Management Finally Raised Its Mid-Cycle Margin. The Price Had Already Raised It Twice.

Results vs. Consensus

Valero reported before the open on July 30 and held its call at 10:00 a.m. ET. Every published estimate was beaten by more than 20%, and the four consensus providers we track disagreed with each other by more than most companies beat by.

Q2 2026 Scorecard

The four consensus reads we cross-checked put adjusted earnings per share between $9.87 and $10.22 and revenue between $35.95 billion and $39.47 billion. Every one was beaten by 22.7% to 27.1% on earnings. The revenue spread is the more interesting artefact: $3.5 billion of disagreement across four providers, roughly 9% of the mean. Refining revenue is dominated by pass-through crude cost, and Brent averaged $97.06 in the quarter against $77.92 three months earlier, so a revenue beat of this shape mostly measures who forecast the oil price. We do not score it as a result.

Year-over-year comparison

Sequential comparison

Valero prints only three-month and six-month columns, so the March quarter is recovered by subtraction. Every recovered line agrees with the figures Valero filed in April, which is the check that the subtraction is sound.

Quality of Beat, line by line

• Revenue: almost entirely price and crude pass-through. Throughput rose 1.0% year over year while revenue rose 48.8%, and Brent averaged $97.06 against $66.59. The number that matters is not revenue but refining margin, which nearly doubled per barrel.
• Volume: roughly $0.74 per share of the $2.43 beat is throughput the company did not guide to. Actual throughput of 2,950 thousand barrels per day against a 2,790 guide midpoint is 14.56 million incremental barrels, which at the reported $23.62 margin less $4.70 cash operating cost is about $275 million pre-tax, or $0.74 per share after tax on 294 million shares. That is operating performance, not market luck, and it happened at a refinery system that was supposed to be constrained.
• Margins: the improvement is broad rather than concentrated. All four refining regions expanded margin per barrel by 67% or more year over year, and refining cash operating expenses fell to $4.70 per barrel from $5.13 in March, helped by natural gas at $2.46 per million British thermal units against $3.11 a quarter earlier.
• EPS: $12.62 is the highest diluted figure Valero has printed. Net income of $3,720 million is below the $4,693 million of the June 2022 quarter. The difference is 18 million fewer shares year over year and roughly 90 million fewer than the 2022 peak count. This is the buyback compounding argument working in real time, and it is the single most durable thing in the quarter.
• Cash: adjusted operating cash flow of $4,485 million against $1,347 million a year ago funded $2.6 billion of shareholder returns and a $2.1 billion cash build simultaneously. Capital investment fell to $350 million from $407 million.

Grading Last Quarter's Commitments

In April we published a twelve-item checklist of what management promised and said we would grade it. This is the grade. It is close to a clean sheet, and the two shortfalls are trivial.

Assessment: Management said it would come back with a Port Arthur number and it did. It said the Benicia depreciation charge would end after the June quarter and the September guide confirms it. It gave a dollar figure for the ethanol credit after two quarters of declining to. On the operating commitments this is as complete a delivery quarter as a refiner can produce, and it materially strengthens the case that the guidance is honest rather than sandbagged. The two items still open, Venezuelan volumes and the general and administrative step-down, are both small and both were open in April.

Segment Performance

Refining by region

Market reference cracks, three-quarter view

U.S. Gulf Coast

The system's centre of gravity produced $2,893 million of adjusted operating income on 1,829 thousand barrels per day, with margin per barrel more than doubling to $24.42. The volume figure is the surprise. Guidance three months ago was 1,690 to 1,740 thousand barrels per day precisely because Port Arthur was expected to constrain the region, and the region ran 89 thousand barrels per day above the top of that range. Whatever the diesel hydrotreater outage was costing in April, it was not costing volume by June.

The other Gulf Coast story is capture rather than crack. Management attributed the improvement in capture rates to two things it controls, a deliberate shift in yield toward jet fuel and premiums earned in the export market.

"If you look at the second quarter of last year, our jet yield was 7%. This year, we ramped that up to 12%, which increased our yield by close to 100,000 barrels a day. That was really supportive of capture rates."
— Gary K. Simmons, Executive Vice President and Chief Operating Officer

Assessment: This is the Gulf Coast bull pillar working exactly as specified: complexity plus water access converting a regional dislocation into realized margin. The 5-point jet yield shift is the kind of optionality that does not show up in any crack spread and is the reason the region earns 65.1% of refining profit on 62.0% of throughput. Note also that the concentration has fallen from the 75%-on-60% we recorded in March. The earnings base has broadened, which lowers single-region risk.

U.S. Mid-Continent

The most improved region in the system. Adjusted operating income per barrel went from $3.31 to $13.82 year over year, and throughput rose 62 thousand barrels per day to 485. In March this region was the exhibit for our gasoline bear point, with the gasoline crack outright negative at minus $0.69 per barrel. It printed $20.14 this quarter.

Assessment: A $20.83 per barrel swing in a regional gasoline crack over one quarter is not a trend, it is a dislocation, and it should be read with the same scepticism we apply to the distillate crack. But it does dispose of the specific claim that Mid-Continent gasoline economics were structurally broken. They were seasonally and temporarily broken, and the region is now the second-best margin generator per barrel in the system.

North Atlantic

Pembroke and Quebec City produced $742 million on 506 thousand barrels per day, up 110 thousand barrels per day year over year, with operating income per barrel of $16.12 against $6.09. The region carries no adjustments, so reported and adjusted figures are identical. Its diesel crack of $47.50 per barrel is the widest of the four regions and $28.71 above the year-ago level.

Assessment: This is the region most directly levered to the European supply hole, and it is the region that will give back the most if the hole closes. It is currently earning more per barrel than the Gulf Coast on an unadjusted basis, which is not a normal state of the world. Treat its contribution as the most cyclical dollar in the portfolio.

U.S. West Coast

The residual California business earned $199 million adjusted on 130 thousand barrels per day, against a $118 million adjusted loss in March. Margin per barrel of $30.36 is the highest in the system, though on a base that is now half the size it was a year ago. Two things drove it. Californian crude has cheapened materially because refinery closures and pipeline idling left the local market oversupplied, and management is running Wilmington harder on those barrels.

