ExxonMobil (XOM) Q3 2026 earnings review
Exxon's refining profit more than doubles, but its production shrinks
Exxon earned more from making fuel than from producing oil, while its oil and gas output kept falling. A global shortage of diesel took its refining margin marker to a record $50 a barrel, and profit per share excluding one-offs reached $4.23, more than double a year ago. Chief executive Darren Woods said the shortage will last well through next year.
| Profit per share, excluding one-offs | $4.23 $3.52 last quarter; about $1.84 a year ago by our math |
|---|---|
| Refining profit, excluding one-offs | $9.1 billion $4.1 billion last quarter |
| Oil and gas production | 4.50 million barrels a day −5.7% from a year ago |
| 2027 share buybacks | $20 billion new; same pace as 2026 |
⚖️ Verdict: 🟢 Bullish
The story got better because the windfall is lasting longer than one quarter and Exxon put it into debt repayment and next year's buyback; net debt is 7.5% of capital, from 13% in March. One caution: prices and margins explain all of this year's profit growth, so the case still rests on a shortage that ends when Middle East and Russian refineries return.
The question now is how much refining profit survives a reopened Strait of Hormuz. Either lost Middle East, Russian and Chinese supply keeps markets short into 2027, or the $50 marker falls back within a quarter. The marker in the January report will tell.
🐂 Bull Case
Refining Profit More Than Doubled in a Quarter
Energy Products, the segment that turns crude into gasoline, diesel and jet fuel, has become Exxon's biggest earner. Refineries in Russia and the Middle East stayed shut, with "roughly 10 percent of global capacity offline", so the company's own refining margin marker reached a record $50.3 a barrel.
Exxon's refineries answered by running flat out. Its US Gulf Coast crude units ran at 100%, and the group posted its second-highest Gulf Coast diesel volume on record. The segment earned $9.1 billion excluding one-offs, up from $4.1 billion last quarter.
- Refining margin marker: $50.3 a barrel, from $29.0 last quarter and $17.5 a year ago
- Profit per barrel processed: about $26, against about $4 for all of 2025
- Capture: by our math each extra dollar of margin added $233 million in the quarter, above the $200 million the company's own sensitivity implies
- Traded volumes: about four times the 2019 level, Exxon says
This matters because the quarter tests a claim Exxon has made for years: that $17 billion of refining investment since 2019 and $3 billion of structural savings built a business that earns more at any margin. The capture rate says yes. Production and manufacturing expenses fell to 9.9% of revenue from 11.8% a year ago. The reason was higher revenue, not lower spending, because that expense line itself rose 11%.
What to watch: the refining margin marker in the fourth-quarter report, against $50.3 now. A reading that stays above $30 while the Strait of Hormuz remains shut would show that the shortage, not one quarter's trading, sets the margin.
Net Debt Fell $9.7 Billion in Three Months
Exxon pays a dividend it has raised for 44 straight years and buys back about $20 billion of stock a year, and it keeps both going when prices fall. Chief executive Darren Woods told analysts "we're not going to ever cut our dividends", so the balance sheet has to carry that pledge through the bottom of the cycle.
This quarter the cash arrived: free cash flow reached $19.1 billion, twice the $9.4 billion paid out in dividends and buybacks. The rest went to debt. Net debt fell by $9.7 billion in the quarter by our math. It now equals 7.5% of capital, down from 11% in June, which the company calls the lowest ratio among the large oil majors.
- Net debt: $22.1 billion, from $31.8 billion in June and $32.9 billion at year end
- Shareholder returns: $28.0 billion so far this year, $15.1 billion of it buybacks
- Dividend: raised 4% to $1.07 a share
- 2027 buybacks: $20 billion, the same pace as this year
The 2027 buyback decision matters more than the debt paydown, because Exxon set it before knowing where refining margins settle, and it warned that purchases may not fall evenly across the four quarters. So the balance sheet, not the margin, now stands behind the promise.
What to watch: the 2027 planning metrics Exxon promised in a press release before year end, in particular where cash capital spending lands inside the $28–32 billion range. A figure at the top, alongside $20 billion of buybacks, would mean the balance sheet rather than the shortage is funding both.
Permian Holds 1.8 Million Barrels With Automated Rigs
The Permian Basin in Texas and New Mexico is Exxon's largest growth asset, and the company plans to lift it from about 1.8 million oil-equivalent barrels a day this year to 2.5 million by 2030. Production "remained just above 1.8 million oil-equivalent barrels per day" in the quarter, so Exxon has met this year's target.
Woods told analysts that Exxon alone runs automated drilling rigs in the Permian and will expand them to about half of its fleet by 2028. Finance chief Neil Hansen said synergies from the Pioneer acquisition have doubled to $4 billion a year.
