8-K: Gran Tierra Reports Q3 2025 Results, Ecuador Success

Gran Tierra Energy Inc. announced its third quarter 2025 financial and operating results, highlighting exploration success in Ecuador and a new $200 million prepayment facility.

Summary

• A net loss of $20 million was incurred in Q3 2025, compared to a net loss of $13 million in Q2 2025 and net income of $1 million in Q3 2024.
• Adjusted EBITDA was $69 million, down from $77 million in Q2 2025 and $93 million in Q3 2024.
• Funds flow from operations was $42 million ($1.18 per share), representing a 31% decrease from Q3 2024 and a 23% decrease from Q2 2025.
• Total average working interest (WI) production was 42,685 boepd, which was 30% higher than Q3 2024 but 10% lower than Q2 2025 due to externally driven events.
• Current production (October 1-29, 2025) averaged approximately 45,200 boepd.
• A $200 million prepayment facility was secured for Ecuadorian Oriente crude oil, with proceeds expected to be used for debt repayment and select capital initiatives.
• The Canadian Credit Facility was increased from C$50.0 million to C$75.0 million and extended to October 31, 2027.
• Capital expenditures were $57 million in Q3 2025, higher than $51 million in Q2 2025 and $53 million in Q3 2024.
• Net debt stood at $755 million as of September 30, 2025.

Sentiment

Score: 5

Explanation: While the company reported significant operational successes in exploration and development across its regions and enhanced its liquidity through new financing, the financial results for the quarter showed a net loss, decreased EBITDA, and negative free cash flow. Production was also temporarily impacted by external events, leading to a forecast at the lower end of guidance. The forward-looking statements emphasize a shift to free cash flow generation and deleveraging, which is a positive strategic direction.

Positives

• Achieved further exploration success in Ecuador with the Conejo A-1 and A-2 wells and confirmed a new discovery at Chanangue-1, highlighting significant acreage potential.
• The Conejo A-2 well discovered 41 feet of net reservoir with an average porosity of 13.8% in the Hollin formation, suggesting high deliverability.
• Completed all exploration commitments in Ecuador, positioning for increased production into the development phase and long-term growth.
• The re-entry of the legacy Chanangue-1 well resulted in a new oil discovery, currently producing approximately 600 bopd, expected to generate additional future drilling opportunities.
• The development program in the northern area of the Costayaco field in Colombia continued to perform well, with three new wells contributing to production growth (combined average of approximately 1,700 bopd).
• The Cohembi field in Colombia delivered a strong waterflood response, increasing output from the northern area by 135% (from 2,800 to 6,700 gross bopd), with total field production exceeding 9,000 gross bopd, levels not achieved since 2014.
• Successfully drilled and brought two additional Lower Montney wells onstream in Canada, both meeting or exceeding expectations.
• Secured a $200 million prepayment facility for Ecuadorian Oriente crude oil, enhancing liquidity and intended for debt repayment and capital initiatives.
• The Canadian Credit Facilities were increased from C$50.0 million to C$75.0 million and extended to October 31, 2027, enhancing financial flexibility.
• Total average WI production was 42,685 boepd, which was 30% higher than Q3 2024 due to the Canadian operations acquisition and positive exploration well drilling results in Ecuador.
• Current production (October 1-29, 2025) averaged approximately 45,200 boepd, indicating a strong recovery from Q3 impacts.
• Management expects an exit rate of 47,000 to 50,000 boepd.
• Lower Castilla, Oriente, and Vasconia oil differentials were observed compared to Q3 2024.