"And with these logistics bottlenecks, we have seen prices for California crude weaken considerably, and we have been working with our Wilmington refinery to increase processing rates of these barrels and anticipate near-record levels of these crudes in the coming months."
— Randy Hawkins, Vice President, Crude and Feedstocks Supply and Trading

Assessment: An unexpected and slightly uncomfortable outcome. Valero's own exit from Benicia contributed to the local crude glut that is now making its remaining California refinery more profitable. That is a real earnings tailwind and it is also a reminder that this is a one-refinery position in a jurisdiction the company has already decided to shrink in. We do not capitalize it.

Renewable Diesel

Diamond Green Diesel swung from a $79 million loss to $717 million of operating income, on sales volumes of 3,833 thousand gallons per day against 2,732 a year ago and a guide of roughly 3,516. Margin per gallon went from $0.22 to $2.52. The driver is policy arithmetic rather than operations: the renewable volume obligation more than doubled to $13.78 per barrel and the biodiesel renewable identification number went from $1.09 to $2.12.

"So as we look at that going forward, we still see D4 values higher than fat prices. And so you have that tailwind, certainly through 2026 and 2027, with the RVO as it has been set."
— Eric Fisher, Valero Energy

Assessment: The segment did what we said it would do, which is deliver large numbers on inputs neither we nor management control. The forward case is now explicitly framed as a two-year policy window rather than an operating improvement, and management is refusing to add capacity into it. That refusal is the right call and it is also the tell: a business you will not invest in is a business you do not underwrite.

Ethanol

Operating income of $318 million on 4,666 thousand gallons per day of production, with margin per gallon of $1.15 against $0.52. Corn averaged $4.43 per bushel against $4.52 and New York Harbor ethanol went to $2.00 per gallon from $1.84, so the crush improved on both legs. The more consequential disclosure was the first dollar figure Valero has ever attached to the clean fuel production credit.

"But on top of that, the production tax credit that we are now capturing is $0.14 year to date, probably $0.17 for the full year. And if you look into 2027 through 2029, it is probably $0.19 a gallon. Put that in perspective with a historical mid-cycle of $0.25. That says that you are almost doubling the value of ethanol through 2029."
— Eric Fisher, Valero Energy

Assessment: This is the single most useful new number on the call. At roughly 1.7 billion gallons of annual production, $0.19 per gallon is on the order of $325 million of annual credit through 2029, and it is contractual policy rather than a crack spread. It is the first piece of the low-carbon story that can be put into a normalized model with a straight face, and it is why we are raising the combined non-refining contribution in our framework below.

Key Topics & Management Commentary

Overall Management Tone: Confident and, for the first time in our coverage, willing to argue a forward case rather than only report a backward one. The posture on the operating side was matter-of-fact, with the largest quarter in the company's history described in the same register as the last one. The shift versus April is on mid-cycle margins, where restraint gave way to an explicit and mechanistic bull argument, and on capital allocation, where the answers were longer, more hedged and less specific than the operating answers. Analyst pushback was concentrated entirely on what to do with the cash, and management did not fully engage it.

1. The mid-cycle assumption moved

In April, asked whether a physically tighter world changes the margin assumption used to sanction capital, management said it did not. That answer was the load-bearing element of our Hold. This quarter the answer changed, and it changed with a stated mechanism rather than as a mood.

"And we do have a much more constructive view of a future mid-cycle than what you would calculate using historic margins. The primary basis for that view is that when we look at the mid-cycle that you would get by calculating historic margins, product crack spreads were largely set by cracking margins in Northwest Europe. And as supply-and-demand balances have tightened, it appears that refinery crack spreads are now really being set by hydroskimming margins in Northwest Europe."
— Gary K. Simmons, Executive Vice President and Chief Operating Officer

The argument has three legs. First, the marginal barrel setting the global crack is now produced by a less efficient plant, so the clearing price is higher. Second, that plant carries rising carbon-credit costs and inflating operating and capital costs, which raises the floor. Third, crude-quality discounts, particularly for heavy sour, are expected to widen structurally, which is worth more to a high-conversion system than to anyone else.

"Additionally, that hydroskimming capacity is subject to rising costs of carbon credits, which drive those cracks higher, as well as inflationary pressures on both OpEx and CapEx that will result in a higher floor on refinery cracks. Finally, we also see a much more bullish outlook on crude-quality discounts going forward compared to history, especially for heavy sour crude, which also has a very positive impact on our future mid-cycle view as well."
— Gary K. Simmons, Executive Vice President and Chief Operating Officer

The chief executive endorsed it and generalized it to the industry, while pointedly refusing to let it loosen the capital screen.

"We do have, as Gary alluded to, and I think most of the industry accepts, a higher mid-cycle going forward. But the projects we like in refining are more around two things, I would say. One is yield improvement. The other one is what I would call commercial leverage, feedstock leverage."
— R. Lane Riggs, Chairman, Chief Executive Officer and President

Assessment: This is the most important development of the quarter and it cuts against our rating. The specific objection we raised in April, that the company would not put the market's assumed margin into its own sanctioning model, is no longer true. What is still true is that no number was given. "Higher" is not an input. Pressed on how far above the ten-year average cracks would need to sit to justify new capacity, the answer was a framework rather than a figure: mid-cycle margins have to be high enough to keep European hydroskimming running. We would treat a published mid-cycle dollar figure, in a capital markets day or a capital budget, as a genuine thesis event. Directional language on a call is one step short of that.

2. Port Arthur, quantified and closed

The single largest open item in our coverage was the diesel hydrotreater destroyed on March 23, which in April had no cost estimate, no timeline and no sized earnings impact while distillate cracks were at their widest on record. It now has all three.

"Repairs to the Port Arthur DHT unit are expected to be completed and the unit returned to service by year-end. Total repair costs are estimated to be $250 million and are included in our updated guidance for sustaining CapEx. We expect a substantial portion of the cost to be covered by insurance. In the meantime, the refinery continues to operate at normal throughput rates."
— Harminder S. Bhullar, Senior Vice President and Chief Financial Officer

The quarterly report filed the same day carries the number the call did not: a $78 million insurance recovery receivable recorded against losses considered probable of recovery, with no cash received in the quarter, and the recovery subject to a self-insured retention that is not sized. Property-damage recoveries above recognized losses are treated as a gain contingency and are not on the books at all.

