10-Q

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, 2023

OR

☐	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 20, 2023 was 340,452,942.

VALERO ENERGY CORPORATION

TABLE OF CONTENTS

	Page
PART I – FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
Consolidated Balance Sheets as of September 30, 2023 and December 31, 2022	1
Consolidated Statements of Income for the Three and Nine Months Ended September 30, 2023 and 2022	2
Consolidated Statements of Comprehensive Income for the Three and Nine Months Ended September 30, 2023 and 2022	3
Consolidated Statements of Equity for the Three and Nine Months Ended September 30, 2023 and 2022	4
Consolidated Statements of Cash Flows for the Nine Months Ended September 30, 2023 and 2022	6
Condensed Notes to Consolidated Financial Statements	7
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	32
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	62
ITEM 4. CONTROLS AND PROCEDURES	63
PART II – OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS	63
ITEM 1A. RISK FACTORS	64
ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES, USE OF PROCEEDS, AND ISSUER PURCHASES OF EQUITY SECURITIES	64
ITEM 5. OTHER INFORMATION	65
ITEM 6. EXHIBITS	65
SIGNATURE	66

i

PART I – FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

VALERO ENERGY CORPORATION

CONSOLIDATED BALANCE SHEETS

(millions of dollars, except par value)

	September 30, 2023		December 31, 2022
	(unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	5,831	$	4,862
Receivables, net	12,566		11,919
Inventories	7,513		6,752
Prepaid expenses and other	667		600
Total current assets	26,577		24,133
Property, plant, and equipment, at cost	51,208		50,576
Accumulated depreciation	(20,955)		(19,598)
Property, plant, and equipment, net	30,253		30,978
Deferred charges and other assets, net	6,345		5,871
Total assets	$	63,175	$	60,982
LIABILITIES AND EQUITY
Current liabilities:
Current portion of debt and finance lease obligations	$	1,334	$	1,109
Accounts payable	13,342		12,728
Accrued expenses	1,219		1,215
Taxes other than income taxes payable	1,419		1,568
Income taxes payable	278		841
Total current liabilities	17,592		17,461
Debt and finance lease obligations, less current portion	10,107		10,526
Deferred income tax liabilities	5,231		5,217
Other long-term liabilities	2,188		2,310
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	6,900		6,863
Treasury stock, at cost; 333,047,642 and 301,372,958 common shares	(24,381)		(20,197)
Retained earnings	44,774		38,247
Accumulated other comprehensive loss	(1,325)		(1,359)
Total Valero Energy Corporation stockholders’ equity	25,975		23,561
Noncontrolling interests	2,082		1,907
Total equity	28,057		25,468
Total liabilities and equity	$	63,175	$	60,982

See Condensed Notes to Consolidated Financial Statements.

1

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,
	2023		2022		2023		2022
Revenues (a)	$	38,404	$	44,454	$	109,352	$	134,637
Cost of sales:
Cost of materials and other	32,385		38,064		91,820		115,959
Operating expenses (excluding depreciation and amortization expense reflected below)	1,578		1,746		4,495		4,751
Depreciation and amortization expense	671		621		1,979		1,806
Total cost of sales	34,634		40,431		98,294		122,516
Other operating expenses	6		6		18		40
General and administrative expenses (excluding depreciation and amortization expense reflected below)	250		214		703		652
Depreciation and amortization expense	11		11		32		34
Operating income	3,503		3,792		10,305		11,395
Other income, net	122		74		357		87
Interest and debt expense, net of capitalized interest	(149)		(138)		(443)		(425)
Income before income tax expense	3,476		3,728		10,219		11,057
Income tax expense	813		816		2,288		2,410
Net income	2,663		2,912		7,931		8,647
Less: Net income attributable to noncontrolling interests	41		95		298		232
Net income attributable to Valero Energy Corporation stockholders	$	2,622	$	2,817	$	7,633	$	8,415
Earnings per common share	$	7.49	$	7.20	$	21.22	$	20.94
Weighted-average common shares outstanding (in millions)	349		390		359		400
Earnings per common share – assuming dilution	$	7.49	$	7.19	$	21.21	$	20.93
Weighted-average common shares outstanding – assuming dilution (in millions)	349		390		359		401
__________________________
Supplemental information:
(a) Includes excise taxes on sales by certain of our foreign operations	$	1,468	$	1,213	$	4,339	$	3,890

See Condensed Notes to Consolidated Financial Statements.

2

VALERO ENERGY CORPORATION

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(millions of dollars)

(unaudited)

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Net income	$	2,663	$	2,912	$	7,931	$	8,647
Other comprehensive income (loss):
Foreign currency translation adjustment	(314)		(606)		77		(1,035)
Net gain (loss) on pension and other postretirement benefits	(12)		8		(25)		25
Net gain (loss) on cash flow hedges	(78)		69		(68)		74
Other comprehensive loss before income tax expense (benefit)	(404)		(529)		(16)		(936)
Income tax expense (benefit) related to items of other comprehensive income (loss)	(11)		9		(16)		16
Other comprehensive loss	(393)		(538)		—		(952)
Comprehensive income	2,270		2,374		7,931		7,695
Less: Comprehensive income attributable to noncontrolling interests	2		129		264		269
Comprehensive income attributable to Valero Energy Corporation stockholders	$	2,268	$	2,245	$	7,667	$	7,426

See Condensed Notes to Consolidated Financial Statements.

3

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, 2023	$	7	$	6,889	$	(22,586)	$	42,512	$	(971)	$	25,851	$	2,143	$	27,994
Net income	—		—		—		2,622		—		2,622		41		2,663
Dividends on common stock ($1.02 per share)	—		—		—		(360)		—		(360)		—		(360)
Stock-based compensation expense	—		15		—		—		—		15		—		15
Transactions in connection with stock-based compensation plans	—		(4)		10		—		—		6		—		6
Purchases of common stock for treasury	—		—		(1,805)		—		—		(1,805)		—		(1,805)
Distributions to noncontrolling interests	—		—		—		—		—		—		(63)		(63)
Other comprehensive loss	—		—		—		—		(354)		(354)		(39)		(393)
Balance as of September 30, 2023	$	7	$	6,900	$	(24,381)	$	44,774	$	(1,325)	$	25,975	$	2,082	$	28,057
Balance as of June 30, 2022	$	7	$	6,845	$	(17,537)	$	33,079	$	(1,425)	$	20,969	$	1,764	$	22,733
Net income	—		—		—		2,817		—		2,817		95		2,912
Dividends on common stock ($0.98 per share)	—		—		—		(386)		—		(386)		—		(386)
Stock-based compensation expense	—		13		—		—		—		13		—		13
Transactions in connection with stock-based compensation plans	—		—		(1)		—		—		(1)		—		(1)
Purchases of common stock for treasury	—		—		(928)		—		—		(928)		—		(928)
Distributions to noncontrolling interests	—		—		—		—		—		—		(90)		(90)
Other comprehensive income (loss)	—		—		—		—		(572)		(572)		34		(538)
Balance as of September 30, 2022	$	7	$	6,858	$	(18,466)	$	35,510	$	(1,997)	$	21,912	$	1,803	$	23,715

See Condensed Notes to Consolidated Financial Statements.

4

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, 2022	$	7	$	6,863	$	(20,197)	$	38,247	$	(1,359)	$	23,561	$	1,907	$	25,468
Net income	—		—		—		7,633		—		7,633		298		7,931
Dividends on common stock ($3.06 per share)	—		—		—		(1,106)		—		(1,106)		—		(1,106)
Stock-based compensation expense	—		68		—		—		—		68		—		68
Transactions in connection with stock-based compensation plans	—		(31)		38		—		—		7		—		7
Purchases of common stock for treasury	—		—		(4,222)		—		—		(4,222)		—		(4,222)
Contributions from noncontrolling interests	—		—		—		—		—		—		75		75
Distributions to noncontrolling interests	—		—		—		—		—		—		(164)		(164)
Other comprehensive income (loss)	—		—		—		—		34		34		(34)		—
Balance as of September 30, 2023	$	7	$	6,900	$	(24,381)	$	44,774	$	(1,325)	$	25,975	$	2,082	$	28,057
Balance as of December 31, 2021	$	7	$	6,827	$	(15,677)	$	28,281	$	(1,008)	$	18,430	$	1,387	$	19,817
Net income	—		—		—		8,415		—		8,415		232		8,647
Dividends on common stock ($2.94 per share)	—		—		—		(1,186)		—		(1,186)		—		(1,186)
Stock-based compensation expense	—		60		—		—		—		60		—		60
Transactions in connection with stock-based compensation plans	—		(29)		31		—		—		2		—		2
Purchases of common stock for treasury	—		—		(2,820)		—		—		(2,820)		—		(2,820)
Contributions from noncontrolling interests	—		—		—		—		—		—		240		240
Distributions to noncontrolling interests	—		—		—		—		—		—		(93)		(93)
Other comprehensive income (loss)	—		—		—		—		(989)		(989)		37		(952)
Balance as of September 30, 2022	$	7	$	6,858	$	(18,466)	$	35,510	$	(1,997)	$	21,912	$	1,803	$	23,715

See Condensed Notes to Consolidated Financial Statements.

5

VALERO ENERGY CORPORATION

CONSOLIDATED STATEMENTS OF CASH FLOWS

(millions of dollars)

(unaudited)

	Nine Months Ended September 30,
	2023		2022
Cash flows from operating activities:
Net income	$	7,931	$	8,647
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization expense	2,011		1,840
Loss (gain) on early retirement of debt, net	(11)		24
Deferred income tax expense (benefit)	32		(161)
Changes in current assets and current liabilities	(1,695)		(1,617)
Changes in deferred charges and credits and other operating activities, net	(278)		(255)
Net cash provided by operating activities	7,990		8,478
Cash flows from investing activities:
Capital expenditures (excluding variable interest entities (VIEs))	(468)		(552)
Capital expenditures of VIEs:
Diamond Green Diesel Holdings LLC (DGD)	(183)		(682)
Other VIEs	(4)		(30)
Deferred turnaround and catalyst cost expenditures (excluding VIEs)	(665)		(820)
Deferred turnaround and catalyst cost expenditures of DGD	(56)		(13)
Purchases of available-for-sale (AFS) debt securities	(237)		—
Proceeds from sales and maturities of AFS debt securities	220		—
Proceeds from sale of assets	—		32
Investments in nonconsolidated joint ventures	—		(1)
Other investing activities, net	11		(4)
Net cash used in investing activities	(1,382)		(2,070)
Cash flows from financing activities:
Proceeds from debt issuances and borrowings (excluding VIEs)	1,750		1,839
Proceeds from borrowings of VIEs:
DGD	500		684
Other VIEs	86		73
Repayments of debt and finance lease obligations (excluding VIEs)	(2,071)		(4,234)
Repayments of debt and finance lease obligations of VIEs:
DGD	(474)		(718)
Other VIEs	(59)		(51)
Premiums paid on early retirement of debt	(5)		(48)
Purchases of common stock for treasury	(4,180)		(2,769)
Common stock dividend payments	(1,106)		(1,186)
Contributions from noncontrolling interests	75		240
Distributions to noncontrolling interests	(164)		(93)
Other financing activities, net	3		(6)
Net cash used in financing activities	(5,645)		(6,269)
Effect of foreign exchange rate changes on cash	6		(292)
Net increase (decrease) in cash and cash equivalents	969		(153)
Cash and cash equivalents at beginning of period	4,862		4,122
Cash and cash equivalents at end of period	$	5,831	$	3,969

See Condensed Notes to Consolidated Financial Statements.

6

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 disclosed otherwise. Operating results for the interim periods are not necessarily indicative of the results that may be expected for the year ending December 31, 2023. 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, 2022.

The balance sheet as of December 31, 2022 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, 2022.

Significant Accounting Policy

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.

2.    UNCERTAINTY

In September 2022, California adopted Senate Bill No. 1322 (SB 1322), which requires refineries in California to report monthly on the volume and cost of the crude oil they buy, the quantity and price of the wholesale gasoline they sell, and the gross gasoline margin per barrel, among other information. The provisions of SB 1322 were effective January 2023.

