjusted for projections of price increases and energy supply signed agreements, whereas the cost of sale was determined based on the costs incurred in the past. The most relevant cost was the plants maintenance, which was estimated with the provisions from the agreements in force with the suppliers General Electric and Siemens S.A. No growth rates were considered after the budgeted period, pursuant to IAS 36. |
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– | Discount rate: it represents the current market assessment of the specific risks of the Company, taking into consideration the time-value of money. Discount rate calculation is based on the circumstances of the market participants and it is derived from the weighted average cost of capital (WACC). The WACC rate takes into consideration both debt and equity. The cost of equity is derived from the expected return on investment by market participant investors, whereas the cost of debt is based on the conditions of the debt which market participants could access to. The specific risks of the operational segment are incorporated by applying individual beta factors, which are annually assessed from the available public information of the market. |
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| The post-tax discount rate used for determining the value in use as of December 31, 2021 was |
– | Macroeconomic variables: estimated inflation and devaluation rates, as well as exchange rates, were obtained from external sources, which are well known consulting firms dedicated to the local and global economic analysis, widely experienced in the market. An increase in inflation rates over devaluation rates, regarding the variables considered for the determination of the value in use, would entail an additional impairment loss. |
Thermal Station Brigadier López, Luján de Cuyo Combined Cycle Power Plant, Nuevo Puerto combined cycle power plant and Terminal 6 San Lorenzo cogeneration unit belong to the electric power generation from conventional sources operating segment.
2.2.9. Financial instruments. Presentation, recognition and measurement
A financial instrument is any contract that gives rise to a financial asset of one entity and a financial liability or equity instrument of another entity.
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CENTRAL PUERTO S.A.
2.2.9.1. Financial assets
Classification
According to IFRS 9 “Financial instruments”, the Group classifies its financial assets in three categories:
– | Financial assets at amortized cost |
A financial asset is measured at amortized cost if both of the following conditions are met: (i) the asset is held within a business model whose objective is to hold assets in order to collect contractual cash flows; and (ii) the contractual terms of the financial asset give rise on specified dates to solely payments of principal and interest.
Additionally, and for those assets complying with the above-mentioned conditions, IFRS 9 provides for the option of determining, at initial recognition, an asset measured at fair value if doing so would eliminate or significantly reduce a measurement or recognition inconsistency, which would appear if the assets or liabilities valuation or the recognition of their profits or losses are made on different grounds. The Group has not classified a financial asset at fair value using this option.
At the closing of these consolidated financial statements, the financial assets at amortized cost of the Group include certain cash elements and cash equivalents, trade and other receivables and other non-current financial assets.
– | Financial assets at fair value through other comprehensive income |
Financial assets are measured at fair value through other comprehensive income if they are held in a business model whose objective is achieved by both collecting contractual cash flows and selling financial assets.
At the closing of these consolidated financial statements, the Group has not financial assets at fair value through other comprehensive income.
– | Financial assets at fair value through profit or loss |
Any financial assets at fair value through profit or loss belong to a residual category that includes the financial assets that are not held in one of the two business models mentioned, including those kept to negotiate and those classified at fair value at initial recognition.
At the closing of these consolidated financial statements, the financial assets of the Group at fair value through profit or loss include mutual funds, public debt securities, stocks and corporate bonds accounted under other financial assets.
Recognition and measurement
The purchase and sale of financial assets are recognized at the date on which the Group commits to purchase or sale the asset.
Financial assets valued at amortized cost are initially recognized at their fair value plus cost of transaction. These assets accrue interest according to the effective interest rate method.
Financial assets valued at fair value through profit or loss and other comprehensive income are initially recognized at fair value, and transaction costs are recognized as expenses in the comprehensive income statement. Subsequently, they are valued at fair value. Changes in fair value and income from the sale of financial assets at fair value through profit or loss and other comprehensive income are recorded in Finance Income or Finance Expenses and Other comprehensive income, respectively, in the consolidated statement of income and comprehensive income, respectively.
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CENTRAL PUERTO S.A.
In general, the Group uses the transaction price to determine the fair value of a financial instrument at the initial recognition. In the rest of the cases, the Group only records revenue or loss at initial recognition if the fair value of the instrument is evidenced with other comparable and visible transactions of the market for the same instrument or if it is based on a valuation technique that only includes visible market data. Revenue or loss not recognized at the initial recognition of a financial asset is later recognized as long as they derive from a change in factors (including time) in which the market participants consider establishing the price.
The profit or loss of debt instruments which are measured at amortized cost and are not designated as hedge instruments are recognized in profit or loss when the financial assets are removed or when impairment is recognized and during the amortization process by using the effective interest rate method. The Group only reclassifies all investments in debt instruments when it changes the business model used to manage those assets.
Derecognition of financial assets
A financial asset (or, where applicable, a part of a financial asset or part of a group of similar financial assets) is derecognized; that is to say, it is deleted from the statement of financial position, when:
– | the contractual rights to receive cash flows from the asset have expired; |
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– | the contractual rights to receive cash flows from the asset have been transferred or an obligation has been assumed to pay the received cash flows in full without material delay to a third party under a ‘pass-through’ arrangement; and either (a) all the risks and rewards of the asset have been transferred substantially, or (b) all the risks and rewards of the asset have neither been transferred nor retained substantially, but control of the asset has been transferred. |
When the contractual rights to receive cash flows from an asset have been transferred or a pass-through arrangement has been entered into, but all of the risks and rewards of the asset have neither transferred nor retained substantially and no control of it has been transferred, such asset shall continue to be recognized to the extent of the Group’s continuing involvement in it. In this case, the Group shall also recognize the associated liability. The transferred asset and the associated liability are measured on a basis that reflects the rights and obligations that the Group has retained.
Impairment of financial assets
IFRS 9 establishes an “expected credit loss” model (“ECL”). This requires the application of considerable judgment with regard to how changes in economic factors affect ECL, which is determined over a weighted average base. ECL results from the difference between contractual cash flows and cash flows at current value that the Group expects to receive.
The impairment model set forth by IFRS 9 is applicable to the financial assets measured at amortized value or at fair value through changes in other comprehensive income, except for the investment in equity securities and assets from the contracts recognized under IFRS 15.
Pursuant to IFRS 9, loss allowances are measured using one of the following bases:
– | The 12-month ECL: these are expected credit losses that result from those default events on the financial instrument that are possible within 12 months after the reporting date; and |
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– | Full lifetime expected credit losses: these are expected credit losses that result from all possible default events over the life of the financial instrument. |
Given the nature of the clients with which the Group operates and on the base of the foregoing criteria, the Group did not identify expected credit losses.
With regard to financial placements and according to the placement policies in force, the Group monitors the credit rate and the credit risk of these instruments. Pursuant to the analysis, the Group did not identify the need to record impairment of these types of instruments.
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CENTRAL PUERTO S.A.
2.2.9.2. Financial liabilities
Initial recognition and subsequent measurement
Financial liabilities are classified, at initial recognition, as financial liabilities at fair value through profit or loss, loans and borrowings, or as derivatives designated as hedging instruments in an effective hedge ratio, as appropriate.
Financial liabilities are initially recognized at their fair value, net of the incurred transaction costs. Since the Group has no financial assets whose characteristics require the fair value accounting, according to IFRS, after the initial recognition, the financial assets are valued at amortized cost. Any difference between the amount received as financing (net of transaction costs) and the reimbursement value is recognized in comprehensive income throughout the life of the debt financial instrument using the method of effective interest rate.
At the closing date of these consolidated financial statements, the financial liabilities classified as loans and borrowings of the Group include Trade and other payables, and Loans and borrowings that accrue interest.
Derecognition of financial liabilities
A financial liability is derecognized when the obligation under the liability is discharged or cancelled or expires.
When an existing financial liability is replaced by another from the same lender on substantially different terms, or the terms of an existing liability are substantially modified, such an exchange or modification is treated as a derecognition of the original liability and the recognition of a new liability, and the difference in the respective carrying amounts is recognized as finance income or costs in the statement of income, as the case may be.
2.2.9.3. Offsetting financial assets and financial liabilities
Financial assets and financial liabilities are offset, and the net amount presented in the statement of financial position if, and only if, there is a currently enforceable legal right to offset the recognized amounts and there is an intention to settle on a net basis, or to realize the assets and settle the liabilities simultaneously.
2.2.9.4. Financial assets and liabilities with related parties
Assets and liabilities with related parties are recognized initially at fair value plus directly attributable transaction costs. As long as credits and debts with related parties do not derive from arms-length transactions, any difference arising at the initial recognition between such fair value and the consideration given or received in return shall be considered as an equity transaction (capital contribution or payment of dividends, which will depend on whether it is positive or negative).
Following initial recognition, these receivables and payables are measured at their amortized cost through the effective interest rate (EIR) method. The EIR amortization is included in finance income or costs or other operating income or expenses in the statement of income, depending on the nature of the liability giving rise to it.
2.2.9.5. Derivative financial instruments and hedge accounting
Initial recognition and subsequent measurement
The derivative financial instruments used by the Group are initially recognized through their fair values at the date on which the contract is entered into, and they are subsequently measured again at their fair value. The derivative financial instruments are accounted as financial assets when their fair value is positive and as financial liabilities when their fair value is negative.
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CENTRAL PUERTO S.A.
The method to recognize the loss or income from the change in fair value depends on whether the derivative was determined as a hedge instrument; in such case, on the nature of the item it is covering. The Company can determine certain derivative as:
– | Fair value hedge; |
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– | Cash flow hedge; |
At the beginning of the transaction, the Group records the relationship between the hedge instruments and items covered, as well as its objectives for risk management and the strategy to make different hedge operations. It also records its assessment, both at the beginning and on a continuous base, on whether the derivatives used in the hedge transactions are highly effective to compensate changes in fair value or in the cash flows of the items covered.
Fair value hedge
Changes in fair value of derivatives determined and classified as fair value hedge are recorded in the statement of comprehensive income together with any change in the fair value of the covered asset or liability attributable to the covered risk.
Cash flow hedge
The effective part of changes in fair value of the derivatives determined and classified as cash flow hedge are recognized in Other comprehensive income. The loss or income related to the non-effective part is immediately recognized in the statement of comprehensive income within the Finance Expenses or Finance Income, respectively.
The cumulative amounts in Other comprehensive income are recorded in the statement of comprehensive income in the periods in which the item covered affects the comprehensive income. In the case of interest rates hedge, this means the amounts recognized in equity are reclassified as net finance income as interest is accrued on associated debts.
As at December 31, 2021, the Group has no hedging derivative instruments. Hence, swap contracts of interest rate and stock options contracts are measured at their current value at the closing of each period or fiscal year and are stated as assets or liabilities depending on the rights and obligations emerging from the respective contracts. In this way, changes in the accounting measure of such contracts are recognized in the consolidated statement of income under finance income or finance cost, as applicable.
2.2.10. Inventories
Inventories are valued at the lower of restated acquisition cost and net realizable value. In the estimation of recoverable values, the purpose of the asset to be measured and the movements of items of slow or scarce rotation are taken into account. Inventories balance is not higher than its net realizable value at the corresponding dates.
2.2.11. Cash and cash equivalents
Cash is deemed to include both cash fund and freely-available bank deposits on demand. Short-term deposits are deemed to include short-term investments with significant liquidity and free availability that, subject to no previous notice or material cost, may be easily converted into a specific cash amount that is known with a high degree of certainty upon the acquisition, are subject to an insignificant risk of changes in value, maturing up to three months after the date of the related acquisitions, and whose main purpose is not investment or any other similar purpose, but settling short-term commitments.
For the purpose of the consolidated statement of financial position and the consolidated statement of cash flows, cash and cash equivalents comprise cash at banks and on hand and short-term investments meeting the abovementioned conditions.
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CENTRAL PUERTO S.A.
2.2.12. Provisions
Provisions are recognized when the Group has a present obligation (legal or constructive) as a result of a past event, it is probable that an outflow of resources embodying economic benefits will be required to settle the obligation and a reliable estimate can be made of the amount of the obligation. Where the Group expects some or all of a provision to be reimbursed, for example under an insurance contract, the reimbursement is recognized as a separate asset but only when the reimbursement is virtually certain. The expense relating to any provision is presented in the statement of income under the item that better reflects the nature of the provision net of any reimbursement to the extent that the latter is virtually certain.
If the effect of the time value of money is material, provisions are discounted using a current pre-tax market rate that reflects, where appropriate, the risks specific to the liability. Where discounting is used, the increase in the provision due to the passage of time is recognized as a finance cost in the statement of income.
– | Provision for lawsuits and claims |
In the ordinary course of business, the Group is exposed to claims of different natures (e.g., commercial, labor, tax, social security, foreign exchange or customs claims) and other contingent situations derived from the interpretation of current legislation, which result in a loss, the materialization of which depends on whether one more events occur or not. In assessing these situations, Management uses its own judgment and advice of its legal counsel, both internal and external, as well as the evidence available as of the related dates. If the assessment of the contingency reveals the likelihood of the materialization of a loss and the amount can be reliably estimated, a provision for lawsuits and claims is recorded as of the end of the reporting period.
2.2.13. Contingent liabilities
A contingent liability is: (i) a possible obligation that arises from past events and whose existence will be confirmed only by the occurrence or non-occurrence of one or more uncertain future events not wholly within the control of the entity; or (ii) a present obligation that arises from past events but is not recognized because: (a) it is not probable that an outflow of resources embodying economic benefits will be required to settle the obligation; or (2) the amount of the obligation cannot be measured with sufficient reliability.
A contingent liability is not recognized in financial statements; it is reported in notes, unless the possibility of an outflow of resources to settle such liability is remote. For each type of contingent liability as of the relevant reporting period-end dates, the Group shall disclose (i) a brief description of the nature of the obligation and, if possible, (ii) an estimate of its financial impact; (iii) an indication of the uncertainties about the amount or timing of those outflows; and (iv) the possibility of obtaining potential reimbursements.
2.2.14. Contingent assets
A contingent asset is a possible asset that arises from past events and whose existence will be confirmed only by the occurrence or non-occurrence of one or more uncertain future events not wholly within the control of the Group.
A contingent asset is not recognized in financial statements; it is reported in notes only where an inflow of economic benefits is probable. For each type of contingent asset as of the relevant reporting period-end dates, the Group shall disclose (i) a brief description of the nature thereof and, if possible, (ii) an estimate of its financial impact.
2.2.15. Employee benefits
Employee short-term benefits:
The Group recognizes short-term benefits to employees, such as salary, vacation pay, bonuses, among others, on an accrued basis and includes the benefits arising from collective bargaining agreements.
| F-31 |
CENTRAL PUERTO S.A.
Post-employment employee long-term benefits:
The Group grants benefits to all trade-union employees when obtaining the ordinary retirement benefit under the Argentine Integrated Pension Fund System, based on multiples of the relevant employees’ salaries.
The amount recognized as a liability for such benefits includes the present value of the liability at the end of the reporting period, and it is determined through actuarial valuations using the projected unit credit method.
Actuarial gains and losses are fully recognized in other comprehensive income in the period when they occur and immediately allocated to unappropriated retained earnings (accumulated losses), and not reclassified to income in subsequent periods.
