Valero's Best Refining Quarter in Years, and the Unit That Would Have Made It Better Is Still Burned Out

Results vs. Consensus

Valero reported before the open on April 30 and held its call at 10:00 a.m. ET. The print cleared every published bar by a wide margin, and the size of the beat says as much about where the sell-side bar sat as about the quarter itself.

Q1 2026 Scorecard

There is no GAAP-to-adjusted gap this quarter. The only adjustment in the reconciliation table belongs to the prior-year period, where a $1,131 million Benicia and Wilmington impairment, $877 million after tax, turned a $282 million adjusted profit into a $595 million reported loss. Q1 2026 GAAP and adjusted EPS are the same $4.22.

The two consensus vendors we track disagreed on the bar. One carried $3.16 on EPS and $31.38 billion on revenue; the other carried $3.07 and $30.88 billion, having revised up from $2.97 in the final week. We use the higher set above, which is the conservative choice for describing the beat. On the lower bar the surprise is +37.5% on EPS and +4.9% on revenue. The direction of the revisions matters more than the level: the Street was still marking its estimates higher into the print and had not caught up to March.

Year-over-Year Income Statement

The line that matters most in that table is the third one from the top. Cost of materials and other rose 0.5% while revenue rose 7.0%. That is the entire quarter in two numbers: Valero sold more valuable barrels without paying materially more for the crude that made them. Brent averaged $77.92 against $74.89, up 4.0%, but the crude Valero actually ran was cheaper relative to Brent across every heavy grade the company buys.

Sequential Comparison

Two rows in the sequential table deserve to be read together. Refining margin dollars were flat at roughly $3.9 billion, but throughput fell 199 thousand barrels per day, or 6.4%. Valero earned the same gross refining dollars on materially fewer barrels. Some of that throughput decline is the normal first-quarter turnaround calendar; some of it is eight days of a completely shut Port Arthur at the end of March. Either way the per-barrel economics improved 9.5% sequentially into a quarter with a large planned and unplanned outage load, which is the operational read management wanted the market to take.

Assessment: Revenue

Revenue is close to meaningless for a refiner, and we spend as little time on it as the reader will allow. What matters is that the revenue line rose 7.0% while cost of materials rose 0.5%, and that the gap is not a one-quarter accident of hedge timing. It is the arithmetic consequence of two simultaneous moves: crude discounts widened (Brent less Maya went from $9.79 to $11.48, Brent less Western Canadian Select Houston from $7.24 to $13.57) and distillate product cracks widened far more. Valero sits at the intersection of those two moves by construction, not by luck. The one caution is that revenue also rose because Brent itself rose 4.0%, and a refiner's revenue line inflates with crude price regardless of profitability. Do not read the top line as a demand signal.

Assessment: Margins

Refining margin per barrel of $14.90 compares with $12.29 for full-year 2025 and $10.62 for full-year 2024. Adjusted refining operating income per barrel of $6.98 compares with $4.83 and $3.74 for those same years. This is not a marginal improvement on trend; it is roughly 45% above the 2025 full-year level on the gross margin line and 45% above it on the operating line. The composition is what makes it credible. Operating expenses per barrel of $5.13 rose only 1.2% year over year despite lower absolute throughput than the fourth quarter, and management guided that number down to approximately $4.85 for the second quarter. Cost discipline is not carrying the quarter, but it is not leaking it either.

The West Coast is the one margin line that got worse. Refining margin per barrel there fell from $14.43 to $11.74 even though both California gasoline and California diesel reference cracks widened. That looks contradictory until you remember Benicia was being idled through the quarter, so the region ran declining volumes through a fixed cost base with roughly $100 million of accelerated depreciation layered on top. Depreciation per barrel on the West Coast was $9.46 against $3.82 a year ago. That is a wind-down artifact and it substantially disappears after April.

Assessment: EPS

The $4.22 is honest. It carries no tax benefit, no gain on sale, no reserve release and no non-GAAP adjustment at all. It absorbs roughly $0.26 per share of Benicia wind-down depreciation and roughly eight days of a fully shut Port Arthur. It was earned on the smallest share count in the company's modern history. The gap to consensus is large partly because Valero executed well and partly because the sell-side had not marked its March assumptions. Neither of those is a criticism of the print. What the print does not tell you is anything about the second quarter, which will be a fundamentally different quarter fought on different cracks with a damaged hydrotreater.

Segment Performance

All three operating segments improved year over year and all three were profitable, which has not been true in every recent quarter. Renewable Diesel swung by $280 million and Ethanol more than quadrupled. Neither is large enough to matter to the equity on its own, but together they contributed $229 million of operating income against a $121 million combined loss a year ago, a $350 million swing that is roughly 13% of the total operating income improvement.

Refining

Refining is the company. It generated $1,806 million of the $1,731 million of consolidated operating income, meaning the other segments net of corporate were a small drag in aggregate. The regional detail is where the quarter's character shows.

The Gulf Coast is doing the work. It is 60% of throughput and 75% of adjusted refining operating income, and its margin per barrel rose 68% year over year against a 52% rise for the system. North Atlantic, which is Pembroke in Wales and Quebec City, delivered $383 million of operating income on 505 thousand barrels per day, the highest operating income per barrel of any region at $8.42. That is the export-facing diesel machine working exactly as designed: the North Atlantic diesel crack widened from $20.88 to $36.54, the single largest regional crack move in the table.

The West Coast lost $118 million on an adjusted basis against a $2 million loss a year ago. That deterioration is entirely explained by Benicia's wind-down, and the region's throughput guidance of 120 to 130 thousand barrels per day for the second quarter, against 201 thousand this quarter, tells you the drag is being sized down rather than fixed. On our arithmetic the West Coast has been a persistent negative-return asset for Valero, and shrinking it is value-accretive even if the accounting looks ugly on the way out.

