Equinor ASA Q3 FY2026 earnings call

• Production Growth & Guidance: Equinor increased its full-year production growth guidance from 3% to approximately 4%, driven by strong operational execution, high regularity, and better-than-expected decline management at Johan Sverdrup. International production grew 5%, with Bacalao now at plateau production. Renewable power production surged 26%, led by Doggerland, though Empire Wind is slightly delayed with first power expected in H1 2027.
• Strategic Acquisitions & Partnerships: Signed an agreement to acquire a stake in the Lackawanna Energy Center in the US, strengthening its position in the US power market. Partnered with Shell on the Beirut Nord project in Canada, targeting a Final Investment Decision (FID) early next year. Entered Namibia with drilling plans and secured new exploration acreage in Angola and Brazil.
• Financial Strength & Capital Allocation: Reported robust cash flow from operations of $14.7 billion in Q3. Ended the quarter with $24 billion in cash and a net debt ratio of 3.8% (excluding tax lag effects). Board approved a quarterly dividend of 39 cents per share and continued share buybacks, aiming for $3 billion in total buybacks for 2026.
• Safety & Costs: Safety remains a top priority; while long-term trends are improving, there has been an increase in personal injuries since last year. Underlying cost reduction targets of 10% for the year are somewhat behind schedule due to foreign exchange effects and higher energy consumption costs, but discipline remains enforced.
• Balance Sheet Management: Intends to maintain a solid balance sheet to navigate price cycles. While current net debt is low, adjusting for the Norwegian tax lag, the effective net debt ratio is expected to be around 10% by year-end.

The provided transcript does not break down financial performance by specific product segments (e.g., Upstream, Downstream, Renewables) with explicit revenue contribution percentages. However, it highlights the following key financial aggregates for the group: Adjusted operating income was $12.4 billion before tax (up significantly from the prior year). Cash flow from operations after tax was $8.1 billion in Q3, bringing YTD total to $21.8 billion. Adjusted earnings per share were $1.20. The Mongstad Refinery (M&P segment) delivered record results driven by strong refining margins and operational performance, performing well above guidance. LNG contributed positively, while Power results were close to zero. E&P US saw higher realized liquid prices partially offset by turnaround activity at Caesar Tonga and a $105 million impact from Titan asset retirement obligations.

• Production: Increased full-year 2026 production growth guidance from 3% to approximately 4%. 2027 production will be lower than the extraordinary 2026 levels but higher than 2025, building towards 2030 goals.
• Cash Flow: Updated full-year 2026 Cash Flow from Operations (CFO) expectation to approximately $29 billion, up from previous guidance of $25 billion, based on current forward commodity prices which are above the assumptions used previously.
• Capital Expenditure: Maintained organic CAPEX guidance of approximately $13 billion for 2026. Noted that currency effects may exert upward pressure on costs, while some schedule delays (e.g., Empire Wind) may push CAPEX into 2027.
• Shareholder Returns Framework: Introduced a new capital distribution framework for 2027 onwards. Dividends are the first priority, with an expected annual increase of more than 5%. Share buybacks are structured as a flexible tool: $2–4 billion annually if oil is between $60–$80/bbl and European gas is between $7–$11/Mbtu. Buybacks will be announced quarterly rather than annually. If prices exceed these ranges, buybacks may increase non-linearly, but management prioritizes balance sheet strengthening over excessive cyclical payouts.

• Safety Incidents: An increase in the number of personal injury incidents compared to the previous year remains a critical operational risk and focus area.
• European Gas Market Vulnerability: European gas storage is at its lowest level since 2011 (73%), creating a tight market with little flexibility. Risks include potential volatility from weather events (El Niño impacts already priced in), Asian LNG demand, and geopolitical tensions affecting LNG shipping through the Strait of Hormuz.
• Tax Liability Timing: High commodity prices have resulted in significant tax installments in Norway. A six-month tax lag means substantial tax payments will occur in H1 2027, impacting liquidity timing despite strong earnings.
• Project Delays: Empire Wind offshore turbine installation is delayed, pushing first power to H1 2027, although total CAPEX and Investment Tax Credit (ITC) recognition remain unchanged.
• Cost Discipline Challenges: Foreign exchange fluctuations and higher internal energy consumption costs are hindering progress on the 10% underlying cost reduction target.

Q: Chris Coupland asked about the source of the increased production guidance and updated CFO expectations given current high commodity prices. / A: Torgrim Reitan attributed the production increase to strong operations, high regularity, and better-than-expected decline management at Johan Sverdrup, with Bacalao now at plateau. Regarding CFO, he updated the full-year 2026 expectation to ~$29 billion (up from $25B) based on forward prices, noting that significant taxes associated with this high revenue will be paid in H1 2027.

Q: Henri Patricot questioned whether Johan Sverdrup’s performance was extraordinary and what to expect for buybacks if net cash grows significantly. / A: Reitan stated Johan Sverdrup’s decline is consistent with reservoir behavior (11% YTD vs. 10-20% guided) but will accelerate in 2027. On buybacks, he emphasized that while the $24B cash position is high, the cost of carry is low. The priority order is dividends, reinvestment, then a strong balance sheet, with buybacks as the flexible tool. They intend to run a solid balance sheet through cycles.

Q: Alejandro Vigil asked about the European gas winter outlook and M&A opportunities given the US-EU gas price gap. / A: Reitan highlighted a vulnerable European gas market with low storage (73%) and limited LNG flows due to geopolitical risks, leading to potential volatility. On M&A, he confirmed active participation linked to strategy, citing recent acquisitions like Lackawanna that integrate gas and power markets, expecting further integration of these sectors.

Q: Michele della Vigna asked about crude realization premiums in Norway and the status/timing of ITCs for Empire Wind. / A: Reitan noted significant premiums for NCS oils in Europe (e.g., $2 premium for Johan Sverdrup, $8 for Johan Castberg) due to quality and short sailing distances. For Empire Wind, he confirmed 80% completion with turbine installation starting post-Christmas and first power in H1 2027. The $2.5B ITCs will be recognized primarily in 2027 ($2B) and 2028 ($0.5B), aligning with prior guidance.

Q: Jon Olaysen asked for Equinor’s competitive advantages in owning US gas-fired power plants compared to other players. / A: Reitan cited three main advantages: a large, long-term US gas position providing supply security; a strong trading and marketing operation in Stamford familiar with PGM markets; and a strong balance sheet allowing them to act as a long-term partner for data center/AI customers seeking integrated energy solutions.