In March 2023, California adopted Senate Bill No. 2 (such statute, together with any regulations contemplated or issued thereunder, SBx 1-2), which, among other things, (i) authorized the establishment of a maximum gross gasoline refining margin (max margin) and the imposition of a financial penalty for profits above a max margin, (ii) significantly expanded the reporting obligations under SB 1322 and the Petroleum Industry Information Reporting Act of 1980, which include reporting requirements to the

7

VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

California Energy Commission (CEC) for all participants in the petroleum industry supply chain in California (e.g., refiners, marketers, importers, transporters, terminals, producers, renewables producers, pipelines, and ports), (iii) created the Division of Petroleum Market Oversight within the CEC to analyze the data provided under SBx 1-2, and (iv) authorized the CEC to regulate the timing and other aspects of refinery turnaround and maintenance activities in certain instances. SBx 1-2 imposes increased and substantial reporting requirements, which include daily, weekly, monthly, and annual reporting of detailed operational and financial data on all aspects of our operations in California, much of it at the transaction level. The operational data includes our plans for turnaround and maintenance activities at our two California refineries and the manner in which we expect to address the potential impacts on feedstock and product inventories in California as a result of such turnaround and maintenance activities. The provisions of SBx 1-2 became effective June 26, 2023.

In September 2023, Governor Newsom directed the CEC to immediately begin the regulatory processes concerning the potential imposition of a penalty for exceeding a max margin and the timing of refinery turnarounds and maintenance. Consequently, the CEC adopted an order instituting an informational proceeding on a max margin and penalty under SBx 1-2, as well as an order initiating rulemaking activity under SBx 1-2. The CEC indicated the latter rulemaking process will be focused on refinery maintenance and turnarounds; however, it remains uncertain as to whether, when, and to what extent any regulations will address the remaining reporting requirements under SBx 1-2.

We continue to review and analyze the provisions of SBx 1-2 and the possible impacts to our refining and marketing operations in California. While the CEC has not yet established a max margin, imposed a financial penalty for profits above a max margin, or imposed restrictions on turnaround and maintenance activities, Governor Newsom’s direction to the CEC to begin the regulatory processes related to each of those matters, as described above, and the potential implementation of a financial penalty or any restrictions or delays on our ability to undertake turnaround or maintenance activities creates uncertainty due to the potential adverse effects on us. Any adverse effects on our operations or financial performance in California could indicate that the carrying value of our assets in California is not recoverable, which would result in an impairment loss that could be material. In addition, if the circumstances that trigger an impairment loss result in a reduction in the estimated useful lives of the assets, we may be required to recognize an asset retirement obligation that could be material. Other jurisdictions are contemplating similarly focused legislation or actions.

The ultimate timing and impacts of SBx 1-2 and any other similarly focused legislation or actions are subject to considerable uncertainty due to a number of factors, including technological and economic feasibility, legal challenges, and potential changes in law, regulation, or policy, and it is not currently possible to predict the ultimate effects of these matters and developments on us.

8

VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

3.    INVENTORIES

Inventories consisted of the following (in millions):

	September 30, 2023		December 31, 2022
Refinery feedstocks	$	1,878	$	1,949
Refined petroleum products and blendstocks	4,232		3,579
Renewable diesel feedstocks and products	797		583
Ethanol feedstocks and products	270		328
Materials and supplies	336		313
Inventories	$	7,513	$	6,752

As of September 30, 2023 and December 31, 2022, the replacement cost (market value) of last-in, first-out (LIFO) inventories exceeded their LIFO carrying amounts by $6.1 billion and $6.3 billion, respectively. Our non-LIFO inventories accounted for $1.3 billion and $1.6 billion of our total inventories as of September 30, 2023 and December 31, 2022, respectively.

4.    DEBT

Public Debt

In February 2023, we used cash on hand to purchase and retire a portion of the following notes (in millions):

Debt Purchased and Retired	Principal Amount
6.625% Senior Notes due 2037	$	62
3.650% Senior Notes due 2051	26
4.000% Senior Notes due 2052	45
Various other Valero and Valero Energy Partners (VLP) Senior Notes	66
Total	$	199

9

VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

During the nine months ended September 30, 2022, the following activity occurred:

•In September 2022, we used cash on hand to purchase and retire a portion of the following notes in connection with cash tender offers that we publicly announced in August 2022 and completed in September 2022 (in millions):

Debt Purchased and Retired	Principal Amount
3.65% Senior Notes due 2025	$	48
2.850% Senior Notes due 2025	291
4.375% VLP Senior Notes due 2026	62
3.400% Senior Notes due 2026	166
4.350% Senior Notes due 2028	131
4.000% Senior Notes due 2029	552
Total	$	1,250

•In June 2022, we reduced our debt through the acquisition of the $300 million of 4.00 percent Gulf Opportunity Zone Revenue Bonds Series 2010 that are due December 1, 2040, but were subject to mandatory tender on June 1, 2022. We have the option to effectuate a remarketing of these bonds.

•In February 2022, we issued $650 million of 4.000 percent Senior Notes due June 1, 2052. Proceeds from this debt issuance totaled $639 million before deducting the underwriting discount and other debt issuance costs. The proceeds and cash on hand were used to purchase and retire a portion of the following notes in connection with cash tender offers that we publicly announced and completed in February 2022 (in millions):

Debt Purchased and Retired	Principal Amount
3.65% Senior Notes due 2025	$	72
2.850% Senior Notes due 2025	507
4.375% VLP Senior Notes due 2026	168
3.400% Senior Notes due 2026	653
Total	$	1,400

10

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 (amounts in millions and currency in U.S. dollars, except as noted):

				September 30, 2023
	Facility Amount		Maturity Date	Outstanding Borrowings		Letters of Credit Issued (a)		Availability
Committed facilities:
Valero Revolver	$	4,000	November 2027	$	—	$	4	$	3,996
Canadian Revolver (b)	C$	150	November 2023	C$	—	C$	5	C$	145
Accounts receivable sales facility	$	1,300	July 2024	$	—	n/a		$	1,300
Committed facilities of VIEs (c):
DGD Revolver (d)	$	400	June 2026	$	200	$	106	$	94
DGD Loan Agreement (e)	$	100	June 2026	$	—	n/a		$	100
IEnova Revolver (f)	$	830	February 2028	$	748	n/a		$	82
Uncommitted facilities:
Letter of credit facilities	n/a		n/a	n/a		$	177	n/a

________________________

(a)Letters of credit issued as of September 30, 2023 expire at various times in 2023 through 2026.

(b)On October 24, 2023, we amended this facility to (i) extend the maturity date to February 2024 and (ii) reduce the facility amount so that, effective October 31, 2023, the facility amount will equal the amount of the outstanding letters of credit thereunder, and will not permit further borrowings other than certain deemed borrowings to satisfy the reimbursement obligations under such letters of credit.

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

(d)In June 2023, DGD amended this facility to (i) extend the maturity date to June 2026 and (ii) transition the benchmark reference interest rate previously based on the London Interbank Offered Rate (LIBOR) to a secured overnight financing rate (SOFR). The variable interest rate on the DGD Revolver was 7.173 percent and 5.880 percent as of September 30, 2023 and December 31, 2022, respectively.

(e)The amounts shown for this facility 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. In April 2023, DGD extended the maturity date of this agreement to June 2023. In June 2023, DGD entered into a new unsecured revolving loan agreement that replaced and superseded the previous agreement. The new agreement includes the following modifications from the previous agreement: (i) extends the maturity date to June 2026, (ii) increases each member’s commitment from $25 million to $100 million, resulting in an increase in aggregate commitments from $50 million to $200 million, and (iii) transitions the benchmark reference interest rate previously based on the LIBOR to Term SOFR. The variable interest rate on the DGD Loan Agreement was 6.672 percent as of December 31, 2022.

(f)Both parties to this facility have agreed to use a SOFR as the interest rate applied to outstanding borrowings. The variable interest rate on the IEnova Revolver was 9.097 percent and 7.393 percent as of September 30, 2023 and December 31, 2022, respectively.

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CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Activity under our credit facilities was as follows (in millions):

	Nine Months Ended September 30,
	2023		2022
Borrowings:
Accounts receivable sales facility	$	1,750	$	1,200
DGD Revolver	500		659
DGD Loan Agreement	—		25
IEnova Revolver	86		73
Repayments:
Accounts receivable sales facility	(1,750)		(1,200)
DGD Revolver	(400)		(659)
DGD Loan Agreement	(25)		(50)
IEnova Revolver	(55)		(47)

Other Disclosures

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

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Interest and debt expense	$	153	$	154	$	456	$	467
Less: Capitalized interest	4		16		13		42
Interest and debt expense, net of capitalized interest	$	149	$	138	$	443	$	425

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 below) and with respect to our employee stock-based compensation plans.

During the three and nine months ended September 30, 2023, we purchased for treasury 12,805,162 shares and 32,219,955 shares, respectively. During the three and nine months ended September 30, 2022, we purchased for treasury 8,444,754 shares and 24,202,035 shares, respectively. On October 26, 2022, 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, and we completed all authorized share purchases under that program during the second quarter of 2023. On February 23, 2023, 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 (the February 2023 Program). As of September 30, 2023, we had $649 million remaining available for purchase under the February 2023 Program. On September 15, 2023, we announced that our Board authorized us to purchase shares of our outstanding

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CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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 2023 Program.

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,
	2023								2022
	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	$	(774)	$	(193)	$	(4)	$	(971)	$	(991)	$	(430)	$	(4)	$	(1,425)
Other comprehensive income (loss) before reclassifications	(315)		—		(77)		(392)		(606)		—		30		(576)
Amounts reclassified from accumulated other comprehensive loss	—		(7)		47		40		—		7		(3)		4
Effect of exchange rates	—		(2)		—		(2)		—		—		—		—
Other comprehensive income (loss)	(315)		(9)		(30)		(354)		(606)		7		27		(572)
Balance as of end of period	$	(1,089)	$	(202)	$	(34)	$	(1,325)	$	(1,597)	$	(423)	$	23	$	(1,997)

	Nine Months Ended September 30,
	2023								2022
	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	$	(1,168)	$	(183)	$	(8)	$	(1,359)	$	(562)	$	(441)	$	(5)	$	(1,008)
Other comprehensive income (loss) before reclassifications	79		—		(28)		51		(1,035)		(2)		(84)		(1,121)
Amounts reclassified from accumulated other comprehensive loss	—		(20)		2		(18)		—		18		112		130
Effect of exchange rates	—		1		—		1		—		2		—		2
Other comprehensive income (loss)	79		(19)		(26)		34		(1,035)		18		28		(989)
Balance as of end of period	$	(1,089)	$	(202)	$	(34)	$	(1,325)	$	(1,597)	$	(423)	$	23	$	(1,997)

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VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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, 2023, 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 (predominately animal fats, used cooking oils, and inedible distillers corn oils) into renewable diesel and renewable naphtha; 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, these transactions are eliminated in consolidation. Our financial position, results of operations, and cash flows are impacted by the performance of the consolidated VIEs, net of intercompany eliminations, to the extent of our ownership interest in each VIE.