The Group recognizes the net amount of the following amounts as expense or income in the statement of income for the reporting year: (a) the cost of service for the current period; (b) the cost of interest; (c) the past service cost, and (d) the effect of any curtailment or settlement.
Other long-term employee benefits:
The Group grants seniority-based benefits to all trade-union employees when reaching a specific seniority, based on their normal salaries.
The amount recognized as liabilities for other long-term benefits to employees is the present value of the liability at the end of the reporting period. The Group recognizes the net amount of the following amounts as expense or income: (a) the cost of service for the current period; (b) the cost of interest; (c) actuarial income and loss, which shall be recognized immediately and in full; (d) the past service cost, which shall be recognized immediately and in full; and (e) the effect of any curtailment or settlement.
2.2.16. Share-based payments
The cost of share-based payments transactions that are settled with equity instruments of one of our subsidiaries is determined by the fair value at the date when the grant is made using an appropriate valuation model.
This cost is recognized in the consolidated financial statements under employee benefits expense, together with a corresponding total increase in non-controlling interest.
On January 18, 2017, the subsidiary CP Renovables S.A. (“CPR”) entered into a stock option agreement with its minority shareholder at that time that was also its chairman and general manager and a shareholder of the Company (the “minority shareholder”). Under such agreement the minority shareholder has the right to purchase class B shares of CPR that represents 10% of the fully diluted capital stock of CPR. The option is exercisable in whole or in part, at any time prior to the seventh anniversary of the date of the stock option agreement. As of the date of these financial statements, the vesting period has ended while the option was neither exercised nor assigned.
During the years ended December 31, 2020 and 2019 the expense booked in the consolidated financial statements under employee benefits expense amounts to
2.2.17. Investment in associates
The Group’s investments in associates are accounted for using the equity method. An associate is an entity over which the Group has significant influence. Significant influence is the power to participate in the financial and operating policy decisions of the investee, but is neither control nor joint control.
According to the equity method, investments in associates are originally booked in the statement of financial position at cost, plus (less) the changes in the Group’s ownership interests in the associates’ net assets subsequent to the acquisition date. If any, goodwill relating to the associate is included in the carrying amount of the investment and is neither amortized nor individually tested for impairment.
If the cost of the investments is lower than the proportional share as of the date of acquisition on the fair value of the associate’s assets and liabilities, a gain is recognized in the period in which the investment was acquired.
The statement of income reflects the share of the results of operations of the associates adjusted on the basis of the fair values estimated as of the date on which the investment was incorporated. When there has been a change recognized directly in the equity of the associates, the Group recognizes its share of any changes and includes them, when applicable, in the statement of changes in equity.
| F-32 |
CENTRAL PUERTO S.A.
The Group’s share of profit of an associate is shown in a single line on the main body of the consolidated statement of income. This share of profit includes income or loss after taxes of the associates.
The financial information of the associates is prepared for the same reporting period as the Group. When necessary, adjustments are made to bring the accounting policies of the associates in line with those of the Group.
After application of the equity method, the Group determines whether it is necessary to recognize impairment losses on its investment in its associates. At each reporting date, the Group determines whether there is objective evidence that the value of investment in the associates has been impaired. If such was the case, the Group calculates the amount of impairment as the difference between the recoverable amount of the investment in the associates and its carrying value, and recognizes the loss as “Share of losses of an associate” in the statement of income.
The information related to associates is included in Note 3.
2.2.18. Information on operating segments
For management purposes, the Group is organized in four different business units to carry out its activities, as follows:
– | Electric power generation from conventional sources: the Group is engaged in the production of electric power from conventional sources and its sale. |
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– | Electric power generation from renewable sources: the Group also is engaged in the production of electric power from renewable sources and its sale. |
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– | Natural gas transport and distribution: through its equity investees companies belonging to ECOGAS Group, the Group is engaged in the natural gas distribution public sector service in the Cuyo and Centro regions of Argentina and it is also engaged in the natural gas transport sector service through its equity investee Company Transportadora de Gas del Mercosur S.A. Also, the Company resells certain gas transport and distribution capacity that was previously contracted by the Company. |
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|
– | Management and operations of thermal plants: through its equity investees Termoeléctrica José de San Martín S.A. and Termoeléctrica Manuel Belgrano S.A. and its subsidiary Central Vuelta de Obligado S.A. the Group is engaged in the management and operation of these thermal plants. |
The Group has three reporting segments: production of electric power from conventional sources, production of electric power from renewable sources and natural gas transport and distribution. Management and operations activities are included in others, because the information is not material.
The Board of Directors is the Chief Operating Decision Maker (CODM) and monitors the operating results of its business units separately for the purpose of making decisions about resource allocation and performance assessment.
The financial performance of segments is evaluated based on net income and measured consistently with the net income disclosed in the financial statements (Note 4).
2.2.19. Non-current assets held for sale and discontinued operations
The Group classifies non-current assets and disposal groups as held for sale if their carrying amounts will be recovered principally through a sale transaction or its distribution to the shareholders rather than through continuing use. Such assets are measured at the lower of their carrying amount and fair value less costs to sell. Costs to sell are the incremental costs directly attributable to the disposal of an asset (disposal group), excluding finance costs and income tax expense.
| F-33 |
CENTRAL PUERTO S.A.
The criteria for held for sale classification is regarded as met only when the sale is highly probable and the asset or disposal group is available for immediate sale in its present condition. Actions required to complete the sale should indicate that it is unlikely that significant changes to the sale will be made or that the decision to sale will be withdrawn. Management must be committed to the plan to sell the asset and the sale expected to be completed within one year from the date of the classification.
Property, plant and equipment and intangible assets are not depreciated or amortized once classified as held for sale.
Assets and liabilities classified as held for sale are presented separately as current items in the consolidated statement of financial position.
A disposal group qualifies as discontinued operation if:
– | It is a component of the Group that represents a cash generating unit or a group of cash generating units, |
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– | it is classified as held for sale or as for distribution to equity holders, or it has already been disposed for distribution to the shareholders, and; |
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– | it represents a separate major line of business or geographical area of operations or it is a subsidiary acquired exclusively with a view to resale. |
Discontinued operations are excluded from the results of continuing operations and are presented as a single amount as income or loss after tax from discontinued operations in the consolidated statement of income.
2.2.20. Business combinations
Business combinations are accounted using the acquisition method when the Group takes effective control of the acquired company.
The Group will recognize in its financial statements the acquired identifiable assets, the assumed liabilities, any non-controlling interest and, if any, goodwill according to IFRS 3.
The acquisition cost is measured as the aggregate of the transferred consideration, measured at fair value on that date, and the amount of any non-controlling interest in the acquiree. The Group will measure the non- controlling interest in the acquiree at fair value or at the proportional interest in the identifiable net assets of the acquiree.
If the business combination is made in stages, the Group will measure again its previous holding at fair value at the acquisition date and will recognize income or loss in the consolidated statement of comprehensive income.
Goodwill is measured at cost, as excess of the transferred consideration regarding the acquired identifiable assets and the net assumed liabilities of the Group. If this consideration is lower than the fair value of the identifiable assets and of the assumed liabilities, the difference is recognized in the consolidated statement of comprehensive income.
2.3. Significant accounting estimates and assumptions
The preparation of the Group’s financial statements requires management to make significant estimates and assumptions that affect the recorded amounts of revenues, expenses, assets and liabilities, and the disclosure of contingent liabilities, at the end of the reporting period. In this sense, the uncertainties related to the estimates and assumptions adopted could give rise in the future to final results that could differ from those estimates and require significant adjustments to the amounts of the assets and liabilities affected.
| F-34 |
CENTRAL PUERTO S.A.
The key assumptions concerning the future and other key sources of estimation uncertainty at the end of the reporting period, that have a significant risk of causing a material adjustment to the carrying amounts of assets and liabilities within the next financial year, are described below. The Group based its accounting assumptions and significant estimates on parameters available when the financial statements were prepared. Existing circumstances and assumptions about future developments, however, may change due to market changes or circumstances arising beyond the control of the Group. Such changes are reflected in the assumptions when they occur.
Recoverability of property, plant and equipment and intangible assets:
At each closing date of the reported period, the Group evaluates if there is any sign that the property, plant and equipment and/or intangible assets with finite useful lives may have their value impaired. Impairment exists when the book value of assets related to the Cash Generating Unit (CGU) exceeds its recoverable value, which is the higher between its fair value less costs of sale of such asset and value in use. The value in use is calculated through the estimation of future cash flows discounted at their present value through a discount rate that reflects the current assessments of the market over the temporal value of money and the specific risks of each CGU. Projection calculations cover a five-year period. The recoverable value is sensitive to the used discount rate, as well as the estimated inflows.
2.4. New standards and interpretations adopted
As from the fiscal year beginning January 1, 2021, the Group has applied for the first time certain new and/or amended standards and interpretations as issued by the IASB.
Below is a brief description of the new and/or amended standards and interpretations adopted by the Group and their impact on these consolidated financial statements.
Interest Rate Benchmark Reform - Phase 2: Amendments to IFRS 9, IAS 39, IFRS 7, IFRS 4 and IFRS 16
The UK Financial Conduct Authority (FCA), which is the competent authority for the regulation of benchmarks in the UK, advocated a transition away from reliance on London Interbank Offered Rate (“LIBOR”) to alternative reference rates and stated that it would no longer persuade or compel banks to submit rates for the calculation of the LIBOR rates after 2021 (the “FCA Announcement”). The FCA Announcement formed part of ongoing global efforts to reform LIBOR and other major interest rate benchmarks. At this time, the nature and overall timeframe of the transition away from LIBOR is uncertain and no consensus exists as to what rate or rates may become accepted alternatives to LIBOR.
In this sense, the IFRS amendments provide temporary reliefs which address the financial reporting effects when an interbank offered rate (IBOR) is replaced with an alternative nearly risk-free interest rate (RFR).
As of December 31, 2021, the Group has trade receivables under the CVO Agreement, described in Note 1.2 a), as well as loans with due date after 2021, which were indexed to LIBOR and for which the replacement alternative interest rate has not been identified.
These amendments are effective for annual periods beginning on or after 1 January 2021. As of the date of these financial statements, these amendments had no significant impact.
2.5. IFRS issued but not yet effective
The following new and/or amended standards and interpretations have been issued but were not effective as of the date of issuance of these consolidated financial statements of the Group. In this sense, only the new and/or amended standards and interpretations that the Group expects to be applicable in the future are indicated. In general, the Group intends to adopt these standards, as applicable when they become effective.
Amendments to IAS 1 - Classification of liabilities as current or non-current
On January 23, 2020, the IASB issued an amendment to IAS 1 Presentation of Financial Statements that affects the classification of liabilities as current and non-current. The changes affect the requirements of IAS 1 for the presentation of liabilities.
| F-35 |
CENTRAL PUERTO S.A.
Specifically, it clarifies the criteria for classifying liabilities as non-current. The date of application of the modification is set for fiscal years beginning on or after January 1, 2023, with retroactive application. The Group is evaluating the impact of these amendments for the presentation of liabilities.
Amendments to IAS 16 - Property, plant and equipment (“PPE”) - Earnings ahead of schedule
In May 2020, the IASB issued an amendment to IAS 16 that prohibits entities from deducting from the cost of an item of PPE, any proceeds of the sale of items produced while bringing that asset to the location and condition necessary for it to be capable of operating in the manner intended by management. Instead, an entity recognises the proceeds from selling such items, and the costs of producing those items, in profit or loss.
The amendments are effective for annual periods beginning on or after January 1, 2022 and must be applied retrospectively only to items of PPE made available for use on or after the beginning of the earliest period presented when the entity first applies the amendment.
The amendments are not expected to have a significant impact on the Group´s financial statements.
Amendments to IAS 37 - Onerous Contracts: Cost of Fulfilling a Contract
In May 2020, the IASB issued amendments to IAS 37 to specify which costs an entity needs to include when assessing whether a contract is onerous or loss-making.
The amendments apply a “directly related cost approach”. The costs that relate directly to a contract to provide goods or services include both incremental costs and an allocation of costs directly related to contract activities.
The amendments are effective for annual reporting periods beginning on or after January 1, 2022 and are not expected to have a significant impact on the Group´s financial statements.
Amendments to IFRS 3 - Reference to the Conceptual Framework
In May 2020, the IASB issued amendments to IFRS 3 Business Combinations - Reference to Conceptual Framework. The amendments are intended to replace a reference to a previous version of the IASB’s Conceptual Framework (the 1989 Framework) with a reference to the current version issued in March 2018 (the Conceptual Framework) without significantly changing its requirements.
The amendments are effective for periods beginning on or after January 1, 2022 and must be applied retrospectively. Earlier application is permitted if, at the same time or earlier, an entity also applies all of the amendments contained in the Amendments to References to the Conceptual Framework in IFRS Standards (March 2018). The amendments will promote consistency in financial reporting and avoid potential confusion from having more than one version of the Conceptual Framework in use.
The amendments are not expected to have a significant impact on the Group´s financial statements.
Amendments to IAS 8 - Definition of Accounting Estimates
In February 2021, the IASB issued amendments to IAS 8, in which it introduces a new definition of “accounting estimates". The amendments clarify the distinction between changes in accounting estimates and changes in accounting policies and the correction of errors. Also, they clarify how entities use measurement techniques and inputs to develop accounting estimates.
The amended standard clarifies that the effects on an accounting estimate of a change in an input or a change in a measurement technique are changes in accounting estimates if they do not result from the correction of prior period errors. The previous definition of a change in accounting estimate specified that changes in accounting estimates may result from new information or new developments. Therefore, such changes are not corrections of errors.
| F-36 |
CENTRAL PUERTO S.A.
The amendment is effective for annual periods beginning on or after January 1, 2023 and is not expected to have a significant impact on the Group´s financial statements.
Amendments to IAS 1 Presentation of Financial Statements
In February 2021, the IASB issued amendments to IAS 1 and IFRS Practice Statement No. 2 Making Materiality Judgements, in which it provides guidance and examples to help entities apply materiality judgements to accounting policy disclosures.
The amendments aim to help entities provide accounting policy disclosures that are more useful by:
– | Replacing the requirement for entities to disclose their “significant” accounting policies with a requirement to disclose their “material” accounting policies, and |
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– | Adding guidance on how entities apply the concept of materiality in making decisions about accounting policy disclosures |
In assessing the materiality of accounting policy information, entities need to consider both the size of the transactions, other events or conditions and the nature of them.
The amendments are effective for annual periods beginning on or after January 1, 2023. Earlier application of the amendments to IAS 1 is permitted as long as this fact is disclosed. The Group is evaluating the impact of the amendments.
Amendments to IAS 12 - Deferred tax related to assets and liabilities arising from a single transaction
In May 2021, the IASB issued amendments to IAS 12, which narrow the scope of the initial recognition exception under IAS 12, so that it no longer applies to transactions that give rise to equal taxable and deductible temporary differences.