Negatives

• A net loss of $20 million was reported in Q3 2025, compared to a net income of $1 million in Q3 2024.
• Adjusted EBITDA decreased to $69 million from $93 million in Q3 2024 and $77 million in Q2 2025.
• Funds flow from operations decreased by 31% from Q3 2024 and 23% from Q2 2025.
• Total average WI production was 10% lower than Q2 2025, primarily due to a landslide in Ecuador and trunk line repairs at the Moqueta field.
• The Moqueta field was shut in for the entire Quarter due to trunk line repairs.
• The Company is forecasting the lower end of its production guidance range due to deferrals.
• Free cash flow was negative $15.655 million in Q3 2025, compared to positive $7.417 million in Q3 2024 and positive $2.736 million in Q2 2025.
• Oil, Natural Gas and NGL Sales decreased by 1% from Q3 2024, primarily due to a 13% decrease in Brent pricing.
• South American quality and transportation discounts per bbl were slightly higher at $10.76 compared to $10.30 in Q2 2025.
• Total operating expenses increased by 22% to $68 million (26% on a per boe basis) compared to Q2 2025 due to higher workover activities and inventory fluctuations.
• Gross profit decreased 70% to $14.7 million compared to Q3 2024 and 36% from Q2 2025.
• Operating netback was $18.89 per boe, down 12% from Q2 2025 and 45% from Q3 2024.
• Cash netback per boe decreased to $10.28, compared to $12.95 in Q2 2025 and $20.34 in Q3 2024.
• Net debt of $755 million as of September 30, 2025.

Risks

• Ability to successfully integrate the assets and operations of i3 Energy Plc and realize anticipated benefits and operating synergies from the 2024 acquisition.
• Operations in South America are subject to unexpected problems due to guerrilla activity, strikes, local blockades, or protests.
• Technical and operational difficulties may arise which impact 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.
• Changes in commodity prices, including volatility or a prolonged decline 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 predicted, potentially causing further modification of strategy and capital spending.
• Prices and markets for oil and natural gas are unpredictable and volatile.
• The effect of hedges on financial results.
• The accuracy of productive capacity of any particular field.
• Geographic, political, and weather conditions can impact the production, transport, or sale of products.
• Ability to execute the business plan, including acquisitions, and realize expected benefits from current or future initiatives.
• The risk that unexpected delays and difficulties in developing currently owned properties may occur.
• 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 commodity pricing and exchange rates).
• 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.
• The timely receipt of regulatory or other required approvals for 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 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

The Company is forecasting the lower end of its production guidance range for 2025 due to temporary deferrals from external events. However, underlying assets are performing well, with an expected exit rate of 47,000 to 50,000 boepd. The 2026 budget, to be released in mid-December, will focus on free cash flow generation and deleveraging, following the completion of 2025 exploration commitments which resulted in material discoveries.

Management Comments

• "The Third Quarter showcased continued operational success across our portfolio."
• "In Ecuador, we achieved further exploration success with the Conejo A-1 and A-2 wells and confirmed a new discovery at Chanangue-1, all of which highlight the significant potential of our acreage position."
• "In Colombia, new wells at Costayaco continued to perform well, and the Cohembi field delivered a strong waterflood response, with production reaching levels not seen in over a decade."
• "In Canada, we successfully drilled and brought two additional Lower Montney wells onstream, both meeting or exceeding expectations."
• "Production during the Quarter was temporarily impacted primarily by externally driven events, including a landslide in Ecuador that required the shut in of all Ecuador production for several weeks and trunk line repairs at the Moqueta field which resulted in the field being shut in for the Quarter. These volumes represent deferred bbls rather than lost production, and we are already seeing a strong recovery, with current production averaging approximately 45,200 boepd."
• "Based on the deferrals, we are forecasting the lower end of our production guidance range. The underlying assets continue to perform well, and our teams remain focused on ongoing optimization and maximizing production efficiency and cash flow with an expected exit rate of 47,000 to 50,000 boepd."
• "We completed a number of initiatives to enhance liquidity and will be releasing our 2026 budget in mid December which will focus on free cash flow generation."
• "The 2025 capital program was focused on fulfilling exploration commitments, which resulted in numerous material discoveries, and facility construction primarily in the Suroriente Block. With substantially all commitments behind us, the focus turns to free cash flow generation from our substantial, diversified resource base and deleveraging."
• "With the delivery of the Conejo A-2 well, Gran Tierra has completed all of the Exploration commitments in Ecuador and we are now well-positioned to continue to increase production into the development phase and establish our long-term growth position in Ecuador."

