EOG Resources, Inc. Q3 FY2025 earnings call

• The acquisition of Encino in early August strengthened the portfolio, adding a third high-return asset. - Third quarter operational performance was outstanding with volumes exceeding guidance, costs below guidance, resulting in $1.4 billion free cash flow. - Strategic priorities include capital discipline, operational excellence, sustainability, and culture. - Differentiators: diverse high-return portfolio, focus on lowering breakeven costs, commitment to sustainable free cash flow, and strong financial strength. - Operating results: Utica integration progressing well with efficiency gains, Delaware Basin wells performing as designed with cost reductions, Eagle Ford economics improving, Trinidad Mento program initial results positive, international exploration in UAE and Bahrain advancing, service costs softening but high-spec services resilient.

For the third quarter 2025, oil, natural gas, and NGL volumes exceeded the midpoints of guidance. Capital expenditures, cash operating costs, and DD&A came in below guidance midpoints. Free cash flow totaled $1.4 billion. Through the first 3 quarters of 2025, EOG generated $3.7 billion in free cash flow. The Encino acquisition strengthened the portfolio, diversifying the production base and accelerating free cash flow generation.

• 2025 full-year free cash flow forecast increased to $4.5 billion, a $200 million increase from previous forecast. - Q4 CapEx run rate considered a starting point for 2026 planning, though market is dynamic. - Continued investment in gas play, international exploration, and Dorado asset with focus on returns-focused investments.

• Spare capacity returning to the oil market causing near-term oversupply concerns. - Evolving geopolitical risks impacting oil prices. - Service cost softening in the market with tariffs on non-casing steel products affecting high-spec equipment costs.

Q: One macro, one micro question about oil and gas outlooks.

A: Ezra discussed oil spare capacity returning causing near-term oversupply but medium-term bullish due to reduced spare capacity and demand growth; natural gas has LNG feed gas and electricity demand growth as bullish drivers.

Q: Follow-up on Delaware Basin well productivity.

A: Jeff stated Delaware Basin wells performing as designed, with cost reductions, new targets having outstanding economics with payback periods <1 year and rates of return >100% at current prices.

Q: Talk about 2026 plans and portfolio considerations.

A: Ezra mentioned Q4 CapEx run rate as a starting point, with focus on oil no to low growth, continued investment in gas play and international exploration.

Q: Driver of cost guidance drop.

A: Jeff said operating expenses across the board were better than expected, with LOE, GP&T, G&A, and DD&A all coming in below midpoint.

Q: Thoughts on free cash flow allocation and buybacks.

A: Ezra said balance sheet is strong to return close to 100% of free cash flow, with buybacks compelling at current valuations.

Q: Inventory and exploration management.

A: Ezra discussed multi-basin operations as strategic advantage, exploration as cornerstone of strategy with focus on bypass reserves.

Q: Dorado activity and Bahrain exploration.

A: Ezra said Dorado pace governed by full cycle returns, Keith Trasko discussed early days in Bahrain exploration with positive momentum.

Q: Buyback temperature and Utica base production.

A: Ezra said valuations are compelling for buybacks; Jeff discussed Utica base production improvement from integration, efficiency gains, and artificial lift optimizers.

Q: Optimization and lower operating costs.

A: Jeff said it's broad-based across portfolio using data and analytics to minimize downtime.

Q: Appetite for expansion and AI integration.

A: Ezra discussed organic expansion through returns-focused lens; Ezra talked about AI integration in operations and exploration, with in-house development of proprietary apps.