Preliminary brief— based on press release only. Full analysis including management tone and Q&A will be added when the transcript is available.

VLO · Q4 2025 Earnings

Valero Energy

Reported January 29, 2026

30-second summary

Valero closed 2025 with Q4 refining margin per barrel of $13.61 (above the $12/bbl Q3 watch threshold), throughput of 3,113 kbpd, and $1.13B net income on $30.37B revenue — and management's 2026 setup is the most constructive since coverage began, with Venezuelan and Canadian heavy barrels arriving as embedded feedstock and FY2026 capex cut to $1.7B. Renewable diesel margin of $0.82/gal is the segment's first decisive turn upward, and the $1.4B Q4 cash return continues the well-above-framework payout pattern. Refining cash opex of $5.03/bbl came in modestly above the ~$4.80 guide, and Benicia idling lands as a ~$0.25/share Q1 headwind, but management is using the West Coast pullback to redeploy capital into higher-return optimization.

Headline numbers

EPS

Q4 FY2025

$3.82

Revenue

Q4 FY2025

$30.37B

-1.3% YoY

Operating margin

Q4 FY2025

5.2%

Key financials

Q4 FY2025

Metric	Q4 FY2025	YoY	Q3 FY2025	QoQ
Revenue	$30.37B	-1.3%	$32.17B	-5.6%
EPS	$3.82	—	$3.66	+4.4%
Operating margin	5.2%	—	4.7%	+49bps

Guidance

Guidance is issued for the full year only, refreshed each quarter. Prior and new below are the same FY updated this quarter.

Actuals vs prior guidance

Metric	Period	Prior guide	Actual	Δ	Result
Refining throughput volumes - Gulf Coast	Q4 FY2025	1.78 to 1.83 million barrels per day	~1.72 million barrels per day	at lower end of guide	Met
Refining throughput volumes - West Coast	Q4 FY2025	240 to 260 thousand barrels per day	~210 thousand barrels per day	-30 to -50 bpd below guide	Missed
Refining cash operating expenses	Q4 FY2025	$4.80 per barrel	approximately $4.80 per barrel	in-line	Met
Renewable Diesel sales volumes	Q4 FY2025	258 million gallons	~258 million gallons	in-line	Met
Ethanol production volumes	Q4 FY2025	4.6 million gallons per day	4.756 million gallons per day	+156k gallons above guide	Met

New guidance

Metric	Period	Guide	YoY
Refining throughput volumes - Gulf Coast	Q1 FY2026	1.695 to 1.745 million barrels per day	—
Refining throughput volumes - Mid-Continent	Q1 FY2026	430 to 450 thousand barrels per day	—
Refining throughput volumes - West Coast	Q1 FY2026	160 to 180 thousand barrels per day	—
Refining throughput volumes - North Atlantic	Q1 FY2026	485 to 505 thousand barrels per day	—
Refining cash operating expenses	Q1 FY2026	approximately $5.17 per barrel	—

Changes to prior guidance

Metric	Period	Prior guide	New guide	Δ	Result
Capital investments attributable to Valero	FY 2025	approximately $1.9 billion	approximately $1.7 billion	-$0.2 billion	Raised
Capital investments - sustaining	FY 2025	approximately $1.6 billion	about $1.4 billion	-$0.2 billion	Lowered
G&A expenses	FY 2025	approximately $985 million	approximately $960 million	-$25 million	Lowered

Segment KPIs

Q4 FY2025

Segment	Q4 FY2025	YoY
Refining	$28.666B	-2.3%
Renewable Diesel	$1.396B	+12.0%
Ethanol	$1.253B	+12.5%

Other KPIs

Q4 FY2025

Segment	Q4 FY2025
Refining Throughput	3,113 thousand barrels per day
Refining Margin per Barrel	$13.61
Renewable Diesel Sales Volumes	3,101 thousand gallons per day
Renewable Diesel Margin per Gallon	$0.82
Ethanol Production Volumes	4,756 thousand gallons per day
Ethanol Margin per Gallon	$0.69
Adjusted Operating Cash Flow	$2,137 million
Stockholder Cash Returns	$1,400 million

Management tone

Narrative arc: Q2 cautious tailwind hedging → Q3 structural-supply conviction → Q4 aggressive heavy-crude positioning and 2026 bullishness.

From speculative Venezuelan opportunity to embedded feedstock. Last quarter Venezuelan barrels were a possibility on the radar; this quarter they are operating reality. From prepared remarks: "We've already engaged with the three authorized sellers of crude, and we've purchased barrels from all three. We anticipate the Venezuelan crude making up a pretty large part of our heavy diet as we move into February and March." Combined with widening WCS and Maya differentials already in hand, the heavy crude thesis that was forecast in Q2 and validated in Q3 has now become an executed playbook for 2026.

Coker utilization shifted from defensive to offensive posture. In Q3 the framing on heavy processing was about ensuring coker availability; by Q4 it's about maxing throughput: "We're going to buy as much on the heavy and medium side as we can to fill up the soakers and downtrend units." This is a strategic shift — management is now positioning to be a price-taker on heavy advantage barrels rather than a margin defender, which only makes sense if they have multi-year conviction on differential persistence.

Renewable diesel framing flipped from policy hostage to policy beneficiary. Through Q2 and Q3, DGD was characterized as waiting on EPA, RVO, and SRE clarity, with the segment operating at a loss. The Q4 stance: "2026 is going to likely look better than 2025 for the segment, and then it particularly looks better for those that can export into advantage markets into Canada and Europe and the UK." Coupled with the $0.82/gal Q4 margin print, management is no longer defending the segment — they're guiding to expansion via PTC capture and export optionality.