This matters because the 2030 plan needs the basin to grow about 9% a year, and Woods says the volume target is not the point: the test is whether new technology lifts recovery per well. He conceded the benefit "just takes time for that to manifest itself in the portfolio" in a field this size.
What to watch: the 2027 Permian figure in the planning press release due before year end. The 2030 path needs about 1.96 million barrels a day next year by our math, so a lower number would mean the rigs are cutting cost rather than adding barrels.
🐻 Bear Case
Output Falls While the Plan Still Says Growth
Exxon produced 4.50 million oil-equivalent barrels a day, 5.7% less than a year ago and the lowest figure in seven quarters. The decline came from three places: the Middle East, where war keeps about 350,000 barrels a day offline; Guyana, where the contract now gives the group a smaller share of each barrel; and asset sales.
Guyana is the part Exxon warned about. Once partners recovered their $55 billion of investment, the share of output that repays costs fell, and management flagged a step of about 100,000 barrels a day this quarter. It arrived: entitlement effects took 87,000 barrels a day off from the previous quarter, which the company labels "Lower advantaged volumes with accelerated Guyana entitlement impacts".
Woods says that, excluding the Middle East, production rose from a year ago, and the fifth Guyana development, Uaru, starts in the fourth quarter. But Exxon's own slide still shows a full-year plan of about 4.9 million barrels a day, against 4.53 million so far this year. By our math the fourth quarter would need 6.0 million to get there, and the group has not given a figure adjusted for the disruption.
What to watch: the 2026 production figure in the planning press release Exxon promised before year end, and whether it replaces 4.9 million with a disruption-adjusted number. A figure near 4.5 million would mean this year's growth story runs on Permian and Guyana cash, not on barrels.
Prices Explain All of This Year's Profit Growth
"These are lasting improvements, not simply the result of favorable prices and margins," Woods said of the results. Exxon's own earnings bridge tests the claim. Through nine months, profit excluding one-offs rose $18.5 billion from a year ago, and higher prices and margins added $22.7 billion.
- Prices and margins: +$22.7 billion year to date, 123% of the profit increase by our math
- New projects in the Permian, Guyana, Golden Pass, Singapore and the UK: +$2.7 billion
- Structural cost savings: +$1.4 billion year to date, and zero in the quarter against the previous one
- Higher expenses, lower base volumes and Middle East losses: −$7.4 billion combined
So the lasting part is real but small, and this quarter it shrank: against the second quarter, prices and margins added $3.6 billion while volumes from new projects took away $640 million, because Guyana's entitlement fell. The company's own sensitivity shows the exposure the other way. Each dollar off the refining margin marker costs about $200 million a quarter. A return to last December's $18 marker would therefore remove about $6.4 billion a quarter by our math.
That is not a forecast, because Woods expects the shortage to run "well through next year". But one timing item already moved against Exxon: mark-to-market effects on unsettled trades swung from a $2.5 billion gain last quarter to a $2.5 billion loss, the unwind Exxon itself flagged in July.
What to watch: the price and margin line of the earnings bridge in the fourth-quarter report, due in late January. The first quarter in which that line turns negative will show how much profit the investments and cost savings can hold on their own.
Chemicals Profit Fell 40% as Margins Slid
Chemical Products, which makes polyethylene and other plastics, earned $725 million excluding one-offs, down from $1.2 billion last quarter. The company blamed margins that "declined on higher regional product availability and higher feed costs in Europe and Asia Pacific", meaning more supply came back while Exxon's European and Asian plants paid more for raw material.
The North American polyethylene marker fell 31% from last quarter, to $998 a ton. Volumes helped a little, because sales rose on Asian seasonal demand, but they remain 11% below a year ago. This matters because unit profit, about $148 a ton this quarter, sits below the $210 Exxon reports for 2025, so the second-quarter rebound was a price spike inside the same oversupply.
What to watch: the North American polyethylene marker in the fourth-quarter report, now $998 a ton. A second quarterly decline would put chemical earnings back near the level of early 2026, when the segment earned $110 million.
Risks This Quarter Didn't Answer
Six standing concerns got no new numbers in the release, the slides or the call, so each one carries over unchanged into the next quarter.
- Second-quarter reserve additions: Exxon has still not itemised the $1.4 billion booked in June, which includes the Louisiana coastal settlement.
- Qatar LNG repairs: Woods said he does "not have much of an update"; the terms of Exxon's share of the rebuild stay unknown.
- European windfall taxes: nobody raised them; the EU methane rule delay helps, but a levy on refining profits remains possible.
- Guyana: the force-majeure acreage awaiting the ICJ ruling and the 2027 licence expiry went unmentioned.
- Papua LNG: Exxon took operatorship and a 34% stake but gave no investment-decision date; Rovuma is still due "as we get through the back end of this year".
- New ventures: carbon capture gained Nucor and the Rose approval; hydrogen, lithium and data centres went unmentioned, and Kazakhstan and Venezuela remain talks without terms.
