Valero Energy - 10-Q quarterly report FY2025 Q3

VALERO ENERGY CORP/TX0001035002FALSE2025Q3--12-31http://fasb.org/us-gaap/2025#CostDirectMaterialhttp://fasb.org/us-gaap/2025#CostDirectMaterialhttp://fasb.org/us-gaap/2025#CostDirectMaterialhttp://fasb.org/us-gaap/2025#CostDirectMaterial

Includes excise taxes on sales by certain of our foreign operations of $1,827 million and $1,539 million for the three months ended September 30, 2025 and 2024, respectively, and $4,993 million and $4,382 million for the nine months ended September 30, 2025 and 2024, respectively.

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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)


☑			QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended September 30, 2025


☐			TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from _______________ to _______________

Commission File Number 001-13175

VALERO ENERGY CORPORATION

(Exact name of registrant as specified in its charter)


Delaware			74-1828067
(State or other jurisdiction of			(I.R.S. Employer
incorporation or organization)			Identification No.)

One Valero Way

San Antonio, Texas

(Address of principal executive offices)

78249

(Zip Code)

(210) 345-2000

(Registrant’s telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act:

Title of each class

Trading Symbol(s)

Name of each exchange on which registered

Common Stock, par value $0.01 per share

VLO

New York Stock Exchange

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☑ No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☑ No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer

☑

Accelerated filer

☐

Non-accelerated filer

☐

Smaller reporting company

☐

Emerging growth company

☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☑

The number of shares of the registrant’s only class of common stock, $0.01 par value, outstanding as of October 17, 2025 was 305,009,539.

VALERO ENERGY CORPORATION

TABLE OF CONTENTS



			Page
PART I – FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
Consolidated Balance Sheets as of September 30, 2025 and December 31, 2024			1
Consolidated Statements of Income for the Three and Nine Months Ended September 30, 2025 and 2024			2
Consolidated Statements of Comprehensive Income for the Three and Nine Months Ended September 30, 2025 and 2024			3
Consolidated Statements of Equity for the Three and Nine Months Ended September 30, 2025 and 2024			4
Consolidated Statements of Cash Flows for the Nine Months Ended September 30, 2025 and 2024			6
Condensed Notes to Consolidated Financial Statements			7
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS			35
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK			66
ITEM 4. CONTROLS AND PROCEDURES			67
PART II – OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS			67
ITEM 1A. RISK FACTORS			67
ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS			68
ITEM 5. OTHER INFORMATION			68
ITEM 6. EXHIBITS			69
SIGNATURE			70

Table of Contents

PART I – FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

VALERO ENERGY CORPORATION

CONSOLIDATED BALANCE SHEETS

(millions of dollars, except par value)


	September 30, 2025		December 31, 2024
	(unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	4,764	$	4,657

Receivables, net	10,333		10,708
Inventories	7,394		7,761
Prepaid expenses and other	1,013		611
Total current assets	23,504		23,737
Property, plant, and equipment, at cost	49,663		52,368
Accumulated depreciation	(21,922)		(23,054)
Property, plant, and equipment, net	27,741		29,314
Deferred charges and other assets, net	7,370		7,092
Total assets	$	58,615	$	60,143
LIABILITIES AND EQUITY
Current liabilities:
Current portion of debt and finance lease obligations	$	894	$	743
Accounts payable	10,694		12,092
Accrued expenses	1,440		1,130
Taxes other than income taxes payable	1,411		1,360
Income taxes payable	290		170
Total current liabilities	14,729		15,495
Debt and finance lease obligations, less current portion	9,687		9,720
Deferred income tax liabilities	5,023		5,267
Other long-term liabilities	2,430		2,140
Commitments and contingencies
Equity:
Valero Energy Corporation stockholders’ equity:
Common stock, $0.01 par value; 1,200,000,000 shares authorized; 673,501,593 and 673,501,593 shares issued	7		7
Additional paid-in capital	6,972		6,939
Treasury stock, at cost; 368,490,214 and 358,637,890 common shares	(29,686)		(28,178)
Retained earnings	47,169		47,016
Accumulated other comprehensive loss	(708)		(1,272)
Total Valero Energy Corporation stockholders’ equity	23,754		24,512
Noncontrolling interests	2,992		3,009
Total equity	26,746		27,521
Total liabilities and equity	$	58,615	$	60,143

See Condensed Notes to Consolidated Financial Statements.

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VALERO ENERGY CORPORATION

CONSOLIDATED STATEMENTS OF INCOME

(millions of dollars, except per share amounts)

(unaudited)


	Three Months Ended September 30,				Nine Months Ended September 30,
	2025		2024		2025		2024
Revenues (a)	$	32,168	$	32,876	$	92,315	$	99,125
Cost of sales:
Cost of materials and other	27,958		29,965		81,838		88,590

Operating expenses (excluding depreciation and amortization expense reflected below)	1,614		1,482		4,659		4,317
Depreciation and amortization expense	824		675		2,290		2,042
Total cost of sales	30,396		32,122		88,787		94,949
Asset impairment loss	—		—		1,131		—
Other operating expenses	5		3		13		40
General and administrative expenses (excluding depreciation and amortization expense reflected below)	246		234		727		695
Depreciation and amortization expense	12		10		51		34
Operating income	1,509		507		1,606		3,407
Other income, net	86		123		292		389
Interest and debt expense, net of capitalized interest	(139)		(141)		(417)		(421)
Income before income tax expense	1,456		489		1,481		3,375
Income tax expense	390		96		404		726


Net income	1,066		393		1,077		2,649
Less: Net income (loss) attributable to noncontrolling interests	(29)		29		(137)		160
Net income attributable to Valero Energy Corporation stockholders	$	1,095	$	364	$	1,214	$	2,489








Earnings per common share	$	3.54	$	1.14	$	3.89	$	7.66
Weighted-average common shares outstanding (in millions)	309		318		311		324





Earnings per common share – assuming dilution	$	3.53	$	1.14	$	3.89	$	7.66
Weighted-average common shares outstanding – assuming dilution (in millions)	309		318		312		324
__________________________
Supplemental information:
(a) Includes excise taxes on sales by certain of our foreign operations	$	1,827	$	1,539	$	4,993	$	4,382

See Condensed Notes to Consolidated Financial Statements.

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VALERO ENERGY CORPORATION

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(millions of dollars)

(unaudited)


	Three Months Ended September 30,				Nine Months Ended September 30,
	2025		2024		2025		2024
Net income	$	1,066	$	393	$	1,077	$	2,649
Other comprehensive income (loss):
Foreign currency translation adjustment	(157)		326		569		62
Net gain (loss) on pension and other postretirement benefits	(4)		—		1		(11)
Net gain (loss) on cash flow hedges	8		43		8		(49)

Other comprehensive income (loss) before income tax expense (benefit)	(153)		369		578		2
Income tax expense (benefit) related to items of other comprehensive income (loss)	(2)		5		8		(13)
Other comprehensive income (loss)	(151)		364		570		15
Comprehensive income	915		757		1,647		2,664
Less: Comprehensive income (loss) attributable to noncontrolling interests	(25)		51		(131)		135
Comprehensive income attributable to Valero Energy Corporation stockholders	$	940	$	706	$	1,778	$	2,529

See Condensed Notes to Consolidated Financial Statements.

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VALERO ENERGY CORPORATION

CONSOLIDATED STATEMENTS OF EQUITY

(millions of dollars, except per share amounts)

(unaudited)


	Valero Energy Corporation Stockholders’ Equity
	Common Stock		Additional Paid-in Capital		Treasury Stock		Retained Earnings		Accumulated Other Comprehensive Loss		Total		Non- controlling Interests		Total Equity
Balance as of June 30, 2025	$	7	$	6,956	$	(28,757)	$	46,425	$	(553)	$	24,078	$	2,869	$	26,947
Net income (loss)	—		—		—		1,095		—		1,095		(29)		1,066
Dividends on common stock ($1.13 per share)	—		—		—		(351)		—		(351)		—		(351)
Stock-based compensation expense	—		18		—		—		—		18		—		18
Transactions in connection with stock-based compensation plans	—		(2)		2		—		—		—		—		—
Purchases of common stock for treasury	—		—		(931)		—		—		(931)		—		(931)
Contributions from noncontrolling interests	—		—		—		—		—		—		148		148


Other comprehensive income (loss)	—		—		—		—		(155)		(155)		4		(151)
Balance as of September 30, 2025	$	7	$	6,972	$	(29,686)	$	47,169	$	(708)	$	23,754	$	2,992	$	26,746

Balance as of June 30, 2024	$	7	$	6,929	$	(27,373)	$	47,052	$	(1,172)	$	25,443	$	2,807	$	28,250
Net income	—		—		—		364		—		364		29		393
Dividends on common stock ($1.07 per share)	—		—		—		(342)		—		(342)		—		(342)
Stock-based compensation expense	—		11		—		—		—		11		—		11

Purchases of common stock for treasury	—		—		(565)		—		—		(565)		—		(565)

Distributions to noncontrolling interests	—		—		—		—		—		—		(111)		(111)

Other comprehensive income	—		—		—		—		342		342		22		364
Balance as of September 30, 2024	$	7	$	6,940	$	(27,938)	$	47,074	$	(830)	$	25,253	$	2,747	$	28,000

See Condensed Notes to Consolidated Financial Statements.

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VALERO ENERGY CORPORATION

CONSOLIDATED STATEMENTS OF EQUITY (Continued)

(millions of dollars, except per share amounts)

(unaudited)


	Valero Energy Corporation Stockholders’ Equity
	Common Stock		Additional Paid-in Capital		Treasury Stock		Retained Earnings		Accumulated Other Comprehensive Loss		Total		Non- controlling Interests		Total Equity
Balance as of December 31, 2024	$	7	$	6,939	$	(28,178)	$	47,016	$	(1,272)	$	24,512	$	3,009	$	27,521
Net income (loss)	—		—		—		1,214		—		1,214		(137)		1,077
Dividends on common stock ($3.39 per share)	—		—		—		(1,061)		—		(1,061)		—		(1,061)
Stock-based compensation expense	—		68		—		—		—		68		—		68
Transactions in connection with stock-based compensation plans	—		(35)		36		—		—		1		—		1
Purchases of common stock for treasury	—		—		(1,544)		—		—		(1,544)		—		(1,544)
Contributions from noncontrolling interests	—		—		—		—		—		—		245		245
Distributions to noncontrolling interests	—		—		—		—		—		—		(131)		(131)


Other comprehensive income	—		—		—		—		564		564		6		570
Balance as of September 30, 2025	$	7	$	6,972	$	(29,686)	$	47,169	$	(708)	$	23,754	$	2,992	$	26,746

Balance as of December 31, 2023	$	7	$	6,901	$	(25,322)	$	45,630	$	(870)	$	26,346	$	2,178	$	28,524
Net income	—		—		—		2,489		—		2,489		160		2,649
Dividends on common stock ($3.21 per share)	—		—		—		(1,045)		—		(1,045)		—		(1,045)
Stock-based compensation expense	—		63		—		—		—		63		—		63
Transactions in connection with stock-based compensation plans	—		(24)		25		—		—		1		—		1
Purchases of common stock for treasury	—		—		(2,641)		—		—		(2,641)		—		(2,641)
Contributions from noncontrolling interests	—		—		—		—		—		—		90		90
Distributions to noncontrolling interests	—		—		—		—		—		—		(113)		(113)
Conversion of IEnova Revolver debt to equity (see Notes 4 and 6)	—		—		—		—		—		—		457		457

Other comprehensive income (loss)	—		—		—		—		40		40		(25)		15
Balance as of September 30, 2024	$	7	$	6,940	$	(27,938)	$	47,074	$	(830)	$	25,253	$	2,747	$	28,000

See Condensed Notes to Consolidated Financial Statements.

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VALERO ENERGY CORPORATION

CONSOLIDATED STATEMENTS OF CASH FLOWS

(millions of dollars)

(unaudited)


	Nine Months Ended September 30,
	2025		2024
Cash flows from operating activities:
Net income	$	1,077	$	2,649
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization expense	2,341		2,076


Asset impairment loss	1,131		—

Deferred income tax benefit	(288)		(78)
Changes in current assets and current liabilities	157		795
Changes in deferred charges and credits and other operating activities, net	(649)		171
Net cash provided by operating activities	3,769		5,613
Cash flows from investing activities:
Capital expenditures (excluding variable interest entities (VIEs))	(504)		(399)
Capital expenditures of VIEs:
Diamond Green Diesel Holdings LLC (DGD)	(67)		(198)
Other VIEs	(5)		(7)
Deferred turnaround and catalyst cost expenditures (excluding VIEs)	(808)		(844)
Deferred turnaround and catalyst cost expenditures of DGD	(91)		(62)


Purchases of available-for-sale (AFS) debt securities	(18)		(17)
Proceeds from sales and maturities of AFS debt securities	24		79

Investments in nonconsolidated joint ventures	(1)		—
Other investing activities, net	44		11
Net cash used in investing activities	(1,426)		(1,437)
Cash flows from financing activities:
Proceeds from debt issuance and borrowings (excluding VIEs)	5,599		5,200
Proceeds from debt borrowings of VIEs:
DGD	400		250
Other VIEs	—		23
Repayments of debt and finance lease obligations (excluding VIEs)	(5,566)		(5,521)
Repayments of debt and finance lease obligations of VIEs:
DGD	(320)		(519)
Other VIEs	(27)		(13)

Purchases of common stock for treasury	(1,534)		(2,616)
Payment of excise tax on purchases of common stock for treasury	(28)		—
Common stock dividend payments	(1,061)		(1,045)
Contributions from noncontrolling interests	245		90
Distributions to noncontrolling interests	(131)		(113)
Other financing activities, net	(7)		(1)
Net cash used in financing activities	(2,430)		(4,265)
Effect of foreign exchange rate changes on cash	199		19
Net increase (decrease) in cash, cash equivalents, and restricted cash	112		(70)
Cash, cash equivalents, and restricted cash at beginning of period (a)	4,829		5,424
Cash, cash equivalents, and restricted cash at end of period (a)	$	4,941	$	5,354

________________________

(a)Restricted cash is included in prepaid expenses and other in our consolidated balance sheets.

See Condensed Notes to Consolidated Financial Statements.

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VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

1. BASIS OF PRESENTATION AND SIGNIFICANT ACCOUNTING POLICIES

Basis of Presentation

General

The terms “Valero,” “we,” “our,” and “us,” as used in this report, may refer to Valero Energy Corporation, one or more of its consolidated subsidiaries, or all of them taken as a whole. The term “DGD,” as used in this report, may refer to Diamond Green Diesel Holdings LLC, its wholly owned consolidated subsidiary, or both of them taken as a whole.

These interim unaudited financial statements have been prepared in conformity with United States (U.S.) generally accepted accounting principles (GAAP) for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X of the Securities Exchange Act of 1934. Accordingly, they do not include all of the information and notes required by GAAP for complete financial statements. In the opinion of management, these interim unaudited financial statements reflect all adjustments considered necessary for a fair statement of our results for the interim periods presented. All such adjustments are of a normal recurring nature unless otherwise disclosed. Operating results for the interim periods are not necessarily indicative of the results that may be expected for the year ending December 31, 2025. These interim unaudited financial statements should be read in conjunction with our audited financial statements and notes thereto included in our annual report on Form 10-K for the year ended December 31, 2024.

The balance sheet as of December 31, 2024 has been derived from our audited financial statements as of that date. For further information, refer to our audited financial statements and notes thereto included in our annual report on Form 10-K for the year ended December 31, 2024.

Significant Accounting Policies

Use of Estimates

The preparation of financial statements in conformity with GAAP requires us to make estimates and assumptions that affect the amounts reported in these interim unaudited financial statements and accompanying notes. Actual results could differ from those estimates. On an ongoing basis, we review our estimates based on currently available information. Changes in facts and circumstances may result in revised estimates.

Accounting Pronouncements Recently Adopted

ASU 2023-07

In November 2023, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2023-07, Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures, to improve interim and annual disclosures about a public entity’s reportable segments primarily through enhanced disclosures about significant segment expenses and other segment related items. We adopted this ASU effective January 1, 2024 and it did not affect our financial position or our results of operations, but did result in additional disclosures.

