GTE 10-Q Quarterly Report Sept. 30, 2023 | Alphaminr
GRAN TIERRA ENERGY INC.
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GTE 10-Q Quarter ended Sept. 30, 2023

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UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q

(Mark One)

☒ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended September 30, 2023

or
☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from __________ to __________
Commission file number 001-34018
GRAN TIERRA ENERGY INC.
(Exact name of registrant as specified in its charter)
Delaware 98-0479924
(State or other jurisdiction of incorporation or organization) (I.R.S. Employer Identification No.)
500 Centre Street S.E.
Calgary, Alberta Canada T2G 1A6
(Address of principal executive offices, including zip code)
( 403 ) 265-3221
(Registrant’s telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:
Title of each class Trading Symbol(s) Name of each exchange on which registered
Common Stock, par value $0.001 per share
GTE
NYSE American
Toronto Stock Exchange
London Stock Exchange

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. Yes ☒ No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).
Yes ☒ No ☐
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of large accelerated filer, accelerated filer, smaller reporting company, and emerging growth company in Rule 12b-2 of the Exchange Act.
Large accelerated filer ☐ Accelerated filer ☒
Non-accelerated filer ☐ Smaller reporting company ☐
Emerging growth company ☐
If an emerging growth company, 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. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act).      Yes ☐ No ☒

On October 27, 2023, 33,288,305 shares of the registrant’s Common Stock, $0.001 par value, were issued.




Gran Tierra Energy Inc.

Quarterly Report on Form 10-Q

Quarterly Period Ended September 30, 2023

Table of contents
Page
PART I Financial Information
Item 1. Financial Statements
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations
Item 3. Quantitative and Qualitative Disclosures About Market Risk
Item 4. Controls and Procedures
PART II Other Information
Item 1. Legal Proceedings
Item 1A. Risk Factors
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds
Item 5. Other information
Item 6. Exhibits
SIGNATURES
1

CAUTIONARY LANGUAGE REGARDING FORWARD-LOOKING STATEMENTS
This Quarterly Report on Form 10-Q includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). All statements other than statements of historical facts included in this Quarterly Report on Form 10-Q regarding our financial position, estimated quantities and net present values of reserves, business strategy, plans and objectives of our management for future operations, covenant compliance, capital spending plans and benefits of the changes in our capital program or expenditures, our liquidity and those statements preceded by, followed by or that otherwise include the words “believe,” “expect,” “anticipate,” “intend,” “estimate,” “project,” “target,” “goal,” “plan,” “budget,” “objective,” “could,” “should,” or similar expressions or variations on these expressions are forward-looking statements. We can give no assurances that the assumptions upon which the forward-looking statements are based will prove to be correct or that, even if correct, intervening circumstances will not occur to cause actual results to be different than expected. Because forward-looking statements are subject to risks and uncertainties, actual results may differ materially from those expressed or implied by the forward-looking statements. There are a number of risks, uncertainties and other important factors that could cause our actual results to differ materially from the forward-looking statements, including, but not limited to, our operations are located in South America and unexpected problems can arise due to guerilla activity, strikes, local blockades or protests; technical difficulties and operational difficulties may arise which impact the production, transport or sale of our products; other disruptions to local operations; global health events; global and regional changes in the demand, supply, prices, differentials or other market conditions affecting oil and gas, including inflation and changes resulting from a global health crisis, geopolitical events, including the ongoing conflicts in Ukraine and the Gaza region, or from the imposition or lifting of crude oil production quotas or other actions that might be imposed by OPEC, such as its recent decision (occurred June 2023) to cut production and other producing countries and the resulting company or third-party actions in response to such changes; changes in commodity prices, including volatility or a prolonged decline in these prices relative to historical or future expected levels; the risk that current global economic and credit conditions may impact oil prices and oil consumption more than we currently predicts, which could cause further modification of our strategy and capital spending program; prices and markets for oil and natural gas are unpredictable and volatile; the effect of hedges; the accuracy of productive capacity of any particular field; geographic, political and weather conditions can impact the production, transport or sale of our products; our ability to execute our business plan and realize expected benefits from current initiatives; the risk that unexpected delays and difficulties in developing currently owned properties may occur; the ability to replace reserves and production and develop and manage reserves on an economically viable basis; the accuracy of testing and production results and seismic data, pricing and cost estimates (including with respect to commodity pricing and exchange rates); the risk profile of planned exploration activities; the effects of drilling down-dip; the effects of waterflood and multi-stage fracture stimulation operations; the extent and effect of delivery disruptions, equipment performance and costs; actions by third parties; the timely receipt of regulatory or other required approvals for our operating activities; the failure of exploratory drilling to result in commercial wells; unexpected delays due to the limited availability of drilling equipment and personnel; volatility or declines in the trading price of our Common Stock or bonds; the risk that we do not receive the anticipated benefits of government programs, including government tax refunds; our ability to comply with financial covenants in our credit agreement and indentures and make borrowings under any credit agreement; and those factors set out in Part II, Item 1A “Risk Factors” in this Quarterly Report on Form 10-Q and Part I, Item 1A “Risk Factors” in our 2022 Annual Report on Form 10-K (the “2022 Annual Report on Form 10-K”), and in our other filings with the Securities and Exchange Commission (“SEC”) during the current fiscal year. The unprecedented nature of the current volatility in the worldwide economy and oil and gas industry makes it more difficult to predict the accuracy of forward-looking statements. The information included herein (other than in the context of the financial statements) is given as of the filing date of this Quarterly Report on Form 10-Q with the SEC and, except as otherwise required by the federal securities laws, we disclaim any obligation or undertaking to publicly release any updates or revisions to or to withdraw, any forward-looking statement contained in this Quarterly Report on Form 10-Q to reflect any change in our expectations with regard thereto or any change in events, conditions or circumstances on which any forward-looking statement is based.

GLOSSARY OF OIL AND GAS TERMS
In this document, the abbreviations set forth below have the following meanings:
bbl barrel
BOPD barrels of oil per day
NAR net after royalty
Sales volumes represent production NAR adjusted for inventory changes. Our oil and gas reserves are reported as NAR. Our production is also reported NAR, except as otherwise specifically noted as “working interest production before royalties”.


2

PART I - Financial Information

Item 1. Financial Statements
Gran Tierra Energy Inc.
Condensed Consolidated Statements of Operations (Unaudited)
(Thousands of U.S. Dollars, Except Share and Per Share Amounts)
Three Months Ended September 30, Nine Months Ended September 30,
2023 2022 2023 2022
OIL SALES (Note 6)
$ 179,921 $ 168,397 $ 482,013 $ 548,751
EXPENSES
Operating 49,367 41,837 139,227 116,266
Transportation 3,842 2,417 10,599 7,764
Depletion, depreciation and accretion
(Note 3)
55,019 45,320 162,949 128,499
General and administrative (Note 9)
10,238 8,114 32,800 30,286
Foreign exchange loss 1,717 1,489 8,126 486
Derivative instruments loss (Note 9)
— — — 26,611
Other gain (Note 4)
( 354 ) ( 2,598 ) ( 969 ) ( 2,598 )
Interest expense (Note 4)
13,503 11,421 38,017 35,743
133,332 108,000 390,749 343,057
INTEREST INCOME 271 — 1,686 —
INCOME BEFORE INCOME TAXES 46,860 60,397 92,950 205,694
INCOME TAX EXPENSE
Current (Note 7)
26,343 16,820 63,706 63,072
Deferred (Note 7)
13,990 4,914 43,242 36,868
40,333 21,734 106,948 99,940
NET AND COMPREHENSIVE INCOME (LOSS) $ 6,527 $ 38,663 $ ( 13,998 ) $ 105,754
NET INCOME (LOSS) PER SHARE (1)
- BASIC $ 0.20 $ 1.05 $ ( 0.42 ) $ 2.88
- DILUTED $ 0.20 $ 1.04 $ ( 0.42 ) $ 2.84
WEIGHTED AVERAGE SHARES OUTSTANDING - BASIC (Note 5)
33,287,368 36,730,543 33,675,160 36,775,419
WEIGHTED AVERAGE SHARES OUTSTANDING - DILUTED (Note 5)
33,350,050 37,131,074 33,675,160 37,238,790
(1) Reflects our 1-for-10 reverse stock split that became effective May 5, 2023. See Note 5 in the notes to the condensed consolidated financial statements for further discussion.

(See notes to the condensed consolidated financial statements)
3

Gran Tierra Energy Inc.
Condensed Consolidated Balance Sheets (Unaudited)
(Thousands of U.S. Dollars, Except Share and Per Share Amounts)
As at September 30, 2023 As at December 31, 2022
ASSETS
Current Assets
Cash and cash equivalents (Note 10)
$ 123,216 $ 126,873
Restricted cash and cash equivalents (Note 10)
1,142 1,142
Accounts receivable 19,157 10,706
Inventory 25,724 20,192
Other current assets (Note 9)
12,082 9,674
Total Current Assets 181,321 168,587
Oil and Gas Properties
Proved 1,040,254 1,000,424
Unproved 70,253 74,471
Total Oil and Gas Properties 1,110,507 1,074,895
Other capital assets 30,448 26,007
Total Property, Plant and Equipment (Note 3)
1,140,955 1,100,902
Other Long-Term Assets
Deferred tax assets 9,758 22,990
Taxes receivable 46,736 27,796
Other long-term assets (Note 9 and 10)
7,265 15,335
Total Other Long-Term Assets 63,759 66,121
Total Assets $ 1,386,035 $ 1,335,610
LIABILITIES AND SHAREHOLDERS’ EQUITY
Current Liabilities
Accounts payable and accrued liabilities $ 176,489 $ 167,579
Credit facility (Note 4)
49,067 —
Taxes payable 46,398 58,978
Equity compensation award liability (Note 5)
7,794 15,082
Total Current Liabilities 279,748 241,639
Long-Term Liabilities
Long-term debt (Notes 4 and 9)
587,444 589,593
Deferred tax liabilities 35,011 28
Asset retirement obligation 70,712 63,358
Equity compensation award liability (Note 5)
9,525 16,437
Other long-term liabilities 9,055 6,989
Total Long-Term Liabilities 711,747 676,405
Contingencies (Note 8)
Shareholders' Equity (1)
Common Stock (Note 5) ( 33,288,305 and 36,889,862 issued, 33,288,305 and 34,615,116 outstanding shares of Common Stock, par value $ 0.001 per share, as at September 30, 2023, and December 31, 2022, respectively)
10,237 10,272
Additional paid-in capital 1,255,044 1,291,354
Treasury Stock (Note 5)
— ( 27,317 )
Deficit ( 870,741 ) ( 856,743 )
Total Shareholders’ Equity 394,540 417,566
Total Liabilities and Shareholders’ Equity $ 1,386,035 $ 1,335,610
( 1) Reflects our 1-for-10 reverse stock split that became effective May 5, 2023. See Note 5 in the notes to the condensed consolidated financial statements for further discussion.
(See notes to the condensed consolidated financial statements)
4

