First Quarter 2024 Results

Total Current(1) Average Production of Approximately 33,400 BOPD

Funds Flow from Operations of $74 Million, Free Cash Flow of $19 Million and Adjusted EBITDA of $95 Million(2)

CALGARY, Alberta, May 01, 2024 (GLOBE NEWSWIRE) -- Gran Tierra Energy Inc. (“Gran Tierra” or the “Company”) (NYSE American:GTE)(TSX:GTE)(LSE:GTE) today announced the Company’s financial and operating results for the quarter ended March 31, 2024 (“the Quarter”). All dollar amounts are in United States dollars, and production amounts are on an average working interest (“WI”) before royalties basis unless otherwise indicated. Per barrel (“bbl”) and bbl per day (“BOPD”) amounts are based on WI sales before royalties. For per bbl amounts based on net after royalty (“NAR”) production, see Gran Tierra’s Quarterly Report on Form 10-Q filed May 1, 2024.

Message to Shareholders

Gary Guidry, President and Chief Executive Officer of Gran Tierra, commented: “During the Quarter we made significant progress in our development drilling programs. We are very pleased about the successful drilling program in Costayaco that confirmed the Company’s reservoir interpretation and extended the field both to the north and the south. In a field that was originally discovered in 2007, our 2024 program increased production to the highest level since 2017, helping to ensure the Company is well on track to meet its previously announced guidance for 2024.

In addition, we are having excellent results in our core assets under waterflood, the balance sheet is strong, and we are very excited about the initial drilling and open-hole logging results of the Arawana exploration well in the Chanangue block in Ecuador. The analog for the Arawana exploration well is the Company’s Cohembi field 20 kilometers to the north. Arawana is drilling 1.5 km across a fault from the recent Bocachico-1 well. Bocachico-1 had initial 90-day production rates in the Basal Tena (N-Sand geologic equivalent to Cohembi) of greater than 1,100 BOPD and continues to produce at approximately 850 BOPD, 20 degree API oil, has less than 1 percent water cut and has recovered over 330,000 barrels since drilled.

Our mapped area of closure, and the rock properties observed in the Arawana-1 well compares to the Cohembi field. As of the end of 2023, the Cohembi field has produced 28 million barrels of oil equivalent (“MMBOE”) and has remaining reserves of 25 MMBOE proved, 54 MMBOE proved plus probable and 95 MMBOE proved plus probable plus possible.

We are very excited to get this well cased and start testing Arawana-1 in May.”

Key Highlights of the Quarter:

Production: Gran Tierra’s total average WI production was 32,242 BOPD, an increase of 3% compared to the fourth quarter 2023 (“the Prior Quarter”) and up 2% from the first quarter 2023. During the Quarter we had deferred production of approximately 1,000 BOPD as a result of social disruptions in the Acordionero field. Post disruption the field is back to expected production levels of over 17,000 BOPD.

Net Income: Gran Tierra incurred a net loss of $0.1 million, compared to net income of $8 million in the Prior Quarter and a net loss of $10 million in the first quarter of 2023.

Adjusted EBITDA(2): Adjusted EBITDA(2) was $95 million compared to $93 million in the Prior Quarter and $90 million in the first quarter of 2023. Twelve month trailing Net Debt(2) to Adjusted EBITDA(2) was 1.3 times and is expected to be less than 1.0x by year end 2024.

Funds Flow from Operations(2): Funds flow from operations(2) was $74 million ($2.34 basic per share), down 12% from the Prior Quarter and up 24% from the first quarter of 2023.

Free Cash Flow(2): During the Quarter, the Company generated free cash flow of approximately $19 million.

Cash and Debt: As of March 31, 2024, the Company had a cash balance of $127 million, total debt(2) of $637 million and net debt(2) of $510 million. During the Quarter, the Company issued an additional $100 million of 9.50% Senior Notes due October 2029, and received cash proceeds of $88 million.

Credit Facility: During the Quarter, Gran Tierra fully re-paid the outstanding balance on Company’s credit facility of $36 million and the facility was terminated.

Share Buybacks: Gran Tierra purchased approximately 0.9 million shares during the Quarter. Since January 1, 2023 the Company has repurchased approximately 3.3 million shares, or 10% of shares issued and outstanding at January 1, 2023, from free cash flow.

Return on Average Capital Employed(2): Achieved return on average capital employed(2) of 14% during the Quarter and 16% over the trailing twelve months.

