8-K: Gran Tierra Hits Record Production, Returns to Free Cash Flow

Gran Tierra Energy Inc. announced record Q2 2025 production of 47,196 boepd, achieved free cash flow, and secured a mandate for a $200 million prepayment facility.

Summary

• Achieved record total company average quarterly production of 47,196 boepd, which was 44% higher than the second quarter of 2024 and 1% higher than the first quarter of 2025.
• Reported Funds Flow From Operations of $54 million and Adjusted EBITDA of $77 million for the quarter ended June 30, 2025.
• Returned to Free Cash Flow, reporting $2.736 million for the quarter.
• Signed a mandate letter for a $200 million prepayment facility backed by crude oil deliveries, expected to close in the third quarter of 2025.
• Entered into a binding agreement to exit the UK North Sea assets, which is expected to close in the third quarter of 2025.
• Achieved a company record total of 32 million person-hours without a lost time injury since 2022.
• Recorded operating costs per boe of $13.42 for the quarter, the lowest since the first quarter of 2022.
• Incurred a net loss of $13 million, compared to a net loss of $19 million in the prior quarter and net income of $36 million in the second quarter of 2024.
• Total debt was $807 million and net debt was $746 million as of June 30, 2025, with a twelve-month trailing net debt to adjusted EBITDA ratio of 2.3 times.
• Repurchased 239,754 shares of common stock during the quarter, contributing to approximately 5.2 million shares repurchased (15% of shares issued and outstanding on January 1, 2023) from January 1, 2023, to July 28, 2025.

Sentiment

Score: 8

Explanation: Despite a net loss, the company achieved record production, returned to free cash flow, significantly reduced operating costs, and secured new financing, indicating strong operational performance and strategic progress. The negative financial metrics are largely attributable to lower commodity prices and prior period capital expenditures, rather than operational underperformance.

Positives

• Achieved record total company average quarterly production of 47,196 boepd.
• Returned to Free Cash Flow with $2.736 million generated in Q2 2025.
• Signed a mandate letter for a $200 million prepayment facility, enhancing financial flexibility and supporting long-term capital planning.
• Entered into a binding agreement to exit the UK North Sea, optimizing the portfolio.
• Achieved a company record of 32 million person-hours without a lost time injury.
• Recorded operating costs per boe of $13.42, the lowest since Q1 2022.
• Successful development drilling in Colombia (Costayaco and Cohembi) with strong early waterflood response in Cohembi's north area.
• Average drilling cost for five Cohembi wells was ~$3.0 million per well, representing a 47% reduction from the prior operator's average.
• Acordionero production increased to ~14,200 bopd from ~13,800 bopd in Q1 2025 due to proactive waterflood management and facility upgrades.
• Canadian Montney and Clearwater assets are delivering encouraging results, with three gross wells outperforming expectations.
• Derivative hedging strategy contributed a $14 million gain during the quarter.
• Canadian credit facility borrowing base confirmed unchanged at C$100 million, reflecting asset strength and stability.
• South American quality and transportation discounts were lower at $10.30 per bbl, indicating tightening differentials.

Negatives

• Incurred a net loss of $13 million in Q2 2025.
• Adjusted EBITDA decreased to $77 million from $85 million in Q1 2025 and $103 million in Q2 2024.
• Net cash provided by operating activities decreased by 53% to $35 million from Q1 2025 and Q2 2024.
• Oil, Natural Gas and NGL Sales decreased by 8% to $152 million from Q2 2024, primarily due to a 22% decrease in Brent pricing.
• Operating Netback decreased by 6% to $21.39 per boe from Q1 2025 and 45% from Q2 2024, primarily due to lower oil pricing and a change in production mix with the addition of Canadian assets.
• Cash Netback per boe decreased to $12.95, compared to $13.04 in Q1 2025 and $15.85 in Q2 2024.
• G&A expenses before stock-based compensation increased to $3.48 per boe from $2.86 per boe in Q1 2025 due to the timing of certain annual corporate expenses.
• Transportation expenses increased by 10% to $8 million from Q1 2025 as a result of incremental sales volumes transported by Canadian operations.
• Twelve-month trailing net debt to adjusted EBITDA was 2.3 times, which is above the company's long-term target ratio of 1.0 times.