ASU 2023-09

In December 2023, the FASB issued ASU 2023-09, Income Taxes (Topic 740): Improvements to Income Tax Disclosures, to improve annual income tax disclosures by requiring further disaggregation of information in the rate reconciliation and disaggregation of income taxes paid by jurisdiction. This ASU

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VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

also includes certain other amendments intended to improve the effectiveness of annual income tax disclosures. We adopted this ASU effective January 1, 2025 on a retrospective basis and it did not affect our financial position or our results of operations, but will result in additional annual disclosures.

Accounting Pronouncement Not Yet Adopted

ASU 2024-03

In November 2024, the FASB issued ASU 2024-03, Income Statement Reporting—Comprehensive Income—Expense Disaggregation Disclosures (Subtopic 220-40): Disaggregation of Income Statement Expenses, to improve interim and annual disclosures about a public business entity’s expenses by requiring more detailed information in the notes to the financial statements about certain expense categories, including purchases of inventory, employee compensation, depreciation, amortization, and selling expenses. We expect to adopt this ASU effective January 1, 2027 and the adoption will not affect our financial position or our results of operations, but will result in additional disclosures.

2. IMPAIRMENT

In recent years, the State of California adopted legislation that has subjected our refining and marketing operations to potential increased operational restrictions and new reporting requirements. The considerable uncertainty and potential adverse effects on our operations and financial performance resulted in the evaluation of strategic alternatives for our operations in California.

In March 2025, we approved a plan with respect to the operations at our Benicia Refinery and currently intend to cease refining operations by the end of April 2026. In addition, we considered strategic alternatives for our remaining operations in California. As a result, we updated our evaluation of potential impairment and concluded that the carrying values of our Benicia and Wilmington refineries were not recoverable as of March 31, 2025. Therefore, we reduced the carrying values of these assets to their estimated fair values of $722 million and $847 million, respectively, and recognized a combined asset impairment loss of $1.1 billion in our Refining segment in March 2025. See Note 12 for disclosure related to the method used to determine the fair values.

Included in the recoverability assessments discussed above was the recognition of expected asset retirement obligations of $337 million, which primarily reflects the fair value of estimated costs for certain legal obligations to decommission the assets based on a range of potential settlement dates as of March 31, 2025.

In connection with our plan to cease refining operations at our Benicia Refinery, we shortened the estimated useful life of the refinery assets, and as a result, will depreciate the revised carrying value of the net property, plant, and equipment and other noncurrent assets to the estimated salvage value of $107 million through April 2026. Accordingly, in the three and nine months ended September 30, 2025, we recorded incremental depreciation of approximately $100 million and $200 million, respectively, in depreciation and amortization expense.

In addition, we implemented a transition plan for the affected employees of the Benicia Refinery, which includes retention incentive payments and separation benefits. During the third quarter of 2025, we recognized a liability of $50 million for these one-time costs, which we expect to distribute to eligible

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VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

employees by the end of the second quarter of 2026. These costs are included in operating expenses (excluding depreciation and amortization expense) in the three and nine months ended September 30, 2025 and are attributable to our Refining segment.

We continue to evaluate strategic alternatives for our remaining operations in California.

3. INVENTORIES

Inventories consisted of the following (in millions):


	September 30, 2025		December 31, 2024
Refinery feedstocks	$	1,826	$	2,167
Refined petroleum products and blendstocks	4,035		4,016
Renewable diesel feedstocks and products	840		872
Ethanol feedstocks and products	292		342
Materials and supplies	401		364


Inventories	$	7,394	$	7,761

As of September 30, 2025 and December 31, 2024, the replacement cost (market value) of last-in, first-out (LIFO) inventories exceeded their LIFO carrying amounts by $3.4 billion and $4.0 billion, respectively. Our non-LIFO inventories accounted for $1.2 billion and $1.3 billion of our total inventories as of September 30, 2025 and December 31, 2024, respectively.

4. DEBT

Public Debt

On February 7, 2025, we issued $650 million of 5.150 percent Senior Notes due February 15, 2030. Proceeds from this debt issuance totaled $649 million before deducting the underwriting discount and other debt issuance costs. We used a portion of the net proceeds to repay the $189 million outstanding principal balance of our 3.65 percent Senior Notes that matured on March 15, 2025 and the $251 million outstanding principal balance of our 2.850 percent Senior Notes that matured on April 15, 2025.

In March 2024, we repaid the $167 million outstanding principal balance of our 1.200 percent Senior Notes that matured on March 15, 2024.

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VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Credit Facilities

We had outstanding borrowings, letters of credit issued, and availability under our credit facilities as follows (in millions):


				September 30, 2025
	Facility Amount		Maturity Date	Outstanding Borrowings		Letters of Credit Issued (a)		Availability
Committed facilities:
Valero Revolver (b)	$	4,000	November 2027	$	—	$	2	$	3,998
Accounts receivable sales facility	1,300		July 2026	—		n/a		1,300
Committed facilities of VIEs (c):
DGD Revolver (d)	400		June 2026	100		52		248
DGD Loan Agreement (e)	100		June 2026	—		n/a		100
IEnova Revolver (f)	830		February 2028	31		n/a		799
Uncommitted facilities:
Letter of credit facilities	n/a		n/a	n/a		6		n/a
Uncommitted facility of VIE (c):
DGD letter of credit facility	n/a		n/a	n/a		67		n/a

________________________

(a)Letters of credit issued as of September 30, 2025 expire at various times in 2025 through 2026.

(b)In October 2025, we extended the maturity date of this facility to October 2030.

(c)Creditors of the VIEs do not have recourse against us.

(d)The variable interest rate on the unsecured revolving credit facility with a syndicate of financial institutions (the DGD Revolver) was 6.073 percent as of September 30, 2025.

(e)The amounts shown for DGD’s unsecured revolving loan agreement with its members (the DGD Loan Agreement) represent the facility amount available from, and borrowings outstanding to, the noncontrolling member as any transactions between DGD and us under this facility are eliminated in consolidation.

(f)Central Mexico Terminals (defined in Note 6) has an unsecured revolving credit facility (the IEnova Revolver) with IEnova (defined in Note 6). The variable interest rate on the IEnova Revolver was 8.141 percent and 8.443 percent as of September 30, 2025 and December 31, 2024, respectively.

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VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Borrowings and repayments under our credit facilities were as follows (in millions):


	Nine Months Ended September 30,
	2025		2024
Borrowings:
Accounts receivable sales facility	$	4,950	$	5,200
DGD Revolver	400		150
DGD Loan Agreement	—		100
IEnova Revolver	—		23
Repayments:
Accounts receivable sales facility	(4,950)		(5,200)
DGD Revolver	(300)		(400)
DGD Loan Agreement	—		(100)
IEnova Revolver	(27)		—

Other Disclosures

“Interest and debt expense, net of capitalized interest” was comprised as follows (in millions):


	Three Months Ended September 30,				Nine Months Ended September 30,
	2025		2024		2025		2024
Interest and debt expense	$	144	$	145	$	432	$	438
Less: Capitalized interest	5		4		15		17
Interest and debt expense, net of capitalized interest	$	139	$	141	$	417	$	421

5. EQUITY

Treasury Stock

We purchase shares of our outstanding common stock as authorized by our board of directors (Board), including under share purchase programs (described in the table below) and with respect to our employee stock-based compensation plans. During the three and nine months ended September 30, 2025, we purchased for treasury 5,667,134 shares and 10,309,669 shares, respectively. During the three and nine months ended September 30, 2024, we purchased for treasury 3,798,836 shares and 17,054,864 shares, respectively.

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CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Our Board authorized us to purchase shares of our outstanding common stock under various programs with no expiration dates as follows (in millions):


Program Name	Authorization Date	Total Cost Authorized		Remaining Available for Purchase as of September 30, 2025
February 2024 Program	February 22, 2024	$	2,500	$	311
September 2024 Program	September 19, 2024	2,500		2,500

Accumulated Other Comprehensive Loss

Changes in accumulated other comprehensive loss by component, net of tax, were as follows (in millions):


	Three Months Ended September 30,
	2025								2024
	Foreign Currency Translation Adjustment		Defined Benefit Plans Items		Gains (Losses) on Cash Flow Hedges		Total		Foreign Currency Translation Adjustment		Defined Benefit Plans Items		Gains (Losses) on Cash Flow Hedges		Total
Balance as of beginning of period	$	(548)	$	1	$	(6)	$	(553)	$	(993)	$	(170)	$	(9)	$	(1,172)
Other comprehensive income (loss) before reclassifications	(155)		—		(6)		(161)		326		—		33		359
Amounts reclassified from accumulated other comprehensive loss	—		(1)		9		8		—		(5)		(16)		(21)
Effect of exchange rates	—		(2)		—		(2)		—		4		—		4
Other comprehensive income (loss)	(155)		(3)		3		(155)		326		(1)		17		342
Balance as of end of period	$	(703)	$	(2)	$	(3)	$	(708)	$	(667)	$	(171)	$	8	$	(830)

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CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)


	Nine Months Ended September 30,
	2025								2024
	Foreign Currency Translation Adjustment		Defined Benefit Plans Items		Gains (Losses) on Cash Flow Hedges		Total		Foreign Currency Translation Adjustment		Defined Benefit Plans Items		Gains (Losses) on Cash Flow Hedges		Total
Balance as of beginning of period	$	(1,264)	$	(2)	$	(6)	$	(1,272)	$	(735)	$	(162)	$	27	$	(870)
Other comprehensive income (loss) before reclassifications	561		—		(6)		555		68		—		18		86
Amounts reclassified from accumulated other comprehensive loss	—		(5)		9		4		—		(12)		(37)		(49)
Effect of exchange rates	—		5		—		5		—		3		—		3
Other comprehensive income (loss)	561		—		3		564		68		(9)		(19)		40
Balance as of end of period	$	(703)	$	(2)	$	(3)	$	(708)	$	(667)	$	(171)	$	8	$	(830)

6. VARIABLE INTEREST ENTITIES

Consolidated VIEs

We consolidate a VIE when we have a variable interest in an entity for which we are the primary beneficiary. As of September 30, 2025, the significant consolidated VIEs included:

•DGD, a joint venture with a subsidiary of Darling Ingredients Inc. that owns and operates two plants that process waste and renewable feedstocks (predominantly animal fats, used cooking oils, vegetable oils, and inedible distillers corn oils (DCOs)) into renewable diesel, renewable naphtha, and neat sustainable aviation fuel (SAF)1; and

•Central Mexico Terminals, a collective group of three subsidiaries of Infraestructura Energetica Nova, S.A.P.I. de C.V. (IEnova), which is a Mexican company and indirect subsidiary of Sempra Energy, a U.S. public company. We have terminaling agreements with Central Mexico Terminals that represent variable interests. We do not have an ownership interest in Central Mexico Terminals.

The assets of the consolidated VIEs can only be used to settle their own obligations and the creditors of the consolidated VIEs have no recourse to our other assets. We generally do not provide financial guarantees to the VIEs. Although we have provided credit facilities to some of the VIEs in support of their construction or acquisition activities and working capital requirements, these transactions are eliminated in consolidation. Our financial position, results of operations, and cash flows are impacted by

___________________________________________________________________

1 DGD produces synthetic paraffinic kerosene (SPK), a renewable blending component, using the Hydrotreated Esters and Fatty Acids (HEFA) process. SPK is also commonly referred to as “neat SAF.” Current aviation regulations allow SPK to be blended up to 50 percent with conventional jet fuel for use in an aircraft. This blend is commonly referred to as “blended SAF” or “SAF.”

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the performance of the consolidated VIEs, net of intercompany eliminations, to the extent of our ownership interest in each VIE.

The following table presents summarized balance sheet information for the significant assets and liabilities of the consolidated VIEs, which are included in our balance sheets (in millions):


	DGD		Central Mexico Terminals		Other		Total
September 30, 2025
Assets
Cash and cash equivalents	$	136	$	1	$	32	$	169
Other current assets	1,044		18		38		1,100
Property, plant, and equipment, net	3,690		624		62		4,376
Deferred charges and other assets, net	524		68		12		604
Liabilities
Current liabilities, including current portion of debt and finance lease obligations	$	299	$	49	$	4	$	352
Debt and finance lease obligations, less current portion	622		—		—		622



December 31, 2024
Assets
Cash and cash equivalents	$	353	$	—	$	21	$	374
Other current assets	976		9		42		1,027
Property, plant, and equipment, net	3,806		647		64		4,517
Deferred charges and other assets, net	86		69		11		166
Liabilities
Current liabilities, including current portion of debt and finance lease obligations	$	304	$	75	$	4	$	383
Debt and finance lease obligations, less current portion	642		—		—		642

Nonconsolidated VIEs

We hold variable interests in VIEs that have not been consolidated because we are not considered the primary beneficiary. These nonconsolidated VIEs are not material to our financial position or results of operations and are accounted for as equity investments.

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7. EMPLOYEE BENEFIT PLANS

The components of net periodic benefit cost related to our defined benefit plans were as follows (in millions):


	Pension Plans				Other Postretirement Benefit Plans
	2025		2024		2025		2024
Three months ended September 30
Service cost	$	27	$	28	$	—	$	1
Interest cost	34		31		3		3
Expected return on plan assets	(56)		(54)		—		—
Amortization of:
Net actuarial gain	(2)		(1)		(2)		(1)
Prior service cost (credit)	1		(3)		1		—
Settlement loss	3		5		—		—
Net periodic benefit cost	$	7	$	6	$	2	$	3

Nine months ended September 30
Service cost	$	81	$	84	$	2	$	3
Interest cost	102		94		9		9
Expected return on plan assets	(167)		(161)		—		—
Amortization of:
Net actuarial gain	(6)		(4)		(6)		(3)
Prior service cost (credit)	4		(8)		1		—
Settlement loss	6		5		—		—
Net periodic benefit cost	$	20	$	10	$	6	$	9

The components of net periodic benefit cost other than the service cost component (i.e., the non-service cost components) are included in “other income, net.”

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8. INCOME TAXES

Income Tax Expense

For the three and nine months ended September 30, 2025, our effective tax rate was higher than the U.S. federal statutory rate due to lower U.S. income before income tax expense primarily resulting from the asset impairment loss associated with our operations in California, as described in Note 2.

There was no significant variation in the customary relationship between income tax expense and income before income tax expense for the three and nine months ended September 30, 2024.

One Big Beautiful Bill Act

On July 4, 2025, legislation commonly known as the One Big Beautiful Bill Act (OBBB) was enacted, which resulted in a broad range of changes to the U.S. Internal Revenue Code of 1986, as amended (the Code). The most significant provisions affecting us include the following:

•extension of the clean fuel production credit through December 31, 2029;

•requirement that feedstocks for fuel produced after December 31, 2025 must be produced or grown exclusively in the U.S., Mexico, or Canada in order for such fuel to be eligible for the clean fuel production credit;

•elimination of the special clean fuel production credit rate for SAF produced after December 31, 2025;

•permanent reinstatement of the provision that allows companies to expense 100 percent of the cost of qualified property acquired and placed in service after January 19, 2025; and

•modification of several international tax provisions, including those relating to net controlled foreign corporation tested income (formerly global intangible low-taxed income) and foreign-derived deduction eligible income (formerly foreign-derived intangible income) beginning January 1, 2026.

We do not expect that these changes and other provisions of this legislation will have a material effect on our financial position, results of operations, and cash flows in 2025; however, we continue to evaluate the effects of the OBBB on our financial position, results of operations, and cash flows in the future.

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9. EARNINGS PER COMMON SHARE

Earnings per common share was computed as follows (dollars and shares in millions, except per share amounts):


	Three Months Ended September 30,				Nine Months Ended September 30,
	2025		2024		2025		2024
Earnings per common share:
Net income attributable to Valero stockholders	$	1,095	$	364	$	1,214	$	2,489
Less: Income allocated to participating securities	3		1		3		7
Net income available to common stockholders	$	1,092	$	363	$	1,211	$	2,482

Weighted-average common shares outstanding	309		318		311		324

Earnings per common share	$	3.54	$	1.14	$	3.89	$	7.66

Earnings per common share – assuming dilution:
Net income attributable to Valero stockholders	$	1,095	$	364	$	1,214	$	2,489
Less: Income allocated to participating securities	3		1		3		7
Net income available to common stockholders	$	1,092	$	363	$	1,211	$	2,482

Weighted-average common shares outstanding	309		318		311		324
Effect of dilutive securities	—		—		1		—
Weighted-average common shares outstanding – assuming dilution	309		318		312		324

Earnings per common share – assuming dilution	$	3.53	$	1.14	$	3.89	$	7.66

Participating securities include restricted stock and performance awards granted under our 2020 Omnibus Stock Incentive Plan. Dilutive securities include participating securities as well as outstanding stock options. For the three and nine months ended September 30, 2025 and 2024, we computed earnings per common share – assuming dilution using the two-class method for all dilutive securities.