The amendments clarify that where payments that settle a liability are deductible for tax purposes, it is a matter of judgement (having considered the applicable tax law) whether such deductions are attributable for tax purposes to the liability recognised in the financial statements (and interest expense) or to the related asset component (and interest expense). This judgement is important in determining whether any temporary differences exist on initial recognition of the asset and liability.
Under the amendments, the initial recognition exception does not apply to transactions that, on initial recognition, give rise to equal taxable and deductible temporary differences. It only applies if the recognition of a lease asset and lease liability (or decommissioning liability and decommissioning asset component) give rise to taxable and deductible temporary differences that are not equal.
Nevertheless, it is possible that the resulting deferred tax assets and liabilities are not equal (e.g., if the entity is unable to benefit from the tax deductions or if different tax rates apply to the taxable and deductible temporary differences). In such cases, an entity would need to account for the difference between the deferred tax asset and liability in profit or loss
The amendments are effective for annual periods beginning on or after January 1, 2023 and are not expected to have a significant impact on the Group´s financial statements.
Amendments to IFRS 10 Consolidated Financial Statements and IAS 28 Investments in Associates and Joint Ventures - Sale or Contribution of Assets between an Investor and its Associate or Joint Venture
The amendments address the conflict between IFRS 10 Consolidated Financial Statements and IAS 28 Investments in Associates and Joint Ventures in dealing with the loss of control of a subsidiary that is sold or contributed to an associate or joint venture.
| F-37 |
CENTRAL PUERTO S.A.
The amendments clarify that a full gain or loss is recognised when a transfer to an associate or joint venture involves a business as defined in IFRS 3. Any gain or loss resulting from the sale or contribution of assets that does not constitute a business, however, is recognised only to the extent of unrelated investors’ interests in the associate or joint venture.
The IASB decided to defer the effective date of the amendments until such time as it has finalised any amendments that result from its research project on the equity method. The amendments must be applied prospectively. Early application of the amendments is still permitted and must be disclosed.
The Group will evaluate the impact of the amendments once effective and if there is any transaction to which the amendments apply.
3. Investment in associates
The book value of investment in associates as of December 31, 2021 and 2020 amounts to:
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| 12-31-2021 |
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| 12-31-2020 |
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| ARS 000 |
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| ARS 000 |
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The share of the profit of associates for the years ended December 31, 2021, 2020 and 2019 amounts to:
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| 2021 |
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| 2020 |
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| 2019 |
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| ARS 000 |
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| ARS 000 |
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| ARS 000 |
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3.1. Investments in gas distribution
The Group holds ownership interests of
IGCE is a private, unlisted company which holds a
During April 2021, the Group received dividends of
On March 24, 2022 CPSA acquired an
3.2. Transportadora de Gas del Mercosur S.A.
The Group has a 20% interest in Transportadora de Gas del Mercosur S.A. (“TGM”). This Company has a gas pipeline that covers the area from Aldea Brasilera (in the Province of Entre Ríos) to Paso de los Libres (in the Province of Corrientes). TGM is a private unlisted company.
| F-38 |
CENTRAL PUERTO S.A.
4. Operating segments
The following provides summarized information of the operating segments for the years ended December 31, 2021, 2020 and 2019:
2021 |
| Electric Power Generation from conventional sources |
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| Electric Power Generation from renewable sources |
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| Natural Gas Transport and Distribution (1) (2) |
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| Others (1) |
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| Adjustments and Eliminations (3) |
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| Total |
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| ARS 000 |
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| ARS 000 |
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| ARS 000 |
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| ARS 000 |
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| ARS 000 |
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| ARS 000 |
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Revenues |
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Cost of sales |
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Administrative and selling expenses |
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| - |
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Other operating income |
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Other operating expenses |
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| - |
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Impairment of property, plant and equipment and intangible assets |
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| ( | ) |
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| - |
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| - |
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| - |
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| - |
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| ( | ) |
Operating income |
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Other (expenses) income (4) |
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Net (loss) income for the segment |
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Share in the net (loss) income for the segment |
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| - |
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2020 |
| Electric Power Generation from conventional sources |
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| Electric Power Generation from renewable sources |
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| Natural Gas Transport and Distribution (1) (2) |
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| Others (1) |
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| Adjustments and Eliminations (3) |
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| Total |
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| ARS 000 |
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| ARS 000 |
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| ARS 000 |
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| ARS 000 |
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| ARS 000 |
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| ARS 000 |
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Revenues |
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| ( | ) |
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Cost of sales |
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| ( | ) |
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| ( | ) |
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| ( | ) |
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| ( | ) |
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| ( | ) | |
Administrative and selling expenses |
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| ( | ) |
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| ( | ) |
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| ( | ) |
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| - |
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| ( | ) | |
Other operating income |
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Other operating expenses |
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| ( | ) | |
Impairment of property, plant and equipment and intangible assets |
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| ( | ) |
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| - |
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| - |
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| - |
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| - |
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| ( | ) |
Operating income |
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Other (expenses) income (4) |
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| ( | ) |
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Net income (loss) for the segment |
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Share in the net income (loss) for the segment |
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| - |
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2019 |
| Electric Power Generation from conventional sources |
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| Electric Power Generation from re newable sources |
|
| Natural Gas Transport and Distribution (1) (2) |
|
| Others (1) |
|
| Adjustments and Eliminations (3) |
|
| Total |
| ||||||
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| ||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||
Revenues |
|
|
|
|
|
|
|
|
|
|
|
|
|
| ( | ) |
|
|
| |||||
Cost of sales |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
|
|
|
|
| ( | ) | |
Administrative and selling expenses |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
|
| - |
|
|
|
|
|
| ( | ) | |
Other operating income |
|
|
|
|
|
|
|
|
|
|
|
|
|
| ( | ) |
|
|
| |||||
Other operating expenses |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
|
|
|
|
| ( | ) | |
Impairment of property, plant and equipment and intangible assets |
|
| ( | ) |
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| ( | ) |
Operating income |
|
|
|
|
|
|
|
|
|
|
|
|
|
| ( | ) |
|
|
| |||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other (expenses) income (4) |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
|
|
|
|
| ( | ) | |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income for the segment |
|
|
|
|
| ( | ) |
|
|
|
|
|
|
|
| ( | ) |
|
|
| ||||
Share in the net income for the segment |
|
|
|
|
| ( | ) |
|
|
|
|
|
|
|
| - |
|
|
|
| ||||
(1) | Includes information from associates. |
(2) | Includes income (expenses) related to resale of gas transport and distribution capacity. |
(3) | Includes adjustments and eliminations related to equity method investees. |
(4) | Includes finance income and expenses, net allocated to each segment. |
| F-39 |
CENTRAL PUERTO S.A.
Major customers
During the years ended December 31, 2021, 2020 and 2019 revenues from CAMMESA amounted to
5. Revenues
|
| 2021 |
|
| 2020 |
|
| 2019 |
| |||
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| |||
|
|
|
|
|
|
|
|
|
| |||
Revenues from Resolutions 440, 1, SEE 19, SGE Resolution 70/2018, and amendments |
|
|
|
|
|
|
|
|
| |||
Sales under contracts |
|
|
|
|
|
|
|
|
| |||
Steam sales |
|
|
|
|
|
|
|
|
| |||
Resale of gas transport and distribution capacity |
|
|
|
|
|
|
|
|
| |||
Revenues from CVO thermal plant management |
|
|
|
|
|
|
|
|
| |||
|
|
|
|
|
|
|
|
|
| |||
6. Operating expenses
6.1. Cost of sales
|
| 2021 |
|
| 2020 |
|
| 2019 |
| |||
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| |||
|
|
|
|
|
|
|
|
|
| |||
Inventories at beginning of each year |
|
|
|
|
|
|
|
|
| |||
|
|
|
|
|
|
|
|
|
|
|
|
|
Purchases and operating expenses for each year: |
|
|
|
|
|
|
|
|
|
|
|
|
Purchases |
|
|
|
|
|
|
|
|
| |||
Operating expenses (Note 6.2) |
|
|
|
|
|
|
|
|
| |||
Transfers to property, plant and equipment, net |
|
| ( | ) |
|
| - |
|
|
| - |
|
|
|
|
|
|
|
|
|
|
| |||
|
|
|
|
|
|
|
|
|
|
|
|
|
Inventories at the end of each year |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
|
|
|
|
|
|
|
|
|
| |||
6.2. Operating, administrative and selling expenses
|
| 2021 |
|
| 2020 |
|
| 2019 |
| |||||||||||||||
Accounts |
| Operating expenses |
|
| Administrative and selling expenses |
|
| Operating expenses |
|
| Administrative and selling expenses |
|
| Operating expenses |
|
| Administrative and selling expenses |
| ||||||
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| ||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||
Compensation to employees |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||
Other long-term employee benefits |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||
Depreciation of property, plant and equipment |
|
|
|
|
| - |
|
|
|
|
|
| - |
|
|
|
|
|
|
| ||||
Amortization of intangible assets |
|
|
|
|
| - |
|
|
|
|
|
| - |
|
|
|
|
|
| - |
| |||
Purchase of energy and power |
|
|
|
|
| - |
|
|
|
|
|
| - |
|
|
|
|
|
| - |
| |||
Fees and compensation for services |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||
Maintenance expenses |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||
Consumption of materials and spare parts |
|
|
|
|
| - |
|
|
|
|
|
| - |
|
|
|
|
|
| - |
| |||
Insurance |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||
Levies and royalties |
|
|
|
|
| - |
|
|
|
|
|
| - |
|
|
|
|
|
| - |
| |||
Taxes and assessments |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||
Tax on bank account transactions |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||
Others |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||
Total |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||
| F-40 |
CENTRAL PUERTO S.A.
7. Other income and expenses
7.1. Other operating income
|
| 2021 |
|
| 2020 |
|
| 2019 |
| |||
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| |||
|
|
|
|
|
|
|
|
|
| |||
Interest earned from customers |
|
| (1) |
|
| (1) |
|
| (1) | |||
Foreign exchange difference, net |
|
| (2) |
|
| (2) |
|
| (2) | |||
Recovery related to discount of tax credits |
|
|
|
|
| - |
|
|
| - |
| |
Income from sale of property, plant and equipment |
|
|
|
|
| - |
|
|
| - |
| |
Others |
|
|
|
|
|
|
|
|
| |||
|
|
| 10,919,061 |
|
|
| 21,280,499 |
|
|
| 37,714,518 |
|
(1) | Includes |
(2) | Includes |
7.2. Other operating expenses
|
| 2021 |
|
| 2020 |
|
| 2019 |
| |||
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| |||
|
|
|
|
|
|
|
|
|
| |||
Net charge related to the provision for lawsuits and claims |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Impairment of material and spare parts |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Net charge related to the allowance for doubtful accounts |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Trade and tax interests |
|
| ( | ) |
|
| ( | ) |
|
| - |
|
Charge related to discount of tax credits |
|
| - |
|
|
| ( | ) |
|
| ( | ) |
Others |
|
| ( | ) |
|
| - |
|
|
| ( | ) |
|
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
7.3. Finance income
|
| 2021 |
|
| 2020 |
|
| 2019 |
| |||
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| |||
|
|
|
|
|
|
|
|
|
| |||
Interest earned |
|
|
|
|
|
|
|
|
| |||
Net income on financial assets at fair value through profit or loss (1) |
|
|
|
|
|
|
|
|
| |||
Interest rate swap income |
|
|
|
|
| - |
|
|
| - |
| |
|
|
|
|
|
|
|
|
|
| |||
(1) | Net of |
7.4. Finance expenses
|
| 2021 |
|
| 2020 |
|
| 2019 |
| |||
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| |||
|
|
|
|
|
|
|
|
|
| |||
Interest on loans |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Foreign exchange differences |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Bank commissions for loans and others |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Others |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
|
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
| F-41 |
CENTRAL PUERTO S.A.
8. Income tax
The major components of income tax during the years ended December 31, 2021, 2020 and 2019, are the following:
Consolidated statements of income and comprehensive income
Consolidated statement of income
|
| 2021 |
|
| 2020 |
|
| 2019 |
| |||
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| |||
|
|
|
|
|
|
|
|
|
| |||
Current income tax |
|
|
|
|
|
|
|
|
| |||
|
|
|
|
|
|
|
|
|
| |||
Income tax charge for the year |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Adjustment related to current income tax for the prior year |
|
|
|
|
|
|
|
|
| |||
|
|
|
|
|
|
|
|
|
|
|
|
|
Deferred income tax |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Related to the net variation in temporary differences |
|
| ( | ) |
|
| ( | ) |
|
|
| |
Income tax |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Consolidated statement of comprehensive income
|
| 2021 |
|
| 2020 |
|
| 2019 |
| |||
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| |||
|
|
|
|
|
|
|
|
|
| |||
Income tax for the year related to items charged or credited directly to equity |
|
|
|
|
|
|
|
|
| |||
|
|
|
|
|
|
|
|
|
| |||
Deferred income tax income (expense) |
|
| ( | ) |
|
| ( | ) |
|
|
| |
Income tax credited charged to other comprehensive income |
|
| ( | ) |
|
| ( | ) |
|
|
| |
The reconciliation between income tax in the consolidated statement of income and the accounting income multiplied by the statutory income tax rate for the years ended December 31, 2021, 2020 and 2019, is as follows:
|
| 2021 |
|
| 2020 |
|
| 2019 |
| |||
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| |||
|
|
|
|
|
|
|
|
|
| |||
Income before income tax |
|
|
|
|
|
|
|
|
| |||
|
|
|
|
|
|
|
|
|
|
|
|
|
At statutory income tax rate (1) |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Share of the profit of associates |
|
|
|
|
| ( | ) |
|
|
| ||
Effect related to statutory income tax rate change (Note 22) |
|
| ( | ) |
|
|
|
|
|
| ||
IFRIC 23 effect |
|
|
|
|
|
|
|
|
| |||
Effect related to the discount of income tax payable |
|
| ( | ) |
|
|
|
|
| ( | ) | |
Adjustment related to current income tax for the prior year |
|
|
|
|
|
|
|
|
| |||
Loss on net monetary position |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Unrecognized tax-loss carryforwards |
|
| ( | ) |
|
| - |
|
|
| - |
|
Business combination tax effects |
|
| - |
|
|
| - |
|
|
| ( | ) |
Others |
|
|
|
|
|
|
|
| ( | ) | ||
Income tax for the year |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
(1) | The statutory income tax rate used amounts to 35% as of December 31, 2021 and 30% as of December 31, 2020 and 2019. |
| F-42 |
CENTRAL PUERTO S.A.