Feedstock and Yield Mix

This table complicates the narrative in a way worth sitting with. Management spent the call describing a system pointed at maximum heavy sour crude, and the reported heavy sour crude throughput fell 19.1% year over year, a decline of 106 thousand barrels per day. The offset appears in residuals, up 84 thousand barrels per day, and other feedstocks, up 76 thousand. Those two categories together rose 160 thousand barrels per day, which is where very heavy Venezuelan grades and purchased intermediates would land in this presentation. The narrative and the disclosure are reconcilable, but the disclosure does not confirm the narrative on its own, and Valero did not quantify Venezuelan volumes anywhere.

The yield mix barely moved: distillates were 37.7% of total yields against 37.8% a year ago; gasoline 47.5% against 48.3%. That is the important negative finding. Valero did not capture the distillate crack by re-slating the whole system toward diesel. It captured it because its slate was already there, and because within distillate it shifted toward jet, which carried a premium regrade.

"Typically, if you look at Jet as a percentage of total distillates that's a number that averages about 26% in our system." "In March, we got that up to over 30%, yet as a percent of total distillates."
— Gary Simmons, Executive Vice President and Chief Operating Officer

Assessment: The refining result is real and repeatable so long as the crack structure holds, but it is a positioning result rather than an operating-leverage result. There is little evidence in the yield table that Valero has meaningful additional distillate optionality to pull; the jet-versus-diesel shift within distillates is the lever that remains, and management said it is moving two more refineries into jet production. That is worth something, but it is a several-hundred-basis-point mix adjustment, not a step change.

The Crack Structure That Defined the Quarter

Assessment: Read down the gasoline rows and then the diesel rows. Gasoline cracks fell in three of four regions year over year, and the Mid-Continent gasoline crack went negative, meaning the reference gasoline barrel was worth less than the crude that made it. Diesel cracks rose in all four regions, by $10.91 on the Gulf Coast, $7.96 in the Mid-Continent, $15.66 in the North Atlantic and $12.63 on the West Coast. Valero delivered a 52% improvement in system refining margin per barrel out of a market that was actively destroying gasoline economics. That is the strongest single argument for the quality of the asset base, and it is also the clearest warning about what happens if the distillate dislocation resolves while gasoline stays broken.

Renewable Diesel

Diamond Green Diesel produced its best quarter in over a year. The swing from a $0.64 per gallon operating loss to a $0.51 per gallon operating profit is $1.15 per gallon, on volumes up 24.3% year over year. The drivers are visible in the reference table: the RVO nearly doubled to $9.41 per barrel, the biodiesel RIN went from $0.79 to $1.44, and NYMEX diesel rose 22%. Feedstock costs rose too, with used cooking oil up 26% and tallow up 20%, but nowhere near enough to offset the product and credit side.

"the RVO is a pretty strong tailwind. We see a lot of higher margins, certainly higher in 2Q than in 1Q and overall, a better '26 versus '25."
— Eric Fisher, Senior Vice President, Product Supply, Trading and Wholesale

Management also flagged a specific mechanical headwind that will not be obvious from the reference tables:

"the mark-to-market that we have on our forward feedstock positions will be a little bit of a headwind if we see the underlying commodities continue to rise like we did for the last month or so."
— Eric Fisher, Senior Vice President, Product Supply, Trading and Wholesale

Assessment: This is the segment where policy does the heavy lifting, and policy is exactly what neither management nor we can underwrite. The RVO and RIN moves that drove the quarter are administrative outcomes, not market outcomes, and the same administration that granted Jones Act waivers to ease product logistics can revisit blending obligations. Second-quarter volume guidance of approximately 320 million gallons implies roughly 3,516 thousand gallons per day over the 91-day quarter, up about 16% sequentially, with total operating costs guided from $0.60 to approximately $0.46 per gallon. The operating leverage is real. We give the segment credit for a recovery, not for a re-rating.

Ethanol

Ethanol quadrupled year over year and fell 23% sequentially, and neither number is very informative on its own. The reference prices barely moved: corn was down 7.6% year over year and NY Harbor ethanol was flat. The improvement is co-product value and the clean fuel production credit. Management disclosed booking $0.10 per gallon on ten of its twelve plants using the original definition of qualified sales, with more available once final guidance publishes.

"what we booked in the first quarter was $0.10 a gallon on 10 of our plants using the original definition of qualified sales."
— Eric Fisher, Senior Vice President, Product Supply, Trading and Wholesale

The strategic framing was more interesting than the quarter:

"ethanol being an octane component has now become the cheapest form of octane in the world."
— Eric Fisher, Senior Vice President, Product Supply, Trading and Wholesale

Assessment: The global octane argument is the first genuinely new piece of the ethanol thesis we have heard in some time, and it is coherent: if hydrocarbon prices stay elevated, blending economics improve everywhere, and management named Brazil, India and several first-time adopters as sources of incremental demand. Valero is investing in yield and rate expansion at existing plants rather than building capacity, which is the right risk posture. What management did not do is size the credit contribution in dollars, and until they do the segment's earnings quality is unverifiable from the outside.

Key Topics & Management Commentary

Overall Management Tone: Composed and process-oriented, with the operational and commercial narrative delivered as a set of executed decisions rather than as a claim about the environment. The notable feature of this call was restraint: with a 33% earnings beat and the strongest distillate market on record, management declined to raise its mid-cycle margin assumption, declined to signal a buyback acceleration, and declined to give a Port Arthur repair timeline it did not have. Where the answers thinned was on quantification, not on candour; several of the quarter's most consequential drivers were described qualitatively and never sized.

1. The Port Arthur Fire

On March 23 a fire in the diesel hydrotreater at Port Arthur forced a precautionary shutdown of the entire refinery, one of the largest in the Valero system. No injuries were reported. By the call, most of the plant was back: the smaller crude unit train restarted in early April along with the coker, hydrocrackers, reformer and distillate hydrotreater, and the larger crude unit, FCC and alkylation unit were coming up as management spoke. The damage that matters is narrower and worse.