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10. REVENUES AND SEGMENT INFORMATION

Revenue from Contracts with Customers

Disaggregation of Revenue

Revenue is presented in the table below under “Segment Information” disaggregated by product because this is the level of disaggregation that management has determined to be beneficial to users of our financial statements.

Contract Balances

Contract balances were as follows (in millions):


	September 30, 2025		December 31, 2024
Receivables from contracts with customers, included in receivables, net	$	6,321	$	5,812
Contract liabilities, included in accrued expenses	62		82

Remaining Performance Obligations

We have spot and term contracts with customers, the majority of which are spot contracts with no remaining performance obligations. We do not disclose remaining performance obligations for contracts that have terms of one year or less. The transaction price for our remaining term contracts includes a fixed component and variable consideration (i.e., a commodity price), both of which are allocated entirely to a wholly unsatisfied promise to transfer a distinct good that forms part of a single performance obligation. The fixed component is not material and the variable consideration is highly uncertain. Therefore, as of September 30, 2025, we have not disclosed the aggregate amount of the transaction price allocated to our remaining performance obligations.

Segment Information

We have three reportable segments—Refining, Renewable Diesel, and Ethanol. Each segment is a strategic business unit that offers different products and services by employing unique technologies and marketing strategies and whose operations and operating performance are managed and evaluated separately. Operating performance is measured based on the operating income generated by the segment, which includes revenues and expenses that are directly attributable to the management of the respective segment. Intersegment sales are generally derived from transactions made at prevailing market rates. The following is a description of each segment’s business operations.

•The Refining segment includes the operations of our petroleum refineries, the associated activities to market our refined petroleum products, and the logistics assets that support our refining operations. The principal products manufactured by our refineries and sold by this segment include gasolines and blendstocks, distillates, and other products.

•The Renewable Diesel segment represents the operations of DGD, a consolidated joint venture as discussed in Note 6, and the associated activities to market low-carbon fuels. The principal products manufactured by DGD and sold by this segment are renewable diesel, renewable naphtha, and neat SAF. This segment sells some renewable diesel and neat SAF to the Refining

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segment for blending into petroleum-based diesel and conventional jet fuel, respectively, which is then sold to that segment’s customers as finished product.

•The Ethanol segment includes the operations of our ethanol plants and the associated activities to market our ethanol and co-products. The principal products manufactured by our ethanol plants are ethanol and distillers grains. This segment sells some ethanol to the Refining segment for blending into gasoline, which is sold to that segment’s customers as a finished gasoline product.

Operations that are not included in any of the reportable segments are included in the corporate category.

Our chief operating decision maker (CODM) is our Chairman of the Board, Chief Executive Officer and President. Our CODM uses operating income by segment to allocate resources (including employees, property, and financial or capital resources) for each segment primarily during the annual budget process. On a monthly basis, our CODM considers budget-to-actual variances for operating income by segment when evaluating the operating performance of each segment.

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The following tables reflect information about our operating income (loss), including a reconciliation to our consolidated income before income tax expense and total expenditures for long-lived assets, by reportable segment (in millions):


	Refining		Renewable Diesel		Ethanol		Corporate and Eliminations		Total
Three months ended September 30, 2025
Revenues:
Revenues from external customers	$	30,414	$	719	$	1,035	$	—	$	32,168
Intersegment revenues	1		484		259		(744)		—
Total revenues	30,415		1,203		1,294		(744)		32,168
Cost of sales:
Cost of materials and other (a)	26,684		1,077		942		(745)		27,958

Operating expenses (excluding depreciation and amortization expense reflected below)	1,388		78		148		—		1,614
Depreciation and amortization expense	728		76		21		(1)		824
Total cost of sales	28,800		1,231		1,111		(746)		30,396

Other operating expenses	5		—		—		—		5
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		246		246
Depreciation and amortization expense	—		—		—		12		12
Operating income (loss) by segment	$	1,610	$	(28)	$	183	$	(256)	1,509
Other income, net									86
Interest and debt expense, net of capitalized interest									(139)
Income before income tax expense									$	1,456

Total expenditures for long-lived assets (b)	$	324	$	49	$	12	$	24	$	409

________________________

See notes on page 23.

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	Refining		Renewable Diesel		Ethanol		Corporate and Eliminations		Total
Three months ended September 30, 2024
Revenues:
Revenues from external customers	$	31,332	$	632	$	912	$	—	$	32,876
Intersegment revenues	3		593		235		(831)		—
Total revenues	31,335		1,225		1,147		(831)		32,876
Cost of sales:
Cost of materials and other (a)	28,922		1,029		842		(828)		29,965

Operating expenses (excluding depreciation and amortization expense reflected below)	1,256		92		133		1		1,482
Depreciation and amortization expense	589		69		19		(2)		675
Total cost of sales	30,767		1,190		994		(829)		32,122

Other operating expenses	3		—		—		—		3
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		234		234
Depreciation and amortization expense	—		—		—		10		10
Operating income by segment	$	565	$	35	$	153	$	(246)	507
Other income, net									123
Interest and debt expense, net of capitalized interest									(141)
Income before income tax expense									$	489

Total expenditures for long-lived assets (b)	$	344	$	67	$	9	$	9	$	429

________________________

See notes on page 23.

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	Refining		Renewable Diesel		Ethanol		Corporate and Eliminations		Total
Nine months ended September 30, 2025
Revenues:
Revenues from external customers	$	87,495	$	1,777	$	3,043	$	—	$	92,315
Intersegment revenues	5		1,424		681		(2,110)		—
Total revenues	87,500		3,201		3,724		(2,110)		92,315
Cost of sales:
Cost of materials and other (a)	77,995		3,016		2,962		(2,135)		81,838

Operating expenses (excluding depreciation and amortization expense reflected below)	3,986		228		446		(1)		4,659
Depreciation and amortization expense	2,029		205		59		(3)		2,290
Total cost of sales	84,010		3,449		3,467		(2,139)		88,787
Asset impairment loss	1,131		—		—		—		1,131
Other operating expenses	13		—		—		—		13
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		727		727
Depreciation and amortization expense	—		—		—		51		51
Operating income (loss) by segment	$	2,346	$	(248)	$	257	$	(749)	1,606
Other income, net									292
Interest and debt expense, net of capitalized interest									(417)
Income before income tax expense									$	1,481

Total expenditures for long-lived assets (b)	$	1,231	$	158	$	30	$	56	$	1,475

________________________

See notes on page 23.

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	Refining		Renewable Diesel		Ethanol		Corporate and Eliminations		Total
Nine months ended September 30, 2024
Revenues:
Revenues from external customers	$	94,519	$	1,888	$	2,718	$	—	$	99,125
Intersegment revenues	8		1,932		654		(2,594)		—
Total revenues	94,527		3,820		3,372		(2,594)		99,125
Cost of sales:
Cost of materials and other (a)	85,528		3,025		2,625		(2,588)		88,590

Operating expenses (excluding depreciation and amortization expense reflected below)	3,659		262		395		1		4,317
Depreciation and amortization expense	1,793		196		57		(4)		2,042
Total cost of sales	90,980		3,483		3,077		(2,591)		94,949
Other operating expenses	13		—		27		—		40
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		695		695
Depreciation and amortization expense	—		—		—		34		34

Operating income by segment	$	3,534	$	337	$	268	$	(732)	3,407
Other income, net									389
Interest and debt expense, net of capitalized interest									(421)
Income before income tax expense									$	3,375

Total expenditures for long-lived assets (b)	$	1,191	$	260	$	26	$	33	$	1,510

________________________

(a)Cost of materials and other for our Renewable Diesel segment is net of the clean fuel production credit on qualifying sales of certain low-carbon transportation fuels of $206 million and $397 million for the three and nine months ended September 30, 2025, respectively, and the blender’s tax credit on qualified fuel mixtures of $313 million and $952 million for the three and nine months ended September 30, 2024, respectively.

(b)Total expenditures for long-lived assets includes amounts related to capital expenditures and deferred turnaround and catalyst costs.

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CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

The following table provides a disaggregation of revenues from external customers for our principal products by reportable segment (in millions):


	Three Months Ended September 30,				Nine Months Ended September 30,
	2025		2024		2025		2024
Refining:
Gasolines and blendstocks	$	13,287	$	14,361	$	38,382	$	43,004
Distillates	14,582		13,855		40,736		42,286
Other product revenues	2,545		3,116		8,377		9,229
Total Refining revenues	30,414		31,332		87,495		94,519
Renewable Diesel:
Renewable diesel	623		610		1,484		1,829
Renewable naphtha	29		22		114		59
Neat SAF	67		—		179		—
Total Renewable Diesel revenues	719		632		1,777		1,888
Ethanol:
Ethanol	823		685		2,390		1,985
Distillers grains	212		227		653		733
Total Ethanol revenues	1,035		912		3,043		2,718

Revenues	$	32,168	$	32,876	$	92,315	$	99,125

Total assets by reportable segment were as follows (in millions):


	September 30, 2025		December 31, 2024
Refining	$	45,010	$	46,729
Renewable Diesel	5,600		5,680
Ethanol	1,495		1,545
Corporate and eliminations	6,510		6,189
Total assets	$	58,615	$	60,143

As of September 30, 2025 and December 31, 2024, our investments in nonconsolidated joint ventures accounted for under the equity method were $687 million and $695 million, respectively, all of which related to the Refining segment and are reflected in “deferred charges and other assets, net” in our balance sheets.

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11. SUPPLEMENTAL CASH FLOW INFORMATION

In order to determine net cash provided by operating activities, net income is adjusted by, among other things, changes in current assets and current liabilities as follows (in millions):


	Nine Months Ended September 30,
	2025		2024
Decrease in current assets:
Receivables, net	$	619	$	1,382
Inventories	529		574
Prepaid expenses and other	51		265
Increase (decrease) in current liabilities:
Accounts payable	(1,438)		(1,081)
Accrued expenses	264		(93)
Taxes other than income taxes payable	13		(114)
Income taxes payable	119		(138)
Changes in current assets and current liabilities	$	157	$	795

Changes in current assets and current liabilities for the nine months ended September 30, 2025 were primarily due to the following:

•The decrease in receivables was due to a decrease in refined petroleum product sales volumes in September 2025 compared to December 2024 and the collection of $246 million for a blender’s tax credit receivable, partially offset by an increase in related prices in September 2025 compared to December 2024;

•The decrease in inventories was primarily due to lower inventory levels in September 2025 compared to December 2024; and

•The decrease in accounts payable was due to a decrease in crude oil and other feedstock prices combined with a decrease in related volumes purchased in September 2025 compared to December 2024.

Changes in current assets and current liabilities for the nine months ended September 30, 2024 were primarily due to the following:

•The decrease in receivables was due to a decrease in refined petroleum product sales volumes combined with a decrease in related prices in September 2024 compared to December 2023;

•The decrease in inventories was primarily due to lower inventory levels in September 2024 compared to December 2023; and

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•The decrease in accounts payable was due to a decrease in crude oil and other feedstock prices combined with a decrease in related volumes purchased in September 2024 compared to December 2023.

Cash flows related to interest and income taxes were as follows (in millions):


	Nine Months Ended September 30,
	2025		2024
Interest paid in excess of amount capitalized, including interest on finance leases	$	362	$	374
Income taxes paid, net	398		835

Supplemental cash flow information related to our operating and finance leases was as follows (in millions):


	Nine Months Ended September 30,
	2025				2024
	Operating Leases		Finance Leases		Operating Leases		Finance Leases
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows	$	394	$	84	$	392	$	87

Financing cash flows	—		196		—		173
Changes in lease balances resulting from new and modified leases	357		22		346		312

Noncash investing activities for the nine months ended September 30, 2025 included the recognition of expected asset retirement obligations of $337 million, as described in Note 2. There were no other significant noncash investing and financing activities during the nine months ended September 30, 2025, except as noted in the table above.

Noncash financing activities for the nine months ended September 30, 2024 included the conversion by IEnova of $457 million of outstanding borrowings under the IEnova Revolver to additional equity in Central Mexico Terminals. There were no other significant noncash investing and financing activities during the nine months ended September 30, 2024, except as noted in the table above.

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CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

12. FAIR VALUE MEASUREMENTS

Recurring Fair Value Measurements

The following tables present information (in millions) about our assets and liabilities recognized at their fair values in our balance sheets categorized according to the fair value hierarchy of the inputs utilized by us to determine the fair values as of September 30, 2025 and December 31, 2024.

We have elected to offset the fair value amounts recognized for multiple similar derivative contracts executed with the same counterparty, including any related cash collateral assets or obligations as shown below; however, fair value amounts by hierarchy level are presented in the following tables on a gross basis. We have no derivative contracts that are subject to master netting arrangements that are reflected gross in our balance sheets.


	September 30, 2025
							Total Gross Fair Value		Effect of Counter- party Netting		Effect of Cash Collateral Netting		Net Carrying Value on Balance Sheet		Cash Collateral Paid or Received Not Offset
	Fair Value Hierarchy
	Level 1		Level 2		Level 3
Assets
Commodity derivative contracts	$	333	$	—	$	—	$	333	$	(328)	$	—	$	5	$	—



Investments of certain benefit plans	90		—		4		94		n/a		n/a		94		n/a
Investments in AFS debt securities	1		26		—		27		n/a		n/a		27		n/a
Foreign currency contracts	4		—		—		4		n/a		n/a		4		n/a
Total	$	428	$	26	$	4	$	458	$	(328)	$	—	$	130

Liabilities
Commodity derivative contracts	$	341	$	—	$	—	$	341	$	(328)	$	(13)	$	—	$	(66)
Physical purchase contracts	—		7		—		7		n/a		n/a		7		n/a
Blending program obligations	—		134		—		134		n/a		n/a		134		n/a



Total	$	341	$	141	$	—	$	482	$	(328)	$	(13)	$	141

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VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)


	December 31, 2024
							Total Gross Fair Value		Effect of Counter- party Netting		Effect of Cash Collateral Netting		Net Carrying Value on Balance Sheet		Cash Collateral Paid or Received Not Offset
	Fair Value Hierarchy
	Level 1		Level 2		Level 3
Assets
Commodity derivative contracts	$	402	$	—	$	—	$	402	$	(402)	$	—	$	—	$	—
Physical purchase contracts	—		2		—		2		n/a		n/a		2		n/a
Investments of certain benefit plans	89		—		4		93		n/a		n/a		93		n/a
Investments in AFS debt securities	6		20		—		26		n/a		n/a		26		n/a
Foreign currency contracts	6		—		—		6		n/a		n/a		6		n/a
Total	$	503	$	22	$	4	$	529	$	(402)	$	—	$	127

Liabilities
Commodity derivative contracts	$	448	$	—	$	—	$	448	$	(402)	$	(46)	$	—	$	(71)
Physical purchase contracts	—		3		—		3		n/a		n/a		3		n/a
Blending program obligations	—		13		—		13		n/a		n/a		13		n/a

Total	$	448	$	16	$	—	$	464	$	(402)	$	(46)	$	16

A description of our assets and liabilities recognized at fair value along with the valuation methods and inputs we used to develop their fair value measurements are as follows:

•Commodity derivative contracts consist primarily of exchange-traded futures, which are used to reduce the impact of price volatility on our results of operations and cash flows as discussed in Note 13. These contracts are measured at fair value using a market approach based on quoted prices from the commodity exchange and are categorized in Level 1 of the fair value hierarchy.

•Physical purchase contracts represent the fair value of fixed-price corn purchase contracts. The fair values of these purchase contracts are measured using a market approach based on quoted prices from the commodity exchange or an independent pricing service and are categorized in Level 2 of the fair value hierarchy.