Deferred income tax
Deferred income tax relates to the following:
|
| Consolidated statement of financial position |
|
| Consolidated statement of income from continuing operations and statement of other comprehensive income |
| ||||||||||||||
|
| 12-31-2021 |
|
| 12-31-2020 |
|
| 2021 |
|
| 2020 |
|
| 2019 |
| |||||
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| |||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||
Trade receivables |
|
|
|
|
|
|
|
|
|
|
| ( | ) |
|
|
| ||||
Other financial assets |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
|
|
|
|
| ( | ) | |
Employee benefit liability |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||
Provisions and others |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
|
|
| |
Investments in associates |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Property, plant and equipment - Material spare parts - Intangible assets |
|
| ( | ) |
|
| ( | ) |
|
|
|
|
|
|
|
|
| |||
Deferred tax income |
|
| ( | ) |
|
| ( | ) |
|
|
|
|
|
|
|
|
| |||
Tax loss carry-forward |
|
|
|
|
|
|
|
| ( | ) |
|
|
|
|
|
| ||||
Tax inflation adjustment - Asset |
|
|
|
|
|
|
|
| ( | ) |
|
| ( | ) |
|
|
| |||
Tax inflation adjustment - Liability |
|
| ( | ) |
|
| ( | ) |
|
|
|
|
| ( | ) |
|
| ( | ) | |
Deferred income tax (expense) income |
|
|
|
|
|
|
|
|
|
| ( | ) |
|
| ( | ) |
|
|
| |
Deferred income tax liabilities, net |
|
| ( | ) |
|
| ( | ) |
|
|
|
|
|
|
|
|
|
|
|
|
Deferred income tax liability, net, disclosed in the consolidated statement of financial position
|
| Consolidated statement of financial position |
| |||||||||
|
| 2021 |
|
| 2020 |
|
| 2019 |
| |||
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| |||
|
|
|
|
|
|
|
|
|
| |||
Deferred income tax asset |
|
|
|
|
|
|
|
| - |
| ||
Deferred income tax liability |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
Deferred income tax liability, net |
|
| ( | ) |
|
| ( | ) |
|
| ( | ) |
As of December 31, 2021, the Group holds tax loss carry-forward in its subsidiaries for
|
| Expiration year |
|
|
| |||||||||||
|
| 2024 |
|
| 2025 |
|
| 2026 |
|
| Total |
| ||||
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| ||||
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
CP Achiras S.A.U. |
|
|
|
|
|
|
|
| - |
|
|
|
| |||
CP La Castellana S.A.U. |
|
| - |
|
|
|
|
|
| - |
|
|
|
| ||
CPR Energy Solutions S.A.U. |
|
| - |
|
|
| - |
|
|
|
|
|
|
| ||
CP Manque S.A.U. |
|
| - |
|
|
|
|
|
|
|
|
|
| |||
CP Los Olivos S.A.U. |
|
| - |
|
|
|
|
|
|
|
|
|
| |||
Vientos La Genoveva I S.A.U. |
|
| - |
|
|
|
|
|
| - |
|
|
|
| ||
CP Renovables S.A. |
|
| - |
|
|
|
|
|
|
|
|
|
| |||
Proener S.A.U. |
|
| - |
|
|
|
|
|
|
|
|
|
| |||
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
As of December 31, 2021, the Group considered there is no certainty regarding the existence of future taxable income against which tax loss carry-forward for an amount of
| F-43 |
CENTRAL PUERTO S.A.
9. Earnings per share
Earnings per share amounts are calculated by dividing net income for the year attributable to equity holders of the parent by the weighted average number of ordinary shares during the year, net number of treasury shares.
There are no transactions or items generating an effect of dilution.
The following reflects information on income and the number of shares used in the earnings per share computations:
|
| 2021 |
|
| 2020 |
|
| 2019 |
| |||
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| |||
|
|
|
|
|
|
|
|
|
| |||
(Loss) income attributable to equity holders of the parent |
|
| ( | ) |
|
|
|
|
|
| ||
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average number of ordinary shares |
|
|
|
|
|
|
|
|
| |||
There have been no transactions involving ordinary shares or potential ordinary shares between the reporting date and the date of issuance of these consolidated financial statements that may produce a dilution effect.
10. Inventories
|
| 2021 |
|
| 2020 |
| ||
|
| ARS 000 |
|
| ARS 000 |
| ||
|
|
|
|
|
|
| ||
Non-current: |
|
|
|
|
|
| ||
|
|
|
|
|
|
| ||
Materials and spare parts |
|
|
|
|
|
| ||
Provision for obsolete inventory |
|
| ( | ) |
|
| ( | ) |
|
|
|
|
|
|
| ||
|
|
|
|
|
|
|
|
|
Current: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Materials and spare parts |
|
|
|
|
|
| ||
Fuel oil |
|
|
|
|
|
| ||
Diesel oil |
|
|
|
|
|
| ||
|
|
|
|
|
|
| ||
| F-44 |
CENTRAL PUERTO S.A.
11. Property, plant and equipment
|
| Lands and buildings |
|
| Electric power facilities |
|
| Wind turbines |
|
| Gas turbines |
|
| Construction in progress |
|
| Other |
|
| Total |
| |||||||
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| |||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||
Cost |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||
01-01-2020 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||
Additions |
|
|
|
|
|
|
|
| - |
|
|
| - |
|
|
|
|
|
|
|
|
|
| |||||
Transfers |
|
|
|
|
|
|
|
|
|
|
| ( | ) |
|
| ( | ) |
|
|
|
|
| ( | )(2) | ||||
Disposals |
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| ( | ) |
|
| ( | ) |
12-31-2020 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Additions |
|
|
|
|
| - |
|
|
| - |
|
|
|
|
|
|
|
|
|
|
|
|
| |||||
Transfers |
|
|
|
|
|
|
|
|
|
|
| - |
|
|
| ( | ) |
|
|
|
|
| (1) | |||||
Disposals |
|
| - |
|
|
| ( | ) |
|
| - |
|
|
| - |
|
|
| - |
|
|
| ( | ) |
|
| ( | ) |
12-31-2021 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||
|
| Lands and buildings |
|
| Electric power facilities |
|
| Wind turbines |
|
| Gas turbines |
|
| Construction in progress |
|
| Other |
|
| Total |
| |||||||
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| |||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||
Depreciation and impairment |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||
01-01-2020 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||
Depreciation for the year |
|
|
|
|
|
|
|
|
|
|
| - |
|
|
| - |
|
|
|
|
|
|
| |||||
Disposals and impairment |
|
|
|
|
|
|
|
| - |
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||
Transfers |
|
| - |
|
|
| - |
|
|
| - |
|
|
| ( | ) |
|
| - |
|
|
| - |
|
|
| ( | )(3) |
12-31-2020 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Depreciation for the year |
|
|
|
|
|
|
|
|
|
|
| - |
|
|
| - |
|
|
|
|
|
|
| |||||
Disposals and impairment |
|
|
|
|
|
|
|
| - |
|
|
| - |
|
|
|
|
|
| ( | ) |
|
|
| ||||
12-31-2021 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net book value: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
12-31-2021 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||
12-31-2020 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||
(1) | Includes (2,662) transferred to intangible assets related to electrical substation that was transferred to electric energy transport companies and 403,609 transferred from item "Inventories". |
(2) | Includes 81,691 transferred to intangible assets related to transmission lines and electrical substation that were transferred to electric energy transport companies and 6,139,803 transferred to item "property, plant and equipment available for sale". |
(3) | Transferred to item "property, plant and equipment available for sale". |
| F-45 |
CENTRAL PUERTO S.A.
12. Intangible assets
|
| Concession right |
|
| Transmission lines and electrical substations for wind farms |
|
| Turbogas and turbosteam supply agreements for thermal station Brigadier López |
|
| Total |
| ||||
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| ||||
Cost |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
01-01-2020 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
Transfers |
|
| - |
|
|
| (1) |
|
| - |
|
|
|
| ||
12-31-2020 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Transfers |
|
| - |
|
|
| (1) |
|
| - |
|
|
|
| ||
12-31-2021 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Amortization and impairment |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
01-01-2020 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
Amortization for the year |
|
|
|
|
|
|
|
|
|
|
|
| ||||
Impairment |
|
| - |
|
|
| - |
|
|
|
|
|
|
| ||
12-31-2020 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Amortization for the year |
|
| 1,041,843 |
|
|
|
|
|
|
|
|
|
| |||
Impairment |
|
| - |
|
|
| - |
|
|
|
|
|
|
| ||
12-31-2021 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net book value |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
12-31-2020 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
12-31-2021 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
(1) | Transferred from property, plant and equipment. See below. |
Concession right of Piedra del Águila hydroelectric power plant
Includes the amounts paid as consideration for rights relating to the concession of Piedra del Águila hydroelectric power plant awarded by the Argentine government for a 30-year term, until December 28, 2023. The Group amortizes such intangible asset based on straight-line basis over the remaining life of the concession agreement.
For a concession arrangement to fall within the scope of IFRIC 12, usage of the infrastructure must be controlled by the concession grantor. This requirement is met when the following two conditions are met:
– | the grantor controls or regulates what services the operator must provide with the infrastructure, to whom it must provide them, and at what price; and |
|
|
– | the grantor controls the infrastructure, i.e., retains the right to take back the infrastructure at the end of the concession. |
Upon Resolution 95 passed by Argentine government the Company´s concession right of Piedra del Águila hydroelectric power plant met both conditions above.
The main features of the concession contract are as follows:
Control and regulation of prices by concession grantor: Pricing schedule approved by grantor;
Remuneration paid by: CAMMESA;
Grant or guarantee from concession grantor: None;
| F-46 |
CENTRAL PUERTO S.A.
Residual value: Infrastructure returned to grantor for no consideration at end of concession;
Concession end date: December 28, 2023;
IFRIC 12 accounting model: Intangible asset.
Fees and royalties: the Intergovernmental Basin Authority is entitled to a fee of 2.5% of the plant’s revenues, and the provinces of Rio Negro and Neuquén are entitled to royalties of 12% of such revenues. For the years ended December 31, 2021, 2020 and 2019, the fees and royalties amounted
Contractual capital investment obligations and obligations relating to maintenance expenditure on infrastructure under concession are not significant.
Transmission lines of wind farms Achiras and La Castellana
The Group finished the construction of wind farms La Castellana and Achiras, whereby the Group agreed to build high and medium tension lines and the electrical substation to connect the wind farms to SADI, a part of which were given to the companies transporting the energy in accordance with the respective contracts; therefore, such companies are in charge of the maintenance of such transferred installations. Consequently, the Group recognized intangible assets for the works related to the construction of the described equipments.
Electrical substation of wind farms La Genoveva and La Genoveva II
The Group finished the construction of wind farm La Genoveva II, whereby the Group agreed to build the electrical substation that feeds the connection of the wind farm to the SADI, a part of which were given to the company transporting the energy; therefore, such company is in charge of the maintenance of such transferred installations. Consequently, the Group recognized an intangible asset for the works related to the construction of the described equipments.
Turbogas and turbosteam supply agreements for Thermal Station Brigadier López
During fiscal year 2019, as a result of the business combination related to the acquisition of Thermal Station Brigadier Lopez, the Group recognized an intangible asset related to turbogas and turbosteam supply agreements entered into with CAMMESA regarding Thermal Station Brigadier López.
13. Financial assets and liabilities
13.1. Trade and other receivables
|
| 12-31-2021 |
|
| 12-31-2020 |
| ||
|
| ARS 000 |
|
| ARS 000 |
| ||
Non-current: |
|
|
|
|
|
| ||
|
|
|
|
|
|
| ||
Trade receivables - CAMMESA |
|
|
|
|
|
| ||
Receivables from shareholders |
|
|
|
|
|
| ||
Guarantee deposits |
|
|
|
|
|
| ||
|
|
|
|
|
|
| ||
Current: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Trade receivables - CAMMESA |
|
|
|
|
|
| ||
Trade receivables - YPF SA and YPF Energía Eléctrica SA |
|
|
|
|
|
| ||
Trade receivables - Large users |
|
|
|
|
|
| ||
Receivables from associates and other related parties |
|
|
|
|
|
| ||
Other receivables |
|
|
|
|
|
| ||
|
|
|
|
|
|
| ||
|
|
|
|
|
|
|
|
|
Allowance for doubtful accounts - Note 13.1.1. |
|
| ( | ) |
|
| ( | ) |
|
|
|
|
|
|
| ||
| F-47 |
CENTRAL PUERTO S.A.
For the terms and conditions of receivables from related parties, refer to Note 18.
Trade receivables from CAMMESA accrue interest, once they become due.
The Company accrues interests on CVO receivables since the Commercial Approval date and according to the rate agreed in the CVO agreement, as described in Note 1.2.a).
Trade receivables related to YPF and large users accrue interest as stipulated in each individual agreement. The average collection term is generally from 30 to 90 days.
FONINVEMEM I and II
During the years ended December 31, 2020 and 2019 collections of these receivables amounted to
As mentioned in Note 1.2.a), during January and February 2020 we collected the last installments from the total 120 installments that were established by TMB and TSM agreements, respectively.
CVO receivables
As described in Note 1.2.a), in 2010 the Company approved the “CVO agreement” and as from March 20, 2018, CAMMESA granted the “Commercial Approval”.
Receivables under CVO agreement are disclosed under “Trade receivables - CAMMESA”.
As a consequence of the Commercial Approval and in accordance with the CVO agreement, the Company collects the CVO receivables converted in US dollars in 120 equal and consecutive installments.
CVO receivables are expressed in USD and they accrue LIBOR interest at a 5% rate.
During the years ended December 31, 2021, 2020 and 2019, collections of CVO receivables amounted to
The information on the Group’s objectives and credit risk management policies is included in Note 19.
The breakdown by due date of trade and other receivables due as of the related dates is as follows:
|
|
|
|
|
| Past due |
| |||||||||||||||||||||
|
| Total |
|
| To due |
|
| 90 days |
|
| 90-180 days |
|
| 180-270 days |
|
| 270-360 days |
|
| 360 days |
| |||||||
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| |||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||
12-31-2021 |
|
|
|
|
|
|
|
|
|
|
|
|
|
| - |
|
|
| - |
|
|
|
| |||||
13.1.1. Allowance for doubtful accounts
|
| 12-31-2021 |
|
| 12-31-2020 |
| ||||||||||||||||||
Item |
| At beginning |
|
| Increases |
|
| Decreases |
|
| Recoveries |
|
| At end |
|
| At end |
| ||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||
Allowance for doubtful accounts - Trade and other receivables |
|
|
|
|
|
|
|
| ( | )(1) |
|
| ( | ) |
|
|
|
|
|
| ||||
Total 12-31-2021 |
|
|
|
|
|
|
|
| ( | )(1) |
|
| ( | ) |
|
|
|
|
|
|
| |||
Total 12-31-2020 |
|
|
|
|
|
|
|
| ( | ) |
|
| ( | ) |
|
|
|
|
|
|
| |||
(1) | Income (loss) on net monetary position. |
| F-48 |
CENTRAL PUERTO S.A.
13.2. Trade and other payables
|
| 12-31-2021 |
|
| 12-31-2020 |
| ||
|
| ARS 000 |
|
| ARS 000 |
| ||
|
|
|
|
|
|
| ||
Current: |
|
|
|
|
|
| ||
|
|
|
|
|
|
| ||
Trade and other payables |
|
|
|
|
|
| ||
Insurance payable |
|
| - |
|
|
|
| |
Payables to associates and other related parties |
|
|
|
|
|
| ||
|
|
|
|
|
|
| ||
Trade payables are non-interest bearing and are normally settled on 60-day terms.
The information on the Group’s objectives and financial risk management policies is included in Note 19.