Risks

• Ability to successfully integrate the assets and operations of i3 Energy Plc and realize the anticipated benefits and operating synergies expected from the 2024 acquisition.
• Unexpected problems arising from guerrilla activity, strikes, local blockades, or protests in South American operations.
• Technical difficulties and operational difficulties impacting the production, transport, or sale of products.
• Global and regional changes in the demand, supply, prices, differentials, or other market conditions affecting oil and gas, including inflation, tariffs, trade policies, global health crises, geopolitical events (e.g., conflicts in Ukraine and the Middle East), or actions by OPEC and other producing countries.
• Volatility or a prolonged decline in commodity 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 currently predicted, potentially causing further modification of strategy and capital spending program.
• The unpredictability and volatility of prices and markets for oil and natural gas.
• The accuracy of productive capacity of any particular field.
• Geographic, political, and weather conditions impacting the production, transport, or sale of products.
• Ability to execute the business plan, which may include acquisitions, and realize expected benefits from current or future initiatives.
• Unexpected delays and difficulties in developing currently owned properties.
• Ability to replace reserves and production and develop and manage reserves on an economically viable basis.
• Accuracy of testing and production results and seismic data, pricing, and cost estimates.
• The risk profile of planned exploration activities.
• The effects of drilling down-dip, waterflood, and multi-stage fracture stimulation operations.
• The extent and effect of delivery disruptions, equipment performance, and costs.
• Actions by third parties.
• Timely receipt of regulatory or other required approvals for operating activities.
• 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 common stock or bonds.
• The risk of not receiving the anticipated benefits of government programs, including government tax refunds.
• Ability to access debt or equity capital markets from time to time to raise additional capital, increase liquidity, fund acquisitions, or refinance debt.
• The risk of being unable to successfully negotiate final terms and close an anticipated prepayment structure backed by crude oil deliveries.
• Ability to comply with financial covenants in indentures and make borrowings under credit agreements.

Future Outlook

Gran Tierra expects to continue building on the momentum of its Iguana Block discoveries with planned drilling of two high-impact exploration wells in the Charapa Block in Ecuador towards the end of Q3 2025. In Colombia, the final Costayaco development well (Costayaco-65) is scheduled to be brought on production in August 2025. The company forecasts its credit facilities to have a zero balance by the end of the year and anticipates enhanced financial flexibility and optimized debt maturity profile from the new $200 million prepayment facility, expected to close in Q3 2025. The next redetermination of the Canadian credit facility is scheduled on or before November 30, 2025. Gran Tierra also maintains a rolling 12-month hedging program to mitigate volatility.

Management Comments

• Gran Tierra delivered record-setting production this quarter, reflecting the strength of our diversified portfolio and consistent operational execution across Colombia, Ecuador, and Canada.
• In Ecuador, we are building on the momentum of our Iguana Block discoveries with the planned drilling of two high-impact exploration wells in the Charapa Block later this year.
• In Colombia, the successful development drilling at Costayaco and Cohembi, along with the strong early waterflood response in Cohembi's north area, underscores the ongoing potential of our core assets and validates our disciplined approach to reservoir management.
• In Acordionero, our proactive waterflood management, surface facility upgrades, pump upsizes and ongoing improvement in electrical submersible pump run lives continue to mitigate base decline.
• In Canada, our Montney and Clearwater assets are delivering encouraging results, with three gross-wells (1.2 net) brought on stream in the Quarter, outperforming expectations.
• These outcomes further reinforce our strategy of disciplined capital allocation and balanced growth as we focus on generating long-term value for our stakeholders.
• We continue to optimize our portfolio with the signed disposition of the UK North Sea assets, which is expected to close in the third quarter of 2025.
• We currently forecast the facilities to have a zero balance by the end of the year.