"The diesel hydrotreater that experienced the fire along with an adjacent kerosene hydrotreater do remain down which could negatively impact capture rates some in the second quarter."
— Gary Simmons, Executive Vice President and Chief Operating Officer

"We expect to get the kerosene hydrotreater back by the third quarter." "The diesel hydrotreater did sustain extensive damage. We don't have a time line for the rebuild yet on that."
— Gary Simmons, Executive Vice President and Chief Operating Officer

Financially, management gave the market almost nothing to model. Additional 2026 capital expenditure is expected, should be covered by insurance subject to deductibles, and the capital investment guidance stays unchanged until a definitive estimate exists.

"We'll update our 2026 capital investment guidance when we are able to provide a definitive cost estimate and expected repair time line."
— Homer Bhullar, Senior Vice President and Chief Financial Officer

Assessment: Throughput recovery by May 1 is the good news and it is genuinely good; the plant is running. The bad news is the specific unit. A diesel hydrotreater is what converts high-sulfur distillate into saleable ultra-low-sulfur diesel, and the Gulf Coast ULS diesel crack is the single widest crack in Valero's reference table at $27.60 per barrel. Losing that unit indefinitely, in this market, is close to the worst-timed outage the company could have drawn. Management named it as a capture-rate risk for the second quarter without sizing it. We treat the absence of a rebuild timeline as the most important open item in the story.

2. Distillate Strength Against Gasoline Collapse

The quarter's crack structure was violently two-sided, and management's demand commentary explained why. Domestic demand was described as resilient and roughly flat, with the marginal change coming almost entirely from exports.

"So when we look at sales, we would say U.S. demand for gasoline is flat to slightly up." "Really, the big change in demand year-over-year is the pull into the export market since the conflict in Iran."
— Gary Simmons, Executive Vice President and Chief Operating Officer

"The recent DOE data shows exports from the U.S. are up 470,000 barrels a day year-over-year." "relative to the 5-year average, total light product inventories in the U.S. have drawn 30 million barrels since January." "Distillate inventory is at 5-year lows."
— Gary Simmons, Executive Vice President and Chief Operating Officer

The framing management chose is worth noting because it is a rebuttal to the prevailing narrative rather than a restatement of it. Where the market has read falling apparent global consumption as demand destruction, management read it as unmet demand.

"our expectations coming into the year was that new capacity additions, along with more bile renewable fuels on the market would be sufficient to meet incremental demand." "We had very little excess refining capacity globally."
— Gary Simmons, Executive Vice President and Chief Operating Officer

Assessment: The distinction between demand destruction and insufficient supply is not semantic; it determines whether cracks mean-revert on demand elasticity or persist until physical capacity returns. Management's version is supported by the inventory data they cited and by the export figure. It is also, conveniently, the version that supports the equity. We think the evidence favours them on the facts and we still do not think the market should capitalize the condition, because the resolution mechanism is geopolitical rather than economic.

3. Venezuela, Heavy Sour and the Crude Set-Up

Sanctions relief in January reopened Venezuelan barrels to the U.S. Gulf Coast, and the crude discount set widened materially: Brent less Maya went from $9.79 to $11.48 and Brent less Western Canadian Select Houston nearly doubled from $7.24 to $13.57. Management described a system already configured for that trade before the Iran disruption compounded it.

"Since the January sanctions removal, we've meaningfully ramped up Venezuela runs in our systems"
— Valero executive on the crude slate

"Canadian heavy crude today is trading like a $16 discount versus TI in the Gulf."
— Randy Hawkins, Valero Energy

High freight rates and steep backwardation caused the commercial team to shift the sourcing mix toward pipeline barrels and away from waterborne, and to buy more Strategic Petroleum Reserve grades as they came to market.

Assessment: This is the part of the quarter that the published indicators genuinely cannot see, and management said so. It is also the part with the shortest half-life. Venezuelan supply availability is a policy variable that reversed once and can reverse again, and the freight and backwardation conditions that made pipeline barrels advantaged are cycle conditions. We note again that heavy sour crude throughput was reported down 106 thousand barrels per day year over year while the narrative described maximizing heavy sour; the residuals and other feedstocks lines absorbed the difference, and Valero never gave a Venezuelan volume figure.

4. Benicia and the California Exit

Valero began idling processing units and ceased operation of the fuel production units at Benicia during the quarter, completing the idling in April. The cost shows up twice: roughly $100 million of incremental depreciation in the first quarter from the shortened useful life, and a West Coast adjusted operating loss of $118 million against $2 million a year ago. Guidance calls for roughly $33 million of further incremental Benicia depreciation in the second quarter, with an earnings impact of approximately $0.09 per share, after which it stops.

The strategic logic is not in dispute. The West Coast delivered a refining margin of $11.74 per barrel this quarter against a system average of $14.90, in a region where the reference cracks were among the widest in the table. When your best-priced product market produces your worst realized margin, the problem is the cost structure, not the market.

Assessment: This is a rare case where a large accounting charge represents a genuine improvement in enterprise quality. West Coast throughput guidance of 120 to 130 thousand barrels per day against 201 thousand this quarter removes roughly 76 thousand barrels per day of loss-making volume. The accelerated depreciation is non-cash and finishes in April. On a look-through basis the second half of 2026 should carry a materially smaller California drag, and we would expect the West Coast line to move toward break-even at the remaining Wilmington asset. Management has not committed to a further California exit, and the press release's forward-looking language still references plans and operations in California as an open item.

5. The Balance Sheet and the March Notes Issue

Valero ended the quarter with $9.2 billion of total debt, $2.3 billion of finance lease obligations and $5.7 billion of cash, for a debt-to-capitalization ratio net of cash of 18%. Cash rose $1,045 million from year-end. Both moves were deliberate.

