ExxonMobil Holdings Corp 10-Qquarter ended 2026-06-30
Positive
Supply disruptions boosted refining margins but cut volumes; Guyana and Permian growth helped drive the earnings surge.
Filed 2026-08-03 14:55 ET
Key figures · Q2 FY2026 · period ended 2026-06-30
- Revenue$116.0BYoY +42.3%QoQ +36.3%
- Operating income— Not reported
- Net income$14.5BYoY +105.1%QoQ +247.2%
- Total assets$464.5BYoY +3.8%QoQ 0.0%
- Total debt$42.4BYoY +8.7%QoQ −11.1%
How total debt adds up Long-term debt $32,229M + Notes and loans payable $10,139M Total debt $42,368M Lines as the filer presents them on its balance sheet.
- Shareholders' equity$259.4B1YoY −1.2%QoQ +2.0%
- Tangible book value— Unavailable
Notes (1)
- Shareholders' equity: About the summary: The summary's $266B is total equity including noncontrolling interests; shareholders' equity of $259.38B excludes noncontrolling interests.
How this filing reads
- Health+0.8H1 operating cash flow was $32.3B against $13.0B of investment; debt-to-capital was 13.7%.
- Momentum+0.4H1 revenue rose 22% and net income 26%, while production declined 2.5% year over year.
- Outlook0.0Management plans $27B–$29B of 2026 investment; refining margins remain vulnerable to supply normalization.
Executive Summary
ExxonMobil’s Q2 2026 earnings more than doubled to $14.5B, driven by higher commodity prices, unusually strong refining margins, and growth in Guyana and the Permian—not broad-based production growth. The integrated business benefited from supply disruptions that lifted margins, even as those disruptions reduced its own volumes and triggered financial-reserve and impairment charges. H1 operating cash flow of $32.3B funded capital investment and shareholder distributions, while repurchases reduced outstanding shares by 1.6%. For investors, the distinction is between durable contributions from advantaged projects and cost savings, and less-repeatable benefits from exceptional margins and derivative timing.
Key Financial Highlights
| Metric | Q2 2026 | H1 2026 / period-end | Investor interpretation |
|---|---|---|---|
| Revenue and other income | $116B, +42% Y/Y | $201B, +22% Y/Y | Pricing and trading-related revenue drove growth despite lower operating volumes. |
| Net income | $14.5B, +105% Y/Y | $18.7B, +26% Y/Y | Earnings accelerated sharply in Q2. |
| Diluted EPS | $3.48 vs $1.64 | $4.47 vs $3.40 | A smaller share base amplified earnings growth. |
| Operating cash flow | — | $32.3B, +32% Y/Y | Cash exceeded earnings principally because of noncash expenses. |
| Free cash flow | — | $19.3B, +56% Y/Y | Operating cash flow less property, plant and equipment additions covered shareholder distributions. |
| Total assets / total equity | — | $464B / $266B | Assets increased 3.5% from year-end; equity was broadly flat. |
| Debt / cash | — | $42.4B / $10.6B | Debt declined 2.5%; debt-to-total-capital was 13.7%. |
- Cash conversion: H1 depreciation and depletion of $15.5B helped explain operating cash flow exceeding net income, while working capital absorbed $3.86B; property, plant and equipment additions were $13.0B.
- Capital return: H1 repurchases of $10.0B and dividends of $8.63B consumed nearly all free cash flow; outstanding shares declined from 4.179B to 4.112B, demonstrating genuine share-count reduction.
- Earnings timing: Energy Products’ derivative mark-to-market timing added $2.56B to Q2 earnings but reduced H1 earnings by $0.770B; the quarter’s benefit should not be extrapolated.
- Identified charges: H1 Upstream financial-reserve losses were $1.20B; Energy Products identified-item losses were $1.89B, mainly impairments and disruption-related hedge effects.
- Tax contribution: The Q2 effective tax rate fell to 24% from 34%, primarily because of geographic mix, supporting earnings beyond operating improvements.
Business Developments
- Advantaged growth: Guyana and Permian growth added $1.14B to Q2 Upstream earnings, but total production declined 2.5% Y/Y to 4.51M barrels of oil equivalent per day as disruptions offset expansion.
- Refining and product mix: Q2 refinery throughput fell 9.5%, while Energy Products sales increased 2.0%; stronger margins, rather than higher refinery utilization, drove the earnings uplift.
- Cost discipline: Structural savings reached $16.3B cumulatively against 2019, including $1.2B in H1, but cash operating expenses excluding energy and production taxes still rose to $21.9B from $20.8B as activity and market costs outweighed savings.
- Corporate structure: Redomiciliation to Texas completed on 7/1/2026 through a one-for-one share exchange, without changing ownership interests, consolidated operations, or financial reporting.
Risk Assessment
- Commodity and margin normalization: Refining margins were sharply above their historical range, making current profitability vulnerable to restored supply and weaker pricing.
- Geopolitical disruption: Middle East disruptions reduced H1 Upstream earnings by $1.28B and prevented physical shipments associated with some hedges, exposing both operations and trading relationships.
- Derivatives and counterparty exposure: Trading contracts generated $2.3B of H1 before-tax realized and unrealized losses vs $0.534B of gains; netting limits reported balances but does not eliminate settlement or counterparty risk.
- Chemical weakness: Asia-Pacific softness constrained growth despite North American feedstock advantages; Q2 chemical sales fell 15% Y/Y.
- Investment execution: Inflation, supply-chain constraints, permitting, and uncertain commercial scalability can impair returns on conventional and lower-emissions projects.
A 10-Q does not have to restate the risk factors in the annual report. Full list: FY2025 10-K.
Strategic Outlook and Investor Actionables
Management prioritizes Guyana, the Permian, liquefied natural gas, higher-value products, and cost reductions, with planned 2026 investment of $27B–$29B. Lower-emissions opportunities remain conditional on policy support, technology, permitting, and returns—not committed growth.
- Monitor earnings durability: Sustained segment earnings as refining margins and derivative timing normalize would confirm underlying improvement.
- Monitor production conversion: Growth beyond H1’s 4.55M barrels of oil equivalent per day would show advantaged projects overcoming disruptions and base declines.
- Monitor capital coverage: Free cash flow covering dividends and repurchases while investment accelerates would support continued distributions without increasing leverage.
Figures are computed from the filing's XBRL data; the summary and scores are written by an AI model reading the filing.
Model 006 · prompt 18882ea63d