For the terms and conditions of payables to related parties, refer to Note 18.
13.3. Loans and borrowings
|
| 12-31-2021 |
|
| 12-31-2020 |
| ||
|
| ARS 000 |
|
| ARS 000 |
| ||
Non-current |
|
|
|
|
|
| ||
|
|
|
|
|
|
| ||
Long-term loans for project financing (Notes 13.3.1, 13.3.2, 13.3.3, 13.3.4, 13.3.5, 13.3.6 and 13.3.7) |
|
|
|
|
|
| ||
Corporate bonds (Note 13.3.8) |
|
|
|
|
|
| ||
Derivative financial liabilities not designated as hedging instrument - Interest rate swap |
|
|
|
|
|
| ||
|
|
|
|
|
|
| ||
|
|
|
|
|
|
|
|
|
Current |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Long-term loans for project financing (Notes 13.3.1,13.3.2, 13.3.3, 13.3.4, 13.3.5, 13.3.6 and 13.3.7) |
|
|
|
|
|
| ||
Corporate bonds (Note 13.3.8) |
|
| - |
|
|
|
| |
Derivative financial liabilities not designated as hedging instrument - Stock options |
|
|
|
|
|
| ||
Derivative financial liabilities not designated as hedging instrument - Interest rate swap |
|
|
|
|
| - |
| |
Bank and investment accounts overdrafts |
|
|
|
|
|
| ||
|
|
|
|
|
|
| ||
13.3.1 Loans from the IIC-IFC Facility
On October 20, 2017 and January 17, 2018, CP La Castellana S.A.U. and CP Achiras S.A.U. (both of which are subsidiaries of CPR), respectively, agreed on the structuring of a series of loan agreements in favor of CP La Castellana S.A.U. and CP Achiras S.A.U., for a total amount of USD 100,050,000 and USD 50,700,000, respectively, with: (i) International Finance Corporation (IFC) on its own behalf, as Eligible Hedge Provider and as an implementation entity of the Intercreditor Agreement Managed Program; (ii) Inter-American Investment Corporation (“IIC”), as lender on its behalf, acting as agent for the Inter-American Development Bank (“IDB”) and on behalf of IDB as administrator of the Canadian Climate Fund for the Private Sector in the Americas (“C2F”, and together with IIC and IDB, “Group IDB”, and together with IFC, “Senior Creditors”).
As of the date of these financial statements, the loans disbursements have been fully received by the Group.
In accordance with the terms of the agreement subscribed by CP La Castellana, USD 5 million accrue an interest rate equal to LIBOR plus 3.5%, and the rest at LIBOR plus 5.25% and the loan is amortizable quarterly in 52 equal and consecutive installments as from February 15, 2019.
| F-49 |
CENTRAL PUERTO S.A.
In accordance with the terms of the agreement subscribed by CP Achiras, USD 40.7 million accrue a fixed interest rate equal to 8.05%, and the rest accrue a 6.77% fixed interest rate. The loan is amortizable quarterly in 52 equal and consecutive installments as from May 15, 2019.
Other related agreements and documents, such as the Guarantee and Sponsor Support Agreement (the “Guarantee Agreement” by which CPSA completely, unconditionally and irrevocably guarantees, as the main debtor, all payment obligations undertaken by CP La Castellana and CP Achiras until the projects reach the commercial operations date) hedging agreements, guarantee trusts, a mortgage, guarantee agreements on shares, guarantee agreements on wind turbines, direct agreements and promissory notes have been signed.
Pursuant to the Guarantee and Sponsor Support Agreement, among other customary covenants for this type of facilities, we committed, until each project completion date, to maintain (i) a leverage ratio of (a) until (and including) December 31, 2018, not more than 4.00:1.00; and (b) thereafter, not more than 3.5:1.00; and (ii) an interest coverage ratio of not less than 2.00:1.00. In addition, our subsidiary, CPR, and we, upon certain conditions, agreed to make certain equity contributions to CP La Castellana and CP Achiras.
As of December 31, 2021, the Group has met the requirements described in (i) and (ii) above.
We also agreed to maintain, unless otherwise consented to in writing by each senior lender, ownership and control of the CP La Castellana and CP Achiras as follows: (i) until each project completion date, (a) we shall maintain (x) directly or indirectly, at least seventy percent (70%) beneficial ownership of CP La Castellana and CP Achiras; and (y) control of the CP La Castellana and CP Achiras; and (b) CP Renovables shall maintain (x) directly, ninety-five percent (95%) beneficial ownership of CP La Castellana and CP Achiras; and (y) control of CP La Castellana and CP Achiras. In addition, (ii) after each project completion date, (a) we shall maintain (x) directly or indirectly, at least fifty and one tenth percent (50.1%) beneficial ownership of each of CP La Castellana, CP Achiras and CP Renovables; and (y) control of each of CP La Castellana, CP Achiras and CP Renovables; and (b) CP Renovables shall maintain control of CP La Castellana and CP Achiras. As of December 31, 2021, the Group has met such obligations.
Under the subscribed trust guarantee agreement, as at December 31, 2021 and 2020, there are trade receivables with specific assignment for the amount of
As of December 31, 2021 and 2020, the balance of these loans amounts to
13.3.2 Borrowing from Kreditanstalt für Wiederaufbau (“KfW”)
On March 26, 2019 the Company entered into a loan agreement with KfW for an amount of USD 56 million in relation to the acquisition of two gas turbines, equipment and related services relating to the Luján de Cuyo project described in Note 20.7.
In accordance with the terms of the agreement, the loan accrues an interest equal to LIBOR plus 1.15% and it is amortizable quarterly in 47 equal and consecutive installments as from the day falling six months after the commissioning of the gas turbines and equipment.
Pursuant to the loan agreement, among other obligations, CPSA has agreed to maintain a debt ratio of (a) as at December 31, 2021 of no more than 4.00:1.00 and (b) as from that date, no more than 3.5:1.00. As at December 31, 2021, the Company has complied with that requirement.
During 2019 the disbursements for this loan were fully received for a total amount of USD
As at December 31, 2021 and 2020, the balance of this loan amounts to
13.3.3 Loan from Citibank N.A., JP Morgan Chase Bank N.A. and Morgan Stanley Senior Funding INC.
On September 12, 2019, the Company entered into a loan agreement with Citibank N.A., JP Morgan Chase Bank N.A. and Morgan Stanley Senior Funding INC. for USD 180 million to fund the acquisition of the Thermal Station Brigadier López.
| F-50 |
CENTRAL PUERTO S.A.
Pursuant to the agreement, this loan accrues an adjustable interest rate based on LIBOR plus a margin.
Pursuant to the loan agreement, among other obligations, CPSA has agreed to maintain (i) a debt ratio of no more than 2.25:1.00; (ii) an interest coverage ratio of no more than 3.50:1.00 and (iii) and a minimum equity of USD 500 million. As at December 31, 2021, the Company has complied with such obligations.
On June 14, 2019 the loan funds were fully disbursed.
As mentioned in Note 22, on September 15, 2020, BCRA issued Communication “A” 7106, which established certain access restrictions to the foreign exchange market for the repayment of the financial debt in which it allows payment of up to 40% of installments higher than USD 1 million becoming due between October 15, 2020 and March 31, 2021, establishing that a refinancing plan should be submitted for the outstanding amounts, which shall fulfill certain conditions established in the regulation, such as that repayment must have an average life higher than 2 years. This way, the loan installments becoming due between December 2020 and March 2021 were under the scope of the provisions of such regulation.
On December 22, 2020, the Company signed an amendment to the loan, modifying, among others, the amortization schedule so as to comply with the requirements established by Communication “A” 7106, partially postponing installments becoming due in December 2020 and March 2021, extending the final payment term to June 2023, including monthly amortizations as from January 2021 until January 2022, and keeping the amortizations in the initial schedule for June, September and December 2021, each of them equal to 20% of capital. In December 2020, 40% of the installment for such month was paid, complying with the regulations in force and the abovementioned amendment. Amongst others, the amendment involves a two basic points increase in the interest rates as from December 12, 2020.
Other changes derived from the amendment include: a limitation to make dividends payment during 2021, and a USD 25 million maximum allowed for 2022. Moreover, a collateral agreement was signed, which includes the pledge on turbines of Brigadier López Thermal Station, a mortgage on the land in which such power station is located and a LVFDV passive collection collateral assignment.
On June 15, 2021, the Company signed a new amendment, in accordance with Communication “A” 7230 issued by BCRA, as described in Note 22, which changed the amortization schedule, rescheduling 60% of installments, whose original maturity date operated in June, September and December 2021, and extending the loan’s final term up to January 2024. The schedule in force, which includes this amendment and the one dated December 22, 2020, foresees monthly amortizations until January 2022, one amortization in June 2023 for the amount of USD 34.128 million and the last amortization in January 2024 for the amount of USD 55.1 million. Moreover, the financial commitments and obligations undertaken in the first amendment are kept.
This new amendment also implied a 125 basic-point increase in the applicable interest rate as from June 12, 2021 and the dividend payment restriction was maintained until 2021, as well as the USD 25 million limitation for 2022. During 2023, the highest dividend payment allowed is USD 20 million.
As of the date of these financial statements, all payments established in the schedule resulting from the amendments subscribed have been made.
As at December 31, 2021 and 2020, the balance of the loan amounts to
13.3.4 Loan from the IFC to the subsidiary Vientos La Genoveva S.A.U.
On June 21, 2019, Vientos La Genoveva S.A.U., a CPSA subsidiary, entered into a loan agreement with IFC on its own behalf, as Eligible Hedge Provider and as an implementation entity of the Managed Co-Lending Portfolio Program (MCPP) administered by IFC, for an amount of USD
Pursuant to the terms of the agreement subscribed with Vientos La Genoveva S.A.U., this loan accrues an interest rate equal to LIBOR plus 6.50% and it is amortizable quarterly in 55 installments as from November 15, 2020.
| F-51 |
CENTRAL PUERTO S.A.
Other related agreements and documents, such as the Guarantee and Sponsor Support Agreement (the “Guarantee Agreement” by which CPSA completely, unconditionally and irrevocably guarantees, as the main debtor, all payment obligations undertaken by Vientos La Genoveva S.A.U until the project reaches the commercial operations date) hedging agreements, guarantee trusts, guarantee agreements on shares, guarantee agreements on wind turbines, direct agreements and promissory notes have been signed.
Pursuant to the Guarantee Agreement, among other customary covenants for this type of facilities, CPSA has committed, until the project completion date, to maintain (i) a leverage ratio of not more than 3.5:1.00; and (ii) an interest coverage ratio of not less than 2.00:1.00. In addition, CPSA, upon certain conditions, agreed to make certain equity contributions to Vientos La Genoveva S.A.U.
As of December 31, 2021, the Group has met the requirements described in (i) and (ii) above.
Under the subscribed trust guarantee agreement, as at December 31, 2021 and 2020, there are trade receivables with specific assignment for the amounts of
On November 22, 2019 the loan funds were fully disbursed. As at December 31, 2021 and 2020, the balance of the loan amounts to
13.3.5 Loan from Banco de Galicia y Buenos Aires S.A. to CPR Energy Solutions S.A.U.
On May 24, 2019, CPR Energy Solutions S.A.U. (subsidiary of CPR) entered into a loan agreement with Banco de Galicia y Buenos Aires S.A. for an amount of USD
According to the executed agreement, this loan accrues a fixed interest rate equal to
Other agreements and related documents, like the Collateral (in which CPSA totally, unconditionally and irrevocably guarantees, as main debtor, all the payment obligations assumed by CPR Energy Solutions S.A.U. until total fulfillment of the guaranteed obligations or until the project reaches the commercial operation date, what it happens first) -, guarantee agreements on shares, guarantee agreements on wind turbines, promissory notes and other agreements have been executed.
Pursuant to the Collateral, among other obligations, CPSA has agreed to maintain a debt ratio of no more than 3.75:1.00 until the date of completion of the project. In addition, CPSA, under certain conditions, agreed to make capital contributions, directly or indirectly, to subsidiary CPR Energy Solutions S.A.U. Moreover, CPSA has agreed to maintain, unless otherwise consented to in writing by the lender, the ownership (directly or indirectly) and control over CPR Energy Solutions S.A.U. As of September 3, 2021, CPR Energy Solutions S.A.U. has fulfilled all the requirements and conditions to prove the occurrence of the project’s compliance date. As a result, the Collateral posted by the Company was released and CPSA is not subject any more to the obligations previously described.
On May 24, 2019 the loan funds were fully disbursed. As at December 31, 2021 and 2020, the balance of this loan amounts to
13.3.6 Loan from Banco Galicia y Buenos Aires S.A. to subsidiary Vientos La Genoveva II S.A.U.
On July 23, 2019, subsidiary Vientos La Genoveva II S.A.U. entered into a loan agreement with Banco de Galicia y Buenos Aires S.A. for an amount of USD
According to the executed agreement, this loan accrues LIBOR plus
Other agreements and related documents, like the Collateral (in which CPSA totally, unconditionally and irrevocably guarantees, as main debtor, all the payment obligations assumed by Vientos La Genoveva II S.A.U. until total fulfillment of the guaranteed obligations or until the project reaches the commercial operation date, what happens first), guarantee agreements on shares, guarantee agreements on wind turbines, direct agreements and promissory notes have been signed.
| F-52 |
CENTRAL PUERTO S.A.
Pursuant to the Collateral, among other obligations, CPSA has agreed, until the project termination date, to maintain a debt ratio of no more than 3.75:1.00. Moreover, CPSA, under certain conditions, agreed to make capital contributions to subsidiary Vientos La Genoveva II S.A.U. Moreover, CPSA has agreed to maintain, unless otherwise consented to in writing by the lender, the ownership (directly or indirectly) and control over Vientos La Genoveva II S.A.U. As of September 3, 2021, Vientos La Genoveva II S.A.U. has fulfilled all the requirements and conditions to prove the occurrence of the project’s compliance date. As a result, the Collateral posted by the Company was released and CPSA is not subject any more to the obligations previously described.
On July 23, 2019, the loan funds were fully disbursed. As of December 31, 2021 and 2020, the balance of this loan amounts to
13.3.7 Financial trust corresponding to Thermal Station Brigadier López
Within the framework of the acquisition of Thermal Station Brigadier López, the Company assumed the capacity of trustor in the financial trust previously entered into by Integración Energética Argentina S.A., which was the previous owner of the thermal station. The financial debt balance at the transfer date of the thermal station was USD 154,662,725.
According to the provisions of the trust agreement, the financial debt accrues an interest rate equal to the LIBO rate plus 5% or equal to 6.25%, whichever is higher, and it is monthly amortizable. As of December 31, 2021, 8 installments are to be amortized and the financial debt balance amounts to 3,295,153. As of December 31, 2020, the balance of this loan amounted to 10,373,450.
Under the subscribed trust guarantee agreement, as at December 31, 2021 and 2020, there are trade receivables with specific assignment for the amounts of
As of the date of these financial statements, this loan has been paid in full.