Gran Tierra Energy Inc.
Condensed Consolidated Statements of Cash Flows (Unaudited)
(Thousands of U.S. Dollars)
Nine Months Ended September 30,
2023 2022
Operating Activities
Net (loss) income $ ( 13,998 ) $ 105,754
Adjustments to reconcile net (loss) income to net cash provided by operating activities:
Depletion, depreciation and accretion (Note 3)
162,949 128,499
Deferred tax expense (Note 7)
43,242 36,868
Stock-based compensation expense (Note 5)
3,748 6,376
Amortization of debt issuance costs (Note 4)
3,394 2,769
Unrealized foreign exchange (gain) loss ( 7,814 ) 6,138
Other gain (Note 4)
( 969 ) ( 2,598 )
Derivative instrument loss (Note 9)
— 26,611
Cash settlement on derivative instruments
— ( 26,611 )
Cash settlement of asset retirement obligation ( 376 ) ( 1,673 )
Non-cash lease expenses 3,488 2,009
Lease payments ( 1,918 ) ( 1,134 )
Net change in assets and liabilities from operating activities (Note 10)
( 34,235 ) 72,838
Net cash provided by operating activities 157,511 355,846
Investing Activities
Additions to property, plant and equipment ( 179,707 ) ( 163,717 )
Changes in non-cash investing working capital (Note 10)
( 11,051 ) 3,255
Net cash used in investing activities ( 190,758 ) ( 160,462 )
Financing Activities
Proceeds from debt, net of issuance costs (Note 4)
48,125 —
Repayment of debt
— ( 67,623 )
Purchase of Senior Notes (Note 4)
( 6,805 ) ( 17,274 )
Re-purchase of shares of Common Stock (Note 5)
( 10,825 ) ( 14,365 )
Proceeds from exercise of stock options 8 1,294
Lease payments ( 5,101 ) ( 1,991 )
Net cash provided by (used in) financing activities 25,402 ( 99,959 )
Foreign exchange gain (loss) on cash, cash equivalents and restricted cash and cash equivalents 5,897 ( 1,996 )
Net (decrease) increase in cash, cash equivalents and restricted cash and cash equivalents ( 1,948 ) 93,429
Cash and cash equivalents and restricted cash and cash equivalents,
beginning of period (Note 10)
133,358 31,404
Cash and cash equivalents and restricted cash and cash equivalents,
end of period (Note 10)
$ 131,410 $ 124,833
Supplemental cash flow disclosures (Note 10)

(See notes to the condensed consolidated financial statements)
5

Gran Tierra Energy Inc.
Condensed Consolidated Statements of Shareholders’ Equity (Unaudited)
(Thousands of U.S. Dollars)
Three Months Ended September 30, Nine Months Ended September 30,
2023 2022 2023 2022
Share Capital (1)
Balance, beginning of period $ 10,237 $ 10,272 $ 10,272 $ 10,270
Issuance of shares of Common Stock
(Note 5)
— — — 2
Re-purchase of shares of Common Stock (Note 5)
— — ( 35 ) —
Balance, end of period $ 10,237 $ 10,272 $ 10,237 $ 10,272
Additional Paid-in Capital
Balance, beginning of period $ 1,254,449 $ 1,290,075 $ 1,291,354 $ 1,287,582
Exercise of stock options 3 9 8 1,292
Re-purchase of shares of Common Stock (Note 5)
— — ( 38,107 ) —
Stock-based compensation (Note 5)
592 627 1,789 1,837
Balance, end of period $ 1,255,044 $ 1,290,711 $ 1,255,044 $ 1,290,711
Treasury Stock
Balance, beginning of period $ — $ — $ ( 27,317 ) $ —
Purchase of treasury shares (Note 5)
— ( 14,365 ) ( 10,825 ) ( 14,365 )
Cancellation of treasury shares (Note 5)
— — 38,142 —
Balance, end of period $ — $ ( 14,365 ) $ — $ ( 14,365 )
Deficit
Balance, beginning of period $ ( 877,268 ) $ ( 928,681 ) $ ( 856,743 ) $ ( 995,772 )
Net income (loss) 6,527 38,663 ( 13,998 ) 105,754
Balance, end of period $ ( 870,741 ) $ ( 890,018 ) $ ( 870,741 ) $ ( 890,018 )
Total Shareholders’ Equity $ 394,540 $ 396,600 $ 394,540 $ 396,600
(1) Reflects our 1-for-10 reverse stock split that became effective May 5, 2023. See Note 5 in the notes to the condensed consolidated financial statements for further discussion.

(See notes to the condensed consolidated financial statements)
6

Gran Tierra Energy Inc.
Notes to the Condensed Consolidated Financial Statements (Unaudited)
(Expressed in U.S. Dollars, unless otherwise indicated)
1. Description of Business
Gran Tierra Energy Inc. a Delaware corporation (the “Company” or “Gran Tierra”), is a publicly traded company focused on international oil and natural gas exploration and production with assets currently in Colombia and Ecuador.

2. Significant Accounting Policies
These interim unaudited condensed consolidated financial statements have been prepared in accordance with generally accepted accounting principles in the United States of America (“GAAP”). The information furnished herein reflects all normal recurring adjustments that are, in the opinion of management, necessary for the fair presentation of results for the interim periods.

The note disclosure requirements of annual audited consolidated financial statements provide additional disclosures required for interim unaudited condensed consolidated financial statements. Accordingly, these interim unaudited condensed consolidated financial statements should be read in conjunction with the Company’s consolidated financial statements as at and for the year ended December 31, 2022, included in the Company’s 2022 Annual Report on Form 10-K.

The Company’s significant accounting policies are described in Note 2 of the consolidated financial statements, which are included in the Company’s 2022 Annual Report on Form 10-K and are the same policies followed in these interim unaudited condensed consolidated financial statements. The Company has evaluated all subsequent events to the date these interim unaudited condensed consolidated financial statements were issued.

3. Property, Plant and Equipment

(Thousands of U.S. Dollars) As at September 30, 2023 As at December 31, 2022
Oil and natural gas properties
Proved $ 4,812,245 $ 4,617,804
Unproved 70,253 74,471
4,882,498 4,692,275
Other (1)
68,954 61,386
4,951,452 4,753,661
Accumulated depletion, depreciation and impairment ( 3,810,497 ) ( 3,652,759 )
$ 1,140,955 $ 1,100,902
(1) The “other” category includes right-of-use assets for operating and finance leases of $ 47.9 million, which had a net book value of $ 29.3 million as at September 30, 2023 (December 31, 2022 - $ 38.9 million, which had a net book value of $ 24.6 million).

On April 11, 2023, the Company and Ecopetrol S.A. renegotiated the terms of the contract for Company’s operatorship of the Suroriente Block ("Suroriente") which was previously scheduled to end in mid-2024. The duration of the contract was extended for 20 years from September 1, 2023 (the “Effective Date”), the date on which the Company satisfied the relevant conditions precedent and regulatory approval was received. The Company continues to be the operator of Suroriente. In connection with the contract extension, the Company paid cash consideration of $ 6.2 million and provided letters of credit of $ 123.0 million (Note 8) related to committed capital investments to be made over a three-year period from the Effective Date.

For the three and nine months ended September 30, 2023 and 2022, respectively, the Company had no ceiling test impairment losses. The Company used a 12-month unweighted average of the first-day-of the month Brent price prior to the ending date of the periods September 30, 2023, and 2022 of $ 83.86 and $ 94.85 per bbl, respectively, for the purpose of the ceiling test calculations.


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4. Debt and Debt Issuance Costs

The Company’s debt as at September 30, 2023, and December 31, 2022, was as follows:
(Thousands of U.S. Dollars) As at September 30, 2023 As at December 31, 2022
Current
Credit facility $ 50,000 $ —
Unamortized debt issuance costs ( 933 ) —
$ 49,067 $ —
Long-Term
6.25 % Senior Notes, due February 2025 (“ 6.25 % Senior Notes”)
$ 271,909 $ 279,909
7.75 % Senior Notes, due May 2027 (“ 7.75 % Senior Notes”)
300,000 300,000
Unamortized debt issuance costs (1)
( 8,334 ) ( 10,992 )
563,575 568,917
Long-term lease obligation (2)
23,869 20,676
$ 587,444 $ 589,593
Total Debt $ 636,511 $ 589,593
(1) As at December 31, 2022 , the amount of deferred financing fees included $ 0.3 million related to the credit facility.
(2) The current portion of the lease obligation has been included in accounts payable and accrued liabilities on the Company’s balance sheet and totaled $ 10.0 million as at September 30, 2023 (December 31, 2022 - $ 4.8 million).

During the three months ended September 30, 2023, the Company, as guarantor, and Gran Tierra Energy Colombia GmbH and and Gran Tierra Operations Colombia GmbH, as borrowers, amended and restated their credit facility with a market leader in the global commodities industry. As part of the restatement, the initial commitment was adjusted from $ 100 million to $ 50 million (maintaining the potential option of up to additional $ 50 million, subject to approval by the lender). Additionally, the availability period for the draws under the amendment to the credit facility was extended until December 31, 2023. The credit facility continues to bear interest based on the secured overnight financing rate posted by the Federal Reserve Bank of New York plus a credit margin of 6.00 % and a credit-adjusted spread of 0.26 %. Undrawn amounts under the credit facility bear interest at 2.10 % per annum, based on the amount available. The credit facility is secured by the Company’s Colombian assets and economic rights and has final maturity date of August 15, 2024. During the three months ended September 30, 2023, the credit facility was drawn by $ 50 million.

Under the terms of the credit facility, the Company is required to maintain compliance with the following financial covenants:

i. Global Coverage Ratio of at least 150 %, calculated using the net present value of the consolidated future cash flows of the Company up to the final maturity date discounted at 10 % over the outstanding amount on the credit facility at each reporting period. The net present value of the consolidated future cash flows of the Company is required to be based on 80 % of the prevailing ICE Brent forward strip.

ii. Prepayment Life Coverage Ratio of at least 150 %, calculated using the estimated aggregate value of commodities to be delivered under the commercial contract from the commencement date to the final maturity date based on 80 % of the prevailing ICE Brent forward strip and adjusted for quality and transportation discounts over the outstanding amount on the credit facility including interest and all other costs payable to the lender.

iii. Liquidity ratio where the Company’s projected sources of cash exceed projected uses of cash by at least 1.15 times in each quarter period included in one year consolidated future cash flows. The future cash flows represent forecasted expected cash flows from operations, less anticipated capital expenditures, and certain other adjustments. The commodity pricing assumption used in this covenant is required to be 90 % of the prevailing ICE Brent forward strip for the projected future cash flows.