Industry Context

The filing highlights Gran Tierra's continued focus on oil and natural gas exploration and production in Canada, Colombia, and Ecuador. The successful exploration and development activities, particularly in Ecuador and Colombia, suggest the company is actively pursuing growth opportunities in key South American basins, aligning with broader industry trends of optimizing existing assets and exploring new reserves in established regions. The capital structure optimization through a prepayment facility and credit facility extension reflects a common industry strategy to manage debt and enhance liquidity in a volatile commodity price environment. The temporary production impacts due to external events (landslide, trunk line repairs) are common operational challenges in the industry, especially in regions with complex logistics.

Comparison to Industry Standards

• The Cohembi field's production exceeding 9,000 gross bopd, a level not seen since 2014, indicates a strong waterflood response, which is a positive outcome for mature fields and compares favorably to typical decline rates in similar assets without enhanced oil recovery.
• The initial 30-day oil rates from Costayaco wells (ranging from approximately 600 to 1,100 bopd) are robust for new development wells in the region, suggesting competitive well performance.
• The discovery of 41 feet of net reservoir with 13.8% porosity in the Hollin formation at Conejo A-2 is indicative of good reservoir quality, which is a key factor for economic viability in exploration plays, potentially comparable to successful exploration efforts by peers in the Oriente basin.
• The $200 million prepayment facility is a significant financing arrangement, common for companies with strong crude oil portfolios in regions like Ecuador, providing a non-dilutive source of capital compared to equity raises.

Corporate Governance

Stakeholder Impact

• Shareholders: Potential for increased value from exploration success and future free cash flow generation, but current quarter's net loss and negative free cash flow may cause concern. Liquidity enhancements could stabilize the financial position.
• Creditors: The $200 million prepayment facility and extended Canadian credit facility improve the company's ability to manage and repay debt, reducing immediate credit risk.
• Employees: Continued operational activity and exploration success suggest ongoing employment stability and potential for growth.
• Customers: Stable production and new discoveries ensure continued supply of crude oil.
• Suppliers: Ongoing capital expenditures and operational activities indicate continued demand for services and materials.

Next Steps

• Re-enter the Conejo A-1 well to install the final completion and conduct selective testing of each zone to optimize total well production.
• Change the artificial lift system from jet pump to electronic submersible pumps in the Costayaco field, expected to add an incremental 1,000 1,500 bopd.
• Commence a 6-well drilling program in Cohembi, which includes the Raju-1 exploration well.
• Spud the Raju-1 exploration well in early November, targeting a large prospective area north of the current development.
• Expect initial results from the Raju-1 well prior to year end 2025.
• Release the 2026 budget in mid-December, focusing on free cash flow generation and deleveraging.
• Continue to increase production into the development phase and establish a long-term growth position in Ecuador.
• Focus on free cash flow generation from the substantial, diversified resource base and deleveraging.
• Pursue additional new growth opportunities that would further strengthen the Company's portfolio.

Key Dates

Recommendation

Gran Tierra Energy's Q3 2025 results present a mixed picture. While the company achieved notable operational successes, particularly in Ecuador with new discoveries and the completion of exploration commitments, and in Colombia with strong waterflood response, the financial performance for the quarter was weaker, showing a net loss, decreased EBITDA, and negative free cash flow. Production was also temporarily impacted by external events, leading to a forecast at the lower end of guidance. However, the company has proactively addressed liquidity with a new $200 million prepayment facility and an extended Canadian credit facility, and management's stated focus on free cash flow generation and deleveraging for 2026 is a positive strategic shift. Given the strong operational progress and strategic financial moves, but tempered by the current quarter's financial underperformance and production impacts, a "hold" recommendation is appropriate. Investors should monitor the execution of the 2026 budget, the recovery of production, and the realization of free cash flow.

Keywords

oil and gas, exploration, production, Ecuador, Colombia, Canada, Gran Tierra Energy, GTE, Q3 2025 results, financial results, operating results, prepayment facility, credit facility, oil discovery, waterflood, Montney, energy sector, upstream oil and gas