•Blending program obligations represent our liability for the purchase of compliance credits needed to satisfy our blending obligations under various government and regulatory blending programs, such as the U.S. Environmental Protection Agency’s (EPA) Renewable Fuel Standard (RFS), California Low Carbon Fuel Standard (LCFS), Canada Clean Fuel Regulations, U.K. Renewable Transport Fuel Obligation, and similar programs in other jurisdictions in which we operate (collectively, the Renewable and Low-Carbon Fuel Programs). The blending program

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VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

obligations are categorized in Level 2 of the fair value hierarchy and are measured at fair value using a market approach based on quoted prices from an independent pricing service.

•Investments of certain benefit plans consist of investment securities held by trusts for the purpose of satisfying a portion of our obligations under certain U.S. nonqualified benefit plans. The plan assets categorized in Level 1 of the fair value hierarchy are measured at fair value using a market approach based on quoted prices from national securities exchanges. The plan assets categorized in Level 3 of the fair value hierarchy represent insurance contracts, the fair value of which is provided by the insurer.

•Investments in AFS debt securities consist primarily of commercial paper and U.S. government treasury bills and have maturities within one year. The securities categorized in Level 1 are measured at fair value using a market approach based on quoted prices from national securities exchanges and the securities categorized in Level 2 are measured at fair value using a market approach based on quoted prices from independent pricing services. The amortized cost basis of the securities approximates fair value. Realized and unrealized gains and losses were de minimis for the three and nine months ended September 30, 2025 and 2024.

•Foreign currency contracts consist of foreign currency exchange and purchase contracts related to our foreign operations to manage our exposure to exchange rate fluctuations on transactions denominated in currencies other than the local (functional) currencies of our operations. These contracts are valued based on quoted foreign currency exchange rates and are categorized in Level 1 of the fair value hierarchy.

Nonrecurring Fair Value Measurements

There were no assets or liabilities that were measured at fair value on a nonrecurring basis as of September 30, 2025 and December 31, 2024.

As discussed in Note 2, we concluded that the carrying values of the Benicia and Wilmington refineries were impaired as of March 31, 2025. The fair values of the refineries were determined using a market approach based on a comparison of recent property sales and other relevant real estate and market data, which we determined reflects the highest and best use of these assets. These fair values involved significant assumptions and actual results could differ from these estimates.

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VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

The following table presents information (in millions) about our nonfinancial assets measured at fair value on a nonrecurring basis during the nine months ended September 30, 2025.


	March 31, 2025
	Fair Value Measurements Using
	Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Fair Value		Carrying Value as of September 30, 2025 (a)		Loss Recognized (b)
Assets
Long-lived assets of the Benicia Refinery	$	—	$	—	$	722	$	722	$	441	$	901
Long-lived assets of the Wilmington Refinery	—		—		847		847		808		230
Total	$	—	$	—	$	1,569	$	1,569	$	1,249	$	1,131

________________________

(a)The carrying values of the Benicia and Wilmington refineries as of September 30, 2025 are lower than the fair values as of March 31, 2025 primarily due to the recognition of depreciation and amortization expense.

(b)The asset impairment loss was recognized in our Refining segment in March 2025.

Financial Instruments

Our financial instruments include cash and cash equivalents, restricted cash, investments in AFS debt securities, receivables, payables, debt obligations, operating and finance lease obligations, commodity derivative contracts, and foreign currency contracts. The estimated fair values of cash and cash equivalents, restricted cash, receivables, payables, and operating and finance lease obligations approximate their carrying amounts; the carrying value and fair value of debt is shown in the table below (in millions).


		September 30, 2025				December 31, 2024
	Fair Value Hierarchy	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Financial liabilities:
Debt (excluding finance lease obligations)	Level 2	$	8,366	$	8,327	$	8,085	$	7,776

Investments in AFS debt securities, commodity derivative contracts, and foreign currency contracts are recognized at their fair values as shown in “Recurring Fair Value Measurements” above.

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VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

13. PRICE RISK MANAGEMENT ACTIVITIES

General

We are exposed to market risks primarily related to the volatility in the price of commodities, foreign currency exchange rates, and the price of credits needed to comply with the Renewable and Low-Carbon Fuel Programs. We enter into derivative instruments to manage some of these risks, including derivative instruments related to the various commodities we purchase or produce, and foreign currency exchange and purchase contracts, as described below under “Risk Management Activities by Type of Risk.” These derivative instruments are recorded as either assets or liabilities measured at their fair values (see Note 12), as summarized below under “Fair Values of Derivative Instruments.” The effect of these derivative instruments on our income and other comprehensive income (loss) is summarized below under “Effect of Derivative Instruments on Income and Other Comprehensive Income (Loss).”

Risk Management Activities by Type of Risk

Commodity Price Risk

We are exposed to market risks related to the volatility in the price of feedstocks (primarily crude oil, waste and renewable feedstocks, and corn); the products we produce; and natural gas and electricity used in our operations. To reduce the impact of price volatility on our results of operations and cash flows, we use commodity derivative instruments, such as futures and options. Our positions in commodity derivative instruments are monitored and managed on a daily basis by our risk control group to ensure compliance with our stated risk management policy that is periodically reviewed with our Board and/or relevant Board committee.

We primarily use commodity derivative instruments as cash flow hedges and economic hedges. Our objectives for entering into each type of hedge is described below.

•Cash flow hedges – The objective of our cash flow hedges is to lock in the price of forecasted purchases and/or product sales at existing market prices that we deem favorable.

•Economic hedges – Our objectives for holding economic hedges are to (i) manage price volatility in certain feedstock and product inventories and (ii) lock in the price of forecasted purchases and/or product sales at existing market prices that we deem favorable.

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VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

As of September 30, 2025, we had the following outstanding commodity derivative instruments that were used as cash flow hedges and economic hedges, as well as commodity derivative instruments related to the physical purchase of corn at a fixed price. The information presents the notional volume of outstanding contracts by type of instrument and year of maturity (volumes in thousands of barrels, except corn contracts that are presented in thousands of bushels).


	Notional Contract Volumes by Year of Maturity
	2025	2026
Derivatives designated as cash flow hedges:
Refined petroleum products:

Futures – short	3,600	419



Derivatives designated as economic hedges:
Crude oil and refined petroleum products:


Futures – long	94,944	12,098
Futures – short	89,860	13,420







Corn:
Futures – long	60,540	660
Futures – short	89,210	10,420
Physical contracts – long	21,550	9,750

Renewable and Low-Carbon Fuel Programs Price Risk

We are exposed to market risk related to the volatility in the price of credits needed to comply with the Renewable and Low-Carbon Fuel Programs. To manage this risk, we enter into contracts to purchase these credits. Some of these contracts are derivative instruments; however, we elect the normal purchase exception and do not record these contracts at their fair values. The Renewable and Low-Carbon Fuel Programs require us to blend a certain volume of renewable and low-carbon fuels into the petroleum-based transportation fuels we produce in, or import into, the respective jurisdiction to be consumed therein based on annual quotas. To the degree we are unable to blend at the required quotas, we must purchase compliance credits (primarily Renewable Identification Numbers (RINs)). The cost of meeting our credit obligations under the Renewable and Low-Carbon Fuel Programs was $431 million and $156 million for the three months ended September 30, 2025 and 2024, respectively, and $1.2 billion and $535 million for the nine months ended September 30, 2025 and 2024, respectively. These amounts are reflected in cost of materials and other.

Foreign Currency Risk

We are exposed to exchange rate fluctuations on transactions related to our foreign operations that are denominated in currencies other than the local (functional) currencies of our operations. To manage our exposure to these exchange rate fluctuations, we often use foreign currency contracts. These contracts are not designated as hedging instruments for accounting purposes and therefore are classified as economic hedges. As of September 30, 2025, we had foreign currency contracts to purchase $537 million of U.S. dollars. Of these commitments, $467 million matured on or before October 20, 2025 and the remaining $70 million will mature by October 24, 2025.

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VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Fair Values of Derivative Instruments

The following table provides information about the fair values of our derivative instruments as of September 30, 2025 and December 31, 2024 (in millions) and the line items in our balance sheets in which the fair values are reflected. See Note 12 for additional information related to the fair values of our derivative instruments.

As indicated in Note 12, we net fair value amounts recognized for multiple similar derivative contracts executed with the same counterparty under master netting arrangements, including cash collateral assets and obligations. The following table, however, is presented on a gross asset and gross liability basis, which results in the reflection of certain assets in liability accounts and certain liabilities in asset accounts:


	Balance Sheet Location	September 30, 2025				December 31, 2024
		Asset Derivatives		Liability Derivatives		Asset Derivatives		Liability Derivatives
Derivatives designated as hedging instruments:
Commodity contracts	Receivables, net	$	8	$	8	$	12	$	13

Derivatives not designated as hedging instruments:
Commodity contracts	Receivables, net	$	325	$	333	$	390	$	435
Physical purchase contracts	Inventories	—		7		2		3
Foreign currency contracts	Receivables, net	4		—		6		—

Total		$	329	$	340	$	398	$	438

Market Risk

Our price risk management activities involve the receipt or payment of fixed price commitments into the future. These transactions give rise to market risk, which is the risk that future changes in market conditions may make an instrument less valuable. We closely monitor and manage our exposure to market risk on a daily basis in accordance with policies that are periodically reviewed with our Board and/or relevant Board committee. Market risks are monitored by our risk control group to ensure compliance with our stated risk management policy. We do not require any collateral or other security to support derivative instruments into which we enter. We also do not have any derivative instruments that require us to maintain a minimum investment-grade credit rating.

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VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Effect of Derivative Instruments on Income and Other Comprehensive Income (Loss)

The following table provides information about the gain (loss) recognized in income and other comprehensive income (loss) due to fair value adjustments of our cash flow hedges (in millions):


Derivatives in Cash Flow Hedging Relationships	Location of Gain (Loss) Recognized in Income on Derivatives	Three Months Ended September 30,				Nine Months Ended September 30,
		2025		2024		2025		2024
Commodity contracts:
Gain (loss) recognized in other comprehensive income (loss)	n/a	$	(15)	$	83	$	(15)	$	45
Gain (loss) reclassified from accumulated other comprehensive loss into income	Revenues	(23)		40		(23)		94

For cash flow hedges, no component of any derivative instrument’s gain or loss was excluded from the assessment of hedge effectiveness for the three and nine months ended September 30, 2025 and 2024. For the three and nine months ended September 30, 2025 and 2024, cash flow hedges primarily related to forecasted sales of renewable diesel. As of September 30, 2025, the estimated deferred after-tax gain that is expected to be reclassified into revenues within the next 12 months was not material. The changes in accumulated other comprehensive loss by component, net of tax, for the three and nine months ended September 30, 2025 and 2024 are described in Note 5.

The following table provides information about the gain (loss) recognized in income on our derivative instruments with respect to our economic hedges and our foreign currency hedges and the line items in our statements of income in which such gains (losses) are reflected (in millions):


Derivatives Not Designated as Hedging Instruments	Location of Gain (Loss) Recognized in Income on Derivatives	Three Months Ended September 30,				Nine Months Ended September 30,
		2025		2024		2025		2024
Commodity contracts	Revenues	$	(3)	$	(16)	$	(7)	$	(23)
Commodity contracts	Cost of materials and other	—		(9)		(50)		(66)

Foreign currency contracts	Cost of materials and other	13		(17)		(7)		2

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

CAUTIONARY STATEMENT FOR THE PURPOSE OF SAFE HARBOR PROVISIONS OF THE PRIVATE SECURITIES LITIGATION REFORM ACT OF 1995

This report, including without limitation our disclosures below under “OVERVIEW AND OUTLOOK,” includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. You can identify our forward-looking statements by the words “anticipate,” “believe,” “expect,” “plan,” “intend,” “scheduled,” “estimate,” “project,” “projection,” “predict,” “budget,” “forecast,” “goal,” “guidance,” “target,” “ambition,” “could,” “would,” “should,” “may,” “strive,” “seek,” “pursue,” “potential,” “opportunity,” “aimed,” “considering,” “continue,” “evaluate,” and similar expressions.

These forward-looking statements include, among other things, statements regarding:

•the effect, impact, potential duration or timing, or other implications of global geopolitical and other conflicts and tensions, and government and other responses thereto;

•future Refining segment margins, including gasoline and distillate margins, and differentials;

•future Renewable Diesel segment margins;

•future Ethanol segment margins;

•expectations regarding feedstock costs, including crude oil differentials, product prices for each of our segments, transportation costs, and operating expenses;

•anticipated levels of crude oil and liquid transportation fuel inventories, storage capacity, and production;

•expectations with respect to third-party refining, logistics, and low-carbon fuels projects and operations, and the effect and implications thereof on industry and market dynamics;

•expectations regarding the levels of, and costs and timing with respect to, the production and operations at our existing refineries and plants, projects under evaluation, construction, or development, and former projects;

•our plans, actions, assets, and operations in California and expected timing and cost of obligations and other financial statement impacts;

•our anticipated level of capital investments, including deferred turnaround and catalyst cost expenditures, our expected allocation between, and/or within, growth capital expenditures and sustaining capital expenditures, capital expenditures for environmental and other purposes, and joint venture investments, the expected costs and timing applicable to such capital investments and any related projects, and the effect of those capital investments on our business, financial condition, results of operations, and liquidity;

•our anticipated level of cash distributions or contributions, such as our dividend payment rate and contributions to our pension plans and other postretirement benefit plans;

•our ability to meet future cash and credit requirements, whether from funds generated from our operations or our ability to access financial markets effectively, and expectations regarding our liquidity;

•our evaluation of, and expectations regarding, any future activity under our share purchase program or transactions involving our debt securities;

•anticipated trends in the supply of, and demand for, crude oil and other feedstocks, refined petroleum products, renewable diesel, SAF, ethanol, and corn-related co-products in the regions where we operate, as well as globally;

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•expectations regarding environmental, tax, and other regulatory matters, including the matters discussed in Notes 2 and 8 of Condensed Notes to Consolidated Financial Statements and under “PART II, ITEM 1. LEGAL PROCEEDINGS,” the anticipated amounts and timing of payment with respect to our deferred tax liabilities, unrecognized tax benefits, matters impacting our ability to repatriate cash held by our foreign subsidiaries, and the anticipated or potential effects thereof on our business, financial condition, results of operations, and liquidity;

•the effect of general economic and other conditions, including inflation and economic activity levels, on refining, renewable diesel, SAF, and ethanol industry fundamentals;

•expectations regarding our risk management activities, including the anticipated effects of our hedge transactions;

•expectations regarding our counterparties and VIEs, including our ability to pass on increased compliance costs and timely collect receivables, and the credit risk within our accounts receivable or accounts payable;

•expectations regarding adoptions of new, or changes to existing, low-carbon fuel regulations, policies, and standards issued by governments across the world to address greenhouse gas (GHG) emissions and the percentage of low-carbon fuels in the transportation fuel mix, including, but not limited to, the Renewable and Low-Carbon Fuel Programs, blending and tax credits, efficiency standards, or other benefits or incentives that impact the demand for low-carbon fuels; and

•expectations regarding our low-carbon fuels strategy, publicly announced GHG emissions reduction/displacement targets and long-term ambition, and our current, former, and any future low-carbon projects.