13.3.8 CP Manque S.AU. and CP Los Olivos S.A.U. Program of Corporate Bonds
On August 26, 2020, under Resolution No. RESFC-2020 - 20767 - APN.DIR#CNVM, the public offering of the Global Program for the Co-Issuance of Simple Corporate Bonds (not convertible into shares) by CP Manque S.A.U. and CP Los Olivos S.A.U. (both subsidiaries of CPR, and together the “Co-issuers”) for the amount of up to USD
Within the framework of the mentioned program, on September 2, 2020, Corporate Bonds Class I were issued for an amount of USD 35,160,000 at a fix 0% interest rate expiring on September 2, 2023; and Corporate Bonds Class II were issued for 1,109,925 at a variable interest rate equivalent to BADLAR, plus an applicable margin of 0.97% expiring on September 2, 2021. After such maturity date, Corporate Bonds Class II were fully paid.
On June 24, 2020, the Board of Directors of CPSA decided to guarantee unconditionally the co-emission of corporate bonds of its subsidiaries CP Manque S.A.U. and CP Los Olivos S.A.U. (the “Guarantee”). The Guarantee is an obligation with a common guarantee, not subordinated and unconditional. And, it shall have, at all times, the same priority rank regarding the non-guaranteed and unsubordinated obligations, present and future, of the Company. The Guarantee was instrumented through the signature of the Company in its capacity as co-signer of the permanent global certificates deposited in Caja de Valores S.A., in which the Corporate Bonds Class I and Corporate Bonds Class II of CP Manque S.AU. and CP Los Olivos S.AU. are represented.
13.3.9 CPSA Notes Program
On July 31, 2020, the Special Shareholders’ Meeting of the Company approved the creation of a new global issuance program of corporate bonds for a maximum amount of up to USD
| F-53 |
CENTRAL PUERTO S.A.
The information on the Group’s objectives and financial risk management policies is included in Note 19.
13.4. Changes in liabilities arising from financing activities
|
| 01-01-2021 |
|
| Payments |
|
| Non-cash transactions |
|
| Disbursements |
|
| Other |
|
| 12-31-2021 |
| ||||||
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| ||||||
Non-current liabilities |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||
Loans and borrowings |
|
|
|
|
| - |
|
|
| ( | ) |
|
| - |
|
|
|
|
|
|
| |||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current liabilities |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loans and borrowings |
|
|
|
|
| ( | ) |
|
| ( | ) |
|
|
|
|
|
|
|
|
| ||||
|
| 01-01-2020 |
|
| Payments |
|
| Non-cash transactions |
|
| Disbursements |
|
| Other |
|
| 12-31-2020 |
| ||||||
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| ||||||
Non-current liabilities |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loans and borrowings |
|
|
|
|
| - |
|
|
| ( | ) |
|
|
|
|
|
|
|
|
| ||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current liabilities |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other loans and borrowings |
|
|
|
|
| ( | ) |
|
| ( | ) |
|
|
|
|
|
|
|
|
| ||||
The “Non-cash transactions” column includes the income (loss) for exposure to change in purchasing power of currency (Income (loss) on net monetary position), which amounted to
13.5. Quantitative and qualitative information on fair values
Information on the fair value of financial assets and liabilities by category
The following tables is a comparison by category of the carrying amounts and the relevant fair values of financial assets and liabilities.
|
| Carrying amount |
|
| Fair value |
| ||||||||||
|
| 12-31-2021 |
|
| 12-31-2020 |
|
| 12-31-2021 |
|
| 12-31-2020 |
| ||||
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| ||||
Financial assets |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
Trade and other receivables |
|
|
|
|
|
|
|
|
|
|
|
| ||||
Other financial assets |
|
|
|
|
|
|
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|
|
|
|
| ||||
Cash and cash equivalents |
|
|
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|
|
|
|
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|
| ||||
Total |
|
|
|
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|
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|
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|
|
| ||||
|
|
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|
|
|
|
|
|
|
|
|
|
|
|
Financial liabilities |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loans and borrowings |
|
|
|
|
|
|
|
|
|
|
|
| ||||
Total |
|
|
|
|
|
|
|
|
|
|
|
| ||||
| F-54 |
CENTRAL PUERTO S.A.
Valuation techniques
The fair value reported in connection with the abovementioned financial assets and liabilities is the amount at which the instrument could be exchanged in a current transaction between willing parties, other than in a forced or liquidation sale. The following methods and assumptions were used to estimate the fair values:
Management assessed that the fair values of current trade receivables and current loans and borrowings approximate their carrying amounts largely due to the short-term maturities of these instruments.
The Group measures long-terms receivables at fixed and variable rates based on discounted cash flows. The valuation requires that the Group adopt certain assumptions such as interest rates, specific risk factors of each transaction and the creditworthiness of the customer.
Fair value of quoted debt securities, mutual funds, stocks and corporate bonds is based on price quotations at the end of each reporting period.
The fair value of the foreign currency forward contracts is calculated based on appropriate valuation techniques that use market observable data.
Fair value hierarchy
The following tables provides, by level within the fair value measurement hierarchy, as described in Note 2.2.2, the Company’s financial assets, that were measured at fair value on recurring basis as of December 31, 2021 and 2020:
|
| Fair value measurement using: |
| |||||||||||||
12-31-2021 |
| Total |
|
| Level 1 |
|
| Level 2 |
|
| Level 3 |
| ||||
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| ||||
Assets measured at fair value |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
Financial assets at fair value through profit or loss: |
|
|
|
|
|
|
|
|
|
|
|
| ||||
Mutual funds |
|
|
|
|
|
|
|
| - |
|
|
| - |
| ||
Public debt securities |
|
|
|
|
|
|
|
| - |
|
|
| - |
| ||
Stocks and corporate bonds |
|
|
|
|
|
|
|
| - |
|
|
| - |
| ||
Total financial assets measured at fair value |
|
|
|
|
|
|
|
| - |
|
|
| - |
| ||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Liabilities measured at fair value |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Derivative financial liabilities not designated as hedging instruments: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest rate swap |
|
|
|
|
| - |
|
|
|
|
|
| - |
| ||
Stock options |
|
|
|
|
|
|
|
| - |
|
|
| - |
| ||
Total financial liabilities measured at fair value |
|
|
|
|
|
|
|
|
|
|
| - |
| |||
|
| Fair value measurement using: |
| |||||||||||||
12-31-2020 |
| Total |
|
| Level 1 |
|
| Level 2 |
|
| Level 3 |
| ||||
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| ||||
Assets measured at fair value |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
Financial assets at fair value through profit or loss: |
|
|
|
|
|
|
|
|
|
|
|
| ||||
Mutual funds |
|
|
|
|
|
|
|
| - |
|
|
| - |
| ||
Public debt securities |
|
|
|
|
|
|
|
| - |
|
|
| - |
| ||
Stocks and corporate bonds |
|
|
|
|
|
|
|
| - |
|
|
| - |
| ||
Total financial assets measured at fair value |
|
|
|
|
|
|
|
| - |
|
|
| - |
| ||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Liabilities measured at fair value |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Derivative financial liabilities not designated as hedging instruments: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest rate swap |
|
|
|
|
| - |
|
|
|
|
|
| - |
| ||
Stock options |
|
|
|
|
|
|
|
| - |
|
|
| - |
| ||
Total financial liabilities measured at fair value |
|
|
|
|
|
|
|
|
|
|
| - |
| |||
| F-55 |
CENTRAL PUERTO S.A.
There were no transfers between hierarchies and there were not significant variations in assets values.
The information on the Group’s objectives and financial risk management policies is included in Note 19.
13.6. Other financial assets
|
| 12-31-2021 |
|
| 12-31-2020 |
| ||
|
| Book value |
|
| Book value |
| ||
|
| ARS 000 |
|
| ARS 000 |
| ||
CURRENT ASSETS |
|
|
|
|
|
| ||
|
|
|
|
|
|
| ||
Financial assets at fair value through profit or loss |
|
|
|
|
|
| ||
|
|
|
|
|
|
| ||
Public debt securities |
|
|
|
|
|
| ||
Mutual funds |
|
|
|
|
|
| ||
Stocks and corporate bonds |
|
|
|
|
|
| ||
|
|
|
|
|
|
| ||
NON-CURRENT ASSETS |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Financial assets at amortized cost |
|
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Unquoted shares: |
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- TSM |
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| - |
| |
- TMB |
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| - |
| |
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| (1) |
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| - |
| |
(1) | See Note 1.2.a). |
The information on the objectives and financial risk management policies is included in Note 19.
13.7. Financial assets and liabilities in foreign currency
|
| 12-31-2021 |
|
| 12-31-2020 |
| ||||||||||||||
Account |
| Currency and amount (in thousands) |
|
| Effective exchange rate (1) |
|
| Book value |
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| Currency and amount (in thousands) |
|
| Book value |
| |||||
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| ARS 000 |
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| ARS 000 |
| ||||||||
NON-CURRENT ASSETS |
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Trade and other receivables |
| USD |
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| (2) |
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| USD |
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CURRENT ASSETS |
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Cash and cash equivalents |
| USD |
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| USD |
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| EUR |
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| EUR |
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Other financial assets |
| USD |
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| USD |
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| |||||
|
| - | - |
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| - |
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| - |
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| EUR |
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| ||
Trade and other receivables |
| USD |
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| (2) |
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| USD |
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|
| USD |
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| USD |
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NON-CURRENT LIABILITIES |
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Loans and borrowings |
| USD |
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| USD |
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| |||||
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CURRENT LIABILITIES |
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Loans and borrowings |
| USD |
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| USD |
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| |||||
Trade and other payables |
| USD |
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| USD |
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| |||||
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| EUR |
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| EUR |
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USD: US dollar. EUR: Euro.
(1) | At the exchange rate prevailing as of December 31, 2021 as per Banco de la Nación Argentina. |
(2) | At the exchange rate according to Communication “A” 3500 (wholesale) prevailing as of December 31, 2021 as per the Argentine Central Bank. |
| F-56 |
CENTRAL PUERTO S.A.
14. Non-financial assets and liabilities
14.1. Other non-financial assets
|
| 12-31-2021 |
|
| 12-31-2020 |
| ||
|
| ARS 000 |
|
| ARS 000 |
| ||
Non-current: |
|
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| ||
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| ||
Tax credits |
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Income tax credits |
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| ||
Prepayments to vendors |
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Current: |
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Upfront payments of inventories purchases |
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| ||
Prepayment insurance |
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| ||
Tax credits |
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Other |
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| ||
14.2. Other non-financial liabilities
|
| 12-31-2021 |
|
| 12-31-2020 |
| ||
|
| ARS 000 |
|
| ARS 000 |
| ||
Non-current: |
|
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| ||
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| ||
VAT payable |
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Tax on bank account transactions payable |
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Current: |
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VAT payable |
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| ||
Turnover tax payable |
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| ||
Income tax withholdings payable |
|
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| ||
Concession fees and royalties |
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| ||
Tax on bank account transactions payable |
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Other |
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| ||
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| ||
14.3. Compensation and employee benefits liabilities
|
| 12-31-2021 |
|
| 12-31-2020 |
| ||
|
| ARS 000 |
|
| ARS 000 |
| ||
Non-current: |
|
|
|
|
|
| ||
|
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|
| ||
Employee long-term benefits |
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| ||
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Current: |
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Employee long-term benefits |
|
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| - |
| |
Vacation and statutory bonus |
|
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|
| ||
Contributions payable |
|
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| ||
Bonus accrual |
|
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| ||
Other |
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| ||
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| ||
| F-57 |
CENTRAL PUERTO S.A.
The following tables summarize the components of net benefit expense recognized in the consolidated statement of income as long-term employee benefit plans and the changes in the long-term employee benefit liabilities recognized in the consolidated statement of financial position.
|
| 12-31-2021 |
|
| 12-31-2020 |
| ||
|
| ARS 000 |
|
| ARS 000 |
| ||
Benefit plan expenses |
|
|
|
|
|
| ||
|
|
|
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|
| ||
Cost of interest |
|
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| ||
Cost of service for the current year |
|
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| ||
Expense recognized during the year |
|
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| ||
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Defined benefit obligation at beginning of year |
|
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| ||
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Cost of interest |
|
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| ||
Cost of service for the current year |
|
|
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|
| ||
Actuarial gains |
|
| ( | ) |
|
| ( | ) |
Benefits paid |
|
| ( | ) |
|
| ( | ) |
Decrease due to gain on net monetary position |
|
| ( | ) |
|
| ( | ) |
Defined benefit obligation at end of year |
|
|
|
|
|
| ||
The main key assumptions used to determine the obligations as of year-end are as follows:
Main key assumptions used |
| 2021 |
|
| 2020 |
| ||
|
|
|
|
|
|
| ||
Discount rate |
|
| % |
|
| % | ||
|
|
|
|
|
|
|
|
|
Increase in the real annual salary |
|
| % |
|
| % | ||
|
|
|
|
|
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|
|
|
Turn over of participants |
|
| % |
|
| % | ||
A one percentage point change in the discount rate applied would have the following effect:
|
| Increase |
|
| Decrease |
| ||
|
| ARS 000 |
|
| ARS 000 |
| ||
|
|
|
|
|
|
| ||
Effect on the benefit obligation as of the 2021 year-end |
|
| ( | ) |
|
|
| |
Effect on the benefit obligation as of the 2020 year-end |
|
| ( | ) |
|
|
| |
A one percentage point change in the annual salary assumed would have the following effect:
|
| Increase |
|
| Decrease |
| ||
|
| ARS 000 |
|
| ARS 000 |
| ||
|
|
|
|
|
|
| ||
Effect on the benefit obligation as of the 2021 year-end |
|
|
|
|
| ( | ) | |
Effect on the benefit obligation as of the 2020 year-end |
|
|
|
|
| ( | ) | |
As of December 31, 2021 and 2020, the Group had no assets in connection with employee benefit plans.
15. Cash and cash equivalents
For the purpose of the consolidated statement of financial position and the consolidated statement of cash flow, cash and short-term deposits comprise the following items:
|
| 12-31-2021 |
|
| 12-31-2020 |
| ||
|
| ARS 000 |
|
| ARS 000 |
| ||
|
|
|
|
|
|
| ||
Cash at banks and on hand |
|
|
|
|
|
| ||
| F-58 |
CENTRAL PUERTO S.A.
Bank balances accrue interest at variable rates based on the bank deposits daily rates. Short-term deposits are made for varying periods of between one day and three months, depending on the immediate cash requirements of the Group, and earn interest at the respective fixed short-term deposit rates.
16. Equity reserves and dividends
Pursuant to the Argentine Companies Act (Ley General de Sociedades) and the bylaws, 5% of the income for the year must be allocated to the legal reserve until such reserve reaches 20% of the capital stock.