Additional Key Financial Metrics:

Capital Expenditures: Capital expenditures of $55 million were higher than the $39 million in the Prior Quarter due to higher drilling activity during the Quarter and down from $71 million compared to the first quarter of 2023 due to cost optimization of the 2024 drilling program. During the Quarter, Gran Tierra completed its development program in Acordionero and the majority of the program in Costayaco.

Oil Sales: Gran Tierra generated oil sales of $158 million, up 2% from the Prior Quarter and 9% from the first quarter of 2023. Oil sales increased compared to the Prior Quarter primarily due to a 5% increase in sales volumes resulting from the sale of inventory in Ecuador and a decrease in the Castilla differential, offset by higher Vasconia and Oriente differentials. Compared to the first quarter of 2023, oil sales increased due to lower Castilla, Vasconia and Oriente differentials.

Quality and Transportation Discounts: The Company’s quality and transportation discounts per bbl were consistent during the Quarter at $15.36, compared to $15.34 in the Prior Quarter and down from $18.45 in the first quarter of 2023. The Castilla oil differential per bbl narrowed to $8.82 from $9.68 in the Prior Quarter and from $15.17 in the first quarter of 2023 (Castilla is the benchmark for the Company’s Middle Magdalena Valley Basin oil production). The Vasconia differential per bbl widened to $5.05 from $4.58 in the Prior Quarter, and narrowed from $7.87 in the first quarter of 2023. Finally, the Ecuadorian benchmark, Oriente, per bbl was $8.02, up from $7.07 in the Prior Quarter, and down from $13.43 one year ago. The current(1) Castilla differential is approximately $7.60 per bbl, the Vasconia differential is approximately $3.70 per bbl and the Oriente differential is approximately $7.60 per bbl.

Operating Expenses: Gran Tierra’s operating expenses increased by 2% to $48 million, compared to the Prior Quarter primarily due to higher workovers offset by lower lifting costs primarily related to power generation optimizations in Costayaco, Acordionero and Cohembi fields. Compared to the first quarter of 2023, operating expenses increased by 12% on a per bbl basis due to higher workovers and lifting costs associated with preventative maintenance activities, which were partially offset by lower environmental and equipment rental expenses.

Transportation Expenses: The Company’s transportation expenses increased by 16% to $4.6 million, compared to the Prior Quarter of $3.9 million and increased by 50% or $3.1 million when compared to the first quarter of 2023. During the Quarter, Gran Tierra utilized longer distance delivery points due to low river levels in Colombia caused by El Niño preventing, resulting in higher transportation costs.

Operating Netback(2)(3): The Company’s operating netback(2)(3) was $35.37 per bbl, a decrease of 2% from the Prior Quarter and up 1% from the first quarter of 2023.

General and Administrative (“G&A”) Expenses: G&A expenses before stock-based compensation were $3.22 per bbl, down from $3.86 per bbl in the Prior Quarter due to lower legal expenses and lower headcount and down from $3.95 per barrel, when compared to the first quarter of 2023 due to lower legal fees and information technology expenses.

Cash Netback(2): Cash netback(2) per bbl was $25.13, compared to $29.53 in the Prior Quarter primarily as a result of current tax expenses of $1.33 per bbl compared to a recovery of $2.80 per bbl in the Prior Quarter. Compared to one year ago, cash netback per bbl increased by $3.97 to $25.13 per bbl as a result of lower current taxes in the Quarter.

Development Campaign:

Costayaco

Since December 2023, Gran Tierra has drilled seven wells of which six are oil producers and one is a water injector.

The aggregate IP30 rates from the four wells drilled in the north was 5,707 BOPD, unstimulated and on a jet pump. Starting in May 2024, the recently drilled wells will undergo stimulation and installation of optimized artificial lift systems such as Electric Submersible Pumps. This will allow for higher total fluid rates, allowing the wells to produce at full potential for the remainder of the year.

Acordionero

An eleven well development drilling program was started in December 2023. All eleven wells have been drilled to date including nine producers and two water injection wells. All wells are on production and injection. The results from the campaign are consistent with budget while continuing to add material free cash flow for the Company.

Upon completion of the program the drilling rig was mobilized and transported to Ecuador to begin the exploration campaign.

Gran Tierra’s Commitment to Go “Beyond Compliance” in Environmental, Social and Governance

Safety:

2023 was the safest year in Company history, with over 19 million work hours without any incidents causing lost time since June 9, 2022.

Environment:

Through all of Gran Tierra’s reforestation efforts, the Company has planted over 1.6 million trees and has conserved, preserved, or reforested approximately 4,500 hectares of land since 2018.