Assessment: Resolved about as favourably as it could have been. A $250 million repair on a company generating $4.5 billion of adjusted operating cash flow in a quarter is a rounding error, the unit returns inside the year, and the refinery never lost normal rates. The gap between "a substantial portion" on the call and $78 million recognized in the filing is worth watching but is a timing and accounting-conservatism issue rather than a solvency one. We are moving this risk down two notches.

3. Gasoline came back, and the reason is arbitrage rather than demand

The half of the yield slate that looked structurally impaired in March is working again, and management gave a specific and testable explanation that has nothing to do with American driving.

"So the combination of the closed arb for import barrels from Europe and the open arb for export barrels to Latin America has net gasoline imports down about 400,000 barrels a day from where they historically are. That, combined with good domestic demand, is really what is leading to the relative strength in gasoline."
— Gary K. Simmons, Executive Vice President and Chief Operating Officer

Assessment: The mechanism is credible and it is verifiable in trade flows, which is more than we had in April, when the constructive case rested on a supply-side hope about vacuum gas oil scarcity. It is also, precisely because it is an arbitrage story, the most reversible element of the quarter. European gasoline strength is a function of European refining being short, and European refining is short because of the same capacity outages driving the distillate crack. Gasoline and diesel are therefore not two independent bull legs. They are one bet wearing two hats.

4. The duration question, and the only honest answer anyone gave

The entire earnings surplus traces to roughly five million barrels per day of global refining capacity being offline. Management neither claimed to know when that ends nor pretended it was permanent, and cited third-party inventory work rather than its own view.

"When we look at the consultant data that we subscribe to, it would show that globally, total light-product inventories are down about 150 million barrels from where they were at the start of the year. We are about 130 million barrels below where they would normally be at this time of year. Their data would suggest that if the conflict were to end today, global inventories remain below the five-year average range through 2027, with gasoline recovering fastest, followed by diesel and then jet."
— Gary K. Simmons, Executive Vice President and Chief Operating Officer

Management then said it thinks the consultants are too optimistic, on the basis that Middle Eastern damage is physical and that the Ukrainian campaign against Russian refining is escalating rather than easing.

"The only thing I can tell you is, as you know, currently about 1.7 million to 1.9 million barrels a day of Russian capacity is offline. If you look at the trend from May to June to July, it has gotten progressively worse, not better. And then what you hear is that Ukraine is now targeting critical pieces of equipment, whereas before they were targeting tanks."
— Gary K. Simmons, Executive Vice President and Chief Operating Officer

Assessment: This is the crux, and it is the reason a Hold survives a quarter this good. Even the friendly reading has inventories recovering to the five-year range at some point after 2027, and it has gasoline recovering first, which is the half of the slate that just produced the swing. The disclosure is honest and the sourcing is transparent. But an investor buying at $311.71 is not buying a business, they are buying a view on the duration of two wars, and management has been careful to tell you that it does not have direct insight into either.

5. Cash built above the target, on purpose

Cash ended the quarter at $7.9 billion, above the stated $4 billion to $5 billion long-term target, with net debt to capitalization at 11% against a 20% to 30% framework range. The build was $2.1 billion in three months.

"Consistent with our prior messaging, we built cash above the high end of our long-term $4 billion to $5 billion cash target to preserve optionality in a volatile market environment while also exceeding our minimum payout commitment."
— Harminder S. Bhullar, Senior Vice President and Chief Financial Officer

The stated rationale is working-capital defence. A sharp fall in crude drains cash through working capital at exactly the moment a refiner would want to be buying its own stock, and management wants to avoid being constrained then.

"And in this environment, I think building cash and shareholder returns do not have to be mutually exclusive. So I will reiterate that our long-term target on cash and leverage remains unchanged."
— Harminder S. Bhullar, Senior Vice President and Chief Financial Officer

Assessment: Internally consistent with the inventory philosophy we identified as a bull pillar in April. Valero runs physical inventory at working levels rather than a hedged paper book, which removes margin-call drag but leaves it exposed to a crude-price collapse through working capital. Carrying $3 billion of excess cash is the price of that structure. It is defensible. It also means the payout ratio understates what the company could return and overstates what it will.

6. The $5 billion authorization nobody mentioned

Valero repurchased 9,011,171 shares in the quarter against 2,567,930 a year earlier, and 11,338,194 in the half. Shares outstanding fell from 298.9 million at the end of December to 287.9 million at the end of June, a 3.7% reduction in six months. On July 16, two weeks before the call, the board authorized a further $5.0 billion of repurchase on top of the $1,422 million still available under the February program, taking total authorization to $6.4 billion, or roughly 7% of the market capitalization.

None of that was said on the call. The capital-allocation answers instead framed buybacks defensively.

"And, you know, even at a higher share price, buybacks are a better use of cash than the alternatives I have talked about, especially given the fact that we are talking about excess cash here."
— Harminder S. Bhullar, Senior Vice President and Chief Financial Officer

Assessment: The gap between the words and the actions is the most interesting thing on the call. Verbally, management is cautious, notes that accretion is lower at a higher share price, and stresses that the cash build is deliberate. Behaviourally, it retired 3% of the company in one quarter and quadrupled its remaining authorization. Read the second. In April we said we would upgrade on a payout decisively above framework because that would signal management's own view that the stock is cheap. The payout ratio did not move. The authorization did, by more.

7. Growth capital, and the discipline that survived the upgrade

A higher mid-cycle view would ordinarily unlock a capital budget. It has not. Strategic spending is running roughly half its pre-2020 level and management set out why it is staying there.