As of September 30, 2023, the Company was in compliance with all the above covenants.

Senior Notes

During the nine months ended September 30, 2023, the Company purchased in the open market $ 8.0 million of 6.25 % Senior Notes for cash consideration of $ 6.8 million. The purchase resulted in a $ 1.1 million gain, which included the write-off of
8

deferred financing fees of $ 0.1 million. The purchase gain was recorded in “other gain” in the Company’s condensed consolidated statements of operations. Subsequent to the quarter, the Company cancelled all previously purchased 6.25 % Senior Notes. No notes were purchased during the three months ended September 30, 2023.

Subsequent to the quarter, the Company completed exchange offers of $ 247.1 million of 6.25 % Senior Notes and $ 275.8 million of 7.75 % Senior Notes (together with 6.25 % Senior Notes, the “Senior Notes”) for $ 487.6 million newly issued 9.50 % Senior Secured Notes due 2029. The exchange consideration for $ 242.5 million of 6.25 % Senior Notes included early participation premium of $ 80 for each $1,000 aggregate principal amount with the remainder of $ 4.6 million exchanged at $1,000 and for $ 274.2 million of 7.75 % Senior Notes early participation premium of $ 20 for each $1,000 aggregate principal amount with remainder of $ 1.6 million of 7.75 % Senior Notes exchanged at $950 for each $1,000 aggregate principal amount. In addition, the Company paid cash consideration of $ 60.0 million for 6.25 % Senior Notes exchanged as part of total consideration to eligible holders on a pro rata basis, for each $1,000 aggregate principal amount tendered and accepted for the early exchange deadline. The settlement date of the exchange offer was on October 20, 2023. The Senior Notes tendered and accepted for exchange, as well as the notes held as treasury bonds, were cancelled.

Interest Expense

The following table presents the total interest expense recognized in the accompanying interim unaudited condensed consolidated statements of operations:
Three Months Ended September 30, Nine Months Ended September 30,
(Thousands of U.S. Dollars) 2023 2022 2023 2022
Contractual interest and other financing expenses $ 11,909 $ 10,670 $ 34,623 $ 32,974
Amortization of debt issuance costs 1,594 751 3,394 2,769
$ 13,503 $ 11,421 $ 38,017 $ 35,743

5. Share Capital
Shares of Common Stock
Shares issued at December 31, 2022
36,889,862
Shares re-purchased ( 2,274,746 )
Shares outstanding at December 31, 2022
34,615,116
Shares issued on option exercise 1,839
Shares re-purchased ( 1,328,650 )
Shares issued and outstanding at September 30, 2023
33,288,305
On May 5, 2023, the Company completed a 1-for-10 reverse stock split of the Company’s common stock. As a result of the reverse stock split, every ten of the Company’s issued shares of Common Stock were automatically combined into one issued share of Common Stock, without any change to the par value per share. All share and per share numbers have been adjusted to reflect the reverse stock split. The Company’s outstanding options were also proportionately adjusted as a result of the reverse stock split to increase the exercise price and reduce the number of shares issuable upon exercise.
During the year ended December 31, 2022, the Company implemented a share re-purchase program (the “2022 Program”) through the facilities of the Toronto Stock Exchange (“TSX”) and eligible alternative trading platforms in Canada. Under the 2022 Program, the Company was able to purchase at prevailing market prices up to 3,603,396 shares of Common Stock, representing approximately 10 % of the issued and outstanding shares of Common Stock as of August 22, 2022.

During the three and nine months ended September 30, 2023, the Company re-purchased nil and 1,328,650 shares at a weighted average price of nil and $ 8.15 per share, respectively (three and nine months ended September 30, 2022 - 1,073,370 shares). As of September 30, 2023, all 3,603,396 shares held as treasury stock were canceled. The 2022 Program expired in May 2023 when 10 % share maximum was reached.

Equity Compensation Awards

The following table provides information about p erformance stock units (“PSUs”), deferred share units (“DSUs”), and stock option activity for the nine months ended September 30, 2023:
9

PSUs DSUs Stock Options
Number of Outstanding Share Units Number of Outstanding Share Units Number of Outstanding Stock Options Weighted Average Exercise Price/Stock Option ($)
Balance, December 31, 2022 3,152,823 656,186 1,730,286 11.52
Granted 1,504,546 89,643 409,435 8.58
Exercised ( 1,523,408 ) — ( 1,839 ) 4.17
Forfeited ( 21,574 ) — ( 22,336 ) 5.79
Expired — — ( 133,880 ) 25.15
Balance, September 30, 2023 3,112,387 745,829 1,981,666 10.06

For the three and nine months ended September 30, 2023, there was $ 1.9 million and $ 3.7 million of stock-based compensation expense, respectively. For the three and nine months ended September 30, 2022, there was $ 0.2 million of stock-based compensation recovery and $ 6.4 million of stock-based compensation expense, respectively.

As a t September 30, 2023, there was $ 11.4 million (December 31, 2022 - $ 10.5 million) of unrecognized compensation costs related to unvested PSUs and stock options, which are expected to be recognized over a weighted-average period of 1.8 years. During the nine months ended September 30, 2023, the Company paid out $ 15.1 million for PSUs vested on December 31, 2022 (nine months ended September 30, 2022 - $ 2.4 million for PSUs vested on December 31, 2021).

Net Income (Loss) per Share

Basic net income or loss per share is calculated by dividing net income or loss attributable to common shareholders by the weighted average number of shares of Common Stock issued and outstanding during each period.

Diluted net income or loss per share is calculated using the treasury stock method for share-based compensation arrangements. The treasury stock method assumes that any proceeds obtained on the exercise of share-based compensation arrangements would be used to purchase shares of Common Stock at the average market price during the period. The weighted average number of shares is then adjusted by the difference between the number of shares issued from the exercise of share-based compensation arrangements and shares re-purchased from the related proceeds. Anti-dilutive shares represent potentially dilutive securities excluded from the computation of diluted income or loss per share as their impact would be anti-dilutive.

Weighted Average Shares Outstanding

Three Months Ended September 30, Nine Months Ended September 30,
2023 2022 2023 2022
Weighted average number of shares of Common Stock outstanding
33,287,368 36,730,543 33,675,160 36,775,419
Shares issuable pursuant to stock options 129,299 1,133,014 — 1,202,431
Shares assumed to be purchased from proceeds of stock options ( 66,617 ) ( 732,483 ) — ( 739,060 )
Weighted average number of diluted shares of Common Stock outstanding
33,350,050 37,131,074 33,675,160 37,238,790

For the three and nine months ended September 30, 2023, 1,854,307 of options and all options, respectively, on a weighted average basis (three and nine months ended September 30, 2022, 616,167 and 586,388 options, respectively), were excluded from the diluted income (loss) per share calculation as the options were anti-dilutive.

6. Revenue

The Company’s revenues are generated from oil sales at prices that reflect the blended prices received upon shipment by the purchaser at defined sales points or defined by contract relative to ICE Brent and adjusted for Vasconia or Castilla (Colombia sales) or Oriente (Ecuador sales) crude differentials, quality and transportation discounts and premiums each month. For the three and nine months ended September 30, 2023, 100 % of the Company’s revenue resulted from oil sales (three and nine months ended September 30, 2022 - 100 %). During the three and nine months ended September 30, 2023, quality and
10

transportation discounts were 14 % and 18 % of the average ICE Brent price (three and nine months ended September 30, 2022 - 14 % and 13 %), respectively.

During the three months ended September 30, 2023, the Company’s production was sold primarily to one major customer in Colombia, representing 96 % of the total sales volumes (three months ended September 30, 2022 - one major customer, representing 99 % of the total sales volumes).

During the nine months ended September 30, 2023, the Company’s production was sold primarily to one major customer in Colombia, representing 97 % of the total sales volumes (nine months ended September 30, 2022 - two major customers, representing 71 % and 29 % of the total sales volumes).

As at September 30, 2023, accounts receivable included nil of accrued sales revenue related to September 2023 production (December 31, 2022 - nil related to December 2022 production).

7. Taxes

The Company’s effective tax rate was 115 % for the nine months ended September 30, 2023, compared to 49 % in the comparative period of 2022. The increase was primarily due to an increase in non-deductible foreign exchange adjustments and non-deductible third-party royalty in Colombia. These were partially offset by a decrease in valuation allowance.

Current income tax expense was $ 63.7 million for the nine months ended September 30, 2023, compared to $ 63.1 million in the corresponding period of 2022, primarily due to a decrease in taxable income in Colombia, which is subject to a higher Colombian tax rate.

The deferred income tax expense for the nine months ended September 30, 2023, was $ 43.2 million compared to $ 36.9 million in the corresponding period of 2022. In both cases, this can be primarily attributed to higher tax depreciation compared to accounting depreciation and the utilization of tax losses to offset taxable income in Colombia.

For the nine months ended September 30, 2022, the deferred income tax expense was mainly the result of tax depreciation being higher than accounting depreciation and the use of tax losses to offset taxable income in Colombia. The deferred income tax expense in the comparative period of 2021 was also the result of tax depreciation being higher compared to accounting depreciation and the use of tax losses to offset taxable income in Colombia.

For the nine months ended September 30, 2023, the difference between the effective tax rate of 115 % and the 50 % Colombian tax rate was primarily due to an increase in non-deductible foreign exchange adjustments, the impact of foreign taxes, non-deductible royalties in Colombia and non-deductible stock-based compensation. These were partially offset by a decrease in valuation allowance.

For the nine months ended September 30, 2022, the difference between the effective tax rate of 49 % and the 35 % Colombian tax rate was primarily due to an increase in the impact of foreign taxes, increase in the valuation allowance, non-deductible third-party royalties in Colombia, other permanent differences, and non-deductible stock-based compensation which were partially offset by a decrease in foreign currency translation.

8. Contingencies

Legal Proceedings

Gran Tierra has several lawsuits and claims pending. The outcome of the lawsuits and disputes cannot be predicted with certainty; Gran Tierra believes the resolution of these matters would not have a material adverse effect on the Company’s consolidated financial position, results of operations, or cash flows. Gran Tierra records costs as they are incurred or become probable and determinable.

Letters of credit and other credit support

At September 30, 2023, the Company had provided letters of credit and other credit support totaling $ 220.1 million (December 31, 2022 - $ 111.1 million) as security relating to work commitment guarantees in Colombia and Ecuador contained in exploration contracts, the Suroriente Block (Note 3), and other capital or operating requirements.