Reducing Greenhouse Gas (“GHG”) Emissions:

Gran Tierra is reducing GHG emissions at its facilities through gas-to-power projects that conserve excess natural gas that would otherwise be flared, using the gas instead for power generation. In 2023, Gran Tierra’s gas-to-power projects generated 68% of the total energy used in all of the Company’s operations.

Social & Human Rights:

Over 350,000 people participated in and benefited from Gran Tierra’s voluntary social investment programs over the past six years in Colombia and Ecuador.

Gran Tierra has been accepted by the Voluntary Principles Initiative (VPI) as an official member of the Voluntary Principles for Security and Human Rights world-wide initiative.

Installed residential water filters to approximately 150 households in Campo Alegre, Colombia providing clean drinking water to a local community and their two schools.

Gran Tierra’s flagship social program in Ecuador, Sucumbíos Sostenible, provided training and delivered approximately 59,000 cacao plants and over 600 cattle to local community members near our operations in 2023.

Financial and Operational Highlights (all amounts in $000s, except per share and bbl amounts)

• Gran Tierra’s total current average production for second quarter-to-date 2024 is the period of April 1 to April 29, 2024. Gran Tierra’s second quarter-to-date 2024 total average differentials are for the period from April 1 to April 29, 2024
• Funds flow from operations, operating netback, net debt, cash netback, return on average capital employed, earnings before interest, taxes and depletion, depreciation and accretion (“DD&A”) (“EBITDA”) and EBITDA adjusted for non-cash lease expense, lease payments, foreign exchange gains or losses, stock-based compensation expense, unrealized derivative instruments gains or losses, and other financial instruments gains or losses (“Adjusted EBITDA”), cash flow, free cash flow and net debt are non-GAAP measures and do not have standardized meanings under generally accepted accounting principles in the United States of America (“GAAP”). Cash flow refers to funds flow from operations. Free cash flow refers to funds flow from operations less capital expenditures. Refer to “Non-GAAP Measures” in this press release for descriptions of these non-GAAP measures and, where applicable, reconciliations to the most directly comparable measures calculated and presented in accordance with GAAP.
• Reflects our 1-for-10 reverse stock split that became effective May 5, 2023.

Conference Call Information:

Gran Tierra will host its first quarter 2024 results conference call on Wednesday, May 2, 2024, at 9:00 a.m. Mountain Time, 11:00 a.m. Eastern Time. Interested parties may access the conference call by registering at the following link: https://register.vevent.com/register/BI3642d81e05184759a47d21a0fddda043. The call will also be available via webcast at www.grantierra.com.

Corporate Presentation:

About Gran Tierra Energy Inc.

Non-GAAP Measures

*Annualized EBIT was calculated for the three months ended March 31, 2024, by multiplying the quarter-to-date EBIT by 4.

Cash netback as presented is defined as net income or loss adjusted for DD&A expenses, deferred tax expense or recovery, 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 or loss, other gain or loss and financial instruments gain or loss. Management believes that operating netback and cash netback are useful supplemental measures for investors to analyze financial performance and provide an indication of the results generated by Gran Tierra’s principal business activities prior to the consideration of other income and expenses. A reconciliation from net income or loss to cash netback is as follows:

EBITDA, as presented, is defined as net income or loss adjusted for DD&A expenses, interest expense and income tax expense or recovery. 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, other gain or loss and financial instruments loss. 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 financial measure is useful supplemental information for investors to analyze our performance and our financial results. A reconciliation from net income or loss to EBITDA and adjusted EBITDA is as follows:

Adjustments to reconcile net (loss) income to EBITDA and Adjusted EBITDA

Funds flow from operations, as presented, is defined as net income or loss adjusted for DD&A expenses, deferred tax expense or recovery, stock-based compensation expense or recovery, amortization of debt issuance costs, non-cash lease expense, lease payments, unrealized foreign exchange gain or loss, other gain or loss and financial instruments loss. Management uses this financial measure to analyze performance and income or loss generated by our principal business activities prior to the consideration of how non-cash items affect that income or loss, and believes that this financial measure is also useful supplemental information for investors to analyze performance and our financial results. Free cash flow, as presented, is defined as funds flow from operations adjusted for capital expenditures. Management uses this financial measure to analyze cash flow generated by our principal business activities after capital requirements 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 or loss to both funds flow from operations and free cash flow is as follows:

Adjustments to reconcile net (loss) income to funds flow from operations

Net debt as of March 31, 2024, was $510 million, calculated using the sum of 6.25% Senior Notes, 7.75% Senior Notes, and 9.50% Senior Notes excluding deferred financing fees totaling $637 million, less cash and cash equivalents of $127 million.