👓 Other Themes
Woods Sees the Fuel Shortage Lasting Through 2027
Asked when refining margins return to normal, Woods named three variables: Middle East exports, "a third of the shortage out there, roughly"; Russia, where "roughly about half of Russia's refining capacity's been taken offline"; and spare Chinese capacity. His guess is that "it will take certainly well through next year before we see things getting back closer to normal". Separately, the European Parliament delayed the EU methane rule by three years, removing a threat to Exxon's European imports.
💲 Other KPIs
Rising faster than sales: up 47% from a year ago, against quarterly sales up 33%. Receivables are bills customers have not yet paid, and higher fuel prices lift them. Payables rose too, so working capital released $2.2 billion of cash in the quarter rather than absorbing it.
Falling, but more slowly: down 3.4% from a year ago, after 4.0% a year earlier. The annual $20 billion of buybacks now retires a smaller share of the company each year, so the per-share lift from repurchases is shrinking even as the dollar amount holds.
Turned up after two quarters of decline: 3,735 thousand barrels a day, up 4.9% from last quarter as Asia Pacific units came back, but 9.0% below the record a year ago. Europe ran 754 thousand barrels a day, down 29% from a year ago, which caps how much of the margin Exxon can capture.
🔮 Guidance
New. Exxon expects the corporate cost line, mainly interest and head-office expense, to fall to between $500 million and $700 million. The middle of that range sits about a third below this quarter's $864 million, consistent with the lower debt. This quarter landed inside its range after two quarters above it on a reported basis.
Unchanged. Spending so far this year is $20.0 billion. By our math that leaves a range of $7.0–9.0 billion for the fourth quarter, so the pace would at least match this quarter. Last year the December quarter was the heaviest. From 2027 Exxon will report capex as plant additions under GAAP, which this quarter were $7.2 billion against $7.0 billion on the current basis.
Unchanged. The plan still calls for about 1.8 million barrels a day for the year, and the quarter sat just above that level, so the full-year figure is in hand. The next marker is the 2027 number in the planning release due before year end; the 2030 target of 2.5 million needs about 9% growth a year from here.
New. Exxon assumes the same loss as this quarter, about 350,000 barrels a day, mostly the damaged Qatar LNG trains plus UAE barrels it produces but cannot yet ship. The figure assumes the current level of disruption continues, so a reopening of the Strait of Hormuz would lift volume and, at the same time, remove the margin that made this quarter.
New. Scheduled maintenance at refineries and chemical plants will cost up to $1.03 billion of earnings in the fourth quarter, against $760 million in this one. The low end of the range barely moves; the high end adds $270 million, mostly in Energy Products. Upstream maintenance eases to at most $260 million from $290 million. Heavier refinery downtime means Exxon captures less of whatever margin the quarter offers.
Unchanged, with a nuance: the start is now set for "late 4Q", so it adds little to 2026 volume. The vessel adds 250,000 barrels a day of gross capacity, lifting Guyana's installed capacity above 1.1 million by our math. Under the contract Exxon's share of each new barrel is smaller than before cost recovery ended, so the cash effect matters more than the volume.
New. Exxon will buy back $20 billion of stock next year, the same pace as 2026, "assuming reasonable market conditions". It warned the purchases may not fall evenly across the four quarters. This year is on track: $15.1 billion so far, with $5.1 billion in the quarter.
Unchanged on paper. The slide still shows the plan figure set before the war, while output so far this year averages 4.53 million. By our math the fourth quarter would have to reach 6.0 million barrels a day to deliver it, which the 350,000 offline barrels rule out. Exxon has not replaced the figure with a disruption-adjusted one; the planning release before year end is the place to look.
❓ Key Questions
What is the disruption-adjusted production outlook for 2026?
The slide still shows about 4.9 million barrels a day while the year is tracking 4.53 million. A single adjusted number would show how much of the gap is war and how much is Guyana entitlement and asset sales.
How much refining margin would Exxon keep after the Strait reopens?
Energy Products earned $9.1 billion on a $50 marker. The company's sensitivity is $800 million a year per dollar of margin, but capture ran above that this quarter, so the earnings level at a $20 marker remains a guess.
What sits inside the $1.4 billion of second-quarter reserve additions?
The Louisiana coastal settlement went in there, but Exxon has not split it from other matters. The item cut Upstream earnings by $1.2 billion in June, and nobody asked about it on this call.
When will Papua LNG reach a final investment decision?
Exxon took operatorship and raised its stake to 34% yet gave no date for a decision first targeted for late 2025. Rovuma still has a year-end target; Papua's timing decides how much LNG growth follows Golden Pass.
What will Exxon's Qatar LNG repair role cost?
Two Qatar trains, about 3% of 2025 production, stay down for years. Woods gave no update, so the capital Exxon commits to the rebuild and the terms it receives remain unknown.