11


9. Financial Instruments and Fair Value Measurement

Financial Instruments

Financial instruments are initially recorded at fair value, defined as the price that would be received to sell an asset or paid to market participants to settle liability at the measurement date. For financial instruments carried at fair value, GAAP establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. This hierarchy consists of three broad levels:

• Level 1 - Inputs representing quoted market prices in active markets for identical assets and liabilities
• Level 2 - Inputs other than quoted prices included within Level 1 that are observable for the assets and liabilities, either directly or indirectly
• Level 3 - Unobservable inputs for assets and liabilities

At September 30, 2023, the Company’s financial instruments recognized on the balance sheet consist of cash and cash equivalents, restricted cash and cash equivalents, accounts receivable, other current assets, other long-term assets, accounts payable and accrued liabilities, credit facility, long-term debt and other long-term liabilities. The Company uses appropriate valuation techniques based on the available information to measure the fair values of assets and liabilities.

Fair Value Measurement

The following table presents the Company’s fair value measurements of its financial instruments as of September 30, 2023, and December 31, 2022:

(Thousands of U.S. Dollars) As at September 30, 2023 As at December 31, 2022
Level 1
Assets
Prepaid equity forward (“PEF”) - current (1)
$ 6,973 $ 5,981
PEF - long-term (2)
— 9,975
$ 6,973 $ 15,956
Liabilities
6.25 % Senior Notes
$ 255,594 $ 243,801
7.75 % Senior Notes
257,145 241,455
$ 512,739 $ 485,256
Level 2
Assets
Restricted cash and cash equivalents - long-term (2)
$ 7,052 $ 5,343
(1) The current portion of PEF is included in the other current assets on the Company’s condensed consolidated balance sheet
(2) The long-term portion of restricted cash and PEF is included in the other long-term assets on the Company’s condensed consolidated balance sheet

The fair values of cash and cash equivalents, current restricted cash and cash equivalents, accounts receivable, accounts payable and accrued liabilities and credit facility approximate their carrying amounts due to the short-term maturity of these instruments.

Restricted cash - long-term

The fair value of long-term restricted cash and cash equivalents approximated their carrying value because interest rates are variable and reflective of market rates.

12



Prepaid Equity Forward

To reduce the Company’s exposure to changes in the trading price of the Company’s shares of Common Stock on outstanding PSUs and DSUs, the Company entered into a PEF. At the end of the term, the counterparty will pay the Company an amount equivalent to the notional amount of the shares using the price of the Company’s shares of Common Stock at the valuation date. The Company has the discretion to increase or decrease the notional amount of the PEF or terminate the agreement early. As at September 30, 2023, the Company’s PEF had a notional amount of 1.0 million shares with a fair value of $ 7.0 million (As at December 31, 2022 - 1.6 million shares with a fair value of $ 16.0 million). During the three and nine months ended September 30, 2023, the Company recorded a $ 2.2 million gain and $ 3.6 million loss, respectively, on the PEF in general and administrative expenses (three and nine months ended September 30, 2022 - $ 2.6 million and $ 5.3 million gain, respectively). The fair value of the PEF asset was estimated using the Company’s share price quoted in active markets at the end of each reporting period.

Senior Notes

Financial instruments not recorded at fair value at September 30, 2023, were the Senior Notes (Note 4).

At September 30, 2023, the carrying amounts of the 6.25 % Senior Notes and the 7.75 % Senior Notes were $ 269.4 million and $ 294.2 million, respectively, which represented the aggregate principal amount less unamortized debt issuance costs, and the fair values were $ 255.6 million and $ 257.1 million, respectively.

During the three and nine months ended September 30, 2023, the Company did not have any derivative instruments and consequently did not incur any gains and losses related to derivative instruments (three and nine months ended September 30, 2022 - nil and $ 26.6 million loss related to commodity price derivatives, respectively.

10. Supplemental Cash Flow Information

The following table provides a reconciliation of cash and cash equivalents and restricted cash and cash equivalents shown as a sum of these amounts in the interim unaudited condensed consolidated statements of cash flows:
As at September 30, As at December 31,
(Thousands of U.S. Dollars) 2023 2022 2022 2021
Cash and cash equivalents $ 123,216 $ 118,173 $ 126,873 $ 26,109
Restricted cash and cash equivalents - current 1,142 1,142 1,142 392
Restricted cash and cash equivalents -
long-term (1)
7,052 5,518 5,343 4,903
$ 131,410 $ 124,833 $ 133,358 $ 31,404
(1) Included in other long-term assets on the Company’s condensed consolidated balance sheet

Net changes in assets and liabilities from operating activities were as follows:
Nine Months Ended September 30,
(Thousands of U.S. Dollars) 2023 2022
Accounts receivable and other long-term assets $ ( 8,484 ) $ 2,811
Derivatives — ( 2,757 )
PEF 9,664 ( 13,837 )
Prepaids & Inventory ( 6,809 ) ( 6,025 )
Accounts payable and accrued and other long-term liabilities ( 3,040 ) 37,862
Taxes receivable and payable ( 25,566 ) 54,784
Net changes in assets and liabilities from operating activities $ ( 34,235 ) $ 72,838

13

Changes in non-cash investing working capital for the nine months ended September 30, 2023, were comprised of a decrease in accounts payable and accrued liabilities of $ 11.0 million and an increase in accounts receivable of $ 0.1 million (nine months ended September 30, 2022, an increase in accounts payable and accrued liabilities of $ 3.7 million and an increase in accounts receivable of $ 0.4 million).

The following table provides additional supplemental cash flow disclosures:
Nine Months Ended September 30,
(Thousands of U.S. Dollars) 2023 2022
Cash paid for income taxes including withholding tax
$ 85,203 $ 29,881
Cash paid for interest $ 29,446 $ 31,455
Non-cash investing activities:
Net liabilities related to property, plant and equipment, end of period $ 44,067 $ 33,397
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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations
The following discussion of our financial condition and results of operations should be read in conjunction with the “Financial Statements” as set out in Part I, Item 1 of this Quarterly Report on Form 10-Q, as well as the “Financial Statements and Supplementary Data” and “Management’s Discussion and Analysis of Financial Condition and Results of Operations” included in Part II, Items 7 and 8, respectively, of our 2022 Annual Report on Form 10-K. Please see the cautionary language at the beginning of this Quarterly Report on Form 10-Q regarding the identification of and risks relating to forward-looking statements and the risk factors described in Part II, Item 1A “Risk Factors” of this Quarterly Report on Form 10-Q, as well as Part I, Item 1A “Risk Factors” in our 2022 Annual Report on Form 10-K. On May 5, 2023, the Company completed 1-for-10 reverse stock split of the Company’s Common Stock. As a result of the reverse stock split, every ten of the Company’s issued shares of Common Stock were automatically combined into one issued share of Common Stock. All share and per share data included in this quarterly report have been retroactively adjusted to reflect the reverse stock split.

Financial and Operational Highlights

Key Highlights for the third quarter of 2023
• Net income in the third quarter of 2023 was $6.5 million or $0.20 per share basic and diluted, compared to a net income of $38.7 million or $1.05 per share basic and $1.04 per share diluted in the third quarter of 2022
• Income before income taxes in the third quarter of 2023 was $46.9 million, compared to an income before income taxes of $60.4 million in the third quarter of 2022
• Adjusted EBITDA (2) increased to $119.2 million, compared to $116.1 million in the third quarter of 2022 and increased from $97.3 million in the prior quarter
• Funds flow from operations (2) decreased by 16% to $79.0 million, compared to the third quarter of 2022 and increased by 49% from $53.1 million in the prior quarter
• NAR production for the third quarter of 2023 increased by 14% to 26,776 BOPD, compared to 23,472 BOPD in the third quarter of 2022 and decreased by 2% from the prior quarter
• Sales volumes for the third quarter of 2023 increased by 12% to 26,396 BOPD , compared to 23,516 BOPD in the third quarter of 2022 and decreased by 3% from the prior quarter
• Oil sales for the third quarter of 2023 were $179.9 million, 7% higher compared to the third quarter of 2022, primarily due to lower quality and transportation discounts and utilization of marketing arrangements which used Brent monthly average of the month of delivery (“M pricing”) during the current quarter compared to utilization of Brent monthly average following the month of deliveries (“M+1” pricing) which negatively impacted revenues in the third quarter of 2022. Oil sales increased by 14% from $157.9 million in the second quarter of 2023 primarily due to an 11% increase in Brent prices and lower quality and transportation discounts, offset by 3% lower sales volumes
• Operating expenses increased by 18% to $49.4 million or by $0.99 per bbl to $20.33 per bbl when compared to the third quarter of 2022, primarily as a result of higher lifting costs offset by lower workover activities. Operating expenses increased from $48.5 million or $19.54 per bbl in the prior quarter, for the same reason mentioned above
• Transportation expenses per bbl increased by $0.46 when compared to the third quarter of 2022, due to higher transportation tariffs affecting Acordionero sales, utilization of new transportation routes for new exploration wells in Colombia and Ecuador and increased by $0.09 from the second quarter of 2023 due to higher trucking costs resulting from utilization longer distance delivery points and depreciation of U.S. dollar against the Colombian peso
• Operating netback (2) increased to $126.7 million compared to $124.1 million in the third quarter of 2022 and increased from $105.7 million in the prior quarter
• Quality and transportation discounts for the third quarter of 2023 decreased to $11.83 per bbl compared to $13.37 per bbl in the third quarter of 2022, primarily as a result of the tightening of the Castilla and Vasconia differentials and decreased from $14.10 per bbl in the prior quarter for the same reason mentioned above
• General and administrative (“G&A”) expenses before stock-based compensation were comparable to the third quarter of 2022 and decreased by 13% from the second quarter of 2023 due to lower legal fees and consulting costs attributed to optimization projects
• Capital additions for the third quarter of 2023 were $43.1 million, a decrease of 24% compared to the third quarter of 2022, and a decrease of 34% from the second quarter of 2023 due to the completion of the 2023 drilling program in the first half of 2023
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(Thousands of U.S. Dollars, unless otherwise indicated) Three Months Ended September 30, Three Months Ended June 30, Nine Months Ended September 30,
2023 2022 % Change 2023 2023 2022 % Change
Average Daily Volumes (BOPD)
Consolidated
Working Interest (“WI”) Production Before Royalties 33,940 30,391 12 33,719 33,098 30,123 10
Royalties (7,164) (6,919) 4 (6,515) (6,592) (6,948) (5)
Production NAR 26,776 23,472 14 27,204 26,506 23,175 14
(Increase) Decrease in Inventory (380) 44 (964) 67 (222) (141) (57)
Sales (1)
26,396 23,516 12 27,271 26,284 23,034 14
Net Income (Loss) $ 6,527 $ 38,663 (83) $ (10,825) $ (13,998) $ 105,754 (113)
Operating Netback
Oil Sales $ 179,921 $ 168,397 7 $ 157,902 $ 482,013 $ 548,751 (12)
Operating Expenses (49,367) (41,837) 18 (48,491) (139,227) (116,266) 20
Transportation Expenses (3,842) (2,417) 59 (3,691) (10,599) (7,764) 37
Operating Netback (2)
$ 126,712 $ 124,143 2 $ 105,720 $ 332,187 $ 424,721 (22)
G&A Expenses Before Stock-Based Compensation $ 8,307 $ 8,284 — $ 9,549 $ 29,052 $ 23,910 22
G&A Stock-Based Compensation Expense (Recovery) 1,931 (170) 1,236 317 3,748 6,376 (41)
G&A Expenses, Including Stock-Based Compensation $ 10,238 $ 8,114 26 $ 9,866 $ 32,800 $ 30,286 8
Adjusted EBITDA (2)
$ 119,235 $ 116,089 3 $ 97,291 $ 306,391 $ 375,075 (18)
Funds Flow From Operations (2)
$ 79,000 $ 93,746 (16) $ 53,106 $ 192,122 $ 284,681 (33)
Capital Expenditures $ 43,080 $ 57,035 (24) $ 65,565 $ 179,707 $ 163,717 10
(1) Sales volumes represent production NAR adjusted for inventory changes.