"What I would say is, pre-COVID, we would have been at about $1 billion in strategic spending, and that was really capped by, I would say, our project execution efficiency. Post-COVID, we have spent about $500 million on average, maybe creeping up to $700 million, a lot of which, if you look back at it, was renewable spending."
— R. Lane Riggs, Chairman, Chief Executive Officer and President

"We have a higher mid-cycle outlook going forward, but we are not going to lose our discipline with respect to our capital and how we are going to spend money. But with that said, Gary kind of touched on it. The higher cost of these projects also supports the higher mid-cycle as well."
— R. Lane Riggs, Chairman, Chief Executive Officer and President

Full-year capital investment attributable to Valero is now guided to approximately $2 billion, of which roughly $1.7 billion is sustaining and the balance growth, with the Port Arthur repair inside the sustaining figure. Named projects are the $230 million St. Charles fluid catalytic cracker optimization due in the September quarter, and ethanol debottlenecking of 100 to 200 million gallons per year over the next one to two years.

Assessment: This is the behaviour we want and it is also, awkwardly, an argument for the bulls. A management team that raises its mid-cycle view and does not raise its capital budget is telling you it thinks the returns are better in its own shares than in new steel. That is the same signal the buyback authorization sends. It is a genuinely coherent posture.

8. The renewable identification number is short, and nobody knows what happens then

Both non-refining segments and part of the refining crack now hinge on a compliance credit that management believes is heading into shortage.

"We do see the RIN market short, with the bank being hit somewhere between the end of this year and sometime in the middle of next year, given the pace we are at."
— Eric Fisher, Valero Energy

The chief executive added the unhedged version, which is more useful than the answer that preceded it.

"Yeah. Hi. This is Lane. I think the only thing I would add is we have our own view on if and when the bank runs out. And obviously, the RIN is inside the crack. I do not think anybody knows what happens if it goes unfeasible, and it could."
— R. Lane Riggs, Chairman, Chief Executive Officer and President

Assessment: An unusually candid statement of an unquantifiable risk that sits inside the crack spread on which the whole equity is priced. The renewable volume obligation is a cost to the refining segment and a revenue to the renewable diesel segment, so Valero is partly hedged against itself, but not fully. The chief financial officer's framing, that any regulatory intervention will be driven by consumer fuel affordability, is the right way to think about the trigger. This risk has no size attached and cannot be given one.

9. Feedstock advantage widened on three fronts

The crude side of the margin equation improved independently of cracks. Brent less Western Canadian Select Houston widened to $13.92 per barrel from $6.25 a year ago, and Brent less Argus Sour Crude Index to $3.11 from $2.02. On Venezuela, management described a pivot driven by Canadian weather disruption and forecast unprecedented processing rates without giving a barrel figure.

"And that caused us to kind of pivot to more Venezuelan crude. And we would expect to see processing rates of Venezuelan heavy crude in the coming months that exceed our historical maximum."
— Randy Hawkins, Vice President, Crude and Feedstocks Supply and Trading

The reported feedstock slate does not yet corroborate it. Heavy sour crude throughput of 514 thousand barrels per day is below the 554 of a year ago, though up from the 450 implied for the March quarter. Mexican availability is described as lower because of higher domestic runs at Dos Bocas, and as volatile month to month.

Assessment: Third consecutive quarter in which Venezuelan volumes are characterized qualitatively and never sized, while the disclosed heavy sour number moves the other way from the narrative. The wider Canadian discount is real, disclosed and worth money. The Venezuelan claim remains unverifiable from the filings, and we do not give it credit in the model.

10. The third quarter is running better than the second

The most consequential forward statement was not in the guidance table. Asked to bridge the June quarter to the September quarter, management said margins and capture are both better so far, and attributed it to the crude side rather than the product side.

"Still early in the quarter, but to us, both margins and capture rates look constructive relative to the second quarter. As you mentioned, really the biggest tailwind in the quarter is around feedstocks. The market structure thus far is resulting in an improvement in delivered crude costs relative to the benchmarks."
— Gary K. Simmons, Executive Vice President and Chief Operating Officer

The mechanism named is the shape of the curve. Physical grades traded at significant premiums to the screen during the June quarter, and are now trading at discounts, with naphtha, propylene and sulfur all firmer. Working the other way, the jet tailwind that helped Gulf Coast capture has not repeated, though management expects it to return as winter diesel specifications arrive.

Assessment: A refiner saying its current quarter is tracking above the best quarter in its history is a material statement, and it explains most of the session's move. It should be weighed against what it is: unaudited commentary one month into a three-month period, from a business whose margin is not in management's control. It does not change a normalized valuation. It does raise the near-term earnings the buyback gets to compound against.

11. Benicia's cash cost is disclosed, but not where you would look for it

From this quarter, Benicia decommissioning and redevelopment moves out of the Refining segment and into Corporate and Other, which is why the corporate loss widened to $309 million from $244 million while general and administrative expense rose only $13 million. The incremental depreciation of $33 million stays inside the West Coast refining region and, per the September guide, now ends.

The cash figure appears only in the quarterly report. Expected asset retirement obligations were recognized at $337 million, of which approximately $70 million was settled in the quarter and $170 million in the half. Separately, the $44 million LIFO liquidation benefit that management stripped out of adjusted earnings arises from drawing down Californian inventory as Benicia idles, and the same mechanism ran the other way in the December 2025 quarter, when it increased cost of materials by $37 million.

Assessment: $170 million of real cash left the building in the first half against a wind-down whose income-statement footprint is a depreciation charge that is about to disappear. Nobody asked about it. Inventory levels are expected to stay below the December 2025 level, so further LIFO liquidation is likely, and management has now established the practice of adjusting it out in both directions. That is the correct treatment and it deserves credit.

12. Turnaround spending is light, and management says it is timing

First-half deferred turnaround and catalyst spending was $374 million excluding the Diamond Green Diesel joint venture, against roughly $1 billion per year in 2024 and 2025, at the same time the September quarter is guided above historical utilization. That combination usually means maintenance is being deferred into a strong margin environment, which borrows earnings from later years.