We based our forward-looking statements on our current expectations, estimates, and projections about ourselves, current and potential counterparties, our industry, and the global economy and financial markets generally. We caution that these statements are not guarantees of future performance or results and involve known and unknown risks and uncertainties, the ultimate outcomes of which we cannot predict with certainty. In addition, we based many of these forward-looking statements on assumptions about future events, the ultimate outcomes of which we cannot predict with certainty and which may prove to be inaccurate. Accordingly, actual performance or results may differ materially from the future performance or results that we have expressed, suggested, or forecast in the forward-looking statements. Differences between actual performance or results and any future performance or results expressed, suggested, or forecast in these forward-looking statements could result from a variety of factors, including the following:

•the effects arising out of global geopolitical and other conflicts and tensions, including with respect to changes in trade flows and impacts to crude oil and other markets;

•demand for, and supplies of, refined petroleum products (such as gasoline, diesel, jet fuel, and petrochemicals), renewable diesel, SAF, ethanol, and corn-related co-products;

•demand for, and supplies of, crude oil and other feedstocks, as well as other critical materials and supplies;

•the effects of public health threats, pandemics, and epidemics, governmental and societal responses thereto, and the adverse impacts of the foregoing on our business, financial condition, results of operations, and liquidity, and the global economy and financial markets generally;

•acts of terrorism or other third-party actions affecting either our refineries and plants or third-party facilities that could impair our ability to produce or transport refined petroleum products, renewable diesel, SAF, ethanol, or corn-related co-products, to receive feedstocks, or otherwise operate efficiently;

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•the effects of war or hostilities, and political and economic conditions, in countries that produce crude oil or other feedstocks or consume refined petroleum products, renewable diesel, SAF, ethanol, or corn-related co-products;

•the ability of the members of the Organization of Petroleum Exporting Countries (OPEC), and other petroleum-producing nations that collectively make up OPEC+, to agree on and to maintain crude oil price and production controls;

•the level of consumer demand, consumption, and overall economic activity, including the effects from seasonal fluctuations and market prices;

•refinery, renewable diesel plant, or ethanol plant overcapacity or undercapacity;

•the risk that any transactions or capital decisions may not provide the anticipated benefits or may result in unforeseen detriments;

•the actions taken by competitors, including both pricing and adjustments to refining capacity or low-carbon fuels production, as well as changes in the geographic markets where they operate, in response to market conditions;

•the level of competitors’ imports into markets that we supply;

•accidents, unscheduled shutdowns, weather events, civil unrest, expropriation of assets, and other economic, diplomatic, legislative, societal, or political events or developments, terrorism, cyberattacks, or other catastrophes or disruptions affecting our operations, production facilities, machinery, pipelines and other logistics assets, equipment, or information systems, or any of the foregoing of our suppliers, customers, or third-party service providers;

•changes in the cost or availability of transportation or storage capacity for feedstocks and our products;

•pressure and influence of environmental groups and other stakeholders upon policies and decisions related to the production, transportation, storage, refining, processing, marketing, and sales of crude oil or other feedstocks, refined petroleum products, renewable diesel, SAF, ethanol, or corn-related co-products;

•the price, availability, technology related to, and acceptance of alternative fuels and alternative-fuel vehicles, as well as sentiment and perceptions with respect to low-carbon projects and GHG emissions more generally;

•the levels of government subsidies for, and executive orders, mandates, or other policies with respect to, alternative fuels, alternative-fuel vehicles, and other low-carbon technologies or initiatives, including those related to carbon capture, carbon sequestration, and low-carbon fuels, or affecting the price of natural gas and/or electricity;

•the volatility in the market price of compliance credits (primarily RINs needed to comply with the RFS) under the Renewable and Low-Carbon Fuel Programs;

•delay of, cancellation of, or failure to implement planned capital or other strategic projects and realize the various assumptions and benefits projected for such projects or cost overruns in executing such planned projects;

•severe weather events, such as storms, hurricanes, droughts, floods, wildfires, and other weather events, which can unforeseeably affect the price or availability of electricity, natural gas, crude oil, waste and renewable feedstocks, corn, and other feedstocks, critical supplies, refined petroleum products, renewable diesel, SAF, ethanol, and corn-related co-products;

•rulings, judgments, or settlements in litigation or other legal or regulatory matters, such as unexpected environmental remediation or enforcement costs, including those in excess of any reserves or insurance coverage;

•legislative or regulatory action, including the introduction or enactment of legislation or rulemakings by government authorities, environmental regulations, changes to income tax rates, profits, procedures, windfall, margin, or other taxes or penalties, tax changes or restrictions impacting the foreign repatriation of cash, actions implemented under SBx 1-2 and related

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regulation, actions implemented under the Renewable and Low-Carbon Fuel Programs, including changes to volume requirements or other obligations or exemptions under the RFS, and actions arising from the EPA’s or other government agencies’ regulations, policies, or initiatives concerning GHGs, including mandates for or bans of specific technology, which may adversely affect our business, financial condition, results of operations, and liquidity;

•changing economic, regulatory, and political environments and related events in the various countries in which we operate or otherwise do business, including trade restrictions, expropriation or impoundment of assets, failure of foreign governments and state-owned entities to honor their contracts, property disputes, economic instability, restrictions on the transfer of funds, duties and tariffs and their effects on trading relationships, transportation delays, import and export controls, labor unrest, security issues involving key personnel, and decisions, investigations, regulations, issuances or revocations of permits and other authorizations, government shutdowns, and other actions, policies, and initiatives by federal, state, local, and other jurisdictions applicable to us;

•changes in the credit ratings assigned to our debt securities and trade credit;

•the operating, financing, and distribution decisions of our joint ventures or other joint venture members, and other consolidated VIEs, that we do not control;

•changes in currency exchange rates, including the value of the Canadian dollar, the pound sterling, the euro, the Mexican peso, and the Peruvian sol relative to the U.S. dollar;

•the adequacy of capital resources and liquidity, including availability, timing, and amounts of cash flow or our ability to borrow or access financial markets;

•the costs, disruption, and diversion of resources associated with lawsuits, proceedings, demands, or investigations, or campaigns and negative publicity commenced by government authorities, investors, stakeholders, or other interested parties;

•overall economic conditions, including the stability and liquidity of financial markets, and the effect thereof on consumer demand; and

•other factors generally described in the “RISK FACTORS” section included in our annual report on Form 10-K for the year ended December 31, 2024.

Any one of these factors, or a combination of these factors, could materially affect our future business, financial condition, results of operations, and liquidity and whether any forward-looking statements ultimately prove to be accurate. Our forward-looking statements are not guarantees of future performance, and actual results and future performance may differ materially from those expressed, suggested, or forecast in any forward-looking statements. Such forward-looking statements speak only as of the date of this quarterly report on Form 10-Q and we do not intend to update these statements unless we are required by applicable securities laws to do so.

All subsequent written and oral forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by the foregoing, as it may be updated or modified by our future filings with the U.S. Securities and Exchange Commission (SEC). We undertake no obligation to publicly release any revisions to any such forward-looking statements that may be made to reflect events or circumstances after the date of this report or to reflect the occurrence of unanticipated events unless we are required by applicable securities laws to do so.

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NON-GAAP FINANCIAL MEASURES

The following discussions in “OVERVIEW AND OUTLOOK,” “RESULTS OF OPERATIONS,” and “LIQUIDITY AND CAPITAL RESOURCES” include references to financial measures that are not defined under GAAP. These non-GAAP financial measures include Refining, Renewable Diesel, and Ethanol segment margin; adjusted operating income (including adjusted operating income for each of our reportable segments, as applicable); Refining segment adjusted operating expenses (excluding depreciation and amortization expense); and capital investments attributable to Valero. We have included these non-GAAP financial measures to help facilitate the comparison of operating results between periods, to help assess our cash flows, and because we believe they provide useful information as discussed further below. See the tables in note (c) beginning on page 57 for reconciliations of Refining, Renewable Diesel, and Ethanol segment margin; adjusted operating income (including adjusted operating income for each of our reportable segments, as applicable); and adjusted Refining operating expenses (excluding depreciation and amortization expense) to their most directly comparable GAAP financial measures. Also in note (c), we disclose the reasons why we believe our use of such non-GAAP financial measures provides useful information. See the table on page 64 for a reconciliation of capital investments attributable to Valero to its most directly comparable GAAP financial measure. Beginning on page 63, we disclose the reasons why we believe our use of this non-GAAP financial measure provides useful information.

OVERVIEW AND OUTLOOK

Overview

Business Operations Update

Our results for the third quarter and first nine months of 2025 were supported by strong worldwide demand for petroleum-based transportation fuels, while worldwide supply of those products remained constrained. Our results for the first nine months of 2025, however, were also impacted by the asset impairment loss of $1.1 billion ($877 million after taxes) associated with our operations in California, as described in Note 2 of Condensed Notes to Consolidated Financial Statements.

We reported $1.1 billion and $1.2 billion of net income attributable to Valero stockholders for the third quarter of 2025 and the first nine months of 2025, respectively. Our operating results, including operating results by segment, are described in the following summary under “Third Quarter Results” and “First Nine Months Results,” and detailed descriptions can be found under “RESULTS OF OPERATIONS” beginning on page 43.

Our operations generated $3.8 billion of cash during the first nine months of 2025. In addition, we issued $650 million of 5.150 percent Senior Notes due February 15, 2030 during the first nine months of 2025, as described in Note 4 of Condensed Notes to Consolidated Financial Statements. The cash generated by our operations, along with the net proceeds from our debt issuance and cash on hand, was used to make $1.5 billion of capital investments in our business, return $2.6 billion to our stockholders through purchases of common stock for treasury and dividend payments, and repay $440 million of our public debt that matured in the first nine months of 2025. As a result of this and other activity, our cash, cash equivalents, and restricted cash increased by $112 million during the first nine months of 2025 to $4.9 billion as of September 30, 2025. We had $9.9 billion in liquidity as of September 30, 2025. The components of our liquidity and descriptions of our cash flows, capital investments, and other matters impacting our liquidity and capital resources can be found under “LIQUIDITY AND CAPITAL RESOURCES” beginning on page 61.

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Third Quarter Results

For the third quarter of 2025, we reported net income attributable to Valero stockholders of $1.1 billion compared to $364 million for the third quarter of 2024. The increase of $731 million was primarily due to an increase in operating income of $1.0 billion, partially offset by an increase in income tax expense of $294 million. The details of our operating income (loss) and adjusted operating income, where applicable, by segment and in total are reflected below (in millions). Adjusted operating income excludes the adjustments reflected in the tables in note (c) beginning on page 57.


	Three Months Ended September 30,
	2025		2024		Change
Refining segment:
Operating income	$	1,610	$	565	$	1,045
Adjusted operating income	1,665		568		1,097
Renewable Diesel segment:
Operating income (loss)	(28)		35		(63)

Ethanol segment:
Operating income	183		153		30

Total company:
Operating income	1,509		507		1,002
Adjusted operating income	1,564		510		1,054

While our operating income increased by $1.0 billion in the third quarter of 2025 compared to the third quarter of 2024, adjusted operating income increased by $1.1 billion primarily due to the following:

•Refining segment. Refining segment adjusted operating income increased by $1.1 billion primarily due to higher gasoline and distillate (primarily diesel) margins and an increase in throughput volumes, partially offset by a decline in crude oil and other feedstock differentials and increases in adjusted operating expenses (excluding depreciation and amortization expense) and depreciation and amortization expense.

•Renewable Diesel segment. Renewable Diesel segment operating income decreased by $63 million primarily due to higher feedstock costs and a decrease in sales volumes, partially offset by higher product prices (primarily renewable diesel).

•Ethanol segment. Ethanol segment operating income increased by $30 million primarily due to higher ethanol and corn related co-product prices and an increase in production volumes, partially offset by higher corn prices and an increase in operating expenses (excluding depreciation and amortization expense).

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First Nine Months Results

For the first nine months of 2025, we reported net income attributable to Valero stockholders of $1.2 billion compared to $2.5 billion for the first nine months of 2024. The decrease of $1.3 billion was primarily due to a decrease in operating income of $1.8 billion, partially offset by a decrease in income tax expense of $322 million and a decrease in net income attributable to noncontrolling interests of $297 million. The details of our operating income (loss) and adjusted operating income, where applicable, by segment and in total are reflected below (in millions). Adjusted operating income excludes the adjustments reflected in the tables in note (c) beginning on page 57.


	Nine Months Ended September 30,
	2025		2024		Change
Refining segment:
Operating income	$	2,346	$	3,534	$	(1,188)
Adjusted operating income	3,540		3,547		(7)
Renewable Diesel segment:
Operating income (loss)	(248)		337		(585)

Ethanol segment:
Operating income	257		268		(11)
Adjusted operating income	257		295		(38)
Total company:
Operating income	1,606		3,407		(1,801)
Adjusted operating income	2,800		3,447		(647)

While our operating income decreased by $1.8 billion in the first nine months of 2025 compared to the first nine months of 2024, adjusted operating income decreased by $647 million primarily due to the following:

•Refining segment. Refining segment adjusted operating income decreased by $7 million primarily due to a decline in crude oil and other feedstock differentials and increases in adjusted operating expenses (excluding depreciation and amortization expense) and depreciation and amortization expense, partially offset by higher gasoline, distillate (primarily diesel), and other product margins and an increase in throughput volumes.

•Renewable Diesel segment. Renewable Diesel segment operating income decreased by $585 million primarily due to higher feedstock costs and a decrease in sales volumes, partially offset by higher product prices (primarily renewable diesel) and a decrease in operating expenses (excluding depreciation and amortization expense).

•Ethanol segment. Ethanol segment adjusted operating income decreased by $38 million primarily due to higher corn prices and an increase in operating expenses (excluding depreciation and amortization expense), partially offset by higher ethanol prices and an increase in production volumes.

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Outlook

Many uncertainties remain with respect to the supply and demand balances in petroleum-based product markets worldwide. While it is difficult to predict future worldwide economic activity and its resulting impact on product supply and demand, including the effects of tariffs thereon, we have noted several factors below that have impacted or may impact our results of operations during the fourth quarter of 2025.

•Global demand for gasoline, diesel, and jet fuel continues to rise, with demand for jet fuel outpacing other primary petroleum-based transportation fuels. As biofuel consumption increases at a slower pace than in recent years, petroleum-based transportation fuels account for a greater share of the overall increase in demand for finished products.

•Combined light product (gasoline, diesel, and jet fuel) inventories across the U.S. and Europe remain low. Expected reductions in refining capacity in both regions, unplanned outages at Russian refineries due to the Russia-Ukraine conflict, and a prolonged ramp-up of new capacity in emerging markets continue to support utilization of remaining global refining capacity.

•Crude oil differentials are expected to widen as a result of an increase in sour crude oil production from OPEC+ suppliers. However, potential sanction adjustments related to Iran, Russia, and Venezuela and the Russia-Ukraine conflict could result in increased volatility in the crude oil market and potentially impact crude oil differentials.

•Renewable diesel demand is expected to remain consistent with current levels.

•Ethanol demand is expected to follow typical seasonal patterns.

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RESULTS OF OPERATIONS

The following tables, including the reconciliations of non-GAAP financial measures to their most directly comparable GAAP financial measures in note (c) beginning on page 57, highlight our results of operations, our operating performance, and market reference prices that directly impact our operations. Note references in this section can be found on pages 57 through 60.

