EOG Resources (EOG) Q3 2026 Earnings Call: Q&A Summary

Q: Neil Mehta with Goldman Sachs asked for details on the mechanically how the new JKM-linked gas sales agreement works and the potential cash flow uplift.

A: Jeff Hibbard explained that the 10-year, 140,000 MMBtu per day agreement with Engie starts by 2030, features deducts, has offtake at the U.S. Gulf Coast, and increases LNG feed gas volumes to over 1 Bcf gross per day by 2030.

Q: Scott Hanold with RBC Capital Markets asked how EOG secured the contract in current market conditions and whether international market exposure will continue to expand.

A: Jeff Hibbard stated that U.S. LNG projects seeking FID and expanding markets created this opportunity, and EOG's low-cost multi-basin portfolio and strong balance sheet make them an attractive counterparty for similar deals going forward.

Q: Neil Mehta with Goldman Sachs asked about EOG's view on corporate M&A versus bolt-on transactions as commodity prices normalize.

A: Ezra Yacob responded that EOG's long-term strategy remains focused on organic exploration and first-mover technology, while selectively pursuing small bolt-on deals without large production loads rather than corporate M&A.

Q: Stephen Richardson with Evercore asked where EOG is seeing cost inflation for 2027 and how the company is positioned to absorb it.

A: Jeff Leitzell noted that while diesel and steel costs are elevated and service markets have tightened, EOG is offsetting headwinds through 3% to 5% annual efficiency gains, staggered contract timings, 60% of 2027 services already contracted, and direct sourcing of steel.

Q: Stephen Richardson with Evercore asked about EOG's willingness to take on additional pipeline or beyond-the-wellhead infrastructure projects.

A: Ezra Yacob explained that EOG typically prefers partnering with others, but steps into infrastructure like the Janus expansion at cycle peaks when fees rise to capture margins and synergies.

Q: Kevin MacCurdy with Pickering Energy Partners asked about underappreciated Texas gas market fundamentals and the strategy for ramping Dorado.

A: Ezra Yacob highlighted that North American gas is transitioning from weather-driven demand to a market driven by AI-powered electricity, LNG exports, and grid reliability, placing EOG and Dorado in an advantageous position.

Q: Joshua Silverstein with UBS asked if EOG is exploring domestic gas supply agreements in the Utica for data centers and power generation.

A: Ezra Yacob stated that EOG is actively discussing direct gas supply with data centers, hyperscalers, and power generators across their multi-basin footprint.

Q: Doug Leggate with Wolfe asked for color on the Alaska acreage play concept and recent permitting around the Pearsall Shale in South Texas.

A: Ezra Yacob described the Alaska play as a conventional Schrader sand oil prospect identified seismically and noted that 3D data will be purchased next year, while the Pearsall play in South Texas has captured about 100 locations though well costs still need reduction to compete with core inventory.

Q: Doug Leggate with Wolfe asked if the portfolio has the duration of free cash flow required to sustain dividend growth.

A: An unnamed executive answered that EOG has high confidence in the regular dividend based on low breakevens below $45 WTI, $12 billion BOE of resource, and a 20% compound annual growth rate over 28 years.

Q: Phillip Jungwirth with BMO asked how EOG is tracking against its 3-year scenario after year one and what activity is needed to drive low single-digit growth in 2027.

A: Ezra Yacob stated that activity levels remain consistent with Q4 run rates, with capital expenditures including the $200 million planned for the Janus expansion in 2027, while commodity prices and free cash flow generation for year one have exceeded forecasts.

Q: Leo Mariani with ROTH asked if the UAE concession will contribute to 2027 low single-digit oil growth.

A: Jeff Leitzell noted that while the UAE results are strong, volumes for next year will remain minimal as the project is still in the exploration phase.

Q: Phillip Jungwirth with BMO asked about the bigger drivers behind better or consistent well productivity across all plays in 2026.

A: Keith Trasko explained that productivity gains are driven by high-intensity completions, added horsepower, smart testing, and applying continuous operational learnings across the Delaware, Eagle Ford, Utica, and Dorado basins.

Q: Scott Hanold with RBC Capital Markets asked how EOG will manage commodity volatility to hit its annual 70% free cash flow return threshold.

A: Jeff Hibbard reiterated confidence in meeting the 70% commitment, noting that at $88 WTI and $3.40 Henry Hub, EOG expects to return $6.8 billion, favoring share repurchases due to the stock's value.

Q: Leo Mariani with ROTH asked if EOG is making a larger strategic pivot towards natural gas later in the decade.

A: Ezra Yacob clarified that EOG is not making a big call on gas, but rather developing Dorado as the lowest-cost North American gas asset at a disciplined pace to operate a premium gas business alongside its core oil portfolio.

Q: Arun Jayaram with JPMorgan asked how EOG is capturing premium realizations on the oil side.

A: Jeff Leitzell credited the embedded marketing team providing flexibility and diversification, along with exporting 200,000 to 250,000 barrels per day to capture strong international pricing premiums.

Q: Arun Jayaram with JPMorgan asked about EOG's strategy for inventory renewal and offsetting drilled wells in the Delaware Basin.

A: Keith Trasko stated that detailed geologic work has allowed EOG to identify up to 17 unique target zones and add new targets to existing development, maximizing asset value without relying on large external acreage additions.

Q: Bob Brackett with Bernstein Research asked how the conversion of the Aldafra concession from exploration to production works regarding acreage retention and field development plans.

A: Ezra Yacob explained that the path to commerciality involves a field development plan and annual reviews negotiated with the host government, with strong initial well results keeping EOG well on track to target commerciality before the exploration agreement expires.

Q: Kevin MacCurdy with Pickering Energy Partners asked about the rationale behind selling Barnett and Woodford assets and future U.S. portfolio streamlining.

A: Jeff Hibbard stated that the Barnett and Woodford assets were divested to high-grade the portfolio and pull value forward, and while no additional sales are currently planned, EOG continuously evaluates assets against return hurdles.

Q: Joshua Silverstein with UBS asked for an update on oil and liquids midstream infrastructure projects in the Utica.

A: Jeff Leitzell noted that gas processing capacity is ample, while on the oil side, EOG is having constructive conversations regarding takeaway, blending lighter and heavier molecules to improve differentials, and connecting to pipe.