"The notes priced at a refining sector, record low 10-year spread of 102 basis points over treasuries."
— Homer Bhullar, Senior Vice President and Chief Financial Officer

"our decision to move towards the high end of our long-term $4 billion to $5 billion cash target to preserve optionality in a volatile market environment." "we ended the quarter with almost $11 billion of total liquidity."
— Homer Bhullar, Senior Vice President and Chief Financial Officer

Assessment: The $850 million issue at 5.150% for 2036 debt, priced inside anything the sector had achieved at that tenor, is a real and quantified win, and pre-funding 2026 maturities in March rather than waiting was good treasury work. The higher cash balance is the more interesting decision. Carrying cash at the top of a $4 billion to $5 billion range costs real money in a quarter when the company could be repurchasing stock instead. Management framed it as buying optionality against volatility. We read it as a mild but genuine signal that the people closest to the commodity see enough downside variance to want a buffer, which sits awkwardly next to the market's willingness to capitalize current margins.

6. Risk Management: Staying Close to LIFO

The most operationally specific answer of the call concerned how Valero managed commodity risk through a quarter in which crude and product markets dislocated from their futures curves.

"we maintained our inventory positions much closer to LIFO. So that reduced our overall exposure to derivatives and associated price swings, right?"
— Homer Bhullar, Senior Vice President and Chief Financial Officer

The chief executive returned to the same point later in the call, describing it as an explicit discipline rather than an outcome.

The consequence shows in the cash flow statement. Working capital was a $303 million use of cash in a quarter where crude prices rose 23% sequentially and physical markets disconnected from futures, which is a small number in that context and reflects the absence of margin calls on a large derivative book.

Assessment: This is the most underrated disclosure of the quarter and the best answer to the question of why Valero's results are less volatile than peers'. Running inventory at LIFO working levels means the company is not carrying a paper position that has to be defended with cash when the curve moves. It is unglamorous and it is a durable structural advantage rather than a quarterly one. It also means investors should not expect Valero to capture inventory holding gains when prices spike, which is the flip side and which the market sometimes forgets.

7. Capital Returns and the Buyback Framework

Stockholder cash returns totaled $938 million, a 59% payout of adjusted operating cash flow, split roughly $0.36 billion of dividends against roughly $0.57 billion of repurchases. The quarterly dividend was raised 6% to $1.20 per share in January. Pressed on whether a record cash position and a full valuation should change the buyback posture, management defended the framework without widening it.

"our underlying commitments around balance sheet, minimum cash and shareholder returns will not change, but we may move within the balance we've laid out depending on the environment that we're in."
— Homer Bhullar, Senior Vice President and Chief Financial Officer

"this approach has reduced our overall share count by 42% since 2014." "our return on buybacks is close to 20% over that time period, so buybacks do create perpetual value by reducing the share count."
— Homer Bhullar, Senior Vice President and Chief Financial Officer

Assessment: A 42% share count reduction since 2014 is an exceptional record and the reason the company deserves the benefit of the doubt on capital allocation. But the 20% return-on-buyback figure is a backward-looking average earned largely at prices far below today's, and citing it to defend repurchases at a 116% twelve-month gain is the weakest reasoning offered on the call. A 59% payout with cash building toward the top of the target range, in a quarter of record earnings, is a company choosing balance-sheet optionality over per-share accretion. That is a defensible choice. It is not the choice a management team makes when it believes its own stock is cheap.

8. Mid-Cycle Discipline and the Refusal to Re-Rate

The single most consequential exchange of the call concerned whether a structurally tighter refining world changes the margin Valero uses to justify capital spending.

"So I don't know that it will change our approach to mid-cycle margins."
— Gary Simmons, Executive Vice President and Chief Operating Officer

Management was nonetheless explicit that the physical situation is more than a war premium, describing a pre-existing tightening that the conflict pulled forward, and quantifying the restocking arithmetic.

"So at this stage, it's at least 6 months to a year to start restocking inventories back to where they were."
— Gary Simmons, Executive Vice President and Chief Operating Officer

Assessment: Hold these two statements side by side, because they are the entire investment debate. The physical view is bullish and specific: several years of tightness, minimum six to twelve months to restock, and very little excess global capacity. The financial policy view is unchanged: we will not sanction capital against a higher assumed margin. Management is telling investors that they believe the near-term environment and refuse to capitalize it. We think that is exactly right and we think it should be applied to the equity as well as to the capital budget. The market is currently doing the opposite.

9. VGO Scarcity and the Constraint Nobody Is Pricing

A specific physical bottleneck surfaced twice, unprompted the second time.

"It doesn't appear there's sufficient VGO to fill both FCC and hydrocracking capacity."
— Gary Simmons, Executive Vice President and Chief Operating Officer

The consequence management drew is that economics currently favour hydrocracking over catalytic cracking, which would further reduce gasoline production. The chief executive framed vacuum gas oil self-sufficiency as a candidate for capital.

"we like projects that increase our commercial leverage."
— Lane Riggs, Chairman, Chief Executive Officer and President

Assessment: This is a genuinely non-obvious second-order effect and it cuts in Valero's favour twice. If intermediates are scarce, refiners with integrated conversion capacity and Gulf Coast logistics run better than those buying intermediates on the open market. And if hydrocracking economics displace catalytic cracking across the industry, gasoline supply tightens from the supply side just as the summer season arrives, which would repair the one crack that is currently broken. We would rank this the most interesting forward-looking disclosure on the call, and it is nowhere in the reported numbers.

10. Export Policy Risk

With retail gasoline prices under political scrutiny, the possibility of product export restrictions is a live tail risk for a company that describes direct access to global markets as a core advantage. The general counsel addressed it directly.

"And the reality is any kind of export ban actually just makes the situation way worse, and they're keenly aware of that already."
— Rich Walsh, Executive Vice President and General Counsel

Management cited the early Jones Act waiver as evidence that the administration is reaching for supply-side tools rather than restrictive ones, and Valero confirmed it has used those waivers.