The following tables present 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, 2023
Assets
Cash and cash equivalents	$	198	$	—	$	25	$	223
Other current assets	1,387		8		30		1,425
Property, plant, and equipment, net	3,764		668		71		4,503
Liabilities
Current liabilities, including current portion of debt and finance lease obligations	$	549	$	799	$	18	$	1,366
Debt and finance lease obligations, less current portion	676		—		—		676

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CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

	DGD		Central Mexico Terminals		Other		Total
December 31, 2022
Assets
Cash and cash equivalents	$	133	$	—	$	16	$	149
Other current assets	1,106		7		32		1,145
Property, plant, and equipment, net	3,785		681		79		4,545
Liabilities
Current liabilities, including current portion of debt and finance lease obligations	$	626	$	737	$	21	$	1,384
Debt and finance lease obligations, less current portion	693		—		—		693

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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CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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
	2023		2022		2023		2022
Three months ended September 30
Service cost	$	28	$	37	$	1	$	1
Interest cost	30		22		3		2
Expected return on plan assets	(50)		(48)		—		—
Amortization of:
Net actuarial (gain) loss	(2)		14		(1)		—
Prior service credit	(5)		(5)		(1)		(1)
Settlement loss	—		12		—		—
Net periodic benefit cost	$	1	$	32	$	2	$	2
Nine months ended September 30
Service cost	$	84	$	114	$	3	$	4
Interest cost	90		64		9		6
Expected return on plan assets	(151)		(144)		—		—
Amortization of:
Net actuarial (gain) loss	(5)		40		(4)		—
Prior service credit	(14)		(14)		(3)		(3)
Settlement loss	—		12		—		—
Net periodic benefit cost	$	4	$	72	$	5	$	7

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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VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

8.    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,
	2023		2022		2023		2022
Earnings per common share:
Net income attributable to Valero stockholders	$	2,622	$	2,817	$	7,633	$	8,415
Less: Income allocated to participating securities	8		11		24		31
Net income available to common stockholders	$	2,614	$	2,806	$	7,609	$	8,384
Weighted-average common shares outstanding	349		390		359		400
Earnings per common share	$	7.49	$	7.20	$	21.22	$	20.94
Earnings per common share – assuming dilution:
Net income attributable to Valero stockholders	$	2,622	$	2,817	$	7,633	$	8,415
Less: Income allocated to participating securities	8		11		24		31
Net income available to common stockholders	$	2,614	$	2,806	$	7,609	$	8,384
Weighted-average common shares outstanding	349		390		359		400
Effect of dilutive securities	—		—		—		1
Weighted-average common shares outstanding – assuming dilution	349		390		359		401
Earnings per common share – assuming dilution	$	7.49	$	7.19	$	21.21	$	20.93

Participating securities include restricted stock and performance awards granted under our 2020 Omnibus Stock Incentive Plan (OSIP) or our 2011 OSIP. Dilutive securities include participating securities as well as outstanding stock options.

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CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

9.    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, 2023		December 31, 2022
Receivables from contracts with customers, included in receivables, net	$	7,451	$	7,189
Contract liabilities, included in accrued expenses	38		129

During the nine months ended September 30, 2023 and 2022, we recognized as revenue $125 million and $74 million that was included in contract liabilities as of December 31, 2022 and 2021, respectively. Revenue recognized related to contract liabilities during the three months ended September 30, 2023 and 2022 was not material.

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, 2023, 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.

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CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

•The Renewable Diesel segment represents the operations of DGD, a consolidated joint venture as discussed in Note 6, and the associated activities to market renewable diesel and renewable naphtha. The principal products manufactured by DGD and sold by this segment are renewable diesel and renewable naphtha. This segment sells some renewable diesel to the Refining segment, which is then sold to that segment’s customers.

•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.

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CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

The following tables reflect information about our operating income by reportable segment (in millions):

	Refining		Renewable Diesel		Ethanol		Corporate and Eliminations		Total
Three months ended September 30, 2023
Revenues:
Revenues from external customers	$	36,521	$	759	$	1,124	$	—	$	38,404
Intersegment revenues	8		672		310		(990)		—
Total revenues	36,529		1,431		1,434		(990)		38,404
Cost of sales:
Cost of materials and other (a)	31,115		1,169		1,092		(991)		32,385
Operating expenses (excluding depreciation and amortization expense reflected below)	1,366		84		125		3		1,578
Depreciation and amortization expense	597		55		20		(1)		671
Total cost of sales	33,078		1,308		1,237		(989)		34,634
Other operating expenses	6		—		—		—		6
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		250		250
Depreciation and amortization expense	—		—		—		11		11
Operating income by segment	$	3,445	$	123	$	197	$	(262)	$	3,503
Three months ended September 30, 2022
Revenues:
Revenues from external customers	$	42,280	$	967	$	1,207	$	—	$	44,454
Intersegment revenues	9		508		179		(696)		—
Total revenues	42,289		1,475		1,386		(696)		44,454
Cost of sales:
Cost of materials and other (a)	36,389		1,161		1,203		(689)		38,064
Operating expenses (excluding depreciation and amortization expense reflected below)	1,516		69		162		(1)		1,746
Depreciation and amortization expense	568		33		20		—		621
Total cost of sales	38,473		1,263		1,385		(690)		40,431
Other operating expenses	6		—		—		—		6
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		214		214
Depreciation and amortization expense	—		—		—		11		11
Operating income by segment	$	3,810	$	212	$	1	$	(231)	$	3,792

________________________

See note (a) on page 21.

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CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

	Refining		Renewable Diesel		Ethanol		Corporate and Eliminations		Total
Nine months ended September 30, 2023
Revenues:
Revenues from external customers	$	102,924	$	2,990	$	3,438	$	—	$	109,352
Intersegment revenues	8		2,367		790		(3,165)		—
Total revenues	102,932		5,357		4,228		(3,165)		109,352
Cost of sales:
Cost of materials and other (a)	87,398		4,143		3,422		(3,143)		91,820
Operating expenses (excluding depreciation and amortization expense reflected below)	3,832		274		383		6		4,495
Depreciation and amortization expense	1,751		172		59		(3)		1,979
Total cost of sales	92,981		4,589		3,864		(3,140)		98,294
Other operating expenses	17		—		1		—		18
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		703		703
Depreciation and amortization expense	—		—		—		32		32
Operating income by segment	$	9,934	$	768	$	363	$	(760)	$	10,305
Nine months ended September 30, 2022
Revenues:
Revenues from external customers	$	128,588	$	2,417	$	3,632	$	—	$	134,637
Intersegment revenues	24		1,490		507		(2,021)		—
Total revenues	128,612		3,907		4,139		(2,021)		134,637
Cost of sales:
Cost of materials and other (a)	111,308		3,129		3,533		(2,011)		115,959
Operating expenses (excluding depreciation and amortization expense reflected below)	4,111		178		464		(2)		4,751
Depreciation and amortization expense	1,682		87		37		—		1,806
Total cost of sales	117,101		3,394		4,034		(2,013)		122,516
Other operating expenses	38		—		2		—		40
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		652		652
Depreciation and amortization expense	—		—		—		34		34
Operating income by segment	$	11,473	$	513	$	103	$	(694)	$	11,395

________________________

(a)Cost of materials and other for our Renewable Diesel segment is net of the blender’s tax credit on qualified fuel mixtures of $266 million and $191 million for the three months ended September 30, 2023 and 2022, respectively, and $900 million and $545 million for the nine months ended September 30, 2023 and 2022, respectively.

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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,
	2023		2022		2023		2022
Refining:
Gasolines and blendstocks	$	17,025	$	17,862	$	47,302	$	54,026
Distillates	16,392		20,481		47,222		62,352
Other product revenues	3,104		3,937		8,400		12,210
Total Refining revenues	36,521		42,280		102,924		128,588
Renewable Diesel:
Renewable diesel	739		899		2,864		2,311
Renewable naphtha	20		68		126		106
Total Renewable Diesel revenues	759		967		2,990		2,417
Ethanol:
Ethanol	861		966		2,522		2,820
Distillers grains	263		241		916		812
Total Ethanol revenues	1,124		1,207		3,438		3,632
Revenues	$	38,404	$	44,454	$	109,352	$	134,637

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

	September 30, 2023		December 31, 2022
Refining	$	49,171	$	48,484
Renewable Diesel	5,552		5,217
Ethanol	1,501		1,551
Corporate and eliminations	6,951		5,730
Total assets	$	63,175	$	60,982

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CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

10.    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,
	2023		2022
Increase in current assets:
Receivables, net	$	(709)	$	(1,435)
Inventories	(720)		(703)
Prepaid expenses and other	(40)		(201)
Increase (decrease) in current liabilities:
Accounts payable	656		746
Accrued expenses	(31)		38
Taxes other than income taxes payable	(222)		(103)
Income taxes payable	(629)		41
Changes in current assets and current liabilities	$	(1,695)	$	(1,617)

Changes in current assets and current liabilities for the nine months ended September 30, 2023 were primarily due to the following:

•The increase in receivables was due to an increase in refined petroleum product prices in September 2023 compared to December 2022;

•The increase in inventories was due to an increase in inventory volumes in September 2023 compared to December 2022;

•The increase in accounts payable was due to an increase in crude oil and other feedstock prices in September 2023 compared to December 2022; and

•The decrease in income taxes payable was primarily due to income tax payments made during the nine months ended September 30, 2023.

Changes in current assets and current liabilities for the nine months ended September 30, 2022 were primarily due to the following:

•The increase in receivables was due to an increase in refined petroleum product prices in September 2022 compared to December 2021;

•The increase in inventories was due to an increase in inventory volumes valued at higher unit prices in September 2022 compared to December 2021; and

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CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

•The increase in accounts payable was due to an increase in crude oil and other feedstock prices in September 2022 compared to December 2021, partially offset by a decrease in related volumes purchased.

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

	Nine Months Ended September 30,
	2023		2022
Interest paid in excess of amount capitalized, including interest on finance leases	$	372	$	383
Income taxes paid, net	3,098		2,630

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

	Nine Months Ended September 30,
	2023				2022
	Operating Leases		Finance Leases		Operating Leases		Finance Leases
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows	$	316	$	81	$	296	$	59
Financing cash flows	—		190		—		129
Changes in lease balances resulting from new and modified leases	343		84		132		156

There were no significant noncash investing and financing activities during the nine months ended September 30, 2023 or 2022, except as noted in the table above.

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CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

11.    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, 2023 and December 31, 2022.

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 on the balance sheet.

	September 30, 2023
							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	$	909	$	—	$	—	$	909	$	(907)	$	—	$	2	$	—
Foreign currency contracts	4		—		—		4		n/a		n/a		4		n/a
Investments of certain benefit plans	77		—		4		81		n/a		n/a		81		n/a
Investments in AFS debt securities	85		66		—		151		n/a		n/a		151		n/a
Total	$	1,075	$	66	$	4	$	1,145	$	(907)	$	—	$	238
Liabilities
Commodity derivative contracts	$	1,148	$	—	$	—	$	1,148	$	(907)	$	(241)	$	—	$	(141)
Blending program obligations	—		129		—		129		n/a		n/a		129		n/a
Physical purchase contracts	—		14		—		14		n/a		n/a		14		n/a
Total	$	1,148	$	143	$	—	$	1,291	$	(907)	$	(241)	$	143

25

VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

	December 31, 2022
							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	$	830	$	—	$	—	$	830	$	(705)	$	(8)	$	117	$	—
Physical purchase contracts	—		4		—		4		n/a		n/a		4		n/a
Investments of certain benefit plans	72		—		6		78		n/a		n/a		78		n/a
Investments in AFS debt securities	56		165		—		221		n/a		n/a		221		n/a
Total	$	958	$	169	$	6	$	1,133	$	(705)	$	(8)	$	420
Liabilities
Commodity derivative contracts	$	705	$	—	$	—	$	705	$	(705)	$	—	$	—	$	(149)
Blending program obligations	—		55		—		55		n/a		n/a		55		n/a
Physical purchase contracts	—		4		—		4		n/a		n/a		4		n/a
Foreign currency contracts	2		—		—		2		n/a		n/a		2		n/a
Total	$	707	$	59	$	—	$	766	$	(705)	$	—	$	61

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 12. 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.

•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.

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VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

•Investments in AFS debt securities consist primarily of commercial paper and U.S. government treasury bills and have maturities within one year. The securities were reflected in the following balance sheet line items, depending on their original maturities when acquired (in millions):

	September 30, 2023						December 31, 2022
	Level 1		Level 2		Total		Level 1		Level 2		Total
Cash and cash equivalents	$	—	$	33	$	33	$	—	$	125	$	125
Prepaid expenses and other	85		33		118		56		40		96
Investments in AFS debt securities	$	85	$	66	$	151	$	56	$	165	$	221

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, 2023. There were no AFS debt securities held as of and for the nine months ended September 30, 2022.

•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), the California Low Carbon Fuel Standard (LCFS), the Canada Clean Fuel Regulations, and similar programs in other jurisdictions in which we operate (collectively, the Renewable and Low-Carbon Fuel Programs). The blending program 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.

•Foreign currency contracts consist of foreign currency exchange and purchase contracts and foreign currency swap agreements 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

As previously disclosed in our annual report on Form 10-K for the year ended December 31, 2022, we concluded that our ethanol plant located in Lakota, Iowa (Lakota ethanol plant) was impaired as of December 31, 2022, which resulted in an asset impairment loss of $61 million. The fair value of the Lakota ethanol plant was determined using a combination of the income and market approaches and was classified in Level 3. We employed a probability-weighted approach to possible future cash flow scenarios, including the use of peer company metrics and comparison to a recent sales transaction.