Third Quarter Results -

Financial Highlights by Segment and Total Company

(millions of dollars)


	Three Months Ended September 30, 2025
	Refining		Renewable Diesel		Ethanol		Corporate and Eliminations		Total
Revenues:
Revenues from external customers	$	30,414	$	719	$	1,035	$	—	$	32,168
Intersegment revenues	1		484		259		(744)		—
Total revenues	30,415		1,203		1,294		(744)		32,168
Cost of sales:
Cost of materials and other	26,684		1,077		942		(745)		27,958

Operating expenses (excluding depreciation and amortization expense reflected below) (a)	1,388		78		148		—		1,614
Depreciation and amortization expense	728		76		21		(1)		824
Total cost of sales	28,800		1,231		1,111		(746)		30,396

Other operating expenses	5		—		—		—		5
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		246		246
Depreciation and amortization expense	—		—		—		12		12
Operating income (loss) by segment	$	1,610	$	(28)	$	183	$	(256)	1,509
Other income, net									86
Interest and debt expense, net of capitalized interest									(139)
Income before income tax expense									1,456
Income tax expense									390
Net income									1,066
Less: Net loss attributable to noncontrolling interests									(29)
Net income attributable to Valero Energy Corporation stockholders									$	1,095

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Third Quarter Results -

Financial Highlights by Segment and Total Company (continued)

(millions of dollars)


	Three Months Ended September 30, 2024
	Refining		Renewable Diesel		Ethanol		Corporate and Eliminations		Total
Revenues:
Revenues from external customers	$	31,332	$	632	$	912	$	—	$	32,876
Intersegment revenues	3		593		235		(831)		—
Total revenues	31,335		1,225		1,147		(831)		32,876
Cost of sales:
Cost of materials and other	28,922		1,029		842		(828)		29,965

Operating expenses (excluding depreciation and amortization expense reflected below)	1,256		92		133		1		1,482
Depreciation and amortization expense	589		69		19		(2)		675
Total cost of sales	30,767		1,190		994		(829)		32,122
Other operating expenses	3		—		—		—		3
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		234		234
Depreciation and amortization expense	—		—		—		10		10
Operating income by segment	$	565	$	35	$	153	$	(246)	507
Other income, net									123
Interest and debt expense, net of capitalized interest									(141)
Income before income tax expense									489
Income tax expense									96
Net income									393
Less: Net income attributable to noncontrolling interests									29
Net income attributable to Valero Energy Corporation stockholders									$	364

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Third Quarter Results -

Average Market Reference Prices and Differentials


	Three Months Ended September 30,
	2025		2024
Refining
Feedstocks (dollars per barrel)
Brent crude oil	$	68.14	$	78.37
Brent less West Texas Intermediate (WTI) crude oil	3.11		3.18
Brent less WTI Houston crude oil	2.09		1.94
Brent less Dated Brent crude oil	(0.91)		(1.63)

Brent less Argus Sour Crude Index (ASCI) crude oil	3.46		4.30
Brent less Maya crude oil	7.14		11.19
Brent less Western Canadian Select (WCS) Houston crude oil	6.93		10.36
WTI crude oil	65.03		75.19

Natural gas (dollars per million British thermal units (MMBTu))	2.70		1.83

Renewable volume obligation (RVO) (dollars per barrel) (d)	6.38		3.89

Product margins (RVO adjusted unless otherwise noted) (dollars per barrel)
U.S. Gulf Coast:
Conventional Blendstock for Oxygenate Blending (CBOB) gasoline less Brent	7.78		6.28
Ultra-low-sulfur (ULS) diesel less Brent	21.05		11.89
Polymer Grade Propylene less Brent (not RVO adjusted)	(8.22)		12.82
U.S. Mid-Continent:
CBOB gasoline less WTI	12.79		14.08
ULS diesel less WTI	26.16		16.74
North Atlantic:
CBOB gasoline less Brent	14.58		12.16
ULS diesel less Brent	24.64		13.68
U.S. West Coast:
California Reformulated Gasoline Blendstock for Oxygenate Blending (CARBOB) 87 gasoline less Brent	26.69		23.56
California Air Resources Board (CARB) diesel less Brent	29.83		14.22

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Third Quarter Results -

Average Market Reference Prices and Differentials (continued)


	Three Months Ended September 30,
	2025		2024
Renewable Diesel
New York Mercantile Exchange ULS diesel (dollars per gallon)	$	2.35	$	2.31
Biodiesel RIN (dollars per RIN)	1.13		0.60
California LCFS carbon credit (dollars per metric ton)	53.36		53.65

U.S. Gulf Coast (USGC) used cooking oil (UCO) (dollars per pound)	0.62		0.46
USGC DCO (dollars per pound)	0.64		0.48
USGC fancy bleachable tallow (Tallow) (dollars per pound)	0.62		0.47

Ethanol
Chicago Board of Trade (CBOT) corn (dollars per bushel)	4.02		3.92
New York Harbor ethanol (dollars per gallon)	1.96		1.92

Total Company, Corporate, and Other

The following table includes selected financial data for the total company, corporate, and other for the third quarter of 2025 and 2024. The selected financial data is derived from the Financial Highlights by Segment and Total Company tables, unless otherwise noted.


	Three Months Ended September 30,
	2025		2024		Change
Revenues	$	32,168	$	32,876	$	(708)

Cost of sales	30,396		32,122		(1,726)



Operating income	1,509		507		1,002
Adjusted operating income (see note (c))	1,564		510		1,054


Income tax expense	390		96		294

Revenues decreased by $708 million in the third quarter of 2025 compared to the third quarter of 2024 primarily due to decreases in product prices for the petroleum-based transportation fuels associated with sales made by our Refining segment. This decrease in revenues was more than offset by a decrease in cost of sales of $1.7 billion primarily due to decreases in crude oil and other feedstock costs.

Operating income increased by $1.0 billion in the third quarter of 2025; however, adjusted operating income, which excludes the adjustments in the table in note (c), increased by $1.1 billion, from $510 million in the third quarter of 2024 to $1.6 billion in the third quarter of 2025. The components of this $1.1 billion increase in adjusted operating income are discussed by segment in the segment analyses that follow.

Income tax expense increased by $294 million in the third quarter of 2025 compared to the third quarter of 2024 primarily as a result of higher income before income tax expense.

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Refining Segment Results

The following table includes selected financial and operating data of our Refining segment for the third quarter of 2025 and 2024. The selected financial data is derived from the Financial Highlights by Segment and Total Company tables, unless otherwise noted.


	Three Months Ended September 30,
	2025		2024		Change




Operating income	$	1,610	$	565	$	1,045
Adjusted operating income (see note (c))	1,665		568		1,097

Refining margin (see note (c))	3,731		2,413		1,318
Operating expenses (excluding depreciation and amortization expense reflected below) (see note (a))	1,388		1,256		132
Adjusted operating expenses (excluding depreciation and amortization expense reflected below) (see note (c))	1,338		1,256		82
Depreciation and amortization expense	728		589		139


Throughput volumes (thousand barrels per day) (see note (e))	3,087		2,884		203

Refining segment operating income increased by $1.0 billion in the third quarter of 2025; however, Refining segment adjusted operating income, which excludes the adjustments in the table in note (c), increased by $1.1 billion in the third quarter of 2025 compared to the third quarter of 2024. The components of this increase in the adjusted results, along with the reasons for the changes in those components, are outlined below.

•Refining segment margin increased by $1.3 billion in the third quarter of 2025 compared to the third quarter of 2024.

Refining segment margin is primarily affected by the prices for the petroleum-based transportation fuels that we sell and the cost of crude oil and other feedstocks that we process. The table on page 45 reflects market reference prices and differentials that we believe impacted our Refining segment margin in the third quarter of 2025 compared to the third quarter of 2024.

The increase in Refining segment margin was primarily due to the following:

◦An increase in distillate (primarily diesel) margins had a favorable impact of approximately $1.1 billion.

◦An increase in gasoline margins had a favorable impact of approximately $330 million.

◦An increase in throughput volumes of 203,000 barrels per day had a favorable impact of approximately $250 million.

◦A decline in crude oil differentials had an unfavorable impact of approximately $210 million.

◦A decline in differentials for other feedstocks had an unfavorable impact of approximately $230 million.

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•Refining segment adjusted operating expenses (excluding depreciation and amortization expense) increased by $82 million primarily due to increases in energy costs of $48 million, certain employee compensation expenses of $13 million, and chemical and catalyst costs of $5 million.

•Refining segment depreciation and amortization expense increased by $139 million primarily due to incremental depreciation expense of approximately $100 million related to our plan to cease refining operations at our Benicia Refinery by the end of April 2026, as described in Note 2 of Condensed Notes to Consolidated Financial Statements.

Renewable Diesel Segment Results

The following table includes selected financial and operating data of our Renewable Diesel segment for the third quarter of 2025 and 2024. The selected financial data is derived from the Financial Highlights by Segment and Total Company tables, unless otherwise noted.


	Three Months Ended September 30,
	2025		2024		Change


Operating income (loss)	$	(28)	$	35	$	(63)


Renewable Diesel margin (see note (c))	126		196		(70)
Operating expenses (excluding depreciation and amortization expense reflected below)	78		92		(14)
Depreciation and amortization expense	76		69		7

Sales volumes (thousand gallons per day) (see note (e))	2,717		3,544		(827)

Renewable Diesel segment operating income decreased by $63 million in the third quarter of 2025 compared to the third quarter of 2024 primarily due to a decrease in Renewable Diesel segment margin of $70 million.

Renewable Diesel segment margin is primarily affected by the prices for the renewable fuels that we sell and the cost of the feedstocks that we process. The table on page 46 reflects market reference prices that we believe impacted our Renewable Diesel segment margin in the third quarter of 2025 compared to the third quarter of 2024.

The decrease in Renewable Diesel segment margin was primarily due to the following:

•An increase in the cost of the feedstocks that we process had an unfavorable impact of approximately $210 million.

•A decrease in sales volumes of 827,000 gallons per day had an unfavorable impact of approximately $100 million. The decrease in sales volumes was primarily due to reduced production driven by unfavorable economic conditions in the third quarter of 2025.

•An increase in product prices, primarily renewable diesel, had a favorable impact of approximately $240 million.

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Ethanol Segment Results

The following table includes selected financial and operating data of our Ethanol segment for the third quarter of 2025 and 2024. The selected financial data is derived from the Financial Highlights by Segment and Total Company tables, unless otherwise noted.


	Three Months Ended September 30,
	2025		2024		Change



Operating income	$	183	$	153	$	30


Ethanol margin (see note (c))	352		305		47
Operating expenses (excluding depreciation and amortization expense reflected below)	148		133		15
Depreciation and amortization expense	21		19		2

Production volumes (thousand gallons per day) (see note (e))	4,635		4,584		51

Ethanol segment operating income increased by $30 million in the third quarter of 2025 compared to the third quarter of 2024. The components of this increase, along with the reasons for the changes in those components, are outlined below.

•Ethanol segment margin increased by $47 million in the third quarter of 2025 compared to the third quarter of 2024.

Ethanol segment margin is primarily affected by prices for the ethanol and corn related co-products that we sell and the cost of corn that we process. The table on page 46 reflects market reference prices that we believe impacted our Ethanol segment margin in the third quarter of 2025 compared to the third quarter of 2024.

The increase in Ethanol segment margin was primarily due to the following:

◦An increase in ethanol prices had a favorable impact of approximately $30 million.

◦An increase in prices for the co-products that we produce, primarily dry distillers grains and inedible DCOs, had a favorable impact of approximately $30 million.

◦An increase in production volumes of 51,000 gallons per day had a favorable impact of approximately $10 million.

◦An increase in corn prices had an unfavorable impact of approximately $20 million.

•Ethanol segment operating expenses (excluding depreciation and amortization expense) increased by $15 million primarily due to an increase in energy costs.

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First Nine Months Results -

Financial Highlights by Segment and Total Company

(millions of dollars)


	Nine Months Ended September 30, 2025
	Refining		Renewable Diesel		Ethanol		Corporate and Eliminations		Total
Revenues:
Revenues from external customers	$	87,495	$	1,777	$	3,043	$	—	$	92,315
Intersegment revenues	5		1,424		681		(2,110)		—
Total revenues	87,500		3,201		3,724		(2,110)		92,315
Cost of sales:
Cost of materials and other	77,995		3,016		2,962		(2,135)		81,838

Operating expenses (excluding depreciation and amortization expense reflected below) (a)	3,986		228		446		(1)		4,659
Depreciation and amortization expense	2,029		205		59		(3)		2,290
Total cost of sales	84,010		3,449		3,467		(2,139)		88,787
Asset impairment loss (b)	1,131		—		—		—		1,131
Other operating expenses	13		—		—		—		13
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		727		727
Depreciation and amortization expense	—		—		—		51		51
Operating income (loss) by segment	$	2,346	$	(248)	$	257	$	(749)	1,606
Other income, net									292
Interest and debt expense, net of capitalized interest									(417)
Income before income tax expense									1,481
Income tax expense									404
Net income									1,077
Less: Net loss attributable to noncontrolling interests									(137)
Net income attributable to Valero Energy Corporation stockholders									$	1,214

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First Nine Months Results -

Financial Highlights by Segment and Total Company (continued)

(millions of dollars)


	Nine Months Ended September 30, 2024
	Refining		Renewable Diesel		Ethanol		Corporate and Eliminations		Total
Revenues:
Revenues from external customers	$	94,519	$	1,888	$	2,718	$	—	$	99,125
Intersegment revenues	8		1,932		654		(2,594)		—
Total revenues	94,527		3,820		3,372		(2,594)		99,125
Cost of sales:
Cost of materials and other	85,528		3,025		2,625		(2,588)		88,590

Operating expenses (excluding depreciation and amortization expense reflected below)	3,659		262		395		1		4,317
Depreciation and amortization expense	1,793		196		57		(4)		2,042
Total cost of sales	90,980		3,483		3,077		(2,591)		94,949
Other operating expenses	13		—		27		—		40
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		695		695
Depreciation and amortization expense	—		—		—		34		34
Operating income by segment	$	3,534	$	337	$	268	$	(732)	3,407
Other income, net									389
Interest and debt expense, net of capitalized interest									(421)
Income before income tax expense									3,375
Income tax expense									726
Net income									2,649
Less: Net income attributable to noncontrolling interests									160
Net income attributable to Valero Energy Corporation stockholders									$	2,489

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First Nine Months Results -

Average Market Reference Prices and Differentials


	Nine Months Ended September 30,
	2025		2024
Refining
Feedstocks (dollars per barrel)
Brent crude oil	$	69.87	$	81.72
Brent less WTI crude oil	3.08		4.05
Brent less WTI Houston crude oil	2.02		2.53
Brent less Dated Brent crude oil	(0.91)		(0.97)

Brent less ASCI crude oil	2.68		4.39
Brent less Maya crude oil	8.35		11.66
Brent less WCS Houston crude oil	6.81		11.03
WTI crude oil	66.79		77.67

Natural gas (dollars per MMBtu)	2.97		1.79

RVO (dollars per barrel) (d)	5.76		3.65

Product margins (RVO adjusted unless otherwise noted) (dollars per barrel)
U.S. Gulf Coast:
CBOB gasoline less Brent	6.78		7.45
ULS diesel less Brent	17.51		16.87
Polymer Grade Propylene less Brent (not RVO adjusted)	(3.07)		7.28
U.S. Mid-Continent:
CBOB gasoline less WTI	12.32		12.16
ULS diesel less WTI	21.09		18.94
North Atlantic:
CBOB gasoline less Brent	10.97		12.41
ULS diesel less Brent	21.44		19.39
U.S. West Coast:
CARBOB 87 gasoline less Brent	28.94		25.13
CARB diesel less Brent	23.47		19.65

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First Nine Months Results -

Average Market Reference Prices and Differentials (continued)


	Nine Months Ended September 30,
	2025		2024
Renewable Diesel
New York Mercantile Exchange ULS diesel (dollars per gallon)	$	2.30	$	2.51
Biodiesel RIN (dollars per RIN)	1.00		0.56
California LCFS carbon credit (dollars per metric ton)	57.30		56.16
USGC UCO (dollars per pound)	0.56		0.43
USGC DCO (dollars per pound)	0.58		0.47
USGC Tallow (dollars per pound)	0.56		0.44

Ethanol
CBOT corn (dollars per bushel)	4.42		4.23
New York Harbor ethanol (dollars per gallon)	1.87		1.82

Total Company, Corporate, and Other

The following table includes selected financial data for the total company, corporate, and other for the first nine months of 2025 and 2024. The selected financial data is derived from the Financial Highlights by Segment and Total Company tables, unless otherwise noted.


	Nine Months Ended September 30,
	2025		2024		Change
Revenues	$	92,315	$	99,125	$	(6,810)

Cost of sales	88,787		94,949		(6,162)





Asset impairment loss (see note (b))	1,131		—		1,131
Operating income	1,606		3,407		(1,801)
Adjusted operating income (see note (c))	2,800		3,447		(647)


Income tax expense	404		726		(322)
Net income (loss) attributable to noncontrolling interests	(137)		160		(297)

Revenues decreased by $6.8 billion in the first nine months of 2025 compared to the first nine months of 2024 primarily due to decreases in product prices for the petroleum-based transportation fuels associated with sales made by our Refining segment. This decrease in revenues, along with the effect of an asset impairment loss of $1.1 billion in the first nine months of 2025 (see note (b)), was partially offset by a decrease in cost of sales of $6.2 billion primarily due to decreases in crude oil and other feedstock costs.

Operating income decreased by $1.8 billion in the first nine months of 2025; however, adjusted operating income, which excludes the adjustments in the table in note (c) decreased by $647 million, from $3.4 billion in the first nine months of 2024 to $2.8 billion in the first nine months of 2025. The components of this $647 million decrease in adjusted operating income are discussed by segment in the segment analyses that follow.

Income tax expense decreased by $322 million in the first nine months of 2025 compared to the first nine months of 2024 primarily as a result of lower income before income tax expense.