"we have issued several Jones Act waivers primarily for products, both renewables and conventional products moving both from the Gulf Coast to the West Coast and to Florida."
— Randy Hawkins, Valero Energy

Assessment: The economic argument against an export ban is correct and well made. It is also not a probability estimate, and the company offered none. A refiner earning record margins while pump prices rise is a politically exposed position regardless of the economics, and management's confidence rests on the administration's current understanding rather than on any structural protection. We treat this as a low-probability, high-severity risk that is not in the price.

11. The Forward Curve

Asked how to think about back-dated cracks when liquidity thins out along the curve, management gave a directional view rather than a hedged one.

"So that is our view as we think the back end of the curve is undervalued."
— Gary Simmons, Executive Vice President and Chief Operating Officer

The mechanism offered was that high freight and steep backwardation are causing short markets to live hand to mouth on the expectation of cheaper replacement barrels, and that the curve keeps rolling up instead.

Assessment: This is a real opinion, stated plainly, and it is a modest inconsistency with the refusal to raise mid-cycle. If the back of the curve is undervalued and the front is not going to relax for six to twelve months, the sanctioning assumption arguably should move. Management is choosing to be bullish in commentary and conservative in capital policy. That asymmetry is investor-friendly, but it does mean the commentary should be discounted relative to the policy when assessing what the company itself believes.

Guidance & Outlook

Valero does not guide to revenue or earnings. It guides to volumes and costs, which for a refiner is the more useful disclosure because the margin is not in management's control. The second-quarter guide is a step down in volume and a step down in cost.

Implied quarter-over-quarter ramp. The throughput guide midpoint of roughly 2,790 thousand barrels per day is 4.3% below the first quarter's 2,914. Roughly 76 thousand barrels per day of that decline is the deliberate Benicia removal, which takes out loss-making volume, and roughly 39 thousand is the Gulf Coast reduction at the midpoint, which does not. Adjusting for Benicia, the underlying system is guided down about 1.7%, which for a quarter following a major fire is a modest constraint rather than a crippling one.

Where the guide is quietly good. Every cost line moves in Valero's favour. Refining cash operating expenses per barrel fall $0.28, which on roughly 254 million barrels of guided throughput is worth about $71 million of pre-tax income. Total depreciation and amortization falls $110 million sequentially as the Benicia acceleration rolls off. Renewable Diesel unit costs fall $0.14 per gallon on 17.5% more volume. The full-year general and administrative guide of approximately $960 million against $285 million spent in the first quarter implies roughly $225 million per quarter for the balance of the year, against roughly $260 million per quarter over the last three quarters of 2025. Some of that is normal first-quarter compensation seasonality, but not all of it, and management did not explain the step-down.

Street at. There is no published consensus for the operating metrics Valero guides to, so the guide cannot be scored against expectations in the conventional sense. What is scoreable is the direction: on the volumes and costs the company controls, the second quarter is guided better than the first on every line except throughput and interest.

Guidance style. Specific, narrow-banded and complete on everything except the one item investors most want. Ranges are 50 thousand barrels per day wide on a 1.7 million barrel per day region, which is tight. The conspicuous omission is any dollar figure for Port Arthur repair capital or any repair timeline, and the refusal to update total capital investment guidance until that estimate exists. That is defensible practice and it leaves a hole in every model on the Street.

Analyst Q&A Highlights

Demand Resilience Against the Export Pull

The call opened on the question every refining investor is asking in a high-price environment: is demand cracking. The answer separated wholesale volume declines caused by Valero's own asset actions from underlying consumption, and relocated the entire year-over-year change to exports. Management then pushed back on the demand destruction framing directly, arguing that apparent consumption weakness reflects supply that cannot reach the market rather than buyers who have stopped buying.

Q: "I just quickly wanted to pivot to the global refining macro, and I'm trying to understand as these prices are rising, Gary, if you or somebody could comment as to what you're seeing for demand out there, are you seeing any early signs of demand disruption in your system?"
— Manav Gupta, UBS

A: "Despite the fact as you alluded to, the prices for transportation fuels are moving higher, it appears that especially domestic demand appears to be very resilient."
— Gary Simmons, Executive Vice President and Chief Operating Officer

Assessment: Management answered fully and with data rather than assertion, citing export volumes, inventory draws against the five-year average and the closure of the transatlantic arbitrage. The distinction they drew, that this is insufficient supply rather than destroyed demand, is the load-bearing claim of the bull case and they defended it with the strongest evidence available. It is still a claim about a war, not about an economy.

Second-Quarter Modelling Against a 2022 Analogue

A recurring line of questioning attempted to anchor the second quarter to the last comparable crack spike, noting that the share count is roughly a quarter smaller than it was then. The response declined the analogue and gave a balanced list of mechanical pluses and minuses instead, with backwardation and the physical-versus-futures disconnect on the negative side and heavy sour access, jet regrade and secondary product premiums on the positive.

Q: "But as we start thinking about modeling out Q2 here, any pluses and minuses that we should sort of be thinking about and anchoring to and anything about March profitability that can give us a sense of what Q2 could shape up like."
— Neil Mehta, Goldman Sachs

A: "Certainly, the steep backwardation in the crude market is a headwind." "the heavy sour discounts our system be able to maximize heavy sour crude is a tailwind. The premium regrade for jet fuel is a tailwind as well as premium for secondary products."
— Gary Simmons, Executive Vice President and Chief Operating Officer

Assessment: A genuine non-answer, and a reasonable one. Management would not confirm the peak-cycle comparison and would not quantify March. The refusal to give an intra-quarter profitability datapoint when the stock is at a fifty-two-week high is disciplined behaviour, and it is also why the market had to price the second quarter off the indicators rather than off the company.

Why Valero's Results Were Less Volatile Than Peers'

The most substantive exchange of the call asked directly why Valero's earnings dispersion has been narrower than the sector's in the same macro environment, and whether an elevated cash position is a deliberate volatility buffer. The response separated the two and gave a mechanical explanation for the first that has nothing to do with asset quality.