There were no assets or liabilities that were measured at fair value on a nonrecurring basis as of September 30, 2023 and December 31, 2022, except as noted above.

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VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Financial Instruments

Our financial instruments include cash and cash equivalents, 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, 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, 2023				December 31, 2022
	Fair Value Hierarchy	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Financial liabilities:
Debt (excluding finance lease obligations)	Level 2	$	9,150	$	8,549	$	9,241	$	8,902

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.

12.    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 11), as summarized below under “Fair Values of Derivative Instruments.” The effect of these derivative instruments on our income and other comprehensive loss is summarized below under “Effect of Derivative Instruments on Income and Other Comprehensive 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 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 has been approved by our Board.

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.

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VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

•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.

As of September 30, 2023, 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
	2023	2024
Derivatives designated as cash flow hedges:
Refined petroleum products:
Futures – long	915	200
Futures – short	6,765	2,362
Derivatives designated as economic hedges:
Crude oil and refined petroleum products:
Futures – long	81,133	4,214
Futures – short	87,324	5,260
Corn:
Futures – long	66,695	90
Futures – short	82,415	3,290
Physical contracts – long	14,533	3,193

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, 2023, we had foreign currency contracts to purchase $630 million of U.S. dollars. All of these commitments matured on or before October 25, 2023.

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

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VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

our credit obligations under the Renewable and Low-Carbon Fuel Programs was $438 million and $461 million for the three months ended September 30, 2023 and 2022, respectively, and $1.2 billion and $984 million for the nine months ended September 30, 2023 and 2022, respectively. These amounts are reflected in cost of materials and other.

Fair Values of Derivative Instruments

The following table provides information about the fair values of our derivative instruments as of September 30, 2023 and December 31, 2022 (in millions) and the line items in the balance sheets in which the fair values are reflected. See Note 11 for additional information related to the fair values of our derivative instruments.

As indicated in Note 11, 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, 2023				December 31, 2022
		Asset Derivatives		Liability Derivatives		Asset Derivatives		Liability Derivatives
Derivatives designated as hedging instruments:
Commodity contracts	Receivables, net	$	10	$	19	$	61	$	44
Derivatives not designated as hedging instruments:
Commodity contracts	Receivables, net	$	899	$	1,129	$	769	$	661
Physical purchase contracts	Inventories	—		14		4		4
Foreign currency contracts	Receivables, net	4		—		—		—
Foreign currency contracts	Accrued expenses	—		—		—		2
Total		$	903	$	1,143	$	773	$	667

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 approved by our Board. 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 Loss

The following table provides information about the gain (loss) recognized in income and other comprehensive 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,
		2023		2022		2023		2022
Commodity contracts:
Gain (loss) recognized in other comprehensive loss	n/a	$	(197)	$	79	$	(71)	$	(215)
Gain (loss) reclassified from accumulated other comprehensive loss into income	Revenues	(119)		10		(3)		(289)

For cash flow hedges, no component of any derivative instrument’s gains or losses was excluded from the assessment of hedge effectiveness for the three and nine months ended September 30, 2023 and 2022. For the three and nine months ended September 30, 2023 and 2022, cash flow hedges primarily related to forecasted sales of renewable diesel. As of September 30, 2023, the estimated deferred after-tax loss 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, 2023 and 2022 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 the 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,
		2023		2022		2023		2022
Commodity contracts	Revenues	$	(2)	$	(6)	$	(19)	$	(12)
Commodity contracts	Cost of materials and other	(48)		(109)		126		(976)
Commodity contracts	Operating expenses (excluding depreciation and amortization expense)	—		(18)		1		(9)
Foreign currency contracts	Cost of materials and other	19		57		(1)		104
Foreign currency contracts	Other income, net	—		(38)		—		(119)

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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 Form 10-Q, 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,” “could,” “would,” “should,” “may,” “strive,” “seek,” “potential,” “opportunity,” “aimed,” “considering,” “continue,” 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;

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

•future Renewable Diesel segment margins;

•future Ethanol segment margins;

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

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

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

•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 qualified pension plans and other postretirement benefit plans;

•our ability to meet future cash 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 and refined petroleum products, renewable diesel, and ethanol and corn related co-products in the regions where we operate, as well as globally;

•expectations regarding environmental, tax, and other regulatory matters, including SBx 1-2 and the matters discussed under “PART II, ITEM 1. LEGAL PROCEEDINGS” below, the anticipated amounts and timing of payment with respect to our deferred tax liabilities, matters impacting our ability to repatriate cash held by our foreign subsidiaries, and the anticipated effect 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, and ethanol industry fundamentals;

32

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

•expectations regarding our counterparties, 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 standards or policies, blending and tax credits, or efficiency standards that impact demand for renewable fuels; and

•expectations regarding our low-carbon fuels strategy, publicly announced greenhouse gas (GHG) emissions reduction/displacement targets, 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, 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, and ethanol and corn related co-products;

•demand for, and supplies of, crude oil and other feedstocks;

•the effects of public health threats, pandemics, and epidemics, such as the COVID-19 pandemic and variants of the virus, 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 aimed at either our refineries and plants or third-party facilities that could impair our ability to produce or transport refined petroleum products, renewable diesel, ethanol, or corn related co-products, to receive feedstocks, or otherwise operate efficiently;

•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, 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 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 renewable fuels production in response to market conditions;

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

33

•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;

•political 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, 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 and emission credits needed under other environmental emissions programs;

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

•earthquakes, hurricanes, tornadoes, winter storms, 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, and ethanol;

•rulings, judgments, or settlements in litigation or other legal or regulatory matters, including unexpected environmental remediation or enforcement costs, 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, introduction of a global minimum tax, windfall taxes or penalties, tax changes or restrictions impacting the foreign repatriation of cash, actions implemented under SBx 1-2, actions implemented under the Renewable and Low-Carbon Fuel Programs and other environmental emissions 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 or operations;

•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, 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, and other actions, policies, and initiatives by the states, counties, cities, and other jurisdictions in the countries in which we operate or otherwise do business;

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

34

•the operating, financing, and distribution decisions of our joint ventures or other joint venture members 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, 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, 2022.

Any one of these factors, or a combination of these factors, could materially affect our future results of operations 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.

NON-GAAP FINANCIAL MEASURES

The discussions in “OVERVIEW AND OUTLOOK,” “RESULTS OF OPERATIONS,” and “LIQUIDITY AND CAPITAL RESOURCES” below include references to financial measures that are not defined under GAAP. These non-GAAP financial measures include adjusted operating income (including adjusted operating income for each of our reportable segments, as applicable); Refining, Renewable Diesel, and Ethanol segment margin; 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 (f) beginning on page 54 for reconciliations of adjusted operating income (including adjusted operating income for each of our reportable segments, as applicable) and Refining, Renewable Diesel, and Ethanol segment margin to their most directly comparable GAAP financial measures. Also in note (f), we disclose the reasons why we believe our use of such non-GAAP financial measures provides useful information. See the table on page 60 for a reconciliation of capital investments attributable to Valero to its most directly comparable GAAP financial measure. Beginning on page 59, we disclose the reasons why we believe our use of this non-GAAP financial measure provides useful information.

35

OVERVIEW AND OUTLOOK

Overview

Business Operations Update

Our results for the third quarter and first nine months of 2023 were favorably impacted by the continued strong worldwide demand for petroleum-based transportation fuels, while the worldwide supply of those products remained constrained. This global supply and demand imbalance has continued to contribute to strong refining margins for 2023.

The strong demand for our products and continued strength in refining margins were the primary contributors to us reporting $2.6 billion and $7.6 billion of net income attributable to Valero stockholders for the third quarter of 2023 and the first nine months of 2023, respectively. Our operating results, including operating results by segment, are described in the following summary under “Third Quarter Results” and “First Nine Months Results,” with more detailed descriptions found under “RESULTS OF OPERATIONS” beginning on page 39.

Our operations generated $8.0 billion of cash during the first nine months of 2023. This cash was used to make $1.4 billion of capital investments in our business and return $5.3 billion to our stockholders through purchases of common stock for treasury and dividend payments. In addition, we reduced our outstanding debt through the purchase of $199 million of our public debt during the first nine months of 2023. As a result of this and other activity, our cash and cash equivalents increased by $969 million, from $4.9 billion as of December 31, 2022 to $5.8 billion as of September 30, 2023. We had $11.0 billion in liquidity as of September 30, 2023. 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 57.

Third Quarter Results

For the third quarter of 2023, we reported net income attributable to Valero stockholders of $2.6 billion compared to $2.8 billion for the third quarter of 2022. The decrease of $195 million was primarily due to a decrease in operating income of $289 million, partially offset by an increase in “other income, net” of $48 million and a decrease in income attributable to noncontrolling interests of $54 million. The details of our operating income and adjusted operating income by segment and in total are reflected below (in millions). Adjusted operating income excludes the adjustment reflected in the table in note (f) beginning on page 54.

	Three Months Ended September 30,
	2023		2022		Change
Refining segment:
Operating income	$	3,445	$	3,810	$	(365)
Adjusted operating income	3,451		3,816		(365)
Renewable Diesel segment:
Operating income	123		212		(89)
Ethanol segment:
Operating income	197		1		196
Total company:
Operating income	3,503		3,792		(289)
Adjusted operating income	3,509		3,798		(289)

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While our operating income decreased by $289 million in the third quarter of 2023 compared to the third quarter of 2022, adjusted operating income also decreased by $289 million primarily due to the following:

•Refining segment. Refining segment adjusted operating income decreased by $365 million primarily due to lower distillate (primarily diesel) margins, partially offset by higher gasoline margins, higher discounts on crude oils and other feedstocks, and lower operating expenses (excluding depreciation and amortization expense).

•Renewable Diesel segment. Renewable Diesel segment operating income decreased by $89 million primarily due to lower product prices (primarily renewable diesel), higher operating expenses (excluding depreciation and amortization expense), and higher depreciation and amortization expense, partially offset by lower feedstock costs and higher sales volumes.

•Ethanol segment. Ethanol segment operating income increased by $196 million primarily due to lower corn prices, higher production volumes, and lower operating expenses (excluding depreciation and amortization expense), partially offset by lower ethanol and corn related co-product prices.

First Nine Months Results

For the first nine months of 2023, we reported net income attributable to Valero stockholders of $7.6 billion compared to $8.4 billion for the first nine months of 2022. The decrease of $782 million was primarily due to a decrease in operating income of $1.1 billion, partially offset by an increase in “other income, net” of $270 million and a decrease in income tax expense of $122 million. The details of our operating income and adjusted operating income by segment and in total are reflected below (in millions). Adjusted operating income excludes the adjustments reflected in the table in note (f) beginning on page 54.

	Nine Months Ended September 30,
	2023		2022		Change
Refining segment:
Operating income	$	9,934	$	11,473	$	(1,539)
Adjusted operating income	9,951		11,407		(1,456)
Renewable Diesel segment:
Operating income	768		513		255
Ethanol segment:
Operating income	363		103		260
Adjusted operating income	364		82		282
Total company:
Operating income	10,305		11,395		(1,090)
Adjusted operating income	10,323		11,328		(1,005)

While our operating income decreased by $1.1 billion in the first nine months of 2023 compared to the first nine months of 2022, adjusted operating income decreased by $1.0 billion primarily due to the following:

•Refining segment. Refining segment adjusted operating income decreased by $1.5 billion primarily due to lower gasoline and distillate (primarily diesel) margins, partially offset by higher

37

discounts on crude oils and other feedstocks, an increase in throughput volumes, and lower operating expenses (excluding depreciation and amortization expense).

•Renewable Diesel segment. Renewable Diesel segment operating income increased by $255 million primarily due to lower feedstock costs and higher sales volumes, partially offset by lower product prices (primarily renewable diesel), higher operating expenses (excluding depreciation and amortization expense), and higher depreciation and amortization expense.

•Ethanol segment. Ethanol segment adjusted operating income increased by $282 million primarily due to lower corn prices, higher production volumes, and lower operating expenses (excluding depreciation and amortization expense), partially offset by lower ethanol and corn related co-product prices.