"You know, really no thought on our part in terms of delaying our maintenance. We have a fairly steady spend on turnaround activity, and that will continue. We found that it really is important to execution to keep those dates kind of set."
— R. Lane Riggs, Chairman, Chief Executive Officer and President

Assessment: The denial is unambiguous and the reasoning, that schedule integrity matters more than opportunistic timing, is consistent with how this company has behaved. We accept it, and we note that the claim is falsifiable: full-year capital investment is guided to approximately $2 billion with $1.7 billion sustaining, so second-half sustaining spend has to run materially above the first half for the guide to hold. If it does not, the answer was wrong.

Guidance & Outlook

Valero guides to volumes and costs, not to revenue or earnings, which for a refiner is the more useful disclosure because the margin is not management's to forecast. The September guide raises volume and holds cost.

Implied quarter-over-quarter ramp. The throughput guide midpoint of 2,850 thousand barrels per day is 3.4% below the June quarter's 2,950, with the reduction concentrated in North Atlantic, down roughly 46 thousand barrels per day at the midpoint, and West Coast, down 15. Gulf Coast is guided flat at the top of its range, at 1,805 thousand barrels per day midpoint against 1,829 delivered. For a company that beat the top of its last throughput guide by 110 thousand barrels per day, this is a guide that leaves room.

Where the guide is quietly good. Total depreciation falls $37 million as the Benicia acceleration ends exactly on the schedule given in April, and net interest falls $5 million. Refining cash operating expenses rise a nominal $0.05 per barrel on 3.4% less volume, which is effectively flat unit cost on lower throughput. Ethanol volume is guided up 2.9% on lower unit cost. The offsetting item is renewable diesel, guided down 8.7% in volume with unit costs up $0.03 per gallon, which trims the segment even before any policy change.

Street at. There is no published consensus for the metrics Valero guides to, so the guide cannot be scored against expectations. What is scoreable is the pattern: this management team has now guided below what it delivered in each of the last two quarters, by 4% on throughput in June. Assume the same conservatism until it stops working.

Guidance style. Complete for the first time in our coverage. The one hole in April, the absence of a Port Arthur capital number and therefore of a full-year capital investment figure, is filled. Ranges are narrow, the full-year general and administrative and capital figures are given, and the segment cost splits between cash and non-cash are provided. The remaining omissions are choices rather than gaps, and they are covered below.

Analyst Q&A Highlights

Whether the industry has structurally reset to a higher mid-cycle margin

The dominant question of the call, put directly and answered directly. The framing was that each successive geopolitical disruption over several years has produced a larger margin response than expected, which is an argument about the shape of the supply curve rather than about any one event. Management agreed, and set out the mechanism at some length: the marginal crack setter has moved from cracking margins to hydroskimming margins in Northwest Europe, that capacity is exposed to rising carbon-credit and cost inflation, and heavy sour crude discounts are expected to widen. This is the answer that did not exist three months ago.

Q: "Over the last several years, repeated geopolitical disruptions have highlighted just how tight global refining capacity remains post-pandemic, even with meaningful capacity additions in emerging markets. And each successive disruption appears to have produced a larger-than-expected margin response, most recently following events in the Middle East. Do you believe that the industry has structurally shifted to a higher mid-cycle refining margin environment? If so, what are your assumptions that would underpin such an outlook?"
— Theresa Chen, Barclays

A: "And we do have a much more constructive view of a future mid-cycle than what you would calculate using historic margins. The primary basis for that view is that when we look at the mid-cycle that you would get by calculating historic margins, product crack spreads were largely set by cracking margins in Northwest Europe. And as supply-and-demand balances have tightened, it appears that refinery crack spreads are now really being set by hydroskimming margins in Northwest Europe."
— Gary K. Simmons, Executive Vice President and Chief Operating Officer

Assessment: The exchange moves the thesis. The company that would not raise its mid-cycle in April now argues the case unprompted and in detail. The remaining gap is quantitative rather than directional, and a later exchange showed why it matters: asked how far above the ten-year average crack the industry needs to be to justify a new refinery, management said it did not have the number in front of it and fell back to the hydroskimming framework. A view you cannot price is not yet an input.

Bridging the June quarter to the September quarter

The first question of the call, and the one that most plausibly explains the session's move. The questioner framed the setup precisely, noting Gulf Coast indicators up sharply and a less backwardated curve. Management said margins and capture both look better than the June quarter, attributed the improvement to physical crude grades moving from premiums to discounts against the screen, and flagged one offset, that the jet tailwind which helped Gulf Coast capture has not recurred.

Q: "Obviously, an extraordinary quarter. I think a lot of us remember when $4 was your mid-cycle EPS, and doing $12 in a quarter is pretty extraordinary. And that kind of—we are not quarter-to-quarter folks here—but as we think about bridging Q2 to Q3, we would just love your guys’ perspective."
— Neil Mehta, Goldman Sachs

A: "Still early in the quarter, but to us, both margins and capture rates look constructive relative to the second quarter. As you mentioned, really the biggest tailwind in the quarter is around feedstocks. The market structure thus far is resulting in an improvement in delivered crude costs relative to the benchmarks."
— Gary K. Simmons, Executive Vice President and Chief Operating Officer

Assessment: The most valuable disclosure of the call for anyone modelling the next print, and the reason the stock closed at the high end of its range rather than fading the beat. The observation embedded in the question is also worth keeping: a company whose mid-cycle earnings power was once framed at roughly $4 per share annually just earned more than three times that in ninety-one days. That is the definition of a cycle peak, and it is exactly why we will not capitalize it.

What to do with a cash balance above the target range

A recurring line of questioning, raised in different forms across the call. Cash sits at $7.9 billion against a $4 billion to $5 billion long-term target and net debt to capitalization is 11% against a 20% to 30% framework. The answer was that the build is deliberate insurance against a working-capital drain in a crude sell-off, that it does not preclude returning cash, and that the excess will be released back toward the target as volatility falls.

Q: "You are sitting above what we would characterize as your mid-cycle cash balance of $4 billion to $5 billion right now. How are you thinking about deploying it, whether to hold back excess cash or to continue to shrink the share count? Any perspective would be great."
— Neil Mehta, Goldman Sachs

A: "And in this environment, I think building cash and shareholder returns do not have to be mutually exclusive. So I will reiterate that our long-term target on cash and leverage remains unchanged."
— Harminder S. Bhullar, Senior Vice President and Chief Financial Officer

Assessment: Consistent with the inventory philosophy that underpins the low-earnings-volatility pillar, and consistent with what the company actually did, which was pay out 59% and still add $2.1 billion of cash. The honest reading is that the payout ratio is now a floor rather than a target, and that the constraint on returns is management's volatility judgement rather than its cash generation.