Industry Context

Gran Tierra's Q2 2025 results demonstrate resilience in a volatile commodity price environment, with Brent prices decreasing by 11% compared to the prior quarter. The company's strategic focus on diversified assets across Colombia, Ecuador, and Canada, coupled with disciplined capital allocation and hedging strategies, allowed it to achieve record production and return to free cash flow despite market headwinds. The disposition of UK North Sea assets aligns with a broader industry trend of portfolio optimization, allowing companies to focus on core, higher-return regions. The successful integration and outperformance of Canadian Montney and Clearwater assets highlight the value of strategic acquisitions in enhancing overall production and financial stability.

Comparison to Industry Standards

• Cohembi drilling costs averaged ~$3.0 million per well, representing a 47% reduction from the prior operator's average for the last five wells drilled in 2017/18, indicating significant efficiency improvements.
• Canadian Montney wells in Simonette are currently out-performing management's current type curves, suggesting strong asset performance relative to internal benchmarks.
• Operating costs per boe of $13.42 are the lowest since Q1 2022, indicating improved cost efficiency compared to the company's own historical performance.
• The company's twelve-month trailing net debt to adjusted EBITDA ratio of 2.3 times is above its long-term target ratio of 1.0 times, indicating higher leverage compared to its internal financial goal.
• The company's hedging strategy utilizes Brent, West Texas Intermediate (WTI), and AECO natural gas prices as benchmarks, providing downside protection while preserving upside exposure, a common risk management practice in the industry.

Stakeholder Impact

• Shareholders: Positive impact due to record production, return to free cash flow, share buybacks (15% of shares outstanding since Jan 2023), and strategic portfolio optimization (UK North Sea exit). Potential for long-term value generation.
• Employees: Positive impact from a strong safety record (32 million person-hours without a lost time injury), indicating a safe working environment.
• Creditors: Enhanced financial flexibility and optimized debt maturity profile due to the new $200 million prepayment facility and confirmed Canadian credit facility, improving the company's ability to manage its debt obligations.
• Customers: Implied stable supply due to record production volumes.

Next Steps

• Civil works underway to support drilling of final two exploration wells in Charapa Block, Ecuador, with drilling expected to commence toward the end of Q3 2025.
• Costayaco-65 well scheduled to be brought on production in August 2025.
• Fourth Montney well expected to reach total depth in the first half of August.
• Closing of the UK North Sea disposition expected in Q3 2025.
• Progressing toward full documentation and closing of the $200 million prepayment facility in Q3 2025, with funding shortly thereafter.
• Next redetermination of the Canadian credit facility scheduled on or before November 30, 2025.
• Company forecasts credit facilities to have a zero balance by the end of the year.
• Conference call for Q2 2025 results on July 31, 2025.

Key Dates

Recommendation

Gran Tierra Energy's Q2 2025 results demonstrate strong operational execution and strategic progress, making it an attractive 'buy' for a seasoned investor. The company achieved record production, returned to free cash flow, and significantly reduced operating costs per boe to their lowest level since Q1 2022. Key operational successes include efficient drilling in Colombia with substantial cost reductions and outperforming wells in Canada. The securing of a $200 million prepayment facility enhances liquidity and debt management, while the planned exit from the UK North Sea optimizes the portfolio. Although the company reported a net loss and lower EBITDA compared to prior periods, these are largely influenced by commodity price declines and prior capital expenditure timing, rather than fundamental operational weakness. The positive operational momentum, strategic financial moves, and commitment to shareholder returns (via buybacks) suggest a strong outlook for future performance.

Keywords

Gran Tierra Energy, GTE, Oil and Gas, Exploration, Production, Colombia, Ecuador, Canada, Q2 2025 Results, Financial Performance, Operating Results, Record Production, Free Cash Flow, Prepayment Facility, UK North Sea Exit, Montney, Clearwater, Costayaco, Cohembi, Acordionero, Iguana Block, Charapa Block, Hedging, Debt Management, EBITDA, Funds Flow From Operations, Energy Sector, Upstream Oil and Gas