Presentation of Oil and Gas Information

All reserves value and ancillary information contained in this press release have been prepared by the Company's independent qualified reserves evaluator McDaniel & Associates Consultants Ltd. (“McDaniel”) in a report with an effective date of December 31, 2023 (the “GTE McDaniel Reserves Report”) and calculated in compliance with Canadian National Instrument 51-101 – Standards of Disclosure for Oil and Gas Activities (“NI 51-101”) and the Canadian Oil and Gas Evaluation Handbook (“COGEH”), unless otherwise expressly stated.

Estimates of net present value and future net revenue contained herein do not necessarily represent fair market value. Estimates of reserves and future net revenue for individual properties may not reflect the same level of confidence as estimates of reserves and future net revenue for all properties, due to the effect of aggregation. There is no assurance that the forecast price and cost assumptions applied by McDaniel in evaluating Gran Tierra’s reserves will be attained and variances could be material. All reserves assigned in the GTE McDaniel Reserves Report are located in Colombia and Ecuador and presented on a consolidated basis by foreign geographic area. There are numerous uncertainties inherent in estimating quantities of crude oil reserves. The reserve information set forth in the GTE McDaniel Reserves Report are estimates only and there is no guarantee that the estimated reserves will be recovered. Actual reserves may be greater than or less than the estimates provided therein.

Proved reserves are those reserves that can be estimated with a high degree of certainty to be recoverable. It is likely that the actual remaining quantities recovered will exceed the estimated proved reserves. Probable reserves are those additional reserves that are less certain to be recovered than proved reserves. It is equally likely that the actual remaining quantities recovered will be greater or less than the sum of the estimated proved plus probable reserves. Possible reserves are those additional reserves that are less certain to be recovered than Probable reserves. There is a 10% probability that the quantities actually recovered will equal or exceed the sum of Proved plus Probable plus Possible reserves.

Disclosure of Reserve Information and Cautionary Note to U.S. Investors

Unless expressly stated otherwise, all estimates of proved, probable and possible reserves and related future net revenue disclosed in this press release have been prepared in accordance with NI 51-101. Estimates of reserves and future net revenue made in accordance with NI 51-101 will differ from corresponding GAAP standardized measure prepared in accordance with applicable SEC rules and disclosure requirements of the U.S. Financial Accounting Standards Board (“FASB”), and those differences may be material. NI 51-101, for example, requires disclosure of reserves and related future net revenue estimates based on forecast prices and costs, whereas SEC and FASB standards require that reserves and related future net revenue be estimated using average prices for the previous 12 months and that the standardized measure reflect discounted future net income taxes related to the Company’s operations. In addition, NI 51-101 permits the presentation of reserves estimates on a “company gross” basis, representing Gran Tierra’s working interest share before deduction of royalties, whereas SEC and FASB standards require the presentation of net reserve estimates after the deduction of royalties and similar payments. There are also differences in the technical reserves estimation standards applicable under NI 51-101 and, pursuant thereto, the COGEH, and those applicable under SEC and FASB requirements. In addition to being a reporting issuer in certain Canadian jurisdictions, Gran Tierra is a registrant with the SEC and subject to domestic issuer reporting requirements under U.S. federal securities law, including with respect to the disclosure of reserves and other oil and gas information in accordance with U.S. federal securities law and applicable SEC rules and regulations (collectively, “SEC requirements”). Disclosure of such information in accordance with SEC requirements is included in the Company’s Annual Report on Form 10-K and in other reports and materials filed with or furnished to the SEC and, as applicable, Canadian securities regulatory authorities. The SEC permits oil and gas companies that are subject to domestic issuer reporting requirements under U.S. federal securities law, in their filings with the SEC, to disclose only estimated proved, probable and possible reserves that meet the SEC’s definitions of such terms. Gran Tierra has disclosed estimated proved, probable and possible reserves in its filings with the SEC. In addition, Gran Tierra prepares its financial statements in accordance with United States generally accepted accounting principles, which require that the notes to its annual financial statements include supplementary disclosure in respect of the Company’s oil and gas activities, including estimates of its proved oil and gas reserves and a standardized measure of discounted future net cash flows relating to proved oil and gas reserve quantities. This supplementary financial statement disclosure is presented in accordance with FASB requirements, which align with corresponding SEC requirements concerning reserves estimation and reporting.