GeoPark (GPRK) Q3 2026 earnings review
GeoPark funds its Argentine expansion, but hedge losses crush profit
GeoPark's oil hedges and rising Colombian field bills wiped out the benefit of higher crude prices this quarter. Unhedged crude sales rose 27% as Brent oil averaged $91 per barrel, but $36 million in cash hedge losses pulled total revenue down 7% to $116 million. Production and operating costs jumped 73% on surging Colombian electricity tariffs, pushing the Latin American oil producer into a pre-tax loss that only an Argentine inflation tax credit turned into a $7 million net profit.
| Revenue | $116.2M -7% from a year ago after $36.4M of hedge losses |
|---|---|
| Operating profit | $11.6M -64% from a year ago as field costs jumped 73% |
| Adjusted Ebitda (profit before interest, tax and depreciation) | $45.8M -36% from a year ago; 9-month total $190.2M |
| Share count after Nov 2 Venezuela deal | +78% 42.1M new shares give Grupo Gilinski 56.3% control |
⚖️ Verdict: 🔴 Bearish
The story got worse because cost inflation and hedge ceilings crushed cash margins just as a related-party deal diluted shareholders. On November 2, the company issued 42 million new shares — expanding its share count by 78% by our math — to buy a Venezuelan oil contract from its largest investor, Grupo Gilinski, giving Gilinski 56% control. On the positive side, an October $550 million bond sale pushed debt maturities out to 2033 and funded its growing Argentine shale business.
The question now is whether Argentine shale growth can outrun Colombian cost inflation and massive share dilution. Supporters see a funded Vaca Muerta drilling plan and new Venezuelan barrels, while skeptics see per-share value diluted by 42 million new shares and upside capped by oil hedges through 2027. Fourth-quarter barrel production rates and initial Venezuelan economics in the annual report will tell.
🐂 Bull Case
Bond Deal and New Block Back Argentina
GeoPark is building its Argentine shale business in the Vaca Muerta basin to offset older fields in Colombia, while critics worry about how it will pay for the multi-year drilling plan. In October, the Latin American oil producer priced $550 million of 9.5% senior notes due 2033, using the money to pay off all $94.7 million of its 2027 notes and buy back $266.8 million of its 2030 notes.
The company said it will use the remaining cash "to fund capital expenditures related to the development of the Group's Vaca Muerta assets and for general corporate purposes". It also won the Corralera Noreste block in Neuquén, committing about $95 million for a 90% operating stake. By our math, Argentina generated $13.9 million of revenue and $3.9 million of segment profit in the third quarter, up from $18.4 million across the entire first half.
What to watch: fourth-quarter Argentine production in barrels per day when the full-year operational release arrives. Reaching the 5,000 to 6,000 barrel year-end target would show the new wells are delivering on schedule.
Argentine Tax Credit Kept Bottom Line Positive
Higher operating expenses and oil hedge settlements pushed GeoPark into a loss before taxes of $5.8 million, compared with a pre-tax profit of $19.8 million a year ago. However, the company recorded a $12.4 million income tax benefit for the quarter, which allowed it to report $6.6 million in net profit.
That tax gain came from a $12.0 million deferred tax benefit in Argentina, where inflation adjustments lifted the tax value of its equipment and properties relative to the US dollar. In Colombia, the company also collected a $14.6 million income tax refund during the first nine months, which helped keep nine-month net income taxes paid positive at $8.5 million against $94.9 million of cash taxes paid a year earlier.
What to watch: the consolidated effective tax rate in the fourth-quarter report. A return to Colombia's 50% statutory tax rate without Argentine inflation credits would leave net profit exposed to pre-tax losses.
🐻 Bear Case
Hedge Ceilings Turned $91 Oil Into Losses
GeoPark uses oil price hedges — contracts that lock in a price floor and ceiling — as a standing policy to protect its spending budget, though the ceilings cap its revenue when crude rallies. Brent oil averaged about $91 per barrel in the third quarter and topped $100 in September, lifting the company's unhedged crude oil sales by 26.6% from a year ago to $152.6 million.
- Cash hedge losses in revenue: $36.4 million in the third quarter, vs a $1.5 million gain a year ago
- Total revenue after hedges: $116.2 million, down 7.1% from a year ago
- Derivative liabilities on the balance sheet: $165.2 million at September 30, up from $20.2 million in June
- Fourth-quarter three-way hedges: 25,000 barrels per day with call ceilings between $69.35 and $71.43
Because most 2026 ceilings sit near $71 to $72 per barrel, the oil producer paid out nearly a quarter of its crude revenue to hedge counterparties and settled $18.3 million in cash in October alone. Total derivative liabilities reached $165.2 million, "primarily driven by the increase in the forward oil price curve", while Brent reached $110 in October.
What to watch: fourth-quarter realized hedge losses in Note 3 of the annual report. With Brent near $110 in October and 25,000 barrels per day capped around $71, cash settlements will remain heavy.
Colombian Power Tariffs Lifted Field Operating Costs
Rising field expenses in Colombia have squeezed margins all year. In the third quarter, production and operating costs — the direct expense of pumping and treating oil — jumped 73.0% from a year ago to $57.5 million, climbing from 26.6% of revenue to 49.5% and cutting operating profit by nearly two-thirds to $11.6 million.