(2) Non-GAAP measures

Operating netback, EBITDA, adjusted EBITDA, and funds flow from operations are non-GAAP measures that do not have any standardized meaning prescribed under GAAP. Management views these measures as financial performance measures. Investors are cautioned that these measures should not be construed as alternatives to oil sales, net income (loss) or other measures of financial performance as determined in accordance with GAAP. Our method of calculating these measures may differ from other companies and, accordingly, may not be comparable to similar measures used by other companies. Disclosure of each non-GAAP financial measure is preceded by the corresponding GAAP measure so as not to imply that more emphasis should be placed on the non-GAAP measure.

Operating netback, as presented, is defined as oil sales less operating and transportation expenses. Management believes that operating netback is a useful supplemental measure for management and investors to analyze financial performance and provides an indication of the results generated by our principal business activities prior to the consideration of other income and expenses. A reconciliation from oil sales to operating netback is provided in the table above.

EBITDA, as presented, is defined as net income (loss) adjusted for depletion, depreciation and accretion (“DD&A”) expenses, interest expense and income tax expense. Adjusted EBITDA, as presented, is defined as EBITDA adjusted for non-cash lease expense, lease payments, foreign exchange gain or loss, stock-based compensation expense or recovery, unrealized derivative instruments gain and other gain. Management uses this supplemental measure to analyze performance and income generated by our principal business activities prior to the consideration of how non-cash items affect that income and believes that this
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financial measure is useful supplemental information for investors to analyze our performance and our financial results. A reconciliation from net income (loss) to EBITDA and adjusted EBITDA is as follows:

Three Months Ended September 30, Three Months Ended June 30, Nine Months Ended September 30,
(Thousands of U.S. Dollars) 2023 2022 2023 2023 2022
Net income (loss) $ 6,527 $ 38,663 $ (10,825) $ (13,998) $ 105,754
Adjustments to reconcile net income (loss) to EBITDA and Adjusted EBITDA
DD&A expenses 55,019 45,320 56,209 162,949 128,499
Interest expense 13,503 11,421 12,678 38,017 35,743
Income tax expense 40,333 21,734 33,732 106,948 99,940
EBITDA (non-GAAP) $ 115,382 $ 117,138 $ 91,794 $ 293,916 $ 369,936
Non-cash lease expense 1,235 851 1,109 3,488 2,009
Lease payments (676) (402) (636) (1,918) (1,134)
Foreign exchange loss
1,717 1,489 4,707 8,126 486
Stock-based compensation expense (recovery) 1,931 (170) 317 3,748 6,376
Unrealized derivative instruments gain — (219) — — —
Other gain (354) (2,598) — (969) (2,598)
Adjusted EBITDA (non-GAAP) $ 119,235 $ 116,089 $ 97,291 $ 306,391 $ 375,075

Funds flow from operations, as presented, is defined as net income (loss) adjusted for DD&A expenses, deferred income tax expense, stock-based compensation expense or recovery, amortization of debt issuance costs, non-cash lease expense, lease payments, unrealized foreign exchange gain or loss, unrealized derivative instruments gain and other gain. Management uses this financial measure to analyze performance and income generated by our principal business activities prior to the consideration of how non-cash items affect that income and believes that this financial measure is also useful supplemental information for investors to analyze performance and our financial results. A reconciliation from net income (loss) to funds flow from operations is as follows:
Three Months Ended September 30, Three Months Ended June 30, Nine Months Ended September 30,
(Thousands of U.S. Dollars) 2023 2022 2023 2023 2022
Net income (loss) $ 6,527 $ 38,663 $ (10,825) $ (13,998) $ 105,754
Adjustments to reconcile net income (loss) to funds flow from operations
DD&A expenses 55,019 45,320 56,209 162,949 128,499
Deferred income tax expense 13,990 4,914 13,975 43,242 36,868
Stock-based compensation expense (recovery) 1,931 (170) 317 3,748 6,376
Amortization of debt issuance costs 1,594 751 1,019 3,394 2,769
Non-cash lease expense 1,235 851 1,109 3,488 2,009
Lease payments (676) (402) (636) (1,918) (1,134)
Unrealized foreign exchange (gain) loss (266) 6,636 (8,062) (7,814) 6,138
Unrealized derivative instruments gain — (219) — — —
Other gain (354) (2,598) — (969) (2,598)
Funds flow from operations (non-GAAP) $ 79,000 $ 93,746 $ 53,106 $ 192,122 $ 284,681










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Additional Operational Results

Three Months Ended September 30, Three Months Ended June 30, Nine Months Ended September 30,
(Thousands of U.S. Dollars) 2023 2022 % Change 2023 2023 2022 % Change
Oil sales $ 179,921 $ 168,397 7 $ 157,902 $ 482,013 $ 548,751 (12)
Operating expenses 49,367 41,837 18 48,491 139,227 116,266 20
Transportation expenses 3,842 2,417 59 3,691 10,599 7,764 37
Operating netback (1)
126,712 124,143 2 105,720 332,187 424,721 (22)
DD&A expenses 55,019 45,320 21 56,209 162,949 128,499 27
G&A expenses before stock-based compensation 8,307 8,284 — 9,549 29,052 23,910 22
G&A stock-based compensation expense (recovery) 1,931 (170) 1,236 317 3,748 6,376 (41)
Foreign exchange loss 1,717 1,489 15 4,707 8,126 486 1,572
Derivative instruments loss — — — — — 26,611 (100)
Other gain (354) (2,598) (86) — (969) (2,598) (63)
Interest expense 13,503 11,421 18 12,678 38,017 35,743 6
80,123 63,746 26 83,460 240,923 219,027 10
Interest income 271 — 100 647 1,686 — 100
Income before income taxes 46,860 60,397 (22) 22,907 92,950 205,694 (55)
Current income tax expense 26,343 16,820 57 19,757 63,706 63,072 1
Deferred income tax expense 13,990 4,914 185 13,975 43,242 36,868 17
40,333 21,734 86 33,732 106,948 99,940 7
Net income (loss) $ 6,527 $ 38,663 (83) $ (10,825) $ (13,998) $ 105,754 (113)
Sales Volumes (NAR)
Total sales volumes, BOPD 26,396 23,516 12 27,271 26,284 23,034 14
Brent Price per bbl $ 85.92 $ 97.70 (12) $ 77.73 $ 81.94 $ 102.48 (20)
Consolidated Results of Operations per bbl Sales Volumes NAR
Oil sales $ 74.09 $ 77.84 (5) $ 63.63 $ 67.18 $ 87.27 (23)
Operating expenses 20.33 19.34 5 19.54 19.40 18.49 5
Transportation expenses 1.58 1.12 41 1.49 1.48 1.23 20
Operating netback (1)
52.18 57.38 (9) 42.60 46.30 67.55 (31)
DD&A expenses 22.66 20.95 8 22.65 22.71 20.43 11
G&A expenses before stock-based compensation 3.42 3.83 (11) 3.85 4.05 3.80 7
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G&A stock-based compensation expense (recovery) 0.80 (0.08) 1,100 0.13 0.52 1.01 (49)
Foreign exchange loss 0.71 0.69 3 1.90 1.13 0.08 1,313
Derivative instruments loss — — — — — 4.23 (100)
Other gain (0.15) (1.20) (88) — (0.14) (0.41) (66)
Interest expense 5.56 5.28 5 5.11 5.30 5.68 (7)
33.00 29.47 12 33.64 33.57 34.82 (4)
Interest income 0.11 — 100 0.26 0.23 — 100
Income before income taxes 19.29 27.91 (31) 9.22 12.96 32.73 (60)
Current income tax expense 10.85 7.77 40 7.96 8.88 10.03 (11)
Deferred income tax expense 5.76 2.27 154 5.63 6.03 5.86 3
16.61 10.04 65 13.59 14.91 15.89 (6)
Net income (loss) $ 2.68 $ 17.87 (85) $ (4.37) $ (1.95) $ 16.84 (112)
(1) Operating netback is a non-GAAP measure that does not have any standardized meaning prescribed under GAAP. Refer to “Financial and Operational Highlights—non-GAAP measures” for a definition of this measure.

Oil Production and Sales Volumes, BOPD
Three Months Ended September 30, Three Months Ended June 30, Nine Months Ended September 30,
2023 2022 2023 2023 2022
Average Daily Volumes (BOPD)
WI Production Before Royalties 33,940 30,391 33,719 33,098 30,123
Royalties (7,164) (6,919) (6,515) (6,592) (6,948)
Production NAR 26,776 23,472 27,204 26,506 23,175
(Increase) Decrease in Inventory (380) 44 67 (222) (141)
Sales 26,396 23,516 27,271 26,284 23,034
Royalties, % of WI Production Before Royalties 21 % 23 % 19 % 20 % 23 %

Oil production NAR for the three and nine months ended September 30, 2023, increased by 14% in each of the periods compared to the corresponding periods of 2022 due to successful drilling and workover campaigns in Acordionero, Costayaco and Moqueta fields in Colombia and exploration success in Ecuador.

Oil production NAR decreased by 2% compared to the prior quarter due to higher royalties driven by an increase in benchmark oil prices in the current quarter.

Royalties as a percentage of WI production for the three and nine months ended September 30, 2023, decreased to 21% and 20%, respectively, compared to the corresponding periods of 2022 commensurate with the decrease in benchmark oil prices and the price sensitive royalty regime in Colombia. Royalties as a percentage of WI production increased compared to 19% in the prior quarter due to the increase in benchmark oil prices.
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629
631
The Midas block includes the Acordionero, Chuira, Ayombero and Gaitas oil fields, and the Chaza block includes the Costayaco and Moqueta oil fields.

Realized price per bbl for the three months ended September 30, 2023 decreased by 5%, compared to the corresponding period of 2022, primarily as a result of a 12% decrease in Brent price, offset by lower differentials in the current quarter.