Q: "But despite operating in the same macro environment, your results appear to have been less volatile. And from your perspective, I'm curious as to what you think has enabled that. Does it reflect differences in crude sourcing, product placing or hedging strategies or something else structural in the business."
— Theresa Chen, Barclays

A: "we maintained our inventory positions much closer to LIFO. So that reduced our overall exposure to derivatives and associated price swings, right? And then in addition to that, that also ensures that you don't have a significant draw on cash for margin calls."
— Homer Bhullar, Senior Vice President and Chief Financial Officer

Assessment: This is the answer to keep. The lower volatility is not a story about better refineries; it is a story about not carrying a paper inventory position that has to be funded when the curve moves against you. It is verifiable in the cash flow statement, where working capital consumed only $303 million in a quarter of extreme price movement. It is also structural and repeatable, which makes it one of the few genuine quality arguments for paying a premium multiple.

The Port Arthur Damage Assessment

The most consequential question of the call asked what the restart path and the external signposts look like. Management gave a detailed and credible unit-by-unit account of the restart, then stopped precisely where the money is.

Q: "And then on Port Arthur, I recognize you're still going through the assessment. But to the extent you can, could you just talk through the refinery damage assessment process and potential restart time line? And what are the signposts that we should be watching for from the outside here?"
— Joseph Laetsch, Morgan Stanley

A: "we would expect by May 1 that throughput looks fairly normalized at the Port Arthur refinery." "The diesel hydrotreater did sustain extensive damage. We don't have a time line for the rebuild yet on that."
— Gary Simmons, Executive Vice President and Chief Operating Officer

Assessment: Management answered the throughput question and declined the earnings question, which is the correct order of candour and the wrong order for a model. The gap between a normalized throughput rate and an indefinitely damaged hydrotreater is exactly the gap between a volume story and a margin story, and in a quarter where the Gulf Coast ULS diesel crack is $27.60 per barrel it is the difference that matters. No investor left this call able to size the second-quarter capture-rate hit.

Capital Allocation Against a Full Valuation

A pointed challenge argued that the balance sheet leaves few uses for surplus cash and that a discounted free cash flow on non-windfall margins already supports a large number, then asked how the company thinks about buying its own stock at this level. The response reasserted the framework, cited the historical repurchase record, and did not engage with the valuation premise.

Q: "And my question is that your valuation today, if you sort of look at the implied free cash flow forever, not the windfall we have now is north of $7 billion at a 10% discount rate. How do you think about your valuation in the context of what you do with that cash as it relates specifically to share buybacks?"
— Douglas Leggate, Wolfe Research

A: "our underlying commitments around balance sheet, minimum cash and shareholder returns will not change, but we may move within the balance we've laid out depending on the environment that we're in. and we clearly did that with respect to cash during the first quarter."
— Homer Bhullar, Senior Vice President and Chief Financial Officer

Assessment: The question asked whether the stock is cheap and the answer described a policy. That is a dodge, and a revealing one. The explicit statement that the company moved within the framework toward cash during the quarter is management telling the market what it did with the marginal dollar at these prices, and it did not buy stock with it. Investors should weight that action above the historical twenty-percent return figure that was offered in its place.

Whether a Twice-Disrupted World Changes the Investment Framework

A structural question asked whether two successive geopolitical dislocations change how the company thinks about medium-term investment, using the flagged vacuum gas oil shortage as the worked example. The question itself was broad; the answer is the artifact, and it produced the clearest articulation of the capital framework given on the call, sorting projects into commercial leverage, reliability and yield improvement, and confirming that intermediates self-sufficiency is moving through the gating process.

A: "we like projects that increase our commercial leverage. So if you think about your VGO question, that's a position that we want to get through our gating system to maybe position ourselves not to be so lenient or so dependent upon BDO imports. And so doesn't mean we're going to lose our discipline, but it means that we see that there's an issue has been really pointed out with respect to these projects is the conflicts."
— Lane Riggs, Chairman, Chief Executive Officer and President

Assessment: The framework is coherent and the discipline caveat was volunteered rather than extracted, which is a good sign. What it confirms is that the company's response to a structurally tighter world is a set of short-cycle optimization projects, not a capacity expansion. That is the correct answer for shareholders and it is also a quiet statement that management does not believe the current margin environment justifies building anything.

Ethanol Economics and the Production Credit

A question probing whether the ethanol beat was co-product driven or credit driven produced both the global octane argument and the only specific quantification of the credit given on the call, along with an explicit statement that the larger portion remains unbooked pending final guidance that may not arrive until next year.

Q: "Was that just a function of improving values on the co-products or were you able to record any 45 contributions in the ethanol segment? And I guess, what's the overall outlook for and the potential contribution this year in ethanol."
— Matthew Blair, Tudor, Pickering, Holt & Co.

A: "what we booked in the first quarter was $0.10 a gallon on 10 of our plants using the original definition of qualified sales. And so what we'll ultimately see once the guidance is published, which hopefully, at the end of this year, but it may not be until next year is you'll get the next $0.10 to $0.20 across all our plants across all our sales."
— Eric Fisher, Senior Vice President, Product Supply, Trading and Wholesale

Assessment: A rare piece of genuinely modellable disclosure, with an honest timing caveat attached. The booked credit is narrow in both rate and coverage, and the incremental opportunity is roughly two to three times the size of what has been recognized. Because it depends on published guidance rather than on operations, we treat it as unmodelled optionality rather than as an estimate, and we note that management themselves flagged that it may slip a year.