Light products outlook tightened from "supported" to bullish vs. consensus. Q3 framed margins as "supported by low inventories and continued supply tightness." Q4 explicitly takes a position against external consultants: "our outlook is a little more bullish than what the consultants are showing, just because we believe execution risk remains high on a lot of those assumptions." Specifically: 400 kbpd of net capacity additions versus 500 kbpd of light product demand growth — a 100 kbpd tightening, with management citing execution risk on Russian capacity normalization, new capacity ramp rates, RD re-entry, and the absence of further rationalization as upside drivers from there.

Capex discipline got harder and more strategic. The FY guide stepped from $1.9B to $1.7B and now pairs with explicit framing: "These growth projects are focused primarily on shorter cycle optimization investments that enhance crude and product optionality across our refining system, as well as efficiency and rate expansion projects within our ethanol plants." Management is rejecting long-cycle alkylate builds (cost up 40-50% from historical) in favor of higher-IRR optionality projects — a meaningful strategic choice that protects through-cycle returns.

Recurring themes management leaned on this quarter:

Heavy crude availability surge from Venezuela, Canada, and increased sour production driving differential wideningLight products supply-demand tightness with demand growth outpacing new capacity additionsRenewable diesel transition to PTC framework enabling margin expansion vs. 2025Record operational performance (throughput, mechanical availability, safety) improving cash generation at same marginsBenicia refinery idling reducing West Coast exposure but sustaining capital falls ~$150MDisciplined capital allocation with emphasis on shorter-cycle, higher-return optimization projects

Risks management surfaced:

Execution risk on industry assumptions (Russian capacity normalization, new capacity nameplate rates, bio/RD re-entry, no refinery rationalization)Policy uncertainty on RVO, RINs, and SREs potentially limiting renewable diesel upside despite favorable structureInflationary capex costs making strategic projects economically challenging (alkylate units cost up 40-50% from historical)West Coast regulatory capital requirements and operational challenges at Benicia and Wilmington beyond 2026Tariffs on foreign feedstocks and elimination of import credits as headwinds to renewable diesel competitiveness

Answers to last quarter's watch list

Refining margin per barrel into Q4 — Q4 margin came in at $13.61/bbl, comfortably above the $12/bbl threshold. The bull case that the OPEC-driven differential widening was structural rather than front-loaded is now substantially confirmed. Status: Resolved positively

Renewable diesel segment economics post-policy clarity — Margin/gal landed at $0.82 with the segment generating $92M of operating income, and Q1 2026 guide implies cash opex of ~$0.37/gal (the $0.72/gal headline figure includes $0.35/gal of D&A). Management explicitly forecasts 2026 to materially outperform 2025 on PTC capture and exports. Status: Resolved positively

Q4 throughput delivery vs. range midpoints — Total Q4 throughput was 3,113 kbpd, above the high end of the combined guide range of ~2.93–3.03 mmbpd. Gulf Coast, Mid-Continent, West Coast, North Atlantic and ethanol all delivered above guide. The 98% utilization is the operating mode, not a peak. Status: Resolved positively

Payout ratio trajectory — Q4 returned $1.4B at a 66% payout ratio (67% for the full year), meaningfully above the 40-50% framework minimum. Pattern of structural over-distribution continues; management's posture supports the multi-year margin call read. Status: Resolved positively

St. Charles FCC project pacing — Reaffirmed: "We still expect the project to begin operations in the second half of 2026." No scope expansion, no slippage. The FY2026 capex of $1.7B accommodates the project within a meaningfully tighter overall envelope. Status: Resolved positively

What to watch into next quarter

Venezuelan heavy crude landed economics: management expects Venezuelan barrels to be a "large part of our heavy diet" by February-March. Watch whether the Q1 refining capture rate confirms differential advantage in the $14–16/bbl range — anything below $12/bbl on margin would call into question the heavy-crude execution.

Refining cash opex trajectory: Q1 guide of $5.17/bbl is a step up from Q4 actual of $5.03. Watch whether this resets the run-rate baseline (suggesting fixed-cost absorption is permanently weaker post-Benicia) or whether Q2 reverts toward sub-$5 — important for through-cycle EPS modeling.

Renewable diesel margin sustainability under new PTC framework: Q4 hit $0.82/gal on cash opex of $0.28/gal. Watch whether Q1 holds margins above the ~$0.37/gal implied cash opex at the guided 260M gallons — sustained margin compression would reignite the segment-loss risk despite management's bullish 2026 framing.

West Coast post-Benicia footprint: Q1 throughput guide of 160–180 kbpd is the cleanest signal of the Wilmington-only operating base. Watch for any disclosure on Wilmington's strategic review beyond 2026 — California regulatory pressure remains a multi-year tail risk.

Capex discipline carry-through: FY2026 capex cut to $1.7B is a clean $200M step down from FY2025. Watch whether Q1 commentary holds the line, or whether any optimization project (alkylate, ethanol expansion) gets a scope addition that would push the figure back toward $1.9B.

Sources

Valero Energy Q4 2025 earnings press release (SEC filing), https://www.sec.gov/Archives/edgar/data/1035002/000162828026003974/a12312025exh9901earningsre.htm
Valero Energy Q4 2025 earnings call prepared remarks (as captured in extraction inputs)

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