Outlook

Many uncertainties remain with respect to the supply and demand imbalance in the petroleum-based products market worldwide. While it is difficult to predict future worldwide economic activity and its impact on product supply and demand, as well as any effect that the uncertainty described in Note 2 of Condensed Notes to Consolidated Financial Statements or other political or regulatory developments may have on us, we have noted several factors below that have impacted or may impact our results of operations during the fourth quarter of 2023.

•Gasoline and diesel demand have returned to pre-pandemic levels and are expected to follow typical seasonal patterns. Jet fuel demand continues to improve and is approaching pre-pandemic levels in the U.S.

•Combined light product (primarily diesel) inventories in the U.S. and Europe are below historical levels reflecting tight global petroleum product balances, which should support continued high utilization of refining capacity.

•After narrowing early this year on reduced sour crude oil production from OPEC+ suppliers, crude oil discounts have recently begun to widen; however, the renewed conflict in the Middle East will likely cause increased volatility in the crude oil market and potentially impact crude oil discounts.

•Renewable diesel margins are expected to remain consistent with current levels.

•Ethanol demand is expected to follow typical seasonal patterns.

38

RESULTS OF OPERATIONS

The following tables, including the reconciliations of non-GAAP financial measures to their most directly comparable GAAP financial measures in note (f) beginning on page 54, 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 53 through 56.

Third Quarter Results -

Financial Highlights By Segment and Total Company

(millions of dollars)

	Three Months Ended September 30, 2023
	Refining		Renewable Diesel		Ethanol		Corporate and Eliminations		Total
Revenues:
Revenues from external customers	$	36,521	$	759	$	1,124	$	—	$	38,404
Intersegment revenues	8		672		310		(990)		—
Total revenues	36,529		1,431		1,434		(990)		38,404
Cost of sales:
Cost of materials and other	31,115		1,169		1,092		(991)		32,385
Operating expenses (excluding depreciation and amortization expense reflected below)	1,366		84		125		3		1,578
Depreciation and amortization expense	597		55		20		(1)		671
Total cost of sales	33,078		1,308		1,237		(989)		34,634
Other operating expenses	6		—		—		—		6
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		250		250
Depreciation and amortization expense	—		—		—		11		11
Operating income by segment	$	3,445	$	123	$	197	$	(262)	3,503
Other income, net									122
Interest and debt expense, net of capitalized interest									(149)
Income before income tax expense									3,476
Income tax expense									813
Net income									2,663
Less: Net income attributable to noncontrolling interests									41
Net income attributable to Valero Energy Corporation stockholders									$	2,622

39

Third Quarter Results -

Financial Highlights By Segment and Total Company (continued)

(millions of dollars)

	Three Months Ended September 30, 2022
	Refining		Renewable Diesel		Ethanol		Corporate and Eliminations		Total
Revenues:
Revenues from external customers	$	42,280	$	967	$	1,207	$	—	$	44,454
Intersegment revenues	9		508		179		(696)		—
Total revenues	42,289		1,475		1,386		(696)		44,454
Cost of sales:
Cost of materials and other	36,389		1,161		1,203		(689)		38,064
Operating expenses (excluding depreciation and amortization expense reflected below)	1,516		69		162		(1)		1,746
Depreciation and amortization expense	568		33		20		—		621
Total cost of sales	38,473		1,263		1,385		(690)		40,431
Other operating expenses	6		—		—		—		6
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		214		214
Depreciation and amortization expense	—		—		—		11		11
Operating income by segment	$	3,810	$	212	$	1	$	(231)	3,792
Other income, net (d)									74
Interest and debt expense, net of capitalized interest									(138)
Income before income tax expense									3,728
Income tax expense									816
Net income									2,912
Less: Net income attributable to noncontrolling interests									95
Net income attributable to Valero Energy Corporation stockholders									$	2,817

40

Third Quarter Results -

Average Market Reference Prices and Differentials

	Three Months Ended September 30,
	2023		2022
Refining
Feedstocks (dollars per barrel)
Brent crude oil	$	86.18	$	97.59
Brent less West Texas Intermediate (WTI) crude oil	3.72		5.83
Brent less WTI Houston crude oil	2.21		3.69
Brent less Dated Brent crude oil	(0.78)		(2.97)
Brent less Argus Sour Crude Index (ASCI) crude oil	3.43		8.23
Brent less Maya crude oil	8.77		13.11
Brent less Western Canadian Select (WCS) Houston crude oil	9.98		17.68
WTI crude oil	82.46		91.76
Natural gas (dollars per million British Thermal Units (MMBTu))	2.38		7.31
Renewable volume obligation (RVO) (dollars per barrel) (e)	7.42		8.11
Product margins (RVO adjusted unless otherwise noted) (dollars per barrel)
U.S. Gulf Coast:
Conventional Blendstock of Oxygenate Blending (CBOB) gasoline less Brent	14.70		5.70
Ultra-low-sulfur (ULS) diesel less Brent	30.87		41.01
Propylene less Brent (not RVO adjusted)	(57.98)		(46.73)
U.S. Mid-Continent:
CBOB gasoline less WTI	25.46		19.27
ULS diesel less WTI	37.10		52.25
North Atlantic:
CBOB gasoline less Brent	22.93		20.17
ULS diesel less Brent	33.91		44.19
U.S. West Coast:
California Reformulated Gasoline Blendstock of Oxygenate Blending (CARBOB) 87 gasoline less Brent	43.33		41.48
California Air Resources Board (CARB) diesel less Brent	47.66		43.68

41

Third Quarter Results -

Average Market Reference Prices and Differentials (continued)

	Three Months Ended September 30,
	2023		2022
Renewable Diesel
New York Mercantile Exchange ULS diesel (dollars per gallon)	$	3.03	$	3.55
Biodiesel RIN (dollars per RIN)	1.40		1.71
California LCFS carbon credit (dollars per metric ton)	74.46		86.21
U.S. Gulf Coast (USGC) used cooking oil (UCO) (dollars per pound)	0.64		0.73
USGC distillers corn oil (DCO) (dollars per pound)	0.72		0.73
USGC fancy bleachable tallow (Tallow) (dollars per pound)	0.68		0.78
Ethanol
Chicago Board of Trade corn (dollars per bushel)	4.99		6.60
New York Harbor ethanol (dollars per gallon)	2.39		2.58

Total Company, Corporate, and Other

The following table includes selected financial data for the total company, corporate, and other for the third quarter of 2023 and 2022. The selected financial data is derived from the Financial Highlights by Segment and Total Company tables, unless otherwise noted.

	Three Months Ended September 30,
	2023		2022		Change
Revenues	$	38,404	$	44,454	$	(6,050)
Cost of sales	34,634		40,431		(5,797)
Operating income	3,503		3,792		(289)
Adjusted operating income (see note (f))	3,509		3,798		(289)
Other income, net (see note (d))	122		74		48
Net income attributable to noncontrolling interests	41		95		(54)

Revenues decreased by $6.1 billion in the third quarter of 2023 compared to the third quarter of 2022 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 partially offset by a decrease in cost of sales of $5.8 billion primarily due to decreases in crude oil and other feedstock costs. These changes resulted in a $289 million decrease in operating income, from $3.8 billion in the third quarter of 2022 to $3.5 billion in the third quarter of 2023.

Adjusted operating income also decreased by $289 million, from $3.8 billion in the third quarter of 2022 to $3.5 billion in the third quarter of 2023. The components of this $289 million decrease in adjusted operating income are discussed by segment in the segment analyses that follow.

42

“Other income, net” increased by $48 million in the third quarter of 2023 compared to the third quarter of 2022 due to the items noted in the following table (in millions):

	Three Months Ended September 30,
	2023		2022		Change
Interest income on cash	$	74	$	36	$	38
Gain from early retirement of debt (see note (d))	—		26		(26)
Equity income on joint ventures and other	48		12		36
Other income, net	$	122	$	74	$	48

Net income attributable to noncontrolling interests decreased by $54 million in the third quarter of 2023 compared to the third quarter of 2022 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 beginning on page 44.

Refining Segment Results

The following table includes selected financial and operating data of our Refining segment for the third quarter of 2023 and 2022. The selected financial data is derived from the Financial Highlights by Segment and Total Company tables, unless otherwise noted.

	Three Months Ended September 30,
	2023		2022		Change
Operating income	$	3,445	$	3,810	$	(365)
Adjusted operating income (see note (f))	3,451		3,816		(365)
Refining margin (see note (f))	5,414		5,900		(486)
Operating expenses (excluding depreciation and amortization expense reflected below)	1,366		1,516		(150)
Depreciation and amortization expense	597		568		29
Throughput volumes (thousand barrels per day) (see note (g))	3,022		3,005		17

Refining segment operating income decreased by $365 million in the third quarter of 2023 compared to the third quarter of 2022. Refining segment adjusted operating income, which excludes the adjustment in the table in note (f), also decreased by $365 million in the third quarter of 2023 compared to the third quarter of 2022. 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 decreased by $486 million in the third quarter of 2023 compared to the third quarter of 2022.

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 41 reflects market reference prices and differentials that we believe impacted our Refining segment margin in the third quarter of 2023 compared to the third quarter of 2022.

43

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

◦A decrease in distillate (primarily diesel) margins had an unfavorable impact of approximately $1.3 billion.

◦An increase in gasoline margins had a favorable impact of approximately $534 million.

◦Higher discounts on crude oils had a favorable impact of approximately $180 million.

◦Higher discounts on other feedstocks had a favorable impact of approximately $150 million.

•Refining segment operating expenses (excluding depreciation and amortization expense) decreased by $150 million primarily due to a decrease in energy costs (primarily natural gas) of $208 million, partially offset by increases in certain employee compensation expenses of $15 million and chemicals and catalyst costs of $14 million.

Renewable Diesel Segment Results

The following table includes selected financial and operating data of our Renewable Diesel segment for the third quarter of 2023 and 2022. The selected financial data is derived from the Financial Highlights by Segment and Total Company tables, unless otherwise noted.

	Three Months Ended September 30,
	2023		2022		Change
Operating income	$	123	$	212	$	(89)
Renewable Diesel margin (see note (f))	262		314		(52)
Operating expenses (excluding depreciation and amortization expense reflected below)	84		69		15
Depreciation and amortization expense	55		33		22
Sales volumes (thousand gallons per day) (see note (g))	2,992		2,231		761

Renewable Diesel segment operating income decreased by $89 million in the third quarter of 2023 compared to the third quarter of 2022. The components of this decrease, along with the reasons for the changes in those components, are outlined below.

•Renewable Diesel segment margin decreased by $52 million in the third quarter of 2023 compared to the third quarter of 2022.

Renewable Diesel segment margin is primarily affected by the price for the renewable diesel that we sell and the cost of the feedstocks that we process. The table on page 42 reflects market reference prices that we believe impacted our Renewable Diesel segment margin in the third quarter of 2023 compared to the third quarter of 2022.

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

◦A decrease in product prices, primarily renewable diesel, had an unfavorable impact of approximately $393 million.

44

◦A decrease in the cost of feedstocks we process had a favorable impact of approximately $234 million.

◦An increase in sales volumes of 761,000 gallons per day had a favorable impact of approximately $118 million. The increase in sales volumes was primarily due to the additional production resulting from the completion of the new DGD Port Arthur Plant that commenced operations in the fourth quarter of 2022, partially offset by the effect of unplanned downtime resulting from a fire at the DGD St. Charles Plant in the third quarter of 2023.

•Renewable Diesel segment operating expenses (excluding depreciation and amortization expense) increased by $15 million primarily due to increased costs resulting from the new DGD Port Arthur Plant that commenced operations in the fourth quarter of 2022.

•Renewable Diesel segment depreciation and amortization expense increased by $22 million primarily due to depreciation expense associated with the new DGD Port Arthur Plant that commenced operations in the fourth quarter of 2022.

Ethanol Segment Results

The following table includes selected financial and operating data of our Ethanol segment for the third quarter of 2023 and 2022. The selected financial data is derived from the Financial Highlights by Segment and Total Company tables, unless otherwise noted.

	Three Months Ended September 30,
	2023		2022		Change
Operating income	$	197	$	1	$	196
Ethanol margin (see note (f))	342		183		159
Operating expenses (excluding depreciation and amortization expense reflected below)	125		162		(37)
Depreciation and amortization expense	20		20		—
Production volumes (thousand gallons per day) (see note (g))	4,329		3,498		831

Ethanol segment operating income increased by $196 million in the third quarter of 2023 compared to the third quarter of 2022. The components of this increase, along with the reasons for the changes in those components, are outlined below.

