Published on: 2026-07-31
Updated on: 2026-07-31
ExxonMobil reports second-quarter 2026 results before the US open on Friday 31 July, with parts of the sell side modelling adjusted earnings near $15.7 billion. Whether that is “double” the first quarter depends on which first-quarter number you start from, and that ambiguity is the story.
Stronger realisations, tight product supply and wider crack spreads drove the swing, alongside unwinding derivative timing losses and a working-capital release. Q1 free cash flow was $2.7 billion against $9.2 billion of distributions.
Cash conversion therefore carries more information than the earnings line: the call must separate a supply shock Exxon neither created nor controls from the volume growth and cost reduction it can sustain.
ExxonMobil earnings release at 6:30 a.m. Eastern on 31 July; call at 9:30 a.m. Eastern.
Consensus is unusually scattered, $3.56 to $3.87 across providers, individual estimates from $3.14 to $4.46.
Q1 free cash flow covered about 29% of distributions; read the cash statement first.
Returning OPEC+ barrels and recovering Gulf exports make the quarter hard to annualise.
| Metric | Q2 2026 expectation | Q2 2025 actual |
|---|---|---|
| Adjusted EPS | About $3.68 mean estimate from 19 analysts; range of $3.14-$4.46 | $1.64 |
| Revenue | $95.8bn-$110bn, depending on provider | About $79.5bn-$81.5bn |
| Free cash flow | Sharp increase expected; no consensus estimate | - |
| Production | Growth expected from 4.6m boe/d in Q1 | - |
| 2026 buybacks | Up to $20bn planned | - |
These are analyst estimates, not guidance. The reporting entity is now ExxonMobil Holdings Corporation after July’s move of legal domicile to Texas; the listing and business are unchanged.
Exxon published three first-quarter profit figures. GAAP earnings were $4.2 billion, the lowest since early 2021. Excluding identified items: $4.9 billion, or $1.16 a share. Excluding identified items and estimated timing effects: $8.8 billion.
A $15.7 billion quarter is about 78% above the $8.8 billion figure and more than triple the $4.9 billion one. Any headline calling it “double” measures from the most flattering base, and the gap between those figures is precisely the timing effect now reversing.
A 7 July filing indicated earnings should improve by about $5.8 billion sequentially, based on the midpoint of Exxon’s disclosed ranges. The composition is instructive. Higher liquids realisations alone should add $3.5bn to $3.9bn to upstream earnings, with Brent averaging $96.68 a barrel, 23% above Q1.
Yet guided total upstream improvement sits nearer $1.6bn at the midpoint, the difference absorbed by disrupted volumes, turnarounds and other costs. A useful check on the windfall narrative.
Energy Products contributes $2.0bn to $2.4bn, Chemical Products $1.0bn to $1.2bn and Specialty Products $300m to $500m. Much of the Energy Products swing is timing, not margin: Exxon expects positive timing effects of $2.2bn to $3.0bn, reversing the $3.9bn drag on Q1 GAAP earnings.
That is recovered deferred earnings, not higher earning power. Middle East disruptions cut the other way, an estimated $600m to $800m off upstream and $200m to $400m off Energy Products.
First-quarter operating cash flow was $8.7 billion as reported but $13.8 billion before margin postings, collateral against derivative positions. As those positions settle, the collateral returns. Much of any improvement will therefore be released working capital rather than incremental operating cash: real and spendable, but not repeatable.
None originated with Exxon. OPEC+ set the baseline. Shipping was the second: the Strait of Hormuz normally carries around 20 million barrels a day, and when transit slowed the binding constraint shifted from reserves in the ground to barrels able to reach buyers.
Brent pushed above $109 in April; dated benchmarks briefly topped $140. Refining was the third, with June runs roughly 6 million barrels a day below a year earlier, per the IEA, as Middle East export refineries went offline and Russian throughput was curtailed.
Exxon neither created the shortage nor sets prices. Its advantage was owning upstream and refining capacity large enough to monetise both legs.
Volumes and unit costs are the company-controlled half. Exxon produced 4.6 million oil-equivalent barrels per day in Q1, with record Guyana output above 900,000 gross barrels per day, an enlarged Permian position and first LNG from Golden Pass.
At an investor conference in May, Senior Vice President Neil Chapman said Exxon would not chase volumes: no upstream project above a $35 cost of supply has been sanctioned since around 2018, and Permian cost of supply is now $30 or below.
On a pro-cyclical cash surge, he described generating the cash, paying down debt and leaving allocation to the board. The corporate plan assumes no windfall at all, targeting $145 billion of cumulative surplus cash through 2030 at $65 Brent.
Two sources of cash sit behind one headline: price-driven cash from realisations and crack spreads, volume-driven cash from barrels, unit costs and project delivery. Only the second survives a lower oil price, and only the second deserves a mid-cycle multiple.
Partly. A ceasefire restored Hormuz flows through June, and North Sea Dated fell $31 a barrel to $68 by early July, briefly below pre-war levels, before renewed hostilities lifted Brent back toward $100. WTI traded near $84 on Thursday, with Kpler counting 14 Hormuz transits on Wednesday against single digits a week earlier.
OPEC+ approved a further 188,000 barrels per day for August, a fifth consecutive monthly increase, and meets again on 2 August.
Extra quota does not guarantee softer prices; demand, inventories and compliance intervene. Refining looks slower to normalise: the IEA expects global runs to fall 2.4 million barrels a day this year.
Reported earnings move on timing effects, impairments and inventory accounting without any change in money received. Free cash flow is what remains to fund the dividend, the buyback and reinvestment.
The arithmetic is unforgiving. A $1.03 quarterly dividend plus a $20 billion annual repurchase implies distributions of about $37.2 billion, roughly $9.3 billion of free cash flow needed every quarter.
Q1 delivered $2.7 billion; Q4 2025 delivered $5.6 billion against $9.5 billion paid out. Exxon cannot fund distributions indefinitely from the balance sheet. The test is coverage.
XOM closed Thursday at $156.97, up about 30.4% in 2026 and 15% over the past month, below its 52-week high of $176.41. Average sell-side targets sit near $167, and on trailing EV/EBITDA the shares trade near 10 times against a sector average closer to 7.
Positioning turned cautious into the print: BofA downgraded to Neutral days beforehand while raising its target to $158, and Zacks’ model, despite four straight beats averaging about 6%, does not flag one this time. Reaction should hinge on cash conversion, production guidance, buyback pace and whether management calls the quarter a peak.
Before the US open on Friday 31 July, at 6:30 a.m. Eastern; call at 9:30 a.m. Eastern.
No. It disclosed segment-level market and timing effects on 7 July but published no cash or earnings forecast. Any figure circulating is an estimate.
Estimates span $3.14 to $4.46 a share on revenue of $78bn to $115bn, with real disagreement over realised prices, disrupted volumes and how much of the timing reversal lands this quarter.
Supply is recovering, OPEC+ is restoring barrels, and part of the improvement reflects timing reversals and a working-capital release rather than operating gains.
Exxon’s results show how an integrated model performs when crude and product supply tighten together. Repeating them depends on volume growth, lower unit costs and execution; scarcity rents are replaced by cash the business generates itself.