Realized price per bbl for the nine months ended September 30, 2023, decreased by 23%, compared to the corresponding period of 2022, primarily as a result of 20% decrease in Brent price and higher differentials in the current period.

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For the three and nine months ended September 30, 2023, Castilla differentials decreased to $6.64 and increased to $10.41 per bbl from $9.15 and $7.89 per bbl, respectively, in the corresponding periods of 2022. Vasconia differentials decreased to $3.59 and increased to $5.66 per bbl from $3.77 and $4.17 per bbl, respectively, in the corresponding periods of 2022.

Compared to the prior quarter, the average realized price per bbl increased due to an 11% increase in Brent price and lower differentials.
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Oil sales for the three months ended September 30, 2023, increased by 7% to $179.9 million, compared to the corresponding period of 2022 due to lower Castilla and Vasconia differentials and utilization of marketing arrangements which used Brent monthly average of the month of delivery (“M pricing”) during the current quarter compared to marketing arrangements which used Brent monthly average following the month of deliveries (“M+1” pricing) which negatively impacted revenues in the corresponding period of 2022.

Oil sales for the nine months ended September 30, 2023, decreased by 12% to $482.0 million, compared to the corresponding period of 2022 due to a 20% decrease in Brent price, higher Castilla and Vasconia differentials offset by 14% higher sales volumes.

Compared to the prior quarter, oil sales increased by 14%, primarily as a result of an 11% increase in Brent price and lower Castilla, Vasconia and Oriente differentials partially offset by a 3% decrease in sales volumes.

The following table shows the effect of changes in realized price and sale volumes on our oil sales for the three and nine months ended September 30, 2023, compared to the prior quarter and the corresponding periods of 2022:
(Thousands of U.S. Dollars) Third Quarter 2023 Compared with Second Quarter 2023 Third Quarter 2023 Compared with Third Quarter 2022 Nine Months Ended September 30, 2023 Compared with Nine Months Ended September 30, 2022
Oil sales for the comparative period $ 157,902 $ 168,397 $ 548,751
Realized sales price increase (decrease) effect 25,408 (9,095) (144,152)
Sales volumes (decrease) increase effect (3,389) 20,619 77,414
Oil sales for the three and nine months ended
September 30, 2023
$ 179,921 $ 179,921 $ 482,013
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Operating Netback
Three Months Ended September 30, Three Months Ended June 30, Nine Months Ended September 30,
(Thousands of U.S. Dollars) 2023 2022 2023 2023 2022
Oil Sales $ 179,921 $ 168,397 $ 157,902 $ 482,013 $ 548,751
Transportation Expenses (3,842) (2,417) (3,691) (10,599) (7,764)
176,079 165,980 154,211 471,414 540,987
Operating Expenses (49,367) (41,837) (48,491) (139,227) (116,266)
Operating Netback (1)
$ 126,712 $ 124,143 $ 105,720 $ 332,187 $ 424,721
(U.S. Dollars Per bbl Sales Volumes NAR)
Brent $ 85.92 $ 97.70 $ 77.73 $ 81.94 $ 102.48
One Month Forward Brent (“M+1”) Adjustment — (6.49) — — (2.23)
Quality and Transportation Discounts (11.83) (13.37) (14.10) (14.76) (12.98)
Average Realized Price 74.09 77.84 63.63 67.18 87.27
Transportation Expenses (1.58) (1.12) (1.49) (1.48) (1.23)
Average Realized Price Net of Transportation Expenses 72.51 76.72 62.14 65.70 86.04
Operating Expenses (20.33) (19.34) (19.54) (19.40) (18.49)
Operating Netback (1)
$ 52.18 $ 57.38 $ 42.60 $ 46.30 $ 67.55
(1) Operating netback is a non-GAAP measure that does not have any standardized meaning prescribed under GAAP. Refer to “Financial and Operational Highlights—non-GAAP measures” for a definition and reconciliation of this measure.

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239
241
Operating expense s for the three months ended September 30, 2023, increased by 18% to $49.4 million or by $0.99 per bbl to $20.33 per bbl, compared to the corresponding period of 2022, primarily as a result of $3.28 per bbl higher lifting costs associated with road and pipeline maintenance, power generation due to to increased compressed natural gas purchases and higher diesel tariffs and equipment rental associated with testing exploratory wells, offset by $2.29 per bbl of lower workovers. As a result of an El-Niño-induced drought, power costs have increased across Colombia, which relies on hydroelectricity for more than two-thirds of its installed power capacity. In addition, operating costs increased as a result of the depreciation of U.S. dollar against the Colombian peso.

Operating expenses for the nine months ended September 30, 2023, increased by 20% to $139.2 million or by $0.91 per bbl to $19.40 per bbl, compared to the corresponding period of 2022, primarily as a result of $2.17 higher lifting costs associated with environmental activities, equipment rental, power generation and road maintenance, offset by $1.26 per bbl lower workovers.
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Compared to the prior quarter, operating expenses increased by 2% or $0.79 per bbl from $48.5 million or $19.54 per bbl, primarily due to $1.48 per bbl higher lifting costs attributed to road maintenance and power generation, partially offset by $0.69 per bbl lower workovers.

Transportation expenses

We have options to sell our oil through multiple pipelines and trucking routes. Each option has varying effects on realized sales price and transportation expenses. The following table shows the percentage of oil volumes we sold in Colombia and Ecuador using each option for the three and nine months ended September 30, 2023, and 2022, and the prior quarter:

Three Months Ended September 30, Three Months Ended June 30, Nine Months Ended September 30,
2023 2022 2023 2023 2022
Volume transported through pipeline 3 % — % 1 % 2 % — %
Volume sold at wellhead 47 % 47 % 46 % 46 % 47 %
Volume transported via truck to sales point 50 % 53 % 53 % 52 % 53 %
100 % 100 % 100 % 100 % 100 %

Volumes transported through pipeline or via truck receive a higher realized price, but incur higher transportation expenses. Conversely, volumes sold at the wellhead have the opposite effect of a lower realized price, offset by lower transportation expenses.

Transportation expenses for the three and nine months ended September 30, 2023, increased by 59% and 37% to $3.8 million and $10.6 million, respectively, compared to the corresponding periods of 2022 due to higher transportation tariffs affecting Acordionero sales, and the utilization of new transportation routes related to sales from new exploration wells in Colombia and Ecuador.

On a per bbl basis, transportation expenses increased by 41% and 20% to $1.58 and $1.48 for the three and nine months ended September 30, 2023, respectively, compared to the corresponding periods of 2022 for the same reason mentioned above.

Transportation expenses increased by 4% from $3.7 million in the prior quarter due to higher trucking costs resulting from using longer distance delivery points and depreciation of the U.S. dollar against the Colombian peso. On a per bbl basis, transportation expenses increased by $0.09 from $1.49 in the prior quarter for the same reasons mentioned above.
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319
DD&A Expenses
Three Months Ended September 30, Three Months Ended June 30, Nine Months Ended September 30,
2023 2022 2023 2023 2022
DD&A Expenses, thousands of U.S. Dollars $ 55,019 $ 45,320 $ 56,209 $ 162,949 $ 128,499
DD&A Expenses, U.S. Dollars per bbl 22.66 20.95 22.65 22.71 20.43

DD&A expenses for the three and nine months ended September 30, 2023, increased by 21% and 27% or by $1.71 and $2.28 per bbl, respectively, due to increased production and higher costs in the depletable base compared to the corresponding periods of 2022.

DD&A expenses decreased by 2% compared to the prior quarter and increased by $0.01 per bbl when compared to the prior quarter, due to additions to the depletable reserves along with lower production.

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G&A Expenses
Three Months Ended September 30, Three Months Ended June 30, Nine Months Ended September 30,
(Thousands of U.S. Dollars) 2023 2022 % Change 2023 2023 2022 % Change
G&A Expenses Before Stock-Based Compensation $ 8,307 $ 8,284 — $ 9,549 $ 29,052 $ 23,910 22
G&A Stock-Based Compensation Expense (Recovery) 1,931 (170) 1,236 317 3,748 6,376 (41)
G&A Expenses, Including Stock-Based Compensation $ 10,238 $ 8,114 26 $ 9,866 $ 32,800 $ 30,286 8
(U.S. Dollars Per bbl Sales Volumes NAR)
G&A Expenses Before Stock-Based Compensation $ 3.42 $ 3.83 (11) $ 3.85 $ 4.05 $ 3.80 7
G&A Stock-Based Compensation Expense (Recovery) 0.80 (0.08) 1,100 0.13 0.52 1.01 (49)
G&A Expenses, Including Stock-Based Compensation $ 4.22 $ 3.75 13 $ 3.98 $ 4.57 $ 4.81 (5)

G&A expenses before stock-based compensation for the three months ended September 30, 2023, were comparable to the corresponding period of 2022. On a per bbl basis, G&A expenses before stock-based compensation decreased by $0.41 per bbl to $3.42 due to higher sales volumes in the current quarter.

G&A expenses before stock-based compensation for the nine months ended September 30, 2023, increased by 22% to $29.1 million, due to higher consulting costs and legal fees attributed to optimization projects when compared to the corresponding period of 2022. On a per bbl basis, G&A expenses before stock-based compensation increased by $0.25 per bbl to $4.05 per bbl, for the same reason mentioned above and higher sales volumes during current period.

G&A expenses after stock-based compensation for the three months ended September 30, 2023, increased 26% compared to the corresponding period of 2022 and increased by $0.47 per bbl due to share price appreciation in the current quarter.

G&A expenses after stock-based compensation for the nine months ended September 30, 2023, increased by 8% due to higher G&A expenses before stock-based compensation offset by share price devaluation and decreased by $0.24 per bbl due to higher sales volumes when compared to the corresponding period of 2022.

Compared to the prior quarter, G&A expenses before stock-based compensation decreased by 13% or $0.43 on a per bbl basis due to lower legal fees and consulting costs attributed to optimization projects.

Compared to the prior quarter, G&A expenses after stock-based compensation increased by 4% or $0.24 on a per bbl basis due to share price appreciation in the third quarter of 2023.
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1341
Foreign Exchange Gains and Losses

For the three and nine months ended September 30, 2023, we had a $1.7 million and $8.1 million loss on foreign exchange, compared to a $1.5 million and $0.5 million loss in the corresponding periods of 2022, respectively, and a $4.7 million loss in the prior quarter. Accounts receivable, taxes receivable and payable, deferred income taxes, accounts payable, and prepaid equity forward (“PEF”) are considered monetary items and require translation from local currencies to U.S. dollar functional currency at each balance sheet date. This translation was the primary source of the foreign exchange losses in the periods.