Whether the dividend and buyback mix should be rebalanced

The sharpest challenge of the call, and the one management engaged least directly. The premise was that if the mid-cycle is genuinely higher and net debt is effectively zero, the capital return framework itself should change rather than simply run at its minimum. The response ruled out acquisitions and growth as uses, defended buybacks on a long-run realized return above 20%, acknowledged that accretion falls as the share price rises, and framed dividend growth as deliberately prudent to keep it sustainable through the cycle.

Q: "First of all, we are just sitting here watching extraordinary margins. We do not know what the duration is. But you have got practically no net debt. I think you are kind of signaling a preparedness to be patient with building cash. Why is a rebalancing of dividends and buybacks not an appropriate thing to consider if you believe mid-cycle should be higher going forward?"
— Doug Leggate, Wolfe Research

A: "So absent those uses, we are clearly not just going to have cash sit on our balance sheet, you know, given, as you highlighted, our already low net leverage. Now, you know, we have talked about this, and I recognize that at a higher share price, accretion from buybacks is lower."
— Harminder S. Bhullar, Senior Vice President and Chief Financial Officer

Assessment: This is the exchange to reread against the filing. Two weeks before this answer, the board authorized $5.0 billion of additional repurchase, and in the quarter just reported the company retired 3% of its shares. Nothing in the verbal answer signals that. Management is talking down a capital return posture it has already escalated, which is the opposite of the usual failure mode and should be read as a positive.

Why gasoline is participating this time

A comparison-driven question noting that in the 2022 episode diesel moved and gasoline did not, whereas this time gasoline is closing the gap. The answer was entirely about trade flows: European strength has closed the transatlantic import arbitrage while Latin American export demand is open, cutting net United States gasoline imports by roughly 400 thousand barrels per day against normal. Domestic demand was described as good but as the second factor, not the first.

Q: "So if you could talk a little bit about what is driving the relative strength in gasoline, and are the gasoline markets really that tight?"
— Manav Gupta, UBS

A: "So the combination of the closed arb for import barrels from Europe and the open arb for export barrels to Latin America has net gasoline imports down about 400,000 barrels a day from where they historically are. That, combined with good domestic demand, is really what is leading to the relative strength in gasoline."
— Gary K. Simmons, Executive Vice President and Chief Operating Officer

Assessment: A specific, checkable answer, which is more than the vacuum gas oil argument offered in April. It also establishes that the gasoline recovery and the distillate strength share a single root cause in European refining shortage. Investors treating the two as independent legs of the bull case are double-counting one bet.

How long the Russian capacity stays offline

A question grounded in precedent, noting that Russian refineries recovered faster than expected in the 2022 and 2023 episode. Management drew a distinction that matters: the earlier campaign targeted storage tanks, which are quick to restore, and the current one targets process equipment, which is not. The trend from May through July was described as deteriorating rather than improving.

Q: "So do you have any sense of the extent of damage at these Russian plants and if they are going to be able to come back relatively quickly once the bombing stops, or if they will be down for an extended period of time?"
— Jason Gabelman, TD Cowen

A: "And then what you hear is that Ukraine is now targeting critical pieces of equipment, whereas before they were targeting tanks. And so you can understand that, you know, you have a tank fire and you can recover quickly. However, if they are taking out pieces of critical equipment, it could take a lot longer."
— Gary K. Simmons, Executive Vice President and Chief Operating Officer

Assessment: The most important qualification came immediately before this in the same answer, that management has no direct insight and is reading the same open sources everyone else is. The tanks-versus-equipment distinction is a real analytical point and it lengthens the plausible duration of the dislocation. It remains a view on a war, held by a refiner, offered with an explicit disclaimer. Size the position accordingly.

Whether light first-half turnaround spending is deferred maintenance

The most useful sceptical question of the call. First-half turnaround and catalyst spending ran roughly $374 million against about $1 billion per year in the two prior years, while the September quarter is guided above historical utilization. That combination is the classic signature of maintenance pushed into a high-margin window. Management denied it flatly, on the grounds that fixed turnaround dates matter to execution quality, and reaffirmed the full-year capital guide.

Q: "First-half turnaround CapEx ran about $374 million, which is pretty low relative to the $1 billion per year you have been averaging over 2025 and 2024. I mean, it also looks like 3Q throughput guidance is going to be a bit higher than historical utilization. I know you talk about future turnarounds, but is there an ability to push some of these out?"
— Phillip Jungwirth, BMO Capital Markets

A: "You know, really no thought on our part in terms of delaying our maintenance. We have a fairly steady spend on turnaround activity, and that will continue. We found that it really is important to execution to keep those dates kind of set."
— R. Lane Riggs, Chairman, Chief Executive Officer and President

Assessment: The denial is clean and the reasoning is credible for this operator. It is also the single most testable claim on the call. The full-year guide of approximately $2 billion with $1.7 billion sustaining requires second-half sustaining spend far above the first half. We will grade it in January, and a shortfall would mean the earnings in the second half were partly borrowed from 2027.