What They're NOT Saying

1. No dollar quantification of the Port Arthur earnings impact. Management described the diesel hydrotreater outage as something that "could negatively impact capture rates some in the second quarter" and left it there. They gave a throughput guide that embeds it, but no capture-rate delta, no lost-margin estimate and no insurance recovery figure. Every model on the Street now contains a Port Arthur assumption that came from the analyst rather than the company.
2. No repair timeline and no repair capital estimate. The company stated that additional 2026 capital expenditure is expected, that it should be covered by insurance subject to deductibles, and that capital investment guidance will be updated when a definitive estimate exists. Five weeks after the fire, with the plant otherwise restarted, the absence of even a range is conspicuous. The most benign reading is engineering caution. The less benign reading is that the rebuild is long.
3. No Venezuelan volume figure. Management said Venezuela runs had been meaningfully ramped since the January sanctions relief and described the barrels as economically advantaged, but gave no volume, no discount capture and no dollar contribution. Meanwhile reported heavy sour crude throughput fell 106 thousand barrels per day year over year. The two statements are reconcilable through the residuals and other feedstocks lines, but the company left investors to do that reconciliation unaided.
4. No explanation for the general and administrative step-down. First-quarter G&A of $285 million against a full-year guide of approximately $960 million implies roughly $225 million per quarter for the balance of 2026, against roughly $260 million per quarter across the last three quarters of 2025. That is a meaningful cost reduction embedded in guidance and nobody described where it comes from or asked.
5. No sizing of the ethanol production credit. The disclosure was $0.10 per gallon on ten of twelve plants on the original definition of qualified sales. It was not converted into dollars, and the segment's $90 million of operating income was not decomposed between credit, co-products and core crush. The next $0.10 to $0.20 was framed as available across all plants and all sales, which is a materially larger number, with a timing caveat that stretches into next year.
6. No forward view on California beyond Benicia. Benicia is idled and West Coast throughput is guided to 120 to 130 thousand barrels per day. The press release's forward-looking language still lists plans, actions, assets and operations in California as an open matter, and the region still lost $118 million on an adjusted basis this quarter. Management was not asked and did not volunteer whether Wilmington is a keeper.
7. No probability framing on export restrictions. The general counsel argued convincingly that an export ban would be counterproductive and that the administration understands this. He did not say the risk was zero, did not describe any contingency planning, and did not address what a partial or product-specific restriction would do to a system that describes global market access as a core advantage.

Market Reaction

• Pre-print setup: The stock closed at $251.30 on April 29, up 54.4% year to date against 4.2% for the S&P 500, up 116.5% over the trailing twelve months, and up 1.7% over the trailing thirty days. The fifty-two-week closing range entering the print was $114.75 to $254.32, so the shares came in within 1.2% of a fifty-two-week closing high.
• Reaction session (April 30, a before-the-open reporter): Opened at $245.88, a 2.2% gap lower, traded a range of $243.02 to $253.25, and closed at $252.58, up 0.5% or $1.28 on the day.
• Volume: 3.5 million shares against a 3.9 million thirty-day average, roughly 0.9 times normal. There was no volume event.
• Peer and index reaction the same session: The S&P 500 rose 1.0%. The energy sector ETF rose 1.1%. Among refining peers, Phillips 66 rose 3.3%, Marathon Petroleum rose 2.7%, HF Sinclair rose 1.9% and PBF Energy rose 0.5%. Valero underperformed both the index and every large refining peer except PBF on the day it beat by 33%.

The market's verdict was not about the quarter. A 33% earnings beat that produces a half-percent session, on below-average volume, against a refining group up two to three percent, is the market saying the print was already owned and the news was elsewhere. Three things explain the muted response, and they compound.

First, positioning. Entering the print the shares had more than doubled in twelve months in a market that had risen four percent. There was no undiscovered story to be revealed at 7:00 a.m. on April 30, and the buyers who needed convincing had already been convinced by the crack screens.

Second, the quarter was backward-looking in the way that matters. Valero's realized refining margin of $14.90 per barrel is an average over January, February and March. The market in late April was pricing a distillate structure that had moved sharply after the quarter closed. A first-quarter number, however good, does not update the estimate that is actually driving the equity, and management's refusal to characterize March profitability specifically removed the one bridge that would have connected them.

Third, and most specifically, Port Arthur. The opening gap of 2.2% lower came before the 10:00 a.m. call, on a press release whose only reference to the incident sat in the safe-harbor language. The recovery through the session tracks the call, where management confirmed that throughput would be normalized by May 1 while disclosing that the diesel hydrotreater is out with no rebuild timeline. That is a mixed message and the stock finished roughly where it started, having underperformed peers who carry no equivalent outage. The relative move, not the absolute one, is the market's read. Valero finished 2.8 percentage points behind Phillips 66, 2.2 behind Marathon Petroleum and 1.4 behind HF Sinclair on a day the whole group rallied, and that spread is a reasonable first estimate of what the Street thinks the hydrotreater is worth.

Street Perspective

Debate: Is this a cycle peak or a structural re-rating in refining margins?

Bull view: The bull case being made on the Street is that this is not a normal crack spike. A large share of Middle Eastern refining capacity is physically damaged rather than merely offline, Russian refining has been repeatedly set back, capacity additions globally have been insufficient for years, and distillate inventories sit at five-year lows. Rebuilding damaged units takes years, not months, so the mid-cycle margin genuinely resets higher and the multiple applied to refiners should reset with it.

Bear view: The bear camp contends that every refining crack spike in living memory has been called structural at the top, and that the mechanism resolving this one is a ceasefire rather than a capital cycle. High margins are also self-correcting: they pull every functioning refiner to maximum rates, accelerate restarts, and delay closures that were otherwise scheduled. Gasoline cracks, which collapsed this quarter, show what the demand side actually looks like once price does its work.

Our take: The bulls have the better evidence on physical supply and the bears have the better evidence on duration. The decisive datapoint is that Valero's own management, who see the physical market daily and have every incentive to justify a higher assumed margin because it would unlock capital projects, explicitly declined to raise their mid-cycle assumption. When the operator will not underwrite the re-rating, an outside investor should not pay for it.