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Net income attributable to noncontrolling interests decreased by $297 million in the first nine months of 2025 compared to the first nine months of 2024 primarily due to lower earnings associated with DGD, whose operations compose our Renewable Diesel segment. See Note 6 of Condensed Notes to Consolidated Financial Statements regarding our accounting for DGD and the Renewable Diesel segment analysis on page 55.

Refining Segment Results

The following table includes selected financial and operating data of our Refining segment for the first nine months of 2025 and 2024. The selected financial data is derived from the Financial Highlights by Segment and Total Company tables, unless otherwise noted.


	Nine Months Ended September 30,
	2025		2024		Change
Operating income	$	2,346	$	3,534	$	(1,188)
Adjusted operating income (see note (c))	3,540		3,547		(7)

Refining margin (see note (c))	9,505		8,999		506

Operating expenses (excluding depreciation and amortization expense reflected below) (see note (a))	3,986		3,659		327
Adjusted operating expenses (excluding depreciation and amortization expense reflected below) (see note (c))	3,936		3,659		277
Depreciation and amortization expense	2,029		1,793		236
Asset impairment loss (see note (b))	1,131		—		1,131

Throughput volumes (thousand barrels per day) (see note (e))	2,947		2,885		62

Refining segment operating income decreased by $1.2 billion in the first nine months of 2025 compared to the first nine months of 2024; however, Refining segment adjusted operating income, which excludes the adjustments in the table in note (c), decreased by $7 million in the first nine months of 2025 compared to the first nine months of 2024. The components of this decrease in the adjusted results, along with the reasons for the changes in those components, are outlined below.

•Refining segment margin increased by $506 million in the first nine months of 2025 compared to the first nine months of 2024.

Refining segment margin is primarily affected by the prices for the petroleum-based transportation fuels that we sell and the cost of crude oil and other feedstocks that we process. The table on page 52 reflects market reference prices and differentials that we believe impacted our Refining segment margin in the first nine months of 2025 compared to the first nine months of 2024.

The increase in Refining segment margin was primarily due to the following:

◦An increase in margins for products other than gasoline and distillates had a favorable impact of approximately $710 million.

◦An increase in distillate (primarily diesel) margins had a favorable impact of approximately $680 million.

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◦An increase in gasoline margins had a favorable impact of approximately $340 million.

◦An increase in throughput volumes of 62,000 barrels per day had a favorable impact of approximately $200 million.

◦A decline in crude oil differentials had an unfavorable impact of approximately $970 million.

◦A decline in differentials for other feedstocks had an unfavorable impact of approximately $420 million.

•Refining segment adjusted operating expenses (excluding depreciation and amortization expense) increased by $277 million primarily due to increases in energy costs of $144 million and maintenance expenses of $49 million and the effect of a favorable property tax settlement of $51 million in the first nine months of 2024.

•Refining segment depreciation and amortization expense increased by $236 million primarily due to incremental depreciation expense of approximately $200 million related to our plan to cease refining operations at our Benicia Refinery by the end of April 2026, as described in Note 2 of Condensed Notes to Consolidated Financial Statements.

Renewable Diesel Segment Results

The following table includes selected financial and operating data of our Renewable Diesel segment for the first nine months of 2025 and 2024. The selected financial data is derived from the Financial Highlights by Segment and Total Company tables, unless otherwise noted.


	Nine Months Ended September 30,
	2025		2024		Change
Operating income (loss)	$	(248)	$	337	$	(585)


Renewable Diesel margin (see note (c))	185		795		(610)
Operating expenses (excluding depreciation and amortization expense reflected below)	228		262		(34)
Depreciation and amortization expense	205		196		9

Sales volumes (thousand gallons per day) (see note (e))	2,629		3,588		(959)

Renewable Diesel segment operating income decreased by $585 million in the first nine months of 2025 compared to the first nine months of 2024. The components of this decrease, along with the reasons for the changes in those components, are outlined below.

•Renewable Diesel segment margin decreased by $610 million in the first nine months of 2025 compared to the first nine months of 2024.

Renewable Diesel segment margin is primarily affected by the prices for the renewable fuels that we sell and the cost of the feedstocks that we process. The table on page 53 reflects market reference prices that we believe impacted our Renewable Diesel segment margin in the first nine months of 2025 compared to the first nine months of 2024.

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The decrease in Renewable Diesel segment margin was primarily due to the following:

◦An increase in the cost of the feedstocks that we process had an unfavorable impact of approximately $560 million.

◦A decrease in sales volumes of 959,000 gallons per day had an unfavorable impact of approximately $380 million. The decrease in sales volumes was primarily due to reduced production driven by unfavorable economic conditions and planned maintenance activities at the DGD St. Charles Plant in the first nine months of 2025.

◦An increase in product prices, primarily renewable diesel, had a favorable impact of approximately $340 million.

•Renewable Diesel segment operating expenses (excluding depreciation and amortization expense) decreased by $34 million primarily due to decreases in chemicals and catalysts costs of $21 million and outside services of $17 million.

Ethanol Segment Results

The following table includes selected financial and operating data of our Ethanol segment for the first nine months of 2025 and 2024. The selected financial data is derived from the Financial Highlights by Segment and Total Company tables, unless otherwise noted.


	Nine Months Ended September 30,
	2025		2024		Change
Operating income	$	257	$	268	$	(11)
Adjusted operating income (see note (c))	257		295		(38)

Ethanol margin (see note (c))	762		747		15
Operating expenses (excluding depreciation and amortization expense reflected below)	446		395		51
Depreciation and amortization expense	59		57		2

Production volumes (thousand gallons per day) (see note (e))	4,562		4,508		54

Ethanol segment operating income decreased by $11 million in the first nine months of 2025 compared to the first nine months of 2024; however, Ethanol segment adjusted operating income, which excludes the adjustment in the table in note (c), decreased by $38 million in the first nine months of 2025 compared to the first nine months of 2024. The components of this decrease in the adjusted results, along with the reasons for the changes in those components, are outlined below.

•Ethanol segment margin increased by $15 million in the first nine months of 2025 compared to the first nine months of 2024.

Ethanol segment margin is primarily affected by prices for the ethanol and corn related co-products that we sell and the cost of corn that we process. The table on page 53 reflects market reference prices that we believe impacted our Ethanol segment margin in the first nine months of 2025 compared to the first nine months of 2024.

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The increase in Ethanol segment margin was primarily due to the following:

◦An increase in ethanol prices had a favorable impact of approximately $75 million.

◦An increase in production volumes of 54,000 gallons per day had a favorable impact of approximately $20 million.

◦An increase in corn prices had an unfavorable impact of approximately $80 million.

•Ethanol segment operating expenses (excluding depreciation and amortization expense) increased by $51 million primarily due to an increase in energy costs.

________________________

The following notes relate to references on pages 43 through 56.

(a)Operating expenses (excluding depreciation and amortization expense) for the three and nine months ended September 30, 2025 includes employee retention and separation costs of $50 million related to the Benicia Refinery. In connection with our plan to cease refining operations at the Benicia Refinery, we implemented a transition plan for eligible employees, which includes retention incentive payments and separation benefits.

(b)In March 2025, we approved a plan with respect to the operations at our Benicia Refinery and currently intend to cease refining operations by the end of April 2026. In addition, we considered strategic alternatives for our remaining operations in California. As a result, we evaluated the assets of the Benicia and Wilmington refineries for impairment as of March 31, 2025 and concluded that the carrying values of these assets were not recoverable. Therefore, we reduced the carrying values of the Benicia and Wilmington refineries to their estimated fair values and recognized a combined asset impairment loss of $1.1 billion in the nine months ended September 30, 2025.

(c)We use certain financial measures (as noted below) that are not defined under GAAP and are considered to be non-GAAP measures.

We have defined these non-GAAP measures and believe they are useful to the external users of our financial statements, including industry analysts, investors, lenders, and rating agencies. We believe these measures are useful to assess our ongoing financial performance because, when reconciled to their most comparable GAAP measures, they provide improved comparability between periods after adjusting for certain items that we believe are not indicative of our core operating performance and that may obscure our underlying business results and trends. These non-GAAP measures should not be considered as alternatives to their most comparable GAAP measures nor should they be considered in isolation or as a substitute for an analysis of our results of operations as reported under GAAP. In addition, these non-GAAP measures may not be comparable to similarly titled measures used by other companies because we may define them differently, which diminishes their utility.

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Non-GAAP measures are as follows (in millions):

◦Refining margin is defined as Refining segment operating income excluding operating expenses (excluding depreciation and amortization expense), depreciation and amortization expense, the asset impairment loss, and other operating expenses, as reflected in the table below.


	Three Months Ended September 30,				Nine Months Ended September 30,
	2025		2024		2025		2024
Reconciliation of Refining operating income to Refining margin
Refining operating income	$	1,610	$	565	$	2,346	$	3,534
Adjustments:


Operating expenses (excluding depreciation and amortization expense) (see note (a))	1,388		1,256		3,986		3,659
Depreciation and amortization expense	728		589		2,029		1,793
Asset impairment loss (see note (b))	—		—		1,131		—
Other operating expenses	5		3		13		13
Refining margin	$	3,731	$	2,413	$	9,505	$	8,999

◦Renewable Diesel margin is defined as Renewable Diesel segment operating income (loss) excluding operating expenses (excluding depreciation and amortization expense) and depreciation and amortization expense, as reflected in the table below.


	Three Months Ended September 30,				Nine Months Ended September 30,
	2025		2024		2025		2024
Reconciliation of Renewable Diesel operating income (loss) to Renewable Diesel margin
Renewable Diesel operating income (loss)	$	(28)	$	35	$	(248)	$	337
Adjustments:

Operating expenses (excluding depreciation and amortization expense)	78		92		228		262
Depreciation and amortization expense	76		69		205		196

Renewable Diesel margin	$	126	$	196	$	185	$	795

◦Ethanol margin is defined as Ethanol segment operating income excluding operating expenses (excluding depreciation and amortization expense), depreciation and amortization expense, and other operating expenses, as reflected in the table below.


	Three Months Ended September 30,				Nine Months Ended September 30,
	2025		2024		2025		2024
Reconciliation of Ethanol operating income to Ethanol margin
Ethanol operating income	$	183	$	153	$	257	$	268
Adjustments:

Operating expenses (excluding depreciation and amortization expense)	148		133		446		395
Depreciation and amortization expense	21		19		59		57
Other operating expenses	—		—		—		27
Ethanol margin	$	352	$	305	$	762	$	747

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◦Adjusted Refining operating income is defined as Refining segment operating income excluding employee retention and separation costs, the asset impairment loss, and other operating expenses, as reflected in the table below.


	Three Months Ended September 30,				Nine Months Ended September 30,
	2025		2024		2025		2024
Reconciliation of Refining operating income to adjusted Refining operating income
Refining operating income	$	1,610	$	565	$	2,346	$	3,534
Adjustments:
Employee retention and separation costs (see note (a))	50		—		50		—
Asset impairment loss (see note (b))	—		—		1,131		—

Other operating expenses	5		3		13		13
Adjusted Refining operating income	$	1,665	$	568	$	3,540	$	3,547

◦Adjusted Ethanol operating income is defined as Ethanol segment operating income excluding other operating expenses, as reflected in the table below.


	Three Months Ended September 30,				Nine Months Ended September 30,
	2025		2024		2025		2024
Reconciliation of Ethanol operating income to adjusted Ethanol operating income
Ethanol operating income	$	183	$	153	$	257	$	268


Adjustment: Other operating expenses	—		—		—		27
Adjusted Ethanol operating income	$	183	$	153	$	257	$	295

◦Adjusted operating income is defined as total company operating income excluding employee retention and separation costs, the asset impairment loss, and other operating expenses, as reflected in the table below.


	Three Months Ended September 30,				Nine Months Ended September 30,
	2025		2024		2025		2024
Reconciliation of total company operating income to adjusted operating income
Total company operating income	$	1,509	$	507	$	1,606	$	3,407
Adjustments:
Employee retention and separation costs (see note (a))	50		—		50		—
Asset impairment loss (see note (b))	—		—		1,131		—


Other operating expenses	5		3		13		40
Adjusted operating income	$	1,564	$	510	$	2,800	$	3,447

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◦Adjusted Refining operating expenses (excluding depreciation and amortization expense) is defined as Refining segment operating expenses (excluding depreciation and amortization expense) excluding employee retention and separation costs.


	Three Months Ended September 30,				Nine Months Ended September 30,
	2025		2024		2025		2024
Reconciliation of Refining operating expenses (excluding depreciation and amortization expense) to adjusted Refining operating expenses (excluding depreciation and amortization expense)
Operating expenses (excluding depreciation and amortization expense)	$	1,388	$	1,256	$	3,986	$	3,659

Adjustment: Employee retention and separation costs (see note (a))	(50)		—		(50)		—


Adjusted Refining operating expenses (excluding depreciation and amortization expense)	$	1,338	$	1,256	$	3,936	$	3,659

(d)The RVO cost represents the average market cost on a per barrel basis to comply with the RFS program. The RVO cost is calculated by multiplying (i) the average market price during the applicable period for the RINs associated with each class of renewable fuel (i.e., biomass-based diesel, cellulosic biofuel, advanced biofuel, and total renewable fuel) by (ii) the quotas for the volume of each class of renewable fuel that must be blended into petroleum-based transportation fuels consumed in the U.S., as set or proposed by the EPA, on a percentage basis for each class of renewable fuel and adding together the results of each calculation.

(e)We use throughput volumes, sales volumes, and production volumes for the Refining segment, Renewable Diesel segment, and Ethanol segment, respectively, due to their general use by others who operate facilities similar to those included in our segments.

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LIQUIDITY AND CAPITAL RESOURCES

Our Liquidity

Our liquidity consisted of the following as of September 30, 2025 (in millions):


Available capacity from our committed facilities (a):
Valero Revolver	$	3,998
Accounts receivable sales facility	1,300
Total available capacity	5,298
Cash and cash equivalents (b)	4,595
Total liquidity	$	9,893

________________________

(a)Excludes the committed facilities of the consolidated VIEs.

(b)Excludes $169 million of cash and cash equivalents related to the consolidated VIEs that is for their use only.

Information about our outstanding borrowings, letters of credit issued, and availability under our credit facilities is reflected in Note 4 of Condensed Notes to Consolidated Financial Statements.

On February 7, 2025, we issued $650 million of 5.150 percent Senior Notes due February 15, 2030. Proceeds from this debt issuance totaled $649 million before deducting the underwriting discount and other debt issuance costs. A portion of the net proceeds from this debt issuance was used for the repayment of our outstanding 3.65 percent Senior Notes due March 15, 2025 and 2.850 percent Senior Notes due April 15, 2025. The remaining net proceeds were used for general corporate purposes.

We believe we have sufficient funds from operations and from available capacity under our credit facilities to fund our ongoing operating requirements and other commitments over the next 12 months and thereafter for the foreseeable future. We expect that, to the extent necessary, we can raise additional cash through equity or debt financings in the public and private capital markets or the arrangement of additional credit facilities. However, there can be no assurances regarding the availability of any future financings or additional credit facilities or whether such financings or additional credit facilities can be made available on terms that are acceptable to us.

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Cash Flows

Components of our cash flows are set forth below (in millions):


	Nine Months Ended September 30,
	2025		2024
Cash flows provided by (used in):
Operating activities	$	3,769	$	5,613
Investing activities	(1,426)		(1,437)
Financing activities:
Debt issuance and borrowings	5,999		5,473
Repayments of debt and finance lease obligations	(5,913)		(6,053)
Return to stockholders:
Purchases of common stock for treasury	(1,534)		(2,616)
Common stock dividend payments	(1,061)		(1,045)
Return to stockholders	(2,595)		(3,661)
Other financing activities	79		(24)
Financing activities	(2,430)		(4,265)
Effect of foreign exchange rate changes on cash	199		19
Net increase (decrease) in cash, cash equivalents, and restricted cash	$	112	$	(70)

Cash Flows for the Nine Months Ended September 30, 2025

In the first nine months of 2025, we used the $3.8 billion of cash generated by our operations and the $6.0 billion from our debt issuance and borrowings to make $1.4 billion of investments in our business, repay $5.9 billion of debt and finance lease obligations, return $2.6 billion to our stockholders through purchases of our common stock for treasury and dividend payments, and increase our available cash on hand by $112 million. The debt issuance, borrowings, and repayments are described in Note 4 of Condensed Notes to Consolidated Financial Statements.