•Ethanol segment margin increased by $159 million in the third quarter of 2023 compared to the third quarter of 2022. 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 42 reflects market reference prices that we believe impacted our Ethanol segment margin in the third quarter of 2023 compared to the third quarter of 2022.

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

◦Lower corn prices had a favorable impact of approximately $184 million.

45

◦An increase in production volumes of 831,000 gallons per day had a favorable impact of approximately $71 million.

◦Lower ethanol prices had an unfavorable impact of approximately $69 million.

◦Lower prices for the co-products that we produce, primarily dry distillers grains (DDGs), had an unfavorable impact of approximately $29 million.

•Ethanol segment operating expenses (excluding depreciation and amortization expense) decreased by $37 million primarily due to a decrease in energy costs (primarily natural gas).

First Nine Months Results -

Financial Highlights By Segment and Total Company

(millions of dollars)

	Nine Months Ended September 30, 2023
	Refining		Renewable Diesel		Ethanol		Corporate and Eliminations		Total
Revenues:
Revenues from external customers	$	102,924	$	2,990	$	3,438	$	—	$	109,352
Intersegment revenues	8		2,367		790		(3,165)		—
Total revenues	102,932		5,357		4,228		(3,165)		109,352
Cost of sales:
Cost of materials and other	87,398		4,143		3,422		(3,143)		91,820
Operating expenses (excluding depreciation and amortization expense reflected below)	3,832		274		383		6		4,495
Depreciation and amortization expense	1,751		172		59		(3)		1,979
Total cost of sales	92,981		4,589		3,864		(3,140)		98,294
Other operating expenses	17		—		1		—		18
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		703		703
Depreciation and amortization expense	—		—		—		32		32
Operating income by segment	$	9,934	$	768	$	363	$	(760)	10,305
Other income, net (d)									357
Interest and debt expense, net of capitalized interest									(443)
Income before income tax expense									10,219
Income tax expense									2,288
Net income									7,931
Less: Net income attributable to noncontrolling interests									298
Net income attributable to Valero Energy Corporation stockholders									$	7,633

46

First Nine Months Results -

Financial Highlights By Segment and Total Company (continued)

(millions of dollars)

	Nine Months Ended September 30, 2022
	Refining		Renewable Diesel		Ethanol		Corporate and Eliminations		Total
Revenues:
Revenues from external customers	$	128,588	$	2,417	$	3,632	$	—	$	134,637
Intersegment revenues	24		1,490		507		(2,021)		—
Total revenues	128,612		3,907		4,139		(2,021)		134,637
Cost of sales:
Cost of materials and other (a)	111,308		3,129		3,533		(2,011)		115,959
Operating expenses (excluding depreciation and amortization expense reflected below)	4,111		178		464		(2)		4,751
Depreciation and amortization expense (b)	1,682		87		37		—		1,806
Total cost of sales	117,101		3,394		4,034		(2,013)		122,516
Other operating expenses	38		—		2		—		40
General and administrative expenses (excluding depreciation and amortization expense reflected below) (c)	—		—		—		652		652
Depreciation and amortization expense	—		—		—		34		34
Operating income by segment	$	11,473	$	513	$	103	$	(694)	11,395
Other income, net (d)									87
Interest and debt expense, net of capitalized interest									(425)
Income before income tax expense									11,057
Income tax expense									2,410
Net income									8,647
Less: Net income attributable to noncontrolling interests									232
Net income attributable to Valero Energy Corporation stockholders									$	8,415

47

First Nine Months Results -

Average Market Reference Prices and Differentials

	Nine Months Ended September 30,
	2023		2022
Refining
Feedstocks (dollars per barrel)
Brent crude oil	$	82.12	$	102.21
Brent less WTI crude oil	4.68		3.91
Brent less WTI Houston crude oil	3.19		2.28
Brent less Dated Brent crude oil	(0.10)		(2.92)
Brent less ASCI crude oil	5.53		6.58
Brent less Maya crude oil	14.16		9.84
Brent less WCS Houston crude oil	12.19		13.22
WTI crude oil	77.44		98.29
Natural gas (dollars per MMBtu)	2.21		6.29
RVO (dollars per barrel) (e)	7.77		7.45
Product margins (RVO adjusted unless otherwise noted) (dollars per barrel)
U.S. Gulf Coast:
CBOB gasoline less Brent	12.57		12.82
ULS diesel less Brent	25.26		36.89
Propylene less Brent (not RVO adjusted)	(46.32)		(38.04)
U.S. Mid-Continent:
CBOB gasoline less WTI	22.25		19.04
ULS diesel less WTI	32.12		41.81
North Atlantic:
CBOB gasoline less Brent	18.96		21.73
ULS diesel less Brent	28.19		44.22
U.S. West Coast:
CARBOB 87 gasoline less Brent	32.89		36.59
CARB diesel less Brent	31.43		39.70

48

First Nine Months Results -

Average Market Reference Prices and Differentials (continued)

	Nine Months Ended September 30,
	2023		2022
Renewable Diesel
New York Mercantile Exchange ULS diesel (dollars per gallon)	$	2.80	$	3.54
Biodiesel RIN (dollars per RIN)	1.51		1.61
California LCFS carbon credit (dollars per metric ton)	73.65		109.71
USGC UCO (dollars per pound)	0.61		0.77
USGC DCO (dollars per pound)	0.65		0.77
USGC Tallow (dollars per pound)	0.62		0.76
Ethanol
CBOT corn (dollars per bushel)	5.95		7.02
New York Harbor ethanol (dollars per gallon)	2.42		2.60

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 2023 and 2022. The selected financial data is derived from the Financial Highlights by Segment and Total Company tables, unless otherwise noted.

	Nine Months Ended September 30,
	2023		2022		Change
Revenues	$	109,352	$	134,637	$	(25,285)
Cost of sales (see notes (a) and (b))	98,294		122,516		(24,222)
Operating income	10,305		11,395		(1,090)
Adjusted operating income (see note (f))	10,323		11,328		(1,005)
Other income, net (see note (d))	357		87		270
Income tax expense	2,288		2,410		(122)
Net income attributable to noncontrolling interests	298		232		66

Revenues decreased by $25.3 billion in the first nine months of 2023 compared to the first nine months of 2022 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 partially offset by a decrease in cost of sales of $24.2 billion primarily due to decreases in crude oil and other feedstock costs. These changes resulted in a $1.1 billion decrease in operating income, from $11.4 billion in the first nine months of 2022 to $10.3 billion in the first nine months of 2023.

Adjusted operating income decreased by $1.0 billion, from $11.3 billion in the first nine months of 2022 to $10.3 billion in the first nine months of 2023. The components of this $1.0 billion decrease in adjusted operating income are discussed by segment in the segment analyses that follow.

49

“Other income, net” increased by $270 million in the first nine months of 2023 compared to the first nine months of 2022 primarily due to the items noted in the following table (in millions):

	Nine Months Ended September 30,
	2023		2022		Change
Interest income on cash	$	197	$	49	$	148
Net gain (loss) from early retirement of debt (see note (d))	11		(24)		35
Equity income on joint ventures and other	149		62		87
Other income, net	$	357	$	87	$	270

Income tax expense decreased by $122 million in the first nine months of 2023 compared to the first nine months of 2022 primarily as a result of lower income before income tax expense.

Net income attributable to noncontrolling interests increased by $66 million in the first nine months of 2023 compared to the first nine months of 2022 primarily due to higher 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 beginning on page 51.

Refining Segment Results

The following table includes selected financial and operating data of our Refining segment for the first nine months of 2023 and 2022. The selected financial data is derived from the Financial Highlights by Segment and Total Company tables, unless otherwise noted.

	Nine Months Ended September 30,
	2023		2022		Change
Operating income	$	9,934	$	11,473	$	(1,539)
Adjusted operating income (see note (f))	9,951		11,407		(1,456)
Refining margin (see note (f))	15,534		17,200		(1,666)
Operating expenses (excluding depreciation and amortization expense reflected below)	3,832		4,111		(279)
Depreciation and amortization expense	1,751		1,682		69
Throughput volumes (thousand barrels per day) (see note (g))	2,974		2,923		51

Refining segment operating income decreased by $1.5 billion in the first nine months of 2023 compared to the first nine months of 2022. Refining segment adjusted operating income, which excludes the adjustments in the table in note (f), also decreased by $1.5 billion in the first nine months of 2023 compared to the first nine months of 2022. The components of this decrease, along with the reasons for the changes in those components, are outlined below.

•Refining segment margin decreased by $1.7 billion in the first nine months of 2023 compared to the first nine months of 2022.

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.

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The table on page 48 reflects market reference prices and differentials that we believe impacted our Refining segment margin in the first nine months of 2023 compared to the first nine months of 2022.

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

◦A decrease in distillate (primarily diesel) margins had an unfavorable impact of approximately $3.6 billion.

◦A decrease in gasoline margins had an unfavorable impact of approximately $237 million.

◦Higher discounts on crude oils had a favorable impact of approximately $1.6 billion.

◦An increase in throughput volumes of 51,000 barrels per day had a favorable impact of approximately $266 million.

◦Higher discounts on other feedstocks had a favorable impact of approximately $364 million.

•Refining segment operating expenses (excluding depreciation and amortization expense) decreased by $279 million primarily due to a decrease in energy costs of $473 million (primarily natural gas), partially offset by increases in chemicals and catalyst costs of $81 million, maintenance expense of $32 million, and certain employee compensation expenses of $22 million.

Renewable Diesel Segment Results

The following table includes selected financial and operating data of our Renewable Diesel segment for the first nine months of 2023 and 2022. The selected financial data is derived from the Financial Highlights by Segment and Total Company tables, unless otherwise noted.

	Nine Months Ended September 30,
	2023		2022		Change
Operating income	$	768	$	513	$	255
Renewable Diesel margin (see note (f))	1,214		778		436
Operating expenses (excluding depreciation and amortization expense reflected below)	274		178		96
Depreciation and amortization expense	172		87		85
Sales volumes (thousand gallons per day) (see note (g))	3,460		2,084		1,376

Renewable Diesel segment operating income increased by $255 million in the first nine months of 2023 compared to the first nine months of 2022. The components of this increase, along with the reasons for the changes in those components, are outlined below.

•Renewable Diesel segment margin increased by $436 million in the first nine months of 2023 compared to the first nine months of 2022.

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Renewable Diesel segment margin is primarily affected by the price for the renewable diesel that we sell and the cost of the feedstocks that we process. The table on page 49 reflects market reference prices that we believe impacted our Renewable Diesel segment margin in the first nine months of 2023 compared to the first nine months of 2022.

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

◦A decrease in the cost of the feedstocks that we process had a favorable impact of approximately $1.2 billion.

◦An increase in sales volumes of 1.4 million gallons per day had a favorable impact of approximately $515 million. The increase in sales volumes was primarily due to the additional production resulting from the completion of the new DGD Port Arthur Plant that commenced operations in the fourth quarter of 2022, partially offset by the effect of unplanned downtime resulting from a fire at the DGD St. Charles Plant in the third quarter of 2023.

◦A decrease in product prices, primarily renewable diesel, had an unfavorable impact of approximately $1.3 billion.

•Renewable Diesel segment operating expenses (excluding depreciation and amortization expense) increased by $96 million primarily due to increased costs resulting from the new DGD Port Arthur Plant that commenced operations in the fourth quarter of 2022.

•Renewable Diesel segment depreciation and amortization expense increased by $85 million primarily due to depreciation expense associated with the new DGD Port Arthur Plant that commenced operations in the fourth quarter of 2022.

Ethanol Segment Results

The following table includes selected financial and operating data of our Ethanol segment for the first nine months of 2023 and 2022. The selected financial data is derived from the Financial Highlights by Segment and Total Company tables, unless otherwise noted.

	Nine Months Ended September 30,
	2023		2022		Change
Operating income	$	363	$	103	$	260
Adjusted operating income (see note (f))	364		82		282
Ethanol margin (see note (f))	806		606		200
Operating expenses (excluding depreciation and amortization expense reflected below)	383		464		(81)
Depreciation and amortization expense (see note (b))	59		37		22
Production volumes (thousand gallons per day) (see note (g))	4,319		3,799		520

Ethanol segment operating income increased by $260 million in the first nine months of 2023 compared to the first nine months of 2022; however, Ethanol segment adjusted operating income, which excludes the adjustments in the table in note (f), increased by $282 million in the first nine months of 2023

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compared to the first nine months of 2022. The components of this increase in the adjusted results, along with the reasons for the changes in those components, are outlined below.

