Chevron Corp. Q3 FY2026 earnings call

Operational Performance:

• Upstream production reached nearly 4 million barrels of oil equivalent per day (boepd), with U.S. upstream production exceeding 2 million boepd for five consecutive quarters.
• Achieved record crude throughput in the U.S. refining system.
• Venezuela joint ventures produced one month of output following a change to equity accounting; production is on track to reach ~300,000 bpd by year-end, up 20% YoY.
• Natural gas production set a new quarterly record at over 9 billion cubic feet per day.
• Permian Basin maintained sixth consecutive quarter above 1 million boepd.

Technology and AI Integration:

• Deployed AI in the DJ Basin to anticipate downtime, reducing lost production events by 50%.
• Utilized proprietary AI tools (APEX and Scout AI) to accelerate basin assessments from months/weeks to hours, identifying over 150 leads in the Gulf of America.
• Captured more than $100 million in value from AI initiatives year-to-date.
• Deployed a proprietary catalyst increasing distillate yields by over 10% at largest U.S. refineries.

Strategic Developments:

• Announced plans to double Venezuela production to ~600,000 bpd by 2031 via self-funding, low-cost (<$20/bbl) primary recovery.
• Expanded acreage and established new fiscal terms in Venezuela, making it immediately accretive and free cash flow positive.
• Reduced Bakken midstream tariffs by 50%, expanding economic inventory and competitiveness.
• Completed commissioning of a Louisiana oilseed processing plant joint venture with Bungie.
• Added 22 million acres globally over two years, doubling the exploration footprint.

Refining and Chemicals:

• Over 80% of U.S. refinery turnarounds completed with first-quartile duration.
• Increased capacity at TCO by 20% (total >1 million bpd), Ballymore by 7%, and Anchor by 33% (25,000 bpd).
• Advanced chemicals production in the Permian increased cumulative oil equivalent production by up to 23% in the first 12 months.

Financial Discipline:

• Organic capex was $3.9 billion in the quarter.
• Net debt coverage ratio improved to 0.4 times net debt to SafeFO.
• Reduced debt by more than $3 billion and grew cash by more than $4 billion.

The provided transcript does not contain explicit financial breakdowns by specific product segments (e.g., Upstream vs. Downstream revenue contributions in absolute terms and percentages). However, the CFO notes that adjusted upstream earnings decreased due to lower realizations and liftings, while adjusted downstream earnings increased primarily due to higher refining margins and volumes. Overall, Chevron reported total earnings of $9.9 billion ($5.06 per share) and adjusted earnings of $10.4 billion ($5.28 per share). Cash flow from operations excluding working capital was $16.6 billion.

• Fourth quarter organic capex is expected to increase compared to Q3 but will still finish the year at the low end of annual guidance.
• No changes announced to the long-term capital allocation framework or dividend growth commitment.
• Share repurchase rate maintained within the range of $2.5 billion to $3 billion.
• Exploration spend is planned to increase by 50% relative to 2025 levels.
• Full-year 2026 performance remains strong, though specific full-year numerical guidance details were deferred to the appendix/slides not included in the text.

• Volatile commodity markets: Brent crude spread experienced extreme volatility in Q3 (ranging from $68 to $132/bbl), impacting working capital and timing effects.
• Geopolitical and Above-Ground Risks: Management acknowledges risks in Venezuela and Kazakhstan, mitigated through stable contract clauses, international arbitration provisions, and community engagement.
• Regulatory and Permitting Risks: Project Kilby’s expansion depends on securing additional permits for behind-the-meter power generation.
• Operational Disruptions: Potential non-operational disruptions in peer assets (e.g., Permian NOJV workover rigs) could impact market dynamics, though Chevron’s own operations remain stable.
• Market Normalization Risks: Refining and petrochemical margins may moderate as global refinery runs recover and export flows normalize, potentially leading to oversupply if project deferrals persist.

Q: Analyst asked about cost structure and risk management in Venezuela, noting initial cost estimates were lower than expected. / A: CEO Mike Wirth stated risks are managed via competitive fiscal terms, stability clauses, and strong community support. CFO Eimear Bonner confirmed total costs (CapEx + OpEx) are under $20/bbl. The project is factory-like, self-funding, requires no major infrastructure upgrades, and controls its own revenue flow, eliminating exposure to prior debts or marketing intermediaries.

Q: Analyst inquired about the progress and ideal outcome of the TCO (Kazakhstan) concession extension negotiations amid media speculation. / A: CEO Wirth confirmed good progress with technical, commercial, and legal teams meeting regularly. Core issues have narrowed to reasonable items expected after 35 years. The goal is a win-win: competitive returns for partners and responsible stewardship for the Republic. No red flags exist, and updates will be provided upon milestones.

Q: Analyst asked about the financial impact and strategic view of the Bakken asset following midstream contract restructuring. / A: Vice Chairman Mark Nelson highlighted a 50% tariff reduction expands inventory and flexibility. The shift to two rigs while sustaining 180,000 boepd/d improves efficiency. CFO Bonner noted the deal increases corporate ROCE by 0.5%, deconsolidates $3.7 billion of debt, and delivers incremental recurring cash flow, improving back-end earnings and cash flow by 2027.

Q: Analyst asked if the strengthened balance sheet would lead to a change in capital allocation priorities for next year. / A: CFO Bonner stated no change to the longstanding framework: prioritize consistent dividend growth, efficient investment (trending to low end of capex guidance), maintain strong balance sheet, and execute $2.5B-$3B share buybacks. CEO Wirth added that 2027 capital program details will be shared in December after board meetings.

Q: Analyst asked about the potential for LNG debottlenecking in Australia (Gorgon/Wheatstone) similar to upstream/refining efforts. / A: Vice Chairman Nelson viewed debottlenecking as a mindset enabled by centralized project activity. While Gorgon and Wheatstone are already above nameplate, the focus is on world-class reliability and competitive backfill projects. CEO Wirth confirmed significant debottlenecking has already occurred there and offered to share details offline, emphasizing continued reliability and capital-efficient capacity expansion.