Debate: How much is the Port Arthur diesel hydrotreater worth?

Bull view: The optimistic framing is that this is a small unit in a 3.0 million barrel per day system, that throughput is back to normal within a week of the call, that insurance covers the capital, and that the capture-rate impact management flagged was hedged with a single qualifying word. Refiners take units down routinely and the market habitually overreacts.

Bear view: The skeptical framing is that unit selection matters more than unit size. A diesel hydrotreater is the specific piece of equipment that converts distillate into the product carrying the widest crack in the company's reference table, and it is out during the tightest distillate market on record. Insurance replaces the capital, not the foregone margin. And a company that can restart a coker, a hydrocracker, a reformer, an FCC and two crude units within six weeks but cannot give a rebuild timeline for one hydrotreater is telling you the damage is severe.

Our take: The bears are closer. The relative underperformance on the reaction day, between one and three percentage points against a rallying refining group depending on the peer, is the market's own rough estimate and we would not argue it lower. The asymmetry is unattractive: a credible near-term timeline recovers a couple of points, while a disclosure that the rebuild extends past 2026 costs considerably more, and management currently cannot rule either out.

Debate: Should Valero be buying back stock aggressively here?

Bull view: A growing consensus view is that a company generating record cash with the best balance sheet in the sector, trading below several published targets that were raised sharply into the print, should be leaning hard into repurchases. The historical record supports it: a 42% share count reduction since 2014 at a stated return near 20%. Every share retired at a cycle peak permanently increases mid-cycle earnings per share.

Bear view: Some desks argue the opposite, that buying stock at a fifty-two-week high after a 116% twelve-month run is precisely how refiners have historically destroyed capital, and that the discipline of a fixed payout framework exists to prevent exactly that behaviour. Building cash toward the top of the target range preserves the ability to buy the next downturn, which is where the historical 20% return was actually earned.

Our take: Management resolved this debate by their actions and the market has not fully absorbed it. They ran a 59% payout, in line with framework, and directed the marginal dollar to the balance sheet rather than to repurchases. That is a capital allocator with an exceptional record declining to buy their own stock at $250. We weight that revealed preference more heavily than any published target.

Model Framework & Valuation

This is an initiation, so there is no prior model to revise. The table sets out the assumptions we are carrying and what would move each one.

The sensitivity that matters. At 2,800 thousand barrels per day, a full year is roughly 1,022 million barrels of throughput. Each $1.00 per barrel of refining margin is therefore about $1,022 million of pre-tax income, about $787 million after tax at 23%, and about $2.64 of annual earnings per share on 298 million shares. Every other line in the model is noise by comparison. The gap between the first quarter's $14.90 and the 2025 full-year average of $12.29 is worth roughly $6.90 of annualized earnings per share on its own.

Valuation. At the reaction-day close of $252.58 and the 298 million weighted-average diluted shares reported for the quarter, the market capitalization is roughly $75.3 billion. Net debt of $5.8 billion, being $9.2 billion of debt plus $2.3 billion of finance lease obligations less $5.7 billion of cash, gives an enterprise value near $81.0 billion, or roughly $84.1 billion including the $3.1 billion noncontrolling interest that represents the other half of Diamond Green Diesel. Trailing twelve-month GAAP diluted earnings per share, summing the four reported quarters, is $13.76, so the shares trade at roughly 18.4 times trailing earnings. Annualizing the raised $1.20 quarterly dividend gives $4.80 and a yield of 1.9%. Book value per share of roughly $80 puts the shares at about 3.2 times.

Fair value framework. Applying the model above at a $12.29 per barrel refining margin, which is the 2025 full-year outcome, produces normalized earnings near $10 per share, consistent with the $10.44 of adjusted 2025 earnings per share implied by adding back the $877 million after-tax impairment to reported net income. At our $13.50 to $15.50 normalized margin band the range is roughly $13.25 to $18.50 per share. Refiners have historically been capitalized at eight to twelve times trend earnings, and applying ten to twelve times to that band gives roughly $135 to $220 with a midpoint near $175. That is about 31% below the close.

Inverted, the arithmetic is starker. To justify $252.58 at twelve times normalized earnings requires roughly $21 per share of sustainable earnings, which requires a sustained refining margin near $16.45 per barrel. At ten times it requires roughly $25 per share and a margin near $18.05. Against $12.29 for 2025, $10.62 for 2024 and $14.90 in the quarter just reported, the equity is capitalizing a margin structure roughly 34% to 47% above last year's realized level, permanently. The company will not put that number in its own capital sanctioning model.

The offset we do give the bulls is the compounding effect of a windfall year. If 2026 delivers earnings well above trend, a 59% payout returns several billion dollars, and continued repurchase at the current pace retires a mid-single-digit percentage of the share count annually. Two strong years of that mechanically lifts normalized earnings per share by a similar percentage and moves our framework midpoint from roughly $175 toward the $190s. It closes part of the gap. It does not close it.

Thesis Scorecard: Establishing Coverage

This is first coverage, so the scorecard below establishes the pillars we will grade in subsequent quarters rather than scoring a standing thesis. Status tags reflect where each pillar sits after this quarter's print and call.

Overall: The operating thesis is confirmed and the valuation thesis is not. Every bull pillar we would want to see in a refiner performed this quarter: the assets, the balance sheet, the risk framework and the self-help programme all delivered. What did not happen is any evidence that the earnings power on which the shares are priced is durable, and the company's own capital sanctioning behaviour argues against it.

Action: Initiate at Hold. Own the business, do not chase the price. We would upgrade to Outperform on a meaningful de-rating that brings the implied sustainable margin back toward the low teens, on a credible Port Arthur diesel hydrotreater rebuild timeline, or on a payout ratio that moves decisively above the framework level and signals management's own view that the stock is cheap. We would move to Underperform if a ceasefire compresses distillate cracks while gasoline stays broken, or if the Port Arthur rebuild is disclosed as extending beyond 2026.