On April 30, 2019, the Shareholders’ Meeting of the Company approved i) to restore the legal reserve balance to its value prior to the absorption of the accumulated negative earnings resulting from the inflation-adjustment, which had been carried out according to the terms of RG no. 777/18 of the CNV for an amount of
On November 22, 2019, the Shareholders’ Meeting of the Company decided to partially deallocate the voluntary reserve and to destine the deallocated amount to the distribution of a cash dividend for an amount equivalent to ARS
On April 30, 2020, the Shareholders’ Meeting of the Company approved to increase the legal reserve in the amount of
On April 30, 2021, the Shareholders’ Meeting of the Company approved to increase the legal reserve in the amount of
Within the framework of the amendment to the loan agreement with Citibank N.A., JP Morgan Chase Bank N.A. and Morgan Stanley Senior Funding INC -described in Note 13.3.3-, there is a restriction for the payment of dividends until 80% of the loan’s principal and interests are paid. Thus, during 2021 no dividends could be paid while during 2022 and 2023 dividends can be paid up to USD 25 million and USD 20 million, respectively.
17. Provisions
|
| 2021 |
|
| 2020 |
| ||||||||||||||||||
Item |
| At beginning |
|
| Increases |
|
| Decreases |
|
| Recoveries |
|
| At end |
|
| At end |
| ||||||
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| ||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||
Current |
|
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| ||||||
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| ||||||
Provision for lawsuits and claims |
|
|
|
|
|
|
|
| ( | ) (1) |
|
| ( | ) |
|
|
|
|
|
| ||||
Total 2021 |
|
|
|
|
|
|
|
| ( | ) |
|
| ( | ) |
|
|
|
|
|
|
| |||
Total 2020 |
|
|
|
|
|
|
|
| ( | ) (1) |
|
| ( | ) |
|
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| |||
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|
Non-current |
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|
Provision for wind farms dismantling |
|
|
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|
|
|
|
| ( | ) (1) |
|
|
|
|
|
|
|
|
| |||||
12-31-2021 |
|
|
|
|
|
|
|
| ( | ) |
|
|
|
|
|
|
|
|
|
| ||||
12-31-2020 |
|
|
|
|
|
|
|
| ( | ) (1) |
|
|
|
|
|
|
|
|
|
| ||||
(1) | Relates to the effect of the inflation for the year. |
| F-59 |
CENTRAL PUERTO S.A.
18. Information on related parties
The following table provides the transactions performed for the years ended December 31, 2021, 2020 and 2019, and the accounts payable to/receivable from related parties as of December 31, 2021 and 2020:
|
|
|
| Income |
|
| Expenses |
|
| Receivables |
|
| Payables |
| |||||
|
|
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| |||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
Associates: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
| 12-31-2021 |
|
|
|
|
| - |
|
|
|
|
|
| - |
| |||
|
|
| 12-31-2020 |
|
|
|
|
| - |
|
|
|
|
|
| - |
| ||
|
| 12-31-2019 |
|
|
|
|
| - |
|
|
|
|
|
| - |
| |||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| 12-31-2021 |
|
| - |
|
|
|
|
|
| - |
|
|
|
| |||
|
|
| 12-31-2020 |
|
| - |
|
|
|
|
|
| - |
|
|
|
| ||
|
|
| 12-31-2019 |
|
| - |
|
|
|
|
|
| - |
|
|
|
| ||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| 12-31-2021 |
|
| - |
|
|
| - |
|
|
| - |
|
|
|
| ||
|
|
| 12-31-2020 |
|
| - |
|
|
| - |
|
|
| - |
|
|
|
| |
|
|
| 12-31-2019 |
|
| - |
|
|
| - |
|
|
| - |
|
|
|
| |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Related companies: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| 12-31-2021 |
|
|
|
|
|
|
|
| - |
|
|
| - |
| |||
|
|
| 12-31-2020 |
|
|
|
|
|
|
|
| - |
|
|
| - |
| ||
|
|
| 12-31-2019 |
|
|
|
|
|
|
|
| - |
|
|
| - |
| ||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| 12-31-2021 |
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
| |
|
|
| 12-31-2020 |
|
| - |
|
|
|
|
|
| - |
|
|
| - |
| |
|
|
| 12-31-2019 |
|
| - |
|
|
|
|
|
|
|
|
|
| |||
Total |
|
| 12-31-2021 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
|
| 12-31-2020 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
|
| 12-31-2019 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
(1) | Acquisition of natural gas for our thermal station located in Mendoza province. The purchase price is set according to current regulation of the natural gas market. |
|
|
(2) | Administrative, financial, commercial, human resources and general management services rendered under the terms of the management assistance agreement. The management assistance fee is calculated as a percentage of revenues. |
Balances and transactions with shareholders
As at December 31, 2021 and 2020, there is a balance of
On June 24, 2020, the Board of Directors of the Company authorized the purchase of
This transaction was accounted for as a transaction with non-controlling interest in accordance with IFRS 10. Consequently, the difference of 2,967,736 between the book value of the non-controlling interest at the transaction date and the fair value of the consideration paid was directly recognized in equity and attributed to holders of the parent.
This way, the Group´s consolidated interest in the subsidiary CP Renovables S.A. amounts to 100% of the capital stock as at December 31, 2021 and 2020.
Terms and conditions of transactions with related parties
Balances at the related reporting period-ends are unsecured and interest free. There have been no guarantees provided or received for any related party receivables or payables.
| F-60 |
CENTRAL PUERTO S.A.
For the years ended December 31, 2021, 2020 and 2019, the Group has not recorded any impairment of receivables relating to amounts owed by related parties. This assessment is undertaken at the end of each reporting period by examining the financial position of the related party and the market in which the related party operates.
19. Financial risk management objectives and policies
– | Interest rate risk |
Interest rate variations affect the value of assets and liabilities accruing a fixed interest rate, as well as the flow of financial assets and liabilities with floating interest rates.
The Company´s risk administration policy is defined for the purposes of reducing the effect of the purchasing power loss. Net monetary positions during first part of year 2021 were liabilities. Therefore, the Company was not exposed to the purchasing power loss risk. Since last quarter of fiscal year 2021 net monetary positions have been assets; hence, during such period the Company sought to mitigate the risk by implementing adjustment mechanisms through interest and exchange differences. On the other hand, during most of 2020, net monetary positions were liabilities; therefore, the Company was not exposed to the purchasing power loss risk. During 2021, item "Gain / (loss) on net monetary position” registered a net loss due to inflation-exposure of monetary items; while in 2020, item "Gain (loss) on net monetary position" registered a net income due to inflation-exposure of monetary items.
Interest rate sensitivity
The following table shows the sensitivity of income before income tax for the year ended December 31, 2021, to a reasonably possible change in interest rates over the portion of loans bearing interest at a variable interest rate, with all other variables held constant:
Increase in percentage |
| Effect on income before income tax (Loss) |
| ARS 000 | |
|
|
|
| ( |
– | Foreign currency risk |
Foreign currency risk is the risk that the fair value or future cash flows of a financial instrument will fluctuate because of changes in foreign exchange rates.
The Company is exposed to the foreign currency risk at an ARS/USD ratio, mainly due to its operating activities, the investment projects defined by the Company and the financial debt related to the bank loans mentioned in Note 13.3. The Company does not use derivative financial instruments to hedge such risk. However, as of December 31, 2021, the Company has receivables, other financial assets and cash and short-term deposits in foreign currency for USD
Foreign currency sensitivity
The following table shows the sensitivity to a reasonably possible change in the US dollar exchange rate, with all other variables held constant, of income before income tax as of December 31, 2021 (due to changes in the fair value of monetary assets and liabilities).
Change in USD rate |
| Effect on income before income tax (Income) |
| ARS 000 | |
|
|
|
|
| F-61 |
CENTRAL PUERTO S.A.
– | Price risk |
The Company’s revenues depend on the electric power price in the spot market and the production cost paid by CAMMESA. The Company has no power to set prices in the market where it operates, except for the income from agreements entered into in the Term Market, where the price risk is reduced since normally prices are negotiated above the spot market price.
Credit risk
Credit risk is the risk that a counterparty will not meet its obligations under a financial instrument or customer contract, leading to a financial loss. The Company is exposed to credit risk from its operating activities (primarily for trade receivables) and from its financing activities, including holdings of government securities.
– | Trade and other receivables |
The Finance Department is in charge of managing customer credit risk subject to policies, procedures and controls relating to the Group’s credit risk management. Customer receivables are regularly monitored. Although the Group has received no guarantees, it is entitled to request interruption of electric power flow if customers fail to comply with their credit obligations. In regard to credit concentration, see Note 13.1. The need to book impairment is analyzed at the end of each reporting period on an individual basis for major clients. The allowance recorded as of December 31, 2021, is deemed sufficient to cover the potential impairment in the value of trade receivables.
– | Cash and cash equivalents |
Credit risk from balances with banks and financial institutions is managed by the Group’s treasury department in accordance with corporate policy. Investments of surplus funds are made only with approved counterparties; in this case, the risk is limited because high-credit-rating banks are involved.
– | Public and corporate securities |
This risk is managed by the Company’s finance management according to corporate policies, whereby these types of investments may only be made in first-class companies and in instruments issued by the federal or provincial governments.
Liquidity risk
The Group manages its liquidity to guarantee the funds required to support its business strategy. Short-term financing needs related to seasonal increases in working capital are covered through short-and medium-term bank credit lines.
The table below summarizes the maturity profile of the Company’s financial liabilities.
|
| Less than 3 months |
|
| 3 to 12 months |
|
| More than a year |
|
| Total |
| ||||
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
|
| ARS 000 |
| ||||
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
12-31-2021 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
Loans and borrowings |
|
|
|
|
|
|
|
|
|
|
|
| ||||
Trade and other payables |
|
|
|
|
| - |
|
|
| - |
|
|
|
| ||
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
12-31-2020 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loans and borrowings |
|
| 6,807,951 |
|
|
|
|
|
|
|
|
|
| |||
Trade and other payables |
|
|
|
|
| - |
|
|
| - |
|
|
|
| ||
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
| F-62 |
CENTRAL PUERTO S.A.
Guarantees
In connection with the concession right agreement described in Note 12, the Group granted a bank security to provide performance assurance of its obligations in the amount of
On March 19, 2009, the Group entered into a pledge agreement with the former Secretariat of Energy to secure its obligations in favor of FONINVEMEM trusts by virtue of the operation and maintenance agreement of the José de San Martín and Manuel Belgrano power stations, by which it pledged as a collateral 100% of the shares in TSM and TMB.
Likewise, the Group entered into various guarantee agreements to provide performance assurance of its obligations arising from the agreements described in Notes 1.2.a), 13.3.1, 13.3.3, 13.3.4, 13.3.8, 13.3.9 and 20.6.
20. Contracts, acquisitions and agreements
20.1. Maintenance and service contracts
The Group entered into long-term service agreements executed with leading global companies in the construction and maintenance of thermal generation plants, such as (i) General Electric, which is in charge of the maintenance of the Nuevo Puerto Combined Cycle plant, and part of the Mendoza based units, and (ii) Siemens, which is in charge of the maintenance of the combined cycle unit based in Mendoza site, the Thermal Station Brigadier López and Luján de Cuyo and Terminal 6 San Lorenzo cogeneration units.
Under long-term service agreements, suppliers provide materials, spare parts, labor and on-site engineering guidance in connection with scheduled maintenance activities, in accordance with the applicable technical recommendations.
20.2. Agreement for supplying electricity and steam to YPF
As from January 1999 and for a 20-year term, our Luján de Cuyo plant supplies 150 tons per hour of steam to YPF’s refinery in Luján de Cuyo under a steam supply agreement. Under this agreement YPF supplies the Luján de Cuyo plant with the fuel and water needed for operation of the plant.
On February 8, 2018, we signed an agreement to extend the aforementioned agreement with YPF for a period of up to 24 months or up to the start of commercial operation of the new Luján de Cuyo co-generation unit, which is described in Note 20.7, whatever occurs first. This way, this agreement was valid up to September 24, 2019 since the new cogeneration commenced supplying steam to YPF on September 25, 2019, the new steam agreement entering into force on October 5, 2019.
20.3. Acquisition of Siemens gas turbine
On December 18, 2014, the Company acquired from Siemens a gas turbine for electric power generation composed by a turbine and a generator with 286 MW output power, and the proper ancillary equipment and maintenance and assistance services. This equipment was used in the cogeneration project called "Terminal 6 San Lorenzo", which is described in Note 20.7.
20.4. Acquisition of General Electric gas turbine
On March 13th, 2015, the Company acquired a gas turbine from General Electric and hired their specialized technical support services. The unit is a gas turbine with 373 MW output power.
20.5. Acquisition of two Siemens gas turbines
On May 27th, 2016, the Company acquired from Siemens two gas turbines for electric power generation composed by a turbine and a generator with 298 MW output power, and the proper ancillary equipment and maintenance and assistance services.
| F-63 |
CENTRAL PUERTO S.A.
During September 2021, the Company sold such equipment to UNIPER KRAFTWERKE GMBH and UNIPER HUNGARY Kft. for the amount of USD 33,750,000.
20.6. Renewable Energy generation farms
In 2017 the Group entered into a power purchase agreement with CAMMESA for La Castellana and Achiras wind farms for a 20-year term as from the launch of the commercial operations. Likewise, during 2018 the Group entered into a power purchase agreement with CAMMESA for La Genoveva wind farm for a 20-year term as from the launch of the commercial operations.
Regarding wind farm La Castellana II, the Group entered into supply agreements with Rayen Cura S.A.I.C. for a 7-year term and approximately 35,000 MWh/year volume, with Metrive S.A. for a 15-year term and 12,000 MWh/year volume, with N. Ferraris for a 10-year term and 6,500 MWh/year volume and with Banco de Galicia y Buenos Aires S.A. for a 10-year term to supply energy demand for approximately 4,700 MWh/year.
Regarding wind farm La Genoveva II, the Group entered into supply agreements with Aguas y Saneamiento S.A. (AYSA) for a 10-year term from the beginning of operations date of the wind farm and approximately 87.6 GWh/year volume, with PBB Polisur S.R.L. (Dow Chemical) for a term of 6 years and an estimated volume of 80 GWh/year, with Farm Frites for a 5-year term and 9.5 GWh/year volume and with BBVA for a 5-year term and 6 GWh/year volume.
Regarding wind farm Manque, the Group entered into a power purchase agreement with Cervecería y Maltería Quilmes SAICAyG (“Quilmes”) for the wind farm Manque for a 20-year term as from the launch of the commercial operations and for an estimated volume of 235 GWh per year.
Regarding the wind farm Los Olivos, the Group entered into power purchase agreements with S.A. San Miguel A.G.I.C.I. y F., Minera Alumbrera Limited and SCANIA Argentina S.A.U. for a 10-year term as from the launch of commercial operations, to supply them 8.7 GWh/year, 27.4 GWh/year and 20.2 GWh/year, respectively.
Acquisition and operation of wind turbines
The Group has entered into agreements with Nordex Windpower S.A. for the operation and maintenance of Achiras and La Castellana wind farms for a 10-year term.
Moreover, the Group has entered into agreements with Vestas Argentina S.A. for the operation and maintenance of La Genoveva I, La Genoveva II, La Castellana II, Manque and Los Olivos wind farms for a 5- year term.
20.7. Awarding of co-generation projects
On September 25, 2017, the Company was awarded through Resolution SEE 820/2017 with two co-generation projects called “Terminal 6 San Lorenzo” with a capacity of 330 MW and Luján de Cuyo (within our Luján de Cuyo plant) with a capacity of 93 MW.