What They're NOT Saying

1. A number for the higher mid-cycle. Management now argues in detail that the mid-cycle refining margin has structurally reset, endorses it at chief-executive level, and says most of the industry accepts it. It has never said what the number is. Asked how far above the ten-year average crack the industry needs to be to justify new capacity, the answer was that the figure was not to hand. Every valuation of this equity turns on that one input, and the company that has the best claim to know it will not print it.
2. The $5.0 billion repurchase authorization. Approved by the board on July 16 and disclosed only in the quarterly report filed the same morning as the call. Capital allocation was the single most-asked topic on the call and the authorization was never mentioned, in an answer sequence that instead emphasized caution about buying stock at a higher price. The behaviour and the commentary point in opposite directions.
3. What "a substantial portion" of the Port Arthur insurance recovery means. The call gave a $250 million repair estimate and said a substantial portion would be insured. The quarterly report puts $78 million on the balance sheet as a receivable, records no cash received, notes a self-insured retention that is never sized, and treats anything above recognized losses as a gain contingency. The recovery has a number. It was not the number said out loud.
4. The kerosene hydrotreater. In April management said the second unit damaged in the March fire would be back in the third quarter. This quarter the disclosure shifted to whole-refinery language, that Port Arthur returned to normal throughput rates, and the unit was not mentioned again in the release, on the call or in the quarterly report. It is probably fine. It is also a specific commitment that quietly stopped being tracked.
5. Venezuelan volumes, for the third consecutive quarter. Management expects processing rates that "exceed our historical maximum" and has never given a barrel figure, while disclosed heavy sour crude throughput of 514 thousand barrels per day remains 40 below the year-ago level. The narrative and the disclosed slate have now diverged for three quarters running.
6. Why general and administrative expense is supposed to fall. The full-year guide of approximately $960 million was maintained. The first half spent $518 million, so the second half must average $221 million per quarter against $233 million just delivered and $285 million in March. This was unexplained in April and it is unexplained now.
7. The $51 million tariff refund at Diamond Green Diesel. Following the February Supreme Court ruling invalidating tariffs imposed under the International Emergency Economic Powers Act, the joint venture filed a refund claim of $51 million which Customs and Border Protection accepted. It is a gain contingency and correctly unrecognized. It was also never mentioned, in a quarter where the renewable diesel segment was discussed at length.
8. Any framing of what the fourth quarter looks like if the wars end. Management supplied a third-party scenario in which inventories stay below the five-year range through 2027 even on an immediate resolution, and then said it thinks that scenario is too optimistic. Nobody offered, and nobody asked for, the other side: what the earnings power looks like if five million barrels per day of capacity returns faster than expected. That asymmetry in the discussion is itself information.

Market Reaction

• Pre-print setup: the stock closed at $301.32 on July 29, up 85.1% year to date against 6.9% for the S&P 500, up 116.2% over twelve months, and up 15.7% over the trailing thirty days. The 52-week closing range entering the print was $131.77 to $314.80, so the shares were within 4.3% of their highest close of the year.
• Reaction session: shares opened at $296.41, a 1.6% gap lower, traded a range of $294.21 to $313.75, and closed at $311.71, up 3.4% or $10.39. The close was within $2.04 of the intraday high.
• Volume: 2.3 million shares against a 30-day average of 3.2 million, or 0.7 times normal. This was not a repositioning day.
• Peers and market: the S&P 500 rose 1.7% on the same session. Among refiners, HF Sinclair rose 2.7%, Phillips 66 1.8% and Marathon Petroleum 1.7%. The energy sector exchange-traded fund rose 0.5%.

The shape of the session is more informative than the size of the move. A beat of this magnitude opening 1.6% lower says the print itself was substantially anticipated, which is consistent with a stock that had already added 15.7% in the preceding thirty days on observable crack spreads. What turned the session was the call. The rally through the morning coincided with management's statement that the September quarter is tracking above the June quarter on both margin and capture, and with the mid-cycle answer. The market bought the outlook, not the quarter.

The relative performance is the cleanest signal available. In April, Valero closed up 0.5% on its print while Phillips 66 rose 3.3% and Marathon Petroleum 2.7%, an underperformance we attributed at the time to the market pricing the unquantified Port Arthur outage. This quarter the ranking inverted exactly: Valero led the group by 1.6 to 1.7 points on the day the outage was sized and closed. That is roughly the same magnitude of relative move, in the opposite direction. The Port Arthur discount that we said would drive an upgrade if it resolved has resolved, and it has been paid for.

The remaining observation is that the move happened on 0.7 times normal volume, into a stock that has doubled in a year. Low-volume advances at extended levels reflect an absence of sellers more than an arrival of buyers. That is a fragile market structure, and it is not a reason to buy.

Street Perspective

Debate: Is the higher mid-cycle real, or is it a war premium being labelled as structure?

Bull view: The bull case being made on the Street is that the marginal crack setter has genuinely moved to less efficient European capacity, that carbon costs and construction inflation put a rising floor under cracks, and that a decade of underinvestment cannot be reversed inside the planning horizon. Management's own framework, offered unprompted this quarter, is being cited as the authoritative version of this argument.

Bear view: The bear camp contends that the entire surplus is arithmetically attributable to roughly five million barrels per day of capacity offline for war reasons, that the company's own consultants show gasoline recovering first and fastest, and that a structural argument which arrives only after two years of dislocated margins is the oldest pattern in cyclical investing.

Our take: Both are partly right, and the distinction that matters is quantitative. The structural component is probably real and probably worth $2 to $3 per barrel above the pre-2022 mid-cycle, which is why we are raising our normalized band. The dislocation component is worth considerably more than that today, and it is the part the current share price capitalizes. A structural argument that arrives without a number is not yet a valuation input, and management has now had two consecutive quarters in which it could have supplied one.

Debate: Is a 12.9 times trailing multiple cheap or is it a peak-cycle warning?

Bull view: Some desks argue that Valero at roughly 12.9 times trailing earnings, with net debt of $3.5 billion against a $91.6 billion market capitalization, a business retiring 3% of its shares per quarter and management saying the current quarter is running better, is simply mispriced on any conventional screen.

Bear view: The bear camp's reply is that refiners always look cheap at the top, because the denominator is peak earnings. On the December 2025 full-year outcome the same shares trade at roughly 30 times, and on the 2024 outcome at considerably more. A low trailing multiple in a cyclical is a description of where you are in the cycle, not a valuation.

Our take: The bears have the better of this on method and the bulls have a real point on the share count. The trailing multiple is not informative here and neither camp should lean on it. What is informative is the implied sustainable margin, and at $311.71 that is $17.42 to $19.31 per barrel against $12.29 realized in 2025. The buyback argument is the genuine bull rejoinder, because shares retired at a cycle peak permanently raise normalized earnings per share, and this quarter's record was produced by exactly that mechanism.

Debate: Should management be spending the balance sheet rather than defending it?

