EOG Resources, Inc.

In the second quarter, EOG reported adjusted EPS of $5.07, adjusted cash flow from operations per share of $8.29, and free cash flow of $2.8 billion, all described as record results. The company returned just over $1.8 billion to shareholders, including $540 million in regular dividends and $1.3 billion in share repurchases. Cash ended the quarter at $4.9 billion, up about $1.1 billion from Q1, with net debt of $3 billion. For 2026, EOG kept capital expenditures unchanged at $6.5 billion and expects 5% oil production growth and 14% total production growth. Management said the 2026 plan generates $8 billion in free cash flow at strip pricing and midpoint guidance and carries a WTI breakeven below $50 per barrel.

Ezra Yacob framed the quarter as proof that EOG’s business model is working across cycles, citing durable execution, a low-cost multi-basin portfolio, and a strong balance sheet. He emphasized organic exploration as a core competitive advantage and highlighted the UAE as evidence that EOG’s operating model can translate outside North America. His tone was constructive on oil and gas fundamentals, but disciplined on capital allocation and still cautious about giving specifics for 2027 planning.

Ann Janssen focused on the financial strength of the quarter: record adjusted EPS of $5.07, adjusted CFO per share of $8.29, and free cash flow of $2.8 billion. She highlighted shareholder returns of just over $1.8 billion in the quarter, $11.7 billion remaining on the buyback authorization at June 30, and the commitment to return at least 70% of annual free cash flow to shareholders in 2026. She also noted $4.9 billion in cash, net debt of $3 billion, and said the company’s 2026 plan generates $8 billion in free cash flow at strip pricing and midpoint guidance, with a WTI breakeven below $50 per barrel.

Analysts pressed management on whether EOG would continue shifting capital toward oil-prone assets next year; Ezra said the 2026 plan is unchanged, but for 2027 the company is thinking in terms of a 3-year scenario that implies low single-digit oil growth and assumes $60 to $80 WTI. Questions on the UAE focused on commercialization timing, returns, and the role of ADNOC back-in rights; management said the project is still in a 3-year exploration phase, with no strict timeline, and that return hurdles already incorporate subsurface quality, operating environment, political risk, and partner alignment. Analysts also asked about the Austin Chalk, Permian productivity, Canada, and Delaware infrastructure; management said the Chalk is a real sweet spot with about 125 remaining 2-mile locations, Delaware productivity gains are coming from incremental technical improvements rather than a single design change, and Janus remains a strategic lever if midstream conditions tighten again.