The following table presents the change in the U.S. dollar against the Colombian peso and Canadian dollar for the three and nine months ended September 30, 2023, and 2022:

Three Months Ended September 30, Nine Months Ended September 30,
2023 2022 2023 2022
Change in the U.S. dollar against the Colombian peso weakened by strengthened by weakened by strengthened by
3% 10% 16% 14%
Change in the U.S. dollar against the Canadian dollar strengthened by strengthened by weakened by strengthened by
2% 6% —% 8%

Income Tax Expense
Three Months Ended September 30, Nine Months Ended September 30,
(Thousands of U.S. Dollars) 2023 2022 2023 2022
Income before income tax $ 46,860 $ 60,397 $ 92,950 $ 205,694
Current income tax expense $ 26,343 $ 16,820 $ 63,706 $ 63,072
Deferred income tax expense 13,990 4,914 43,242 36,868
Income tax expense $ 40,333 $ 21,734 $ 106,948 $ 99,940
Effective tax rate 86 % 36 % 115 % 49 %

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Current income tax expense was $63.7 million for the nine months ended September 30, 2023, compared to $63.1 million in the corresponding period of 2022, primarily due to a decrease in taxable income in Colombia, which is subject to a higher Colombian tax rate.

The deferred income tax expense for the nine months ended September 30, 2023, was $43.2 million primarily as a result of tax depreciation being higher than accounting depreciation and the use of tax losses to offset taxable income in Colombia.

For the nine months ended September 30, 2023, the difference between the effective tax rate of 115% and the 50% Colombian tax rate was primarily due to an increase in non-deductible foreign exchange adjustments, the impact of foreign taxes, non-deductible royalties in Colombia and non-deductible stock-based compensation. These were partially offset by a decrease in valuation allowance.

For the nine months ended September 30, 2022, the difference between the effective tax rate of 49% and the 35% Colombian tax rate was primarily due to $26.6 million of hedging loss, $35.7 million of financing cost related to Senior Notes, and $21.5 million of corporate costs, which were incurred in jurisdictions where no tax benefit is recognized which was partially offset by $12.5 million of non-taxable foreign exchange gain.












































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Net Income (Loss) and Funds Flow from Operations (a Non-GAAP Measure)
(Thousands of U.S. Dollars) Third Quarter 2023 Compared with Second Quarter 2023 % change Third Quarter 2023 Compared with Third Quarter 2022 % change Nine Months Ended September 30, 2023 Compared with Nine Months Ended September 30, 2022 % change
Net (loss) income for the comparative period $ (10,825) $ 38,663 $ 105,754
Increase (decrease) due to:
Sales price 25,408 (9,095) (144,152)
Sales volumes (3,389) 20,619 77,414
Expenses:
Operating (876) (7,530) (22,961)
Transportation (151) (1,425) (2,835)
Cash G&A 1,242 (23) (5,142)
Net lease payments 86 110 695
Interest, net of amortization of debt issuance costs (250) (1,239) (1,649)
Realized foreign exchange 10,786 (7,130) (21,592)
Cash settlements on derivative instruments — 219 26,611
Current taxes (6,586) (9,523) (634)
Interest income (376) 271 1,686
Net change in funds flow from operations (1) from comparative period
25,894 (14,746) (92,559)
Expenses:
Depletion, depreciation and accretion 1,190 (9,699) (34,450)
Deferred tax (15) (9,076) (6,374)
Proceeds from debt, net of issuance costs (575) (843) (625)
Stock-based compensation (1,614) (2,101) 2,628
Derivative instruments gain or loss, net of settlements on derivative instruments — (219) —
Unrealized foreign exchange (7,796) 6,902 13,952
Other gain 354 (2,244) (1,629)
Net lease payments (86) (110) (695)
Net change in net (loss) income 17,352 (32,136) (119,752)
Net income (loss) for the current period $ 6,527 160% $ 6,527 (83)% $ (13,998) (113)%
(1) Funds flow from operations is a non-GAAP measure that does not have any standardized meaning prescribed under GAAP. Refer to "Financial and Operational Highlights—non-GAAP measures" for a definition and reconciliation of this measure.
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Capital expenditures during the three months ended September 30, 2023, were $43.1 million:

(Millions of U.S. Dollars) Colombia Ecuador Total
Exploration $ 4.0 $ 2.9 $ 6.9
Development:
Drilling and Completions 9.3 — 9.3
Facilities 5.2 0.6 5.8
Workovers 4.8 — 4.8
Other 14.0 2.3 16.3
$ 37.3 $ 5.8 $ 43.1

During the three months ended September 30, 2023, we did not spud any wells neither in Colombia nor in Ecuador.

On April 11, 2023, we and Ecopetrol S.A. renegotiated the terms of the contract for our operatorship of the Suroriente which was previously scheduled to end in mid-2024. The duration of the contract was extended for 20 years from September 1, 2023 (the “Effective Date”), the date on which we satisfied the relevant conditions precedent and regulatory approval was received. We continue to be the operator of Suroriente. In connection with the contract extension, we paid cash consideration of $6.2 million and provided letters of credit of $123.0 million (see Note 8 in the Notes to Condensed Consolidated Financial Statements (Unaudited) in Part I, Item 1 of this Quarterly Report on Form 10-Q which incorporated herein by reference) related to committed capital investments to be made over a three-year period from the Effective Date.

Liquidity and Capital Resources
As at
(Thousands of U.S. Dollars) September 30, 2023 % Change December 31, 2022
Cash and Cash Equivalents $ 123,216 (3) $ 126,873
Credit Facility $ 50,000 100 $ —
6.25% Senior Notes $ 271,909 (3) $ 279,909
7.75% Senior Notes $ 300,000 — $ 300,000

We believe that our capital resources, including cash on hand, cash generated from operations, will provide us with sufficient liquidity to meet our strategic objectives and planned capital program for the next 12 months, given the current oil price trends and production levels. We may also access capital markets to pursue financing. In accordance with our investment policy, available cash balances are held in our primary cash management banks or may be invested in U.S. or Canadian government-backed federal, provincial or state securities or other money market instruments with high credit ratings and short-term liquidity. We believe that our current financial position provides us with the flexibility to respond to both internal growth opportunities and those available through acquisitions. We intend to pursue growth opportunities and acquisitions from time to time, which may require significant capital, be located in basins or countries beyond our current operations, involve joint ventures, or be sizable compared to our current assets and operations.

During the three months ended September 30, 2023, we, as guarantor, and Gran Tierra Energy Colombia GmbH and and Gran Tierra Operations Colombia GmbH, as borrowers, amended and restated their credit facility with a market leader in the global commodities industry. As part of the restatement, the initial commitment was adjusted from $100 million to $50 million (maintaining the potential option of up to additional $50 million, subject to approval by the lender). Additionally, the availability period for the draws under the amendment to the credit facility was extended until December 31, 2023. The credit facility continues to bear interest based on the secured overnight financing rate posted by the Federal Reserve Bank of New York plus a credit margin of 6.00% and a credit-adjusted spread of 0.26%. Undrawn amounts under the credit facility bear interest at 2.10% per annum, based on the amount available. The credit facility is secured by our Colombian assets and economic rights and has final maturity date of August 15, 2024. During the three months ended September 30, 2023, the credit facility was drawn by $50 million.

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Under the terms of the credit facility, we are required to maintain compliance with the following financial covenants:

i. Global Coverage Ratio of at least 150%, calculated using the net present value of the consolidated future cash flows of the Company up to the final maturity date discounted at 10% over the outstanding amount on the credit facility at each reporting period. The net present value of the consolidated future cash flows of the Company is required to be based on 80% of the prevailing ICE Brent forward strip.

ii. Prepayment Life Coverage Ratio of at least 150%, calculated using the estimated aggregate value of commodities to be delivered under the commercial contract from the commencement date to the final maturity date based on 80% of the prevailing ICE Brent forward strip and adjusted for quality and transportation discounts over the outstanding amount on the credit facility including interest and all other costs payable to the lender.

iii. Liquidity ratio where the Company’s projected sources of cash exceed projected uses of cash by at least 1.15 times in each quarter period included in one year consolidated future cash flows. The future cash flows represent forecasted expected cash flows from operations, less anticipated capital expenditures, and certain other adjustments. The commodity pricing assumption used in this covenant is required to be 90% of the prevailing ICE Brent forward strip for the projected future cash flows.

As of September 30, 2023, the Company was in compliance with all the above covenants.

At September 30, 2023, we had a $271.9 million aggregate principal amount of 6.25% Senior Notes due 2025 (“6.25% Senior Notes”) and a $300.0 million aggregate principal amount of 7.75% Senior Notes due 2027 (“7.75% Senior Notes” and together with 6.25% Senior Notes, the “Senior Notes”) outstanding.

During the three and nine months ended September 30, 2023, we purchased in the open market nil and $8.0 million, respectively, of 6.25% Senior Notes for cash consideration of $6.8 million. The purchase resulted in a $1.1 million gain, which included the write-off of deferred financing fees of $0.1 million. Subsequent to the quarter, the Company cancelled all previously purchased 6.25% Senior Notes. No notes were purchased during the three months ended September 30, 2023.

Subsequent to the quarter, we completed exchange offers of $247.1 million of 6.25% Senior Notes and $275.8 million of 7.75% Senior Notes for $487.6 million newly issued 9.50% Senior Secured Notes due 2029. The exchange consideration for $242.5 million of 6.25% Senior Notes included early participation premium of $80 for each $1,000 aggregate principal amount with the remainder of $4.6 million exchanged at $1,000 and for $274.2 million of 7.75% Senior Notes early participation premium of $20 for each $1,000 aggregate principal amount with remainder of $1.6 million of 7.75% Senior Notes exchanged at $950 for each $1,000 aggregate principal amount. In addition, we paid cash consideration of $60.0 million for 6.25% Senior Notes exchanged as part of total consideration to eligible holders on a pro rata basis, for each $1,000 aggregate principal amount tendered and accepted up to the early exchange deadline. The settlement date of the exchange offer was on October 20, 2023. The Senior Notes tendered and accepted for exchange, as well as the notes held as treasury bonds, were cancelled.

During the year ended December 31, 2022, we implemented a share re-purchase program (the “2022 Program”) through the facilities of the Toronto Stock Exchange (“TSX”) and eligible alternative trading platforms in Canada. Under the 2022 Program, we were able to purchase at prevailing market prices up to 3,603,396 shares of Common Stock, representing approximately 10% of the issued and outstanding shares of Common Stock as of August 22, 2022. Re-purchases are subject to prevailing market conditions, the trading price of our Common Stock, our financial performance and other conditions.