Consumables, the largest cost item, more than doubled to $19.3 million, adding 9.9 percentage points of revenue. The company blamed "higher electricity tariffs in Colombia associated with reduced hydroelectric generation, increased thermal generation and higher electricity demand", which pushed nine-month Llanos 34 power bills to $25.6 million from $11.5 million. Contracted staff and well maintenance also rose, and GeoPark paid $5.0 million in August for currency options to "mitigate its exposure to an appreciation of the Colombian peso against the US dollar".
What to watch: second-half lifting cost per barrel when GeoPark reports full-year operational figures. A reading above the $17 to $19 per barrel plan would show power and currency pressures are outpacing field savings.
Gilinski Takes Control Through Venezuela Share Deal
Investor Jaime Gilinski's Grupo Gilinski bought a 20% stake in GeoPark in March for $8.31 per share, raised it to 28% in April, and placed three directors on the nine-member board in July. That concentration raised questions about control and deal-making.
On November 2, GeoPark bought the remaining 95% of Energy Assets International (EAI), a company controlled by Grupo Gilinski that holds a 25-year contract with state oil company PDVSA for the Bare Block in Venezuela's Orinoco Oil Belt. To pay for it, the oil group issued 42.1 million new shares — expanding its outstanding share count by 78.1% by our math — so Grupo Gilinski "became GeoPark Limited's controlling shareholder with approximately 56.3% ownership". Up to 5.4 million more shares could follow by December 1, and bondholders received a fee to add Gilinski to the 2030 notes' permitted-holder list.
What to watch: whether GeoPark issues the additional 5.4 million shares after the December 1 contractual deadline and what capital spending the Venezuelan block requires in 2027.
Risks this quarter didn't answer
Because this report is an interim financial filing without an operational release or earnings call transcript, four standing operational and governance questions received no barrel or per-unit numbers this quarter.
- Llanos 34 natural decline and polymer flood: no injector count or field production rate is in the financial notes; the fourth-quarter operational update will test the nine-injector year-end target.
- Vaca Muerta well flow rates: Argentine revenue rose, but barrel-per-day rates from the first five horizontal wells are not in the filing and await the fourth-quarter operational release.
- Lifting cost per barrel: total dollar production costs rose in the quarter, but the per-barrel figure against the $17 to $19 second-half target requires the quarterly barrel count.
- Colombian community blockades: no disruptions were noted in the financial statements, leaving field uptime to be confirmed in the next operational report.
👓 Other Themes
Middle East Conflict Pushed Oil Above $100
Attacks on Middle Eastern energy facilities, Saudi Arabia's East-West pipeline and shipping in the Strait of Hormuz lifted Brent crude from $72 per barrel in July to over $100 in September and $110 in October. For GeoPark, the rally had mixed effects: higher prices lifted unhedged revenue, but also triggered higher price-linked Colombian royalties, a 15% tax surcharge, wider crude quality discounts, and large cash payments on oil hedges.
💲 Other KPIs
Free cash flow — operating cash flow minus property and equipment purchases — turned negative at -$51.7 million by our math, after generating +$60.1 million in the first half. Third-quarter capital spending reached $67.9 million (58.5% of revenue) while operating cash flow slowed to $16.3 million. Nine-month capital spending of $166.3 million tracks inside the $190–250 million full-year plan.
Net debt — total borrowings of $640.0 million minus $253.4 million in cash — rose from $317.8 million at the end of June as cash funded drilling and working capital. Current borrowings jumped to $199.2 million as the 2027 notes neared maturity and local loans in Colombia and Argentina reached $100.3 million, before October's $550 million bond sale refinanced the notes.
Uncollected customer bills rose 57.9% from $39.1 million at year-end 2025 and 18.8% from $51.9 million in June, even though third-quarter reported revenue fell 18.9% from the second quarter. The build in receivables contributed to a $34.9 million working-capital cash drain over the first nine months.
🔮 Guidance
Unchanged. The oil producer repeated in Note 18 that Colombia's hydrocarbon agency extended Phase 1 of the Llanos 86 block until December 19, 2027, with a commitment to drill one exploratory well. In Brazil, regulators confirmed in September that the company fulfilled its exploratory commitments on three blocks. The interim financial report did not include updated full-year production, cost or capital spending ranges.
❓ Key Questions
What will the Venezuelan Bare Block cost to develop?
GeoPark issued 42.1 million shares — expanding its share count by 78% — to acquire the Bare Block from its now-controlling shareholder Grupo Gilinski, but disclosed no current production, reserves, or 2027 capital spending commitment for the Venezuelan asset.
Where did third-quarter barrel production and lifting costs land?
The interim financial report shows production and operating costs up 73% to $57.5 million and Argentine revenue at $13.9 million by our math, but omits barrel-per-day output and per-barrel lifting cost against the $17–19 second-half target.
How much cash will oil hedges drain at $110 Brent?
With Brent reaching $110 in October and 25,000 barrels per day capped near $71 in the fourth quarter, investors need the expected fourth-quarter cash hedge settlement and whether the >$250 million full-year profit floor still holds.
How will GeoPark fund the $95 million Corralera NE commitment?
Adding a $60.5 million access bonus and two horizontal wells at Corralera Noreste comes on top of the existing Vaca Muerta drilling plan and the new Venezuela venture, raising the multi-year capital requirement.