As previously noted, our operations generated $3.8 billion of cash in the first nine months of 2025, primarily resulting from net income of $1.1 billion, noncash charges to income of $2.5 billion, and a positive change in working capital of $157 million. Noncash charges primarily included a $1.1 billion asset impairment loss associated with our operations in California, as described in Note 2 of Condensed Notes to Consolidated Financial Statements, and $2.3 billion of depreciation and amortization expense, partially offset by a $288 million deferred income tax benefit. Details regarding the components of the change in working capital, along with the reasons for the changes in those components, are described in Note 11 of Condensed Notes to Consolidated Financial Statements. In addition, see “RESULTS OF OPERATIONS” for an analysis of the significant components of our net income.

Our investing activities of $1.4 billion primarily consisted of $1.5 billion in capital investments, as defined on the following page under “Capital Investments,” of which $158 million related to capital investments made by DGD.

Cash Flows for the Nine Months Ended September 30, 2024

In the first nine months of 2024, we used the $5.6 billion of cash generated by our operations, $5.5 billion in debt borrowings, and $70 million of cash on hand to make $1.4 billion of investments in our business, repay $6.1 billion of debt and finance lease obligations, and return $3.7 billion to our stockholders

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through purchases of our common stock for treasury and dividend payments. The debt borrowings and repayments are described in Note 4 of Condensed Notes to Consolidated Financial Statements.

As previously noted, our operations generated $5.6 billion of cash in the first nine months of 2024, driven primarily by net income of $2.6 billion, noncash charges to income of $2.2 billion, and a positive change in working capital of $795 million. Noncash charges primarily included $2.1 billion of depreciation and amortization expense. Details regarding the components of the change in working capital, along with the reasons for the changes in those components, are described in Note 11 of Condensed Notes to Consolidated Financial Statements. In addition, see “RESULTS OF OPERATIONS” for an analysis of the significant components of our net income.

Our investing activities of $1.4 billion primarily consisted of $1.5 billion in capital investments, of which $260 million related to capital investments made by DGD.

Our Capital Resources

Our material cash requirements as of September 30, 2025 primarily consisted of working capital requirements, capital investments, contractual obligations, and other matters, as described below. Our operations have historically generated positive cash flows to fulfill our working capital requirements and other uses of cash as discussed below.

Capital Investments

Capital investments are composed of our capital expenditures, deferred turnaround and catalyst cost expenditures, and investments in nonconsolidated joint ventures, as reflected in our statements of cash flows as shown on page 6. Capital investments exclude acquisitions, if any.

We have publicly announced GHG emissions reduction/displacement targets and a long-term ambition. We believe that our allocation of growth capital into low-carbon projects to date has been consistent with such targets and ambition. Certain low-carbon projects have been completed or are already in execution and the associated capital investments are included in our expected capital investments for 2025. Our capital investments in future years to achieve these targets and ambition are expected to include investments associated with certain low-carbon projects currently at various stages of progress, evaluation, or approval. For additional information, see the “RISK FACTORS” section included in our annual report on Form 10-K for the year ended December 31, 2024.

Capital Investments Attributable to Valero

Capital investments attributable to Valero is a non-GAAP financial measure that reflects our net share of capital investments and is defined as all capital expenditures, deferred turnaround and catalyst cost expenditures, and investments in nonconsolidated joint ventures, excluding the portion of DGD’s capital investments attributable to the other joint venture member and all of the capital expenditures of other consolidated VIEs.

We are a 50 percent joint venture member in DGD and consolidate its financial statements, and DGD’s operations compose our Renewable Diesel segment. As a result, all of DGD’s net cash provided by operating activities (or operating cash flow) is included in our consolidated net cash provided by operating activities. In general, DGD’s members use DGD’s operating cash flow (excluding changes in its current assets and current liabilities) to fund its capital investments rather than distribute all of that cash to themselves. Because DGD’s operating cash flow is effectively attributable to each member, only 50 percent of DGD’s capital investments should be attributed to our net share of capital investments. We also exclude all of the capital expenditures of other VIEs that we consolidate because we do not operate

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those VIEs. See Note 6 of Condensed Notes to Consolidated Financial Statements for more information about the VIEs that we consolidate. We believe capital investments attributable to Valero is an important measure because it more accurately reflects our capital investments.

Capital investments attributable to Valero should not be considered as an alternative to capital investments, which is the most comparable GAAP measure, nor should it be considered in isolation or as a substitute for an analysis of our cash flows as reported under GAAP. In addition, this non-GAAP measure may not be comparable to similarly titled measures used by other companies because we may define it differently, which may diminish its utility.

The following table (in millions) reconciles our capital investments to capital investments attributable to Valero for the nine months ended September 30, 2025 and 2024.


		Nine Months Ended September 30,
	2025			2024
Reconciliation of capital investments to capital investments attributable to Valero
Capital expenditures (excluding VIEs)		$	504		$	399
Capital expenditures of VIEs:
DGD		67			198
Other VIEs		5			7
Deferred turnaround and catalyst cost expenditures (excluding VIEs)		808			844
Deferred turnaround and catalyst cost expenditures of DGD		91			62
Investments in nonconsolidated joint ventures		1			—
Capital investments		1,476			1,510
Adjustments:
DGD’s capital investments attributable to the other joint venture member		(79)			(130)
Capital expenditures of other VIEs		(5)			(7)
Capital investments attributable to Valero		$	1,392		$	1,373

We have developed an extensive multi-year capital investment program, which we update and revise based on changing internal and external factors. We expect to incur approximately $1.9 billion for capital investments attributable to Valero during 2025. Of this amount, approximately $1.6 billion is for sustaining the business and the balance for growth strategies.

Contractual Obligations

As of September 30, 2025, our contractual obligations included debt obligations, interest payments related to debt obligations, operating lease liabilities, finance lease obligations, other long-term liabilities, and purchase obligations. In the ordinary course of business, we had debt-related activities during the nine months ended September 30, 2025, as described in Note 4 of Condensed Notes to Consolidated Financial Statements. There were no material changes outside the ordinary course of business with respect to our contractual obligations during the nine months ended September 30, 2025.

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Other Matters Impacting Liquidity and Capital Resources

Stock Purchase Programs

During the nine months ended September 30, 2025, we purchased for treasury 10,309,669 of our shares for a total cost of $1.5 billion. See Note 5 of Condensed Notes to Consolidated Financial Statements for additional information related to our stock purchase programs. As of September 30, 2025, we had $311 million and $2.5 billion remaining available for purchase under the February 2024 and September 2024 Programs, respectively. We will continue to evaluate the timing of purchases when appropriate. We have no obligation to make purchases under these programs.

Pension Plan Funding

We contributed $88 million to our pension plans and $14 million to our other postretirement benefit plans during the nine months ended September 30, 2025.

Tax Matters

On July 4, 2025, the OBBB was enacted, which resulted in a broad range of changes to the Code, as more fully described in Note 8 of Condensed Notes to Consolidated Financial Statements.

We do not expect that these changes and other provisions of this legislation will have a material effect on our financial condition, results of operations, and liquidity in 2025; however, we continue to evaluate the effects of the OBBB on our financial condition, results of operations, and liquidity in the future.

Cash Held by Our Foreign Subsidiaries

As of September 30, 2025, $4.0 billion of our cash and cash equivalents was held by our foreign subsidiaries. Cash held by our foreign subsidiaries can be repatriated to us through dividends without any U.S. federal income tax consequences, but certain other taxes may apply, including, but not limited to, withholding taxes imposed by certain foreign jurisdictions, U.S. state income taxes, and U.S. federal income tax on foreign exchange gains. Therefore, there is a cost to repatriate cash held by certain of our foreign subsidiaries to us.

Asset Retirement Obligations

See Note 2 of Condensed Notes to Consolidated Financial Statements for information regarding our asset retirement obligations.

Environmental Matters

Our operations are subject to extensive environmental regulations by government authorities relating to, among other matters, the release or discharge of materials into the environment, climate, waste management, pollution prevention measures, GHG and other emissions, our facilities and operations, and characteristics and composition of many of our products. Because environmental laws and regulations have become more complex and stringent and new or revised environmental laws and regulations are continuously being enacted or proposed, the level of future costs and expenditures required for environmental matters could increase.

Concentration of Customers

Our operations have a concentration of customers in the refining industry and customers who are refined petroleum product wholesalers and retailers. These concentrations of customers may impact our overall exposure to credit risk, either positively or negatively, in that these customers may be similarly affected by changes in economic or other conditions, including the uncertainties concerning worldwide events causing volatility in the global crude oil markets. However, we believe that our portfolio of accounts

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receivable is sufficiently diversified to the extent necessary to minimize potential credit risk. Historically, we have not had any significant problems collecting our accounts receivable.

CRITICAL ACCOUNTING ESTIMATES

The preparation of financial statements in conformity with GAAP requires us to make estimates and assumptions that affect the amounts reported in our financial statements and accompanying notes. Actual results could differ from those estimates. There have been no changes to the critical accounting policies that involve critical accounting estimates disclosed in our annual report on Form 10-K for the year ended December 31, 2024.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

INTEREST RATE RISK

The following tables provide information about our debt instruments (dollars in millions), the fair values of which are sensitive to changes in interest rates. A 10 percent increase or decrease in our floating interest rates would not have a material effect on our results of operations. Principal cash flows and related weighted-average interest rates by expected maturity dates are presented. See Note 4 of Condensed Notes to Consolidated Financial Statements for additional information related to our debt.


	September 30, 2025 (a)
	Expected Maturity Dates
	Remainder of 2025			2026			2027			2028			2029			There- after			Total			Fair Value
Fixed rate	$	—		$	672		$	564		$	1,047		$	439		$	5,585		$	8,307		$	8,196
Average interest rate	—		%	4.2		%	2.2		%	4.4		%	4.0		%	5.5		%	5.0		%
Floating rate	$	131		$	—		$	—		$	—		$	—		$	—		$	131		$	131
Average interest rate	6.6		%	—		%	—		%	—		%	—		%	—		%	6.6		%

	December 31, 2024 (a)
	Expected Maturity Dates
	2025			2026			2027			2028			2029			There- after			Total			Fair Value
Fixed rate	$	441		$	672		$	564		$	1,047		$	439		$	4,935		$	8,098		$	7,718
Average interest rate	3.2		%	4.2		%	2.2		%	4.4		%	4.0		%	5.6		%	4.9		%
Floating rate	$	58		$	—		$	—		$	—		$	—		$	—		$	58		$	58
Average interest rate	8.4		%	—		%	—		%	—		%	—		%	—		%	8.4		%

________________________

(a)Excludes unamortized discounts and debt issuance costs.

OTHER MARKET RISKS

We are exposed to market risks primarily related to the volatility in the price of commodities, the price of credits needed to comply with the Renewable and Low-Carbon Fuel Programs, and foreign currency exchange rates. There have been no material changes to these market risks disclosed in our annual report on Form 10-K for the year ended December 31, 2024. See Note 13 of Condensed Notes to Consolidated Financial Statements for a discussion about these market risks as of September 30, 2025.

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ITEM 4. CONTROLS AND PROCEDURES

(a)Evaluation of disclosure controls and procedures.

Our management has evaluated, with the participation of our principal executive officer and principal financial officer, the effectiveness of our disclosure controls and procedures (as defined in Rule 13a-15(e) under the Securities Exchange Act of 1934) as of the end of the period covered by this report, and has concluded that our disclosure controls and procedures were effective as of September 30, 2025.

(b)Changes in internal control over financial reporting.

There has been no change in our internal control over financial reporting that occurred during our last fiscal quarter that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

PART II – OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

During the three months ended September 30, 2025, there were no new proceedings required to be disclosed in this item under SEC regulations and no material developments in proceedings that we previously reported in our annual report on Form 10-K for the year ended December 31, 2024 or in our quarterly report on Form 10-Q for the quarter ended June 30, 2025. Pursuant to SEC regulations, we use a threshold of $1 million for purposes of determining whether disclosure of certain environmental proceedings is required in this item. We believe any such proceedings less than this threshold are not material to our business and financial condition.

ITEM 1A. RISK FACTORS

There have been no material changes to the risk factors disclosed in our annual report on Form 10-K for the year ended December 31, 2024.

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ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

Issuer Purchases of Equity Securities

The following table discloses purchases of shares of our common stock made by us or on our behalf during the third quarter of 2025.


Period	Total Number of Shares Purchased (a)	Average Price Paid per Share (b)		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs	Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plans or Programs (c)
July 2025	6,397	$	147.13	—	$3.7 billion
August 2025	856,546	$	138.07	855,028	$3.6 billion
September 2025	4,804,191	$	167.08	4,803,426	$2.8 billion
Total	5,667,134	$	162.67	5,658,454	$2.8 billion

________________________

(a)The shares reported in this column include 8,680 shares related to our purchases of shares from participants in our stock-based compensation plans in connection with the vesting of restricted stock and other stock compensation transactions in accordance with the terms of our stock-based compensation plans.

(b)The average price paid per share reported in this column excludes brokerage commissions and a one percent excise tax on share purchases.

(c)On February 22, 2024, we announced that our Board authorized us to purchase shares of our outstanding common stock for a total cost of up to $2.5 billion with no expiration date. As of September 30, 2025, we had $311 million remaining available for purchase under the February 2024 Program. On October 29, 2024, we announced that our Board authorized us to purchase shares of our outstanding common stock for a total cost of up to $2.5 billion with no expiration date, which is in addition to the amount remaining under the February 2024 Program. This authorization was granted on September 19, 2024.

ITEM 5. OTHER INFORMATION

(a)None.

(b)None.

(c)During the three months ended September 30, 2025, no director or officer (as defined in Rule 16a-1(f) of the Securities Exchange Act of 1934) of Valero adopted or terminated a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement,” as each term is defined in Item 408 of Regulation S-K.

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ITEM 6. EXHIBITS


Exhibit No.						Description
10.01						Amended and Restated Revolving Credit Agreement, dated as of October 16, 2025, among Valero Energy Corporation, as Borrower, JPMorgan Chase Bank, N.A., as Administrative Agent, and the other financial institutions from time to time party thereto–incorporated by reference to Exhibit 10.1 to Valero’s current report on Form 8-K dated and filed October 16, 2025 (SEC File No. 001-13175).

22.01						Subsidiary Issuer of Guaranteed Securities–incorporated by reference to Exhibit 22.01 to Valero’s quarterly report on Form 10-Q for the quarter ended June 30, 2025 (SEC File No. 001-13175).

*31.01						Rule 13a-14(a) Certification (under Section 302 of the Sarbanes-Oxley Act of 2002) of principal executive officer.

*31.02						Rule 13a-14(a) Certification (under Section 302 of the Sarbanes-Oxley Act of 2002) of principal financial officer.

**32.01						Section 1350 Certifications (under Section 906 of the Sarbanes-Oxley Act of 2002).

***101.INS						Inline XBRL Instance Document–the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.

***101.SCH						Inline XBRL Taxonomy Extension Schema Document.

***101.CAL						Inline XBRL Taxonomy Extension Calculation Linkbase Document.

***101.DEF						Inline XBRL Taxonomy Extension Definition Linkbase Document.

***101.LAB						Inline XBRL Taxonomy Extension Label Linkbase Document.

***101.PRE						Inline XBRL Taxonomy Extension Presentation Linkbase Document.

***104						Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101).

________________________


*			Filed herewith.
**			Furnished herewith.
***			Submitted electronically herewith.

Pursuant to paragraph 601(b)(4)(iii)(A) of Regulation S-K, the registrant has omitted from the foregoing listing of exhibits, and hereby agrees to furnish to the SEC upon its request, copies of certain instruments, each relating to debt not exceeding 10 percent of the total assets of the registrant and its subsidiaries on a consolidated basis.

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SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.



						VALERO ENERGY CORPORATION (Registrant)
			By:			/s/ Jason W. Fraser
						Jason W. Fraser
						Executive Vice President and
						Chief Financial Officer
						(Duly Authorized Officer and Principal
						Financial and Accounting Officer)

Date: October 23, 2025

Valero Energy - 10-Q quarterly report FY2025 Q3

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