Bull view: A growing consensus view is that with effectively no net leverage, $7.9 billion of cash and a stated belief in a higher mid-cycle, the company is under-deploying. The framework payout of 59% is the same it ran in a far weaker quarter, and holding $3 billion above the cash target while the shares compound is capital sitting idle.

Bear view: Others argue the opposite, that a refiner running physical inventory rather than a hedged paper book is structurally exposed to a working-capital drain in a crude sell-off, and that the cash buffer is the price of the low-earnings-volatility profile that makes this the highest-quality balance sheet in the sector.

Our take: The debate is largely resolved by the filing rather than the call. The board authorized $5.0 billion of additional repurchase two weeks before the call, taking available authorization to $6.4 billion, and the company retired 9.0 million shares in the quarter against 2.6 million a year ago. Management is deploying more aggressively than its own commentary suggests. We side with the second camp on the cash buffer and note that the first camp's complaint has already been answered in actions.

Model Update

We are raising the framework on four of ten drivers. The changes are set out against the initiation assumptions published in April so the direction and the reason are both visible.

The sensitivity that matters, restated. At 2,850 thousand barrels per day, a full year is 1,040 million barrels of throughput. Each $1.00 per barrel of refining margin is therefore about $1,040 million pre-tax, about $811 million after tax at 22%, and about $2.76 of annual earnings per share on 294 million shares. That is up from $2.64 in April, entirely because throughput is higher and the share count is lower. Every other line in the model remains noise next to this one.

Valuation at the reaction close. At $311.71 and 294 million diluted shares the market capitalization is $91.6 billion. Net debt of $3.5 billion, being $9.1 billion of debt plus $2.2 billion of finance lease obligations less $7.9 billion of cash, gives an enterprise value of $95.1 billion, or $98.4 billion including the $3.3 billion noncontrolling interest representing the other half of Diamond Green Diesel. Trailing twelve-month diluted earnings per share, summing the four reported quarters, is $24.11, so the shares trade at 12.9 times trailing against 18.4 times three months ago. Book value per share of $85.04 puts them at 3.7 times. The $1.20 quarterly dividend annualizes to $4.80 for a 1.5% yield.

Fair value framework. Applying the revised drivers gives normalized earnings per share of $19.29 at a $15.00 per barrel refining margin and $26.19 at $17.50. Refiners have historically been capitalized at eight to twelve times trend earnings, and we continue to apply ten to twelve times, unchanged from April, because a higher normalized margin belongs in the earnings rather than in the multiple. That produces a range of roughly $193 to $314, with a midpoint case of $22.74 per share at eleven times, or about $250. The close is 24.7% above that midpoint and sits at the top of the full range. In April the equivalent midpoint was $175 against a $252.58 close, a 31% gap. The gap has narrowed. It has not closed.

Inverted, and this is the sentence that decides the rating. To justify $311.71 at twelve times normalized earnings requires about $25.98 per share, which requires a sustained refining margin of $17.42 per barrel. At ten times it requires $31.17 per share and a margin of $19.31. Against $12.29 for 2025, $10.62 for 2024, $19.31 realized in the first half of 2026 and $23.62 in the quarter just reported. Three months ago the equivalent requirement was $16.45 to $18.05 per barrel, which sat above that quarter's own $14.90 print, so the price required an improvement on a record. Today the requirement sits at or just below the first half's realized level. The bar has changed character. It is no longer asking for something the company has never done. It is asking for the current war-driven margin structure to be permanent, with no deterioration, forever.

What the bulls get. Two things, and both are real. First, the buyback compounding is now visible rather than theoretical: this quarter produced the highest earnings per share in the company's history on the second-highest profit pool, and shares outstanding fell 3.7% in six months with $6.4 billion of authorization remaining. Two more years at this pace mechanically lifts normalized earnings per share by roughly a tenth and moves our midpoint from $250 toward the high $270s. Second, the September quarter is running above the June quarter on management's own account, which extends the windfall period the buyback compounds against. Neither closes a 24.7% gap. Both make it smaller than it looks.

Thesis Scorecard Post-Earnings

The pillars below are the ones established at initiation in April, graded against this quarter's print and call. Three of the four bear points weakened.

Overall: the thesis weakened on the operating side and held on valuation. Every operating pillar we would want to see performed, two bear points moved down and one moved up. What did not change is the arithmetic. In April we said the equity capitalized a margin structure roughly 34% to 47% above the prior year's realized level, permanently, and that the company would not put that number in its own model. The company has now partly conceded the first half of that sentence and the share price has advanced 23.4% since, which leaves the gap between price and framework at 24.7% instead of 31%. That is progress, and it is not enough.

A note on our own trigger set. In April we said we would upgrade on a credible Port Arthur rebuild timeline, on a payout decisively above framework, or on a meaningful de-rating. The first fired cleanly. The third moved emphatically against us. The second is genuinely ambiguous: the payout ratio was unchanged at 59% while the company retired 9.0 million shares and the board quadrupled the remaining authorization. Two of three conditions were satisfied and we are not upgrading, which requires an explanation rather than an assertion. The explanation is that the trigger set was badly specified. It named events without naming a price, and the events it named were resolved and repriced in the same session. A rebuild timeline was worth an upgrade at $252.58 because the outage was an unpriced discount. At $311.71 the discount is gone. We are restating the triggers below with prices attached so this cannot recur.

Action: Maintaining Hold, and lowering conviction to 5 from 6. We would upgrade to Outperform on any of three specific conditions: a de-rating to roughly $260 or below without a deterioration in the margin environment, which returns the implied sustainable margin to the middle of our band; a published mid-cycle refining margin figure from the company itself, in a capital budget or capital markets presentation, at or above $16.00 per barrel; or two consecutive quarters of repurchase at the June-quarter pace, which would retire roughly 12% of the shares annually and mechanically close a meaningful part of the valuation gap. We would move to Underperform on a negotiated end to either conflict that returns capacity faster than the consultant scenario assumes, or on gasoline cracks retracing toward the March levels while distillate normalizes. The business is winning every argument it can control. The price is asking it to keep winning the ones it cannot.