On January 4, 2018, the Company entered into power purchase agreements with CAMMESA for each of the mentioned projects for a 15-year term as from the launch of commercial operations. The Group has posted a guarantee for the fulfillment of the “Terminal 6 San Lorenzo” cogeneration project.
On December 15, 2017, we executed a new steam supply contract with YPF for a 15-year term that began when the new co-generation unit at our Luján de Cuyo plant started operations.
Also, on December 27, 2017, we entered into a steam supply agreement with T6 Industrial S.A. for the new co-generation unit at our Terminal 6 San Lorenzo plant for a 15 year-term counted as from the commencement of the cogeneration unit’s commercial operations.
| F-64 |
CENTRAL PUERTO S.A.
On October 5, 2019, the commercial operation of the new cogeneration unit Luján de Cuyo started. On November 21, 2020, the open cycle commercial operation of cogeneration unit Terminal 6 San Lorenzo started, while on August 15, 2021, the power station launched operations at combined cycle. On October 31, 2021, commencement of the cogeneration unit’s commercial operations was completed as the steam supply agreement commenced.
20.8. Purchase of natural gas for generation
As accepted under Regulation SGE No. 70/2018 described in Note 1.2.d), the Company reinstated its activities towards purchasing natural gas as from late November 2018, in order to supply its generation stations. As from December 2018, all natural gas used by the Company was purchased to producers and distributors directly, as well as the transported associated to those consumptions. The Company’s main natural gas providers were YPF, Tecpetrol, Total, Metroenergía and Pluspetrol, among others.
As from December 30, 2019, as stated in Note 1.2.d), the Ministry of Productive Development decided to centralize the purchase of fuel to generate electrical energy through CAMMESA, repealing Resolution No. 70/2018 of the former Secretariat of Energy. The scope of this new measure is for the WEM generation units that commercialize their energy and power in the spot market.
20.9. Acquisition of Thermal Station Brigadier López
In the context of a local and foreign public tender called by Integración Energética Argentina S.A. (“IEASA”), which has been awarded to the Company, on June 14, 2019 the transfer agreement of the production unit that is part of Brigadier López Thermal Station and of the premises on which the Station is located, was signed, including: a) production unit for the Station, which includes personal property, recordable personal property, facilities, machines, tools, spare parts, and other assets used for the Station operation and use; b) IEASA’s contractual position in executed contracts (including turbogas and turbosteam supplying contracts with CAMMESA and the financial trust agreement signed by IEASA as trustor, among others); c) permits and authorizations in effect related to the Station operation; and d) the labor relationship with the transferred employees.
The Station currently has a Siemens gas turbine of 280.5 MW. According to the tender specifications and conditions, it is expected to supplement the gas turbine with a boiler and a steam turbine to reach the closing of the combined cycle, which will generate 420 MW in total.
The cycle closing works’ finishing is pending.
21. Tax integral inflation adjustment
Pursuant to current income tax law, to determine the amount of taxable net profits for fiscal years commencing January 1, 2019, the inflation adjustment calculated on the basis of the provisions set forth in the income tax law will have to be added to or deducted from the fiscal year’s tax result. This adjustment will only be applicable (a) if the variance percentage of the consumers price index (“IPC”) during the 36 months prior to fiscal year closing is higher than 100%, and (b) if for the first, second, and third fiscal year as from its effective date, the accumulated IPC variance is higher than 55%, 30% and 15% of such 100%, respectively. The positive or negative tax inflation adjustment, depending on the case, corresponding to the first, second and third period commenced as from January 1, 2018, which must be calculated in case of verifying the statements on the foregoing paragraphs (a) y (b), shall be charged in a sixth for that fiscal period and the remaining five sixths, equally, in the immediately following fiscal periods.
At December 31, 2019 and during the following fiscal years such conditions have been already met. Consequently, the current and deferred income tax have been booked since the fiscal year ended December 31, 2019 including the effects derived from the application of the tax inflation adjustment under the terms established by the income tax law.
| F-65 |
CENTRAL PUERTO S.A.
22. Measures in the Argentine economy
Foreign exchange market
As from December 2019, the BCRA issued a series of communications whereby it extended indefinitely the regulations on Foreign Market and Foreign Exchange Market issued by BCRA that included regulations on exports, imports and previous authorization from BCRA to access the foreign exchange market to transfer profits and dividends abroad, as well as other restrictions on the operation in the foreign exchange market.
Particularly, as from September 16, 2020, Communication “A” 7106 established, among other measures referred to human persons, the need for refinancing the international financial indebtedness for those loans from the non-financial private sector with a creditor not being a related counterparty of the debtor expiring between October 15, 2020 and March 31, 2021. The affected legal entities were to submit before the Central Bank a refinancing plan under certain criteria: that the net amount for which the foreign exchange market was to be accessed in the original terms did not exceed 40% of the capital amount due for that period and that the remaining capital had been, as a minimum, refinanced with a new external indebtedness with an average life of 2 years. This point shall not be applicable when indebtedness is taken from international entities and official credit agencies, among others. On February 25, 2021, through Communication “A” 7230, BCRA broadened the regulation scope to all those debt installments higher than USD
On July 10, 2021, new measures issued by BCRA and CNV were released. These measures established additional restrictions to the operations in the foreign exchange market, which include the following:
– | The 90-day term established by Communication A “7030”, whereby to access the foreign exchange market an affidavit on the non-performance of certain type of investments purchase and sale operations in the preceding and following 90 days must be submitted, will apply not only to operations expressed as securities sale with foreign currency liquidation or as securities transferences to entities depositing abroad, but also to the securities in exchange of other foreign assets as from July 12, 2021. |
|
|
– | The 90-day term will apply not only to the operations performed by the company accessing the foreign exchange market, but also in the case in which the company delivers Argentine Peso (“Ps.”) or liquidated local assets to a direct controlling shareholder as from July 12, 2021, except in those directly associated to usual operations of goods and/or services acquisition. |
Income Tax
On June 16, 2021, the Argentine Executive Power passed Law No. 27,630, which established changes in the corporate income tax rate for the fiscal periods commencing as from January 1, 2021. Such law establishes payment of the tax based on a structure of staggered rates regarding the level of accumulated taxable net income.
23. COVID-19
On March 11, 2020, the World Health Organization characterized the COVID-19 as a pandemic. Hence, several measures have been undertaken by the Argentine government and other governments around the globe in order to control the outbreak of this contagious disease.
| F-66 |
CENTRAL PUERTO S.A.
In this regard, on March 20, 2020 the Argentine Government issued Decree No. 297/2020 establishing a preventive and mandatory social isolation policy (“the Quarantine” or “ASPO” -for its acronym in Spanish-, indistinctly) as a public health measure to contain the effects of the COVID-19 outbreak. Such decree established that persons were to refrain from going to their workplaces, and may not travel along routes, roads or public spaces. As from the adoption of the Quarantine, the government has extended it in many opportunities and it has ordered the preventive and mandatory social distancing (“DISPO” -for its acronym in Spanish-). Subsequently, the Argentine Executive Power ordered the “General Prevention Measures”. The last one of these measures was issued through Decree No. 678/2021 published in the Official Gazette on October 1, 2021 and it was in force until December 31, 2021. As of the date of these financial statements, the Health Emergency established originally by Decree No. 260/2020, and extended until December 31, 2022 by Decree No. 867/2021, is in effect.
Moreover, as an additional measure to control the virus in Argentina, restrictions were imposed on the entering of people to the country and on international flights several times since the beginning of the pandemic.
On the other hand, since late 2020, the vaccination campaign to prevent COVID-19 has commenced in Argentina.
Pursuant to Decree 297/2020, minimum shifts ensuring the operation and maintenance of electric energy generators were exempted from the Quarantine. Furthermore, on April 7, 2020, pursuant to Administrative Decision 468/2020 issued by the Presidency of the Cabinet of Ministers, the construction of private sector energy infrastructure was included within the activities exempted from the ASPO.
Some of the main identified impacts that this crisis has and may have in the future for the Company are the following:
Operations - Power generation
– | Reduction in the electric energy dispatched. Due to the Quarantine, most of the businesses in Argentina, especially in the industrial sector experienced difficulties in their normal operations. At the beginning of Quarantine the total electric energy demand had significantly declined, and although as of this date the demand has returned to values similar to the ones previous to the pandemic, this situation reduced the Group’s generation of thermal power in such period and it could affect it in the future -but to a lower extent-, in particular our units with higher heat rate (less efficient). |
|
|
– | Increased delays in payments and/or risk of uncollectability from the Group’s private clients. Despite the fact that CAMMESA is paying its obligations, the reduced economic activity due to the Quarantine also affected the cash flow of CAMMESA and the cash flow of our private clients. Even if as of this date the situation has considerably improved, there still exists the risk of delay in the payment of private clients and, therefore, the risk of uncollectability of private clients. |
|
|
– | Personnel safeguard. Multiple measures have been implemented to protect the health of all the personnel who work in the operation and maintenance of the generation units, as well as in the works that were carried out by the Group. Some of those measures include: a) the isolation of the teams that operate the Group’s different units preventing contact between different teams, b) the avoidance of contact between personnel of different shifts, c) the use of extra protection, and additional sanitary measures, d) using virtual meetings, e) identify key personnel in order to have the necessary back up teams should a contingency arise, f) drafting and publication of health and safety plans and/or protocols both for the plants in operation and works in development. These measures have been effective to protect the Group’s personnel, and at the date of these financial statements, a low contagion level has been registered within the Group’s personnel. |
|
|
– | Lack of necessary supplies/equipment, or delays in supplies. The pandemic may also affect the provision of essential supplies. Although the provision of the necessary supplies is also considered an essential activity under the enacted emergency framework and usually a stock of spare parts is kept as backup, the Company cannot assure that the provision of the necessary supplies will not be affected. Furthermore, the measures taken by foreign countries in which some of the Group’s supplies and spare parts are produced, may also affect the Group’s stock of spare parts. Any delay in the provision of essential equipment or supplies may affect the Group’s operations. |
| F-67 |
CENTRAL PUERTO S.A.
Projects under construction during the pandemic
COVID-19 outbreak has had an impact on the projects that were under construction. Therefore, there have been delays in the completion dates originally set.
Since the issuance of Administrative Decision 468/2020 abovementioned, the project construction activities were resumed. This required the implementation of health safety measures according to the requests established and recommended by health authorities. Regard being had to the foregoing, a procedure and a protocol were drafted, which have to be complied with by the personnel, contractors and subcontractors.
Regarding the Terminal 6-San Lorenzo thermal plant described in Note 20.7, once the aforementioned Administrative Decision 468/2020 was issued, construction was resumed on April 27, 2020. Additionally, as mentioned above, travel restrictions and national borders lockdown imposed by the government, among others, delayed the arrival of necessary personnel for the project, some of which were expected to arrive from countries affected by the outbreak. The Company notified CAMMESA and the Energy Secretariat on the situation and requested: (i) the suspension of agreement terms as from March 20, 2020 and until the situation is normalized, and (ii) the non-application of sanctions for the case in which the Company cannot comply with the committed dates on the Wholesale Demand Agreement entered into with CAMMESA mentioned in Note 20.7, so as to avoid possible sanctions stemming from a delay in the completion of the project due to unforeseen and inevitable reasons. In this sense, on June 10, 2020, the Secretariat of Energy ordered CAMMESA to temporarily suspend the calculation of the terms set forth for those projects that had not obtained the commercial authorization, among which the cogeneration station Terminal 6 - San Lorenzo is included, for a maximum postponement term of six months from March 12 to September 12, 2020. On July 15, 2020, the Company communicated the Secretariat of Energy, with copy to CAMMESA, that the temporary suspension of the terms was not sufficient to comply with the new terms under the Wholesale Demand Agreement since the numerous measures adopted due to COVID-19 generated a strong slowdown in all the activities related to the work of the cogeneration unit Terminal 6 - San Lorenzo. Dated September 10, 2020, the Undersecretariat of Electrical Energy granted a new suspension of the terms for the commercial authorization of the projects between September 12, 2020 and November 25, 2020, being subject to certain requirements to be fulfilled before CAMMESA. Then, CAMMESA granted a new extension for 45 days. This way, the calculation of periods had been suspended for a total of 294 days counted as from the originally committed date for the commercial authorization (September 1, 2020), this is to say until June 22, 2021. At the time, the Company requested CAMMESA and the Secretariat of Energy the extension of the commercial authorization of Terminal 6 - San Lorenzo project for additional 90 days. It is worth mentioning that on November 21, 2020, open cycle commercial operation had begun, while on August 15, 2021, the power station was authorized to operate commercially at combined cycle. On August 23, 2021, we received a note from CAMMESA whereby it informed that a penalty for USD 4,444,933 was established on the grounds of the delay on reaching the commercial authorization. The Company rejected such penalty. Finally, on January 27, 2022, the Secretariat of Energy issued Resolution No. 39/2022, which allowed for those generators with projects under the scope of Resolution No. 287/2017, that had not been authorized on the date established within the extensions of the previously granted term, to set a new date. Within this context, the Company stated August 15, 2021 as the new Commercial Authorization date of the project Terminal 6 San Lorenzo (effective completion date). Therefore, the application of the penalty previously mentioned is deemed invalid.
The effects of the COVID-19 crisis also pose challenges to the beginning of works for closing of the combined cycle at the Brigadier López plant, delaying the start of construction of such project, not only because of the restrictions to the construction mentioned above, but also due to lower energy demand and difficulties to obtain the necessary financing for projects in the current market situation.
In addition, the COVID-19 crisis may reduce the possibility of new projects that would enable the use of the gas turbine included under "Gas turbines" item within property, plant and equipment.
| F-68 |
CENTRAL PUERTO S.A.
Access to Capital Markets
Due to the outbreak of COVID-19, access to the capital and financial markets in Argentina and/or in foreign markets was also substantially reduced. Although cash flow and liquidity of the Group is deemed sufficient to meet the working capital, debt service obligations and capital expenditure requirements, any further deterioration of the current economic situation may result in a deterioration of the Company´s finances, in a context of lack of access or substantial reduction of credit availability in the financial markets.
Natural gas distribution operating segment
The COVID-19 pandemic crisis may affect the natural gas distribution associate’s income (ECOGAS Group). Although such economic activity was exempt from the Quarantine, the resulting economic downturn reduced the volumes distributed to the clients at the beginning of the Quarantine. Moreover, some measures adopted by the Argentine government to mitigate the effects of the COVID-19 outbreak in the economy could also affect ECOGAS Group financial performance. For example, the government had ruled a 180-day period, starting on March 1, 2020, where the suspension of the natural gas service was not permitted, upon certain circumstances and limited to certain users; that period was subsequently extended until March 31, 2021.
The Group will continue taking all the available measures to mitigate the effects that the COVID-19 pandemic crisis has on the operations, the projects undergoing and the Group´s financial position.
24. Subsequent events
No facts or operations, other than disclosed, occurred between the closing date of the fiscal year and the date of issuance of these financial statements that may significantly affect such financial statements.
| F-69 |