During the three and nine months ended September 30, 2023, we re-purchased nil and 1,328,650 shares at a weighted average price of nil and $8.15 per share, respectively (three and nine months ended September 30, 2022 - 1,073,370 shares). As of September 30, 2023, all 3,603,396 shares held as treasury stock were canceled. The 2022 Program expired in May 2023 when 10% share maximum was reached.
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Cash Flows

The following table presents our primary sources and uses of cash and cash equivalents and restricted cash and cash equivalents for the periods presented:
Nine Months Ended September 30,
(Thousands of U.S. Dollars) 2023 2022
Sources of cash and cash equivalents:
Net (loss) income $ (13,998) $ 105,754
Adjustments to reconcile net loss to Adjusted EBITDA (1)
and funds flow from operations (1)
DD&A expenses 162,949 128,499
Interest expense 38,017 35,743
Income tax expense 106,948 99,940
Non-cash lease expenses 3,488 2,009
Lease payments (1,918) (1,134)
Foreign exchange loss
8,126 486
Stock-based compensation expense 3,748 6,376
Other gain (969) (2,598)
Adjusted EBITDA (1)
306,391 375,075
Current income tax expense (63,706) (63,072)
Contractual interest and other financing expenses (34,623) (32,974)
Realized foreign exchange (loss) gain
(15,940) 5,652
Funds flow from operations (1)
192,122 284,681
Proceeds from exercise of stock options 8 1,294
Net changes in assets and liabilities from operating activities — 72,838
Foreign exchange gain on cash and cash equivalents and restricted cash and cash equivalents
5,897 —
Proceeds from debt, net of issuance costs 48,125 —
Changes in non-cash investing working capital — 3,255
246,152 362,068
Uses of cash and cash equivalents:
Additions to property, plant and equipment (179,707) (163,717)
Net changes in assets and liabilities from operating activities (34,235) —
Changes in non-cash investing working capital (11,051) —
Repayment of debt — (67,623)
Re-purchase of shares of Common Stock
(10,825) (14,365)
Purchase of Senior Notes
(6,805) (17,274)
Settlement of asset retirement obligations (376) (1,673)
Lease payments (5,101) (1,991)
Foreign exchange loss on cash, and cash equivalents and restricted cash and cash equivalents
— (1,996)
(248,100) (268,639)
Net (decrease) increase in cash and cash equivalents and restricted cash and cash equivalents $ (1,948) $ 93,429
(1) Adjusted EBITDA and funds flow from operations are non-GAAP measures which do not have any standardized meaning prescribed under GAAP. Refer to “Financial and Operational Highlights - non-GAAP measures” for a definition and reconciliation of this measure.

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One of the primary sources of variability in our cash flows from operating activities is the fluctuation in oil prices. Sales volume changes, costs related to operations and debt transactions also impact cash flows. Our cash flows from operating activities are also impacted by foreign currency exchange rate changes. During the three and nine months ended September 30, 2023, funds flow from operations decreased by 16% and 33%, respectively, compared to the corresponding periods of 2022, primarily due to a decrease in Brent price, lower and higher quality and transportation discounts, respectively, higher operating costs and realized foreign exchange loss.

Critical Accounting Policies and Estimates

Our critical accounting policies and estimates are disclosed in Item 7 of our 2022 Annual Report on Form 10-K and have not changed materially since the filing of that document.

Item 3. Quantitative and Qualitative Disclosures About Market Risk

Commodity price risk

Our principal market risk relates to oil prices. Oil prices are volatile and unpredictable and influenced by concerns over world supply and demand imbalance and many other market factors outside of our control. Our revenues are from oil sales at ICE Brent adjusted for quality differentials.

Foreign currency risk

Foreign currency risk is a factor for our Company but is ameliorated to a certain degree by the nature of expenditures and revenues in the countries where we operate. Our reporting currency is U.S. dollars and 100% of our revenues are related to the U.S. dollar price of Brent adjusted for quality differentials. We receive 100% of our revenues in U.S. dollars and the majority of our capital expenditures is in U.S. dollars or is based on U.S. dollar prices. The majority of value added taxes, operating and G&A expenses in Colombia are in the local currency. Certain G&A expenses incurred at our head office in Canada are denominated in Canadian dollars. While we operate in South America exclusively, the majority of our acquisition expenditures have been valued and paid in U.S. dollars.

Additionally, foreign exchange gains and losses result primarily from the fluctuation of the U.S. dollar to the Colombian peso due to our current and deferred tax assets and liabilities which are monetary assets and liabilities denominated in the local currency of the Colombian foreign operations. As a result, a foreign exchange gain or loss must be calculated on conversion to the U.S. dollar functional currency.

Interest Rate Risk

Interest rate risk is the risk that future cash flows will fluctuate as a result of changes in market interest rates. We are exposed to interest rate fluctuations on our credit facility, which bears floating rates of interest. At September 30, 2023, our outstanding balance under the credit facility was $50 million (December 31, 2022 - nil).

Item 4. Controls and Procedures
Disclosure Controls and Procedures
We have established disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, or Exchange Act). Our disclosure controls and procedures are designed to provide reasonable assurance that the information required to be disclosed by Gran Tierra in the reports that it files or submits under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in the SEC rules and forms and that such information is accumulated and communicated to management, including our Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure. Our management, with the participation of our Chief Executive Officer and Chief Financial Officer, evaluated the effectiveness of the design and operation of our disclosure controls and procedures as of the end of the period covered by this report, as required by Rule l3a-15(b) of the Exchange Act. Based on this evaluation, our Chief Executive Officer and Chief Financial Officer have concluded that Gran Tierra’s disclosure controls and procedures were effective as of September 30, 2023.

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Changes in Internal Control over Financial Reporting
There were no changes in our internal control over financial reporting during the quarter ended September 30, 2023, that have materially affected, or are reasonably likely to materially affect our internal control over financial reporting.



PART II - Other Information

Item 1. Legal Proceedings
See Note 8 in the Notes to the Condensed Consolidated Financial Statements (Unaudited) in Part I, Item 1 of this Quarterly Report on Form 10-Q, which is incorporated herein by reference, for any material developments with respect to matters previously reported in our Annual Report on Form 10-K for the year ended December 31, 2022, and any material matters that have arisen since the filing of such report.

Item 1A. Risk Factors

There are numerous factors that affect our business and results of operations, many of which are beyond our control. In addition to information set forth in this quarterly report on Form 10-Q, including in Part I, Item 2 “Management’s Discussion and Analysis of Financial Condition and Results of Operations”, you should carefully read and consider the factors set out in Part I, Item 1A “Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2022. These risk factors could materially affect our business, financial condition and results of operations. The unprecedented nature of ongoing conflicts in several parts of the world, the volatility in the worldwide economy and oil and gas industry may make it more difficult to identify all the risks to our business, results of operations and financial condition and the ultimate impact of identified risks.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

None.

Item 5. Other Information

During the three months ended September 30, 2023, no director or Section 16 officer adopted or terminated any Rule 10b5-1 trading arrangements or non-Rule 10b5-1 trading arrangements (in each case, as defined in Item 408(a) of Regulation S-K).

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Item 6. Exhibits
Exhibit No. Description Reference
3.1 Incorporated by reference to Exhibit 3.3 to the Current Report on Form 8-K, filed with the SEC on November 4, 2016 (SEC File No. 001-34018).
3.2 Incorporated by reference to Exhibit 3.1 to the Current Report on Form 8-K, filed with the SEC on May 5, 2023 (SEC File No. 001-34018).
3.3 Incorporated by reference to Exhibit 3.4 to the Current Report on Form 8-K, filed with the SEC on November 4, 2016 (SEC File No. 001-34018).
3.4 Incorporated by reference to Exhibit 3.1 to the Current Report on Form 8-K filed with the SEC on August 4, 2021 (SEC File No. 001-34018).
3.5 Incorporated by reference to Exhibit 3.1 to the Current Report on Form 8-K filed with the SEC on July 9, 2018 (SEC File No. 001-34018).
10.1 Filed herewith.
31.1 Filed herewith.
31.2 Filed herewith.
32.1 Furnished herewith.

101.INS XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document
101.SCH Inline XBRL Taxonomy Extension Schema Document
101.CAL Inline XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF Inline XBRL Taxonomy Extension Definition Linkbase Document
101.LAB Inline XBRL Taxonomy Extension Label Linkbase Document
101.PRE Inline XBRL Taxonomy Extension Presentation Linkbase Document
104.The cover page from Gran Tierra Energy Inc.’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2023, formatted in Inline XBRL (included within the Exhibit 101 attachments).


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SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
GRAN TIERRA ENERGY INC.
Date: October 31, 2023
/s/ Gary S. Guidry
By: Gary S. Guidry
President and Chief Executive Officer
(Principal Executive Officer)

Date: October 31, 2023
/s/ Ryan Ellson
By: Ryan Ellson
Executive Vice President and Chief Financial Officer
(Principal Financial and Accounting Officer)

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TABLE OF CONTENTS
Part I - Financial InformationItem 1. Financial StatementsItem 2. Management S Discussion and Analysis Of Financial Condition and Results Of OperationsItem 3. Quantitative and Qualitative Disclosures About Market RiskItem 4. Controls and ProceduresPart II - Other InformationItem 1. Legal ProceedingsItem 1A. Risk FactorsItem 2. Unregistered Sales Of Equity Securities and Use Of ProceedsItem 5. Other InformationItem 6. Exhibits

Exhibits

3.1 Certificate of Incorporation. Incorporated by reference to Exhibit 3.3 to the Current Report on Form 8-K, filed with the SEC on November 4, 2016 (SEC File No. 001-34018). 3.2 Certificate of Amendment to Certificate of Incorporation of Gran Tierra Energy Inc., effective May 5, 2023 Incorporated by reference to Exhibit 3.1 to the Current Report on Form 8-K, filed with the SEC on May 5, 2023 (SEC File No. 001-34018). 3.3 Bylaws of Gran Tierra Energy Inc. Incorporated by reference to Exhibit 3.4 to the Current Report on Form 8-K, filed with the SEC on November 4, 2016 (SEC File No. 001-34018). 3.4 Amendment No.1 to Bylaws of Gran Tierra Energy Inc. Incorporated by reference to Exhibit 3.1 to the Current Report on Form 8-K filed with the SEC on August 4, 2021 (SEC File No. 001-34018). 3.5 Certificate of Retirement dated July 9, 2018 Incorporated by reference to Exhibit 3.1 to the Current Report on Form8-K filed with the SEC on July 9, 2018 (SEC File No. 001-34018). 10.1 Deed of Amendment and Restatement to Credit Agreement datedSeptember19, 2023 by and among Gran Tierra Energy Inc., Gran Tierra Energy ColombiaGmbH, Gran TierraOperationsColombiaGmbH. and Trafigura PTE Ltd. as a lender. Filed herewith. 31.1 Certification of Principal Executive Officer Pursuant to Rule 13a-14(a)/15d-14(a), as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 Filed herewith. 31.2 Certification of Principal Financial Officer Pursuant to Rule 13a-14(a)/15d-14(a), as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 Filed herewith. 32.1 Certification of Principal Executive Officer and Principal Financial Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 Furnished herewith.