•Ethanol segment margin increased by $200 million in the first nine months of 2023 compared to the first nine months of 2022.

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 49 reflects market reference prices that we believe impacted our Ethanol segment margin in the first nine months of 2023 compared to the first nine months of 2022.

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

◦Lower corn prices had a favorable impact of approximately $326 million.

◦An increase in production volumes of 520,000 gallons per day had a favorable impact of approximately $117 million.

◦Lower ethanol prices had an unfavorable impact of approximately $182 million.

◦Lower prices for the co-products that we produce, primarily inedible DCO and DDGs, had an unfavorable impact of approximately $64 million.

•Ethanol segment operating expenses (excluding depreciation and amortization expense) decreased by $81 million primarily due to a decrease in energy costs (primarily natural gas) of $99 million, partially offset by increases in chemical and catalyst costs of $6 million and certain employee compensation expenses of $6 million.

________________________

The following notes relate to references on pages 39 through 52.

(a)Under the RFS program, the EPA is required to set annual quotas for the volume of renewable fuels that obligated parties, such as us, must blend into petroleum-based transportation fuels consumed in the U.S. The quotas are used to determine an obligated party’s RVO. The EPA released a final rule on June 3, 2022 that, among other things, modified the volume standards for 2020 and, for the first time, established volume standards for 2021 and 2022.

In 2020, we recognized the cost of the RVO using the 2020 quotas set by the EPA at that time, and in 2021 and the three months ended March 31, 2022, we recognized the cost of the RVO using our estimates of the quotas. As a result of the final rule released by the EPA as noted above, we recognized a benefit of $104 million in the nine months ended September 30, 2022 primarily related to the modification of the 2020 quotas.

(b)Depreciation and amortization expense for the nine months ended September 30, 2022 includes a gain of $23 million on the sale of our ethanol plant located in Jefferson, Wisconsin.

(c)General and administrative expenses (excluding depreciation and amortization expense) for the nine months ended September 30, 2022 includes a charge of $20 million for an environmental reserve adjustment associated with a non-operating site.

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(d)“Other income, net” includes the following:

◦a net gain of $11 million in the nine months ended September 30, 2023 related to the early retirement of $199 million aggregate principal amount of various series of our senior notes; and

◦a gain of $26 million in the three months ended September 30, 2022 and a net charge of $24 million in the nine months ended September 30, 2022 related to the early retirement of $1.25 billion and $2.65 billion, respectively, aggregate principal amount of various series of our senior notes.

(e)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.

(f)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.

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

◦Refining margin is defined as Refining segment operating income excluding the modification of RVO adjustment, 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,
	2023		2022		2023		2022
Reconciliation of Refining operating income to Refining margin
Refining operating income	$	3,445	$	3,810	$	9,934	$	11,473
Adjustments:
Modification of RVO (see note (a))	—		—		—		(104)
Operating expenses (excluding depreciation and amortization expense)	1,366		1,516		3,832		4,111
Depreciation and amortization expense	597		568		1,751		1,682
Other operating expenses	6		6		17		38
Refining margin	$	5,414	$	5,900	$	15,534	$	17,200

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◦Renewable Diesel margin is defined as Renewable Diesel segment operating income 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,
	2023		2022		2023		2022
Reconciliation of Renewable Diesel operating income to Renewable Diesel margin
Renewable Diesel operating income	$	123	$	212	$	768	$	513
Adjustments:
Operating expenses (excluding depreciation and amortization expense)	84		69		274		178
Depreciation and amortization expense	55		33		172		87
Renewable Diesel margin	$	262	$	314	$	1,214	$	778

◦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,
	2023		2022		2023		2022
Reconciliation of Ethanol operating income to Ethanol margin
Ethanol operating income	$	197	$	1	$	363	$	103
Adjustments:
Operating expenses (excluding depreciation and amortization expense)	125		162		383		464
Depreciation and amortization expense (see note (b))	20		20		59		37
Other operating expenses	—		—		1		2
Ethanol margin	$	342	$	183	$	806	$	606

◦Adjusted Refining operating income is defined as Refining segment operating income excluding the modification of RVO adjustment and other operating expenses, as reflected in the table below.

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Reconciliation of Refining operating income to adjusted Refining operating income
Refining operating income	$	3,445	$	3,810	$	9,934	$	11,473
Adjustments:
Modification of RVO (see note (a))	—		—		—		(104)
Other operating expenses	6		6		17		38
Adjusted Refining operating income	$	3,451	$	3,816	$	9,951	$	11,407

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◦Adjusted Ethanol operating income is defined as Ethanol segment operating income excluding the gain on sale of ethanol plant and other operating expenses, as reflected in the table below.

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Reconciliation of Ethanol operating income to adjusted Ethanol operating income
Ethanol operating income	$	197	$	1	$	363	$	103
Adjustments:
Gain on sale of ethanol plant (see note (b))	—		—		—		(23)
Other operating expenses	—		—		1		2
Adjusted Ethanol operating income	$	197	$	1	$	364	$	82

◦Adjusted operating income is defined as total company operating income excluding the modification of RVO adjustment, the gain on sale of ethanol plant, the environmental reserve adjustment, and other operating expenses, as reflected in the table below.

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Reconciliation of total company operating income to adjusted operating income
Total company operating income	$	3,503	$	3,792	$	10,305	$	11,395
Adjustments:
Modification of RVO (see note (a))	—		—		—		(104)
Gain on sale of ethanol plant (see note (b))	—		—		—		(23)
Environmental reserve adjustment (see note (c))	—		—		—		20
Other operating expenses	6		6		18		40
Adjusted operating income	$	3,509	$	3,798	$	10,323	$	11,328

(g)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, 2023 (in millions):

Available capacity from our committed facilities (a):
Valero Revolver	$	3,996
Canadian Revolver (b)	107
Accounts receivable sales facility	1,300
Total available capacity	5,403
Cash and cash equivalents (c)	5,608
Total liquidity	$	11,011

________________________

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

(b)The amount for our Canadian Revolver is shown in U.S. dollars. As set forth in the summary of our credit facilities in Note 4 of Condensed Notes to Consolidated Financial Statements, the availability under our Canadian Revolver as of September 30, 2023 in Canadian dollars was C$145 million.

(c)Excludes $223 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.

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,
	2023		2022
Cash flows provided by (used in):
Operating activities	$	7,990	$	8,478
Investing activities	(1,382)		(2,070)
Financing activities:
Debt issuances and borrowings	2,336		2,596
Repayments of debt and finance lease obligations (including premiums paid on early retirement of debt)	(2,609)		(5,051)
Return to stockholders:
Purchases of common stock for treasury	(4,180)		(2,769)
Common stock dividend payments	(1,106)		(1,186)
Return to stockholders	(5,286)		(3,955)
Other financing activities	(86)		141
Financing activities	(5,645)		(6,269)
Effect of foreign exchange rate changes on cash	6		(292)
Net increase (decrease) in cash and cash equivalents	$	969	$	(153)

Cash Flows for the Nine Months Ended September 30, 2023

In the first nine months of 2023, we used the $8.0 billion of cash generated by our operations and the $2.3 billion in debt borrowings to make $1.4 billion of investments in our business, repay $2.6 billion of debt and finance lease obligations (including premiums paid on the early retirement of debt), return $5.3 billion to our stockholders through purchases of our common stock for treasury and dividend payments, and increase our available cash on hand by $969 million. The debt borrowings and repayments are described in Note 4 of Condensed Notes to Consolidated Financial Statements.

As previously noted, our operations generated $8.0 billion of cash in the first nine months of 2023, driven primarily by net income of $7.9 billion and noncash charges to income of $1.8 billion, partially offset by an unfavorable change in working capital of $1.7 billion. Noncash charges primarily included $2.0 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 10 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 primarily consisted of $1.4 billion in capital investments, as defined below under “Capital Investments,” of which $239 million related to capital investments made by DGD.

Cash Flows for the Nine Months Ended September 30, 2022

In the first nine months of 2022, we used the $8.5 billion of cash generated by our operations, $2.6 billion in debt issuances and borrowings, and $153 million of cash on hand to make $2.1 billion of investments in our business, repay $5.1 billion of debt and finance lease obligations (including premiums paid on the early retirement of debt), and return $4.0 billion to our stockholders through purchases of our common stock for treasury and dividend payments. The debt issuance, borrowings, and repayments are described in Note 4 of Condensed Notes to Consolidated Financial Statements.

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As previously noted, our operations generated $8.5 billion of cash in the first nine months of 2022, driven primarily by net income of $8.6 billion and noncash charges to income of $1.4 billion, partially offset by an unfavorable change in working capital of $1.6 billion. Noncash charges primarily included $1.8 billion of depreciation and amortization expense, partially offset by a $161 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 10 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 primarily consisted of $2.1 billion in capital investments, of which $695 million related to capital investments made by DGD and $30 million related to capital expenditures of VIEs other than DGD.

Our Capital Resources

Our material cash requirements as of September 30, 2023 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 comprised of our capital expenditures, deferred turnaround and catalyst cost expenditures, and investments in nonconsolidated joint ventures, as reflected in our consolidated statements of cash flows as shown on page 6. Capital investments exclude acquisitions, if any.

We have publicly announced GHG emissions reduction/displacement targets for 2025 and 2035. We believe that our expected allocation of growth capital into low-carbon projects is consistent with such targets. Certain of these low-carbon projects have been completed or are already in execution and the associated capital investments are included in our expected capital investments for 2023. Our capital investments in future years, consistent with our targets, are expected to include investments associated with certain low-carbon projects currently at various stages of progress, evaluation, or approval.

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. 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 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.

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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.

	Nine Months Ended September 30,
(millions of dollars)	2023		2022
Reconciliation of capital investments to capital investments attributable to Valero
Capital expenditures (excluding VIEs)	$	468	$	552
Capital expenditures of VIEs:
DGD	183		682
Other VIEs	4		30
Deferred turnaround and catalyst cost expenditures (excluding VIEs)	665		820
Deferred turnaround and catalyst cost expenditures of DGD	56		13
Investments in nonconsolidated joint ventures	—		1
Capital investments	1,376		2,098
Adjustments:
DGD’s capital investments attributable to the other joint venture member	(120)		(347)
Capital expenditures of other VIEs	(4)		(30)
Capital investments attributable to Valero	$	1,252	$	1,721

We have developed an extensive multi-year capital investment program, which we update and revise based on changing internal and external factors. As previously disclosed in our annual report on Form 10-K for the year ended December 31, 2022, we expect to incur approximately $2.0 billion for capital investments attributable to Valero during 2023. Approximately $1.5 billion of the expected capital investments attributable to Valero are for sustaining the business and the balance towards growth strategies, of which approximately 40 percent is allocated to expanding our low-carbon businesses.

Contractual Obligations

As of September 30, 2023, 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, 2023, 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, 2023.

In March 2021, we announced our participation in Navigator’s proposed large-scale carbon capture and sequestration pipeline system in the Mid-Continent region of the U.S. In October 2023, Navigator announced that due to the unpredictable nature of the regulatory and government processes involved, particularly in South Dakota and Iowa, it has decided to cancel this project. Under the terms of agreements associated with the project, we may have some rights from and obligations to Navigator,

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including a portion of the aggregate project costs to date, but we do not expect such obligation will be material.

During the nine months ended September 30, 2023, we used cash on hand to purchase and retire $199 million of our public debt. We will continue to evaluate further deleveraging opportunities.

Other Matters Impacting Liquidity and Capital Resources

Stock Purchase Programs

During the three and nine months ended September 30, 2023, we purchased for treasury 12,805,162 of our shares for a total cost of $1.8 billion and 32,219,955 of our shares for $4.2 billion, respectively. See Note 5 of Condensed Notes to Consolidated Financial Statements for additional information related to our stock purchase programs. As of September 30, 2023, we had $649 million remaining available for purchase under the February 2023 Program. On September 15, 2023, 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 2023 Program. We will continue to evaluate the timing of purchases when appropriate. We have no obligation to make purchases under these programs.

Pension Plan Funding

As disclosed in our annual report on Form 10-K for the year ended December 31, 2022, we plan to contribute $108 million to our pension plans and $21 million to our other postretirement benefit plans during 2023. For the nine months ended September 30, 2023, we have contributed $94 million to our pension plans and $14 million to our other postretirement benefit plans.

Cash Held by Our Foreign Subsidiaries

As of September 30, 2023, $4.1 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.

Environmental Matters

Our operations are subject to extensive environmental regulations by government authorities relating to, among other matters, the 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 are becoming more complex and stringent and new 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 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.

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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, 2022.

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, 2023 (a)
	Expected Maturity Dates
	Remainder of 2023			2024			2025			2026			2027			There- after			Total			Fair Value
Fixed rate	$	—		$	167		$	441		$	672		$	564		$	6,421		$	8,265		$	7,587
Average interest rate	—		%	1.2		%	3.2		%	4.2		%	2.2		%	5.3		%	4.8		%
Floating rate	$	949		$	13		$	—		$	—		$	—		$	—		$	962		$	962
Average interest rate	8.7		%	6.7		%	—		%	—		%	—		%	—		%	8.7		%
	December 31, 2022 (a)
	Expected Maturity Dates
	2023			2024			2025			2026			2027			There- after			Total			Fair Value
Fixed rate	$	—		$	167		$	441		$	672		$	578		$	6,606		$	8,464		$	8,041
Average interest rate	—		%	1.2		%	3.2		%	4.2		%	2.2		%	5.3		%	4.8		%
Floating rate	$	861		$	—		$	—		$	—		$	—		$	—		$	861		$	861
Average interest rate	7.1		%	—		%	—		%	—		%	—		%	—		%	7.1		%

________________________

(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, 2022. See Note 12 of Condensed Notes to Consolidated Financial Statements for a discussion about these market risks as of September 30, 2023.

62

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, 2023.

(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

The information below describes new proceedings or material developments in proceedings that we previously reported in our annual reports on Form 10-K for the years ended December 31, 2022 and December 31, 2021, and that we originally reported in our quarterly report on Form 10-Q for the quarter ended March 31, 2021.

Environmental Enforcement Matters

We are reporting the following proceedings to comply with SEC regulations, which require us to disclose certain information about proceedings arising under federal, state, or local provisions regulating the discharge of materials into the environment or primarily for the purpose of protecting the environment if a governmental authority is a party to such proceeding and we reasonably believe that such proceeding will result in monetary sanctions that exceed a specified threshold. Pursuant to SEC regulations, we use a threshold of $1 million for purposes of determining whether disclosure of any such proceedings is required. We believe proceedings less than this threshold are not material to our business and financial condition.

Bay Area Air Quality Management District (BAAQMD) (Benicia Refinery). We originally reported in our quarterly report on Form 10-Q for the quarter ended March 31, 2021, that we received a Notice of Violation (NOV) from the BAAQMD on March 21, 2019, related to atmospheric emissions of hydrogen commingled with non-methane organic compounds at our Benicia Refinery (the 2019 Atmospheric Emissions NOV), as that was the first quarter in which it became reportable. On December 1, 2020, we received an NOV from the BAAQMD related to pressure relief devices in the Benicia Refinery’s Hydrogen Unit (the 2020 Pressure Relief Device NOV), which we now reasonably believe will result in penalties that are in excess of $1 million. On June 17, 2021, October 11, 2021, and January 26, 2022, we also received certain other compliance related NOVs related to the 2019 Atmospheric Emissions NOV and the 2020 Pressure Relief Device NOV, which we now reasonably believe will result in penalties that are in excess of $1 million. We are in discussion with the BAAQMD with respect to the foregoing, but it is too early to predict the ultimate outcome thereof.

63

BAAQMD (Benicia Refinery). We are also currently in the process of working with the BAAQMD to resolve several other NOVs issued by the BAAQMD to our Benicia Refinery in 2020 and 2019, which primarily relate to various emissions and related compliance issues, which we now reasonably believe will result in penalties that are in excess of $1 million.

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, 2022. However, to the extent SBx 1-2 discussed in Note 2 of Condensed Notes to Consolidated Financial Statements adversely affects our business, financial condition, results of operations, and liquidity, it may also have the effect of heightening many of the other risks described in such risk factors.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES, USE OF PROCEEDS, AND ISSUER PURCHASES OF EQUITY SECURITIES

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 2023.

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 2023	8,180	$	118.01	—	$2.5 billion
August 2023	4,218,383	$	131.38	4,214,764	$1.9 billion
September 2023	8,578,599	$	143.59	8,576,013	$3.1 billion
Total	12,805,162	$	139.55	12,790,777	$3.1 billion

________________________

(a)The shares reported in this column include 14,385 shares related to our purchases of shares from our employees and non-employee directors in connection with the exercise of stock options, 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 23, 2023, 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, 2023, we had $649 million remaining available for purchase under the February 2023 Program. On September 15, 2023, 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 2023 Program.

64

ITEM 5. OTHER INFORMATION

(a)None.

(b)None.

(c)During the three months ended September 30, 2023, 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(a) of Regulation S-K.

ITEM 6. EXHIBITS

Exhibit No.	Description
+10.01	Valero Energy Corporation Supplemental Executive Retirement Plan, as amended and restated effective July 1, 2023–incorporated by reference to Exhibit 10.01 to Valero’s quarterly report on Form 10-Q for the quarter ended June 30, 2023 (SEC File No. 001-13175).
22.01	Subsidiary Issuer of Guaranteed Securities–incorporated by reference to Exhibit 22.01 to Valero’s annual report on Form 10-K for the year ended December 31, 2020 (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.
+	Identifies management contracts or compensatory plans or arrangements required to be filed as an exhibit hereto.

Certain agreements relating to our long-term debt have not been filed as exhibits as permitted by paragraph (b)(4)(iii)(A) of Item 601 of Regulation S-K since the total amount of securities authorized under any such agreements do not exceed 10 percent of our total consolidated assets. Upon request, we will furnish to the SEC all constituent agreements defining the rights of holders of our long-term debt not filed herewith.

65

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 26, 2023

66

EX-31.01

Exhibit 31.01

CERTIFICATION PURSUANT TO SECTION 302

OF THE SARBANES-OXLEY ACT OF 2002

I, R. Lane Riggs, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Valero Energy Corporation;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: October 26, 2023

/s/ R. Lane Riggs

R. Lane Riggs
Chief Executive Officer and President

EX-31.02

Exhibit 31.02

CERTIFICATION PURSUANT TO SECTION 302

OF THE SARBANES-OXLEY ACT OF 2002

I, Jason W. Fraser, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Valero Energy Corporation;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: October 26, 2023

/s/ Jason W. Fraser

Jason W. Fraser
Executive Vice President and Chief Financial Officer

EX-32.01

Exhibit 32.01

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Valero Energy Corporation (the Company) on Form 10-Q for the quarter ended September 30, 2023, as filed with the Securities and Exchange Commission on the date hereof (the Report), the undersigned hereby certifies, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1.The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

2.The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ R. Lane Riggs

R. Lane Riggs

Chief Executive Officer and President

October 26, 2023

A signed original of the written statement required by Section 906 has been provided to Valero Energy Corporation and will be retained by Valero Energy Corporation and furnished to the Securities and Exchange Commission or its staff upon request.

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Valero Energy Corporation (the Company) on Form 10-Q for the quarter ended September 30, 2023, as filed with the Securities and Exchange Commission on the date hereof (the Report), the undersigned hereby certifies, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1.The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

2.The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Jason W. Fraser

Jason W. Fraser

Executive Vice President and Chief Financial Officer

October 26, 2023

A signed original of the written statement required by Section 906 has been provided to Valero Energy Corporation and will be retained by Valero Energy Corporation and furnished to the Securities and Exchange Commission or its staff upon request.

XML

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2023	Oct. 20, 2023
Cover [Abstract]
Document type	10-Q
Document quarterly report	true
Document period end date	Sep. 30, 2023
Document transition report	false
Entity file number	001-13175
Entity registrant name	VALERO ENERGY CORP/TX
Entity incorporation, state or country code	DE
Entity tax identification number	74-1828067
Entity address, address line one	One Valero Way
Entity address, city or town	San Antonio
Entity address, state or province	TX
Entity address, postal zip code	78249
City area code	210
Local phone number	345-2000
Title of 12(b) security	Common Stock, par value $0.01 per share
Trading symbol	VLO
Security exchange name	NYSE
Entity current reporting status	Yes
Entity interactive data current	Yes
Entity filer category	Large Accelerated Filer
Entity small business	false
Entity emerging growth company	false
Entity shell company	false
Entity common stock, shares outstanding		340,452,942
Entity central index key	0001035002
Amendment flag	false
Document fiscal year focus	2023
Document fiscal period focus	Q3
Current fiscal year end date	--12-31

XML

Consolidated Balance Sheets - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Current assets:
Cash and cash equivalents	$ 5,831	$ 4,862
Receivables, net	12,566	11,919
Inventories	7,513	6,752
Prepaid expenses and other	667	600
Total current assets	26,577	24,133
Property, plant, and equipment, at cost	51,208	50,576
Accumulated depreciation	(20,955)	(19,598)
Property, plant, and equipment, net	30,253	30,978
Deferred charges and other assets, net	6,345	5,871
Total assets	63,175	60,982
Current liabilities:
Current portion of debt and finance lease obligations	1,334	1,109
Accounts payable	13,342	12,728
Accrued expenses	1,219	1,215
Taxes other than income taxes payable	1,419	1,568
Income taxes payable	278	841
Total current liabilities	17,592	17,461
Debt and finance lease obligations, less current portion	10,107	10,526
Deferred income tax liabilities	5,231	5,217
Other long-term liabilities	2,188	2,310
Commitments and contingencies
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	6,900	6,863
Treasury stock, at cost; 333,047,642 and 301,372,958 common shares	(24,381)	(20,197)
Retained earnings	44,774	38,247
Accumulated other comprehensive loss	(1,325)	(1,359)
Total Valero Energy Corporation stockholders’ equity	25,975	23,561
Noncontrolling interests	2,082	1,907
Total equity	28,057	25,468
Total liabilities and equity	$ 63,175	$ 60,982

XML

Consolidated Balance Sheets (Parenthetical) - $ / shares	Sep. 30, 2023	Dec. 31, 2022
Valero Energy Corporation stockholders’ equity:
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock, shares authorized (in shares)	1,200,000,000	1,200,000,000
Common stock, shares issued (in shares)	673,501,593	673,501,593
Treasury stock, common (in shares)	333,047,642	301,372,958

XML

Consolidated Statements of Income (unaudited) - USD ($) shares in Millions, $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Revenues	[1]	$ 38,404	$ 44,454	$ 109,352	$ 134,637
Cost of sales:
Cost of materials and other	[2]	32,385	38,064	91,820	115,959
Operating expenses (excluding depreciation and amortization expense reflected below)		1,578	1,746	4,495	4,751
Depreciation and amortization expense		671	621	1,979	1,806
Total cost of sales		34,634	40,431	98,294	122,516
Other operating expenses		6	6	18	40
General and administrative expenses (excluding depreciation and amortization expense reflected below)		250	214	703	652
Depreciation and amortization expense		11	11	32	34
Operating income		3,503	3,792	10,305	11,395
Other income, net		122	74	357	87
Interest and debt expense, net of capitalized interest		(149)	(138)	(443)	(425)
Income before income tax expense		3,476	3,728	10,219	11,057
Income tax expense		813	816	2,288	2,410
Net income		2,663	2,912	7,931	8,647
Less: Net income attributable to noncontrolling interests		41	95	298	232
Net income attributable to Valero Energy Corporation stockholders		$ 2,622	$ 2,817	$ 7,633	$ 8,415
Earnings per common share (in dollars per share)		$ 7.49	$ 7.20	$ 21.22	$ 20.94
Weighted-average common shares outstanding (in shares)		349	390	359	400
Earnings per common share – assuming dilution (in dollars per share)		$ 7.49	$ 7.19	$ 21.21	$ 20.93
Weighted-average common shares outstanding – assuming dilution (in shares)		349	390	359	401
Supplemental information:
Includes excise taxes on sales by certain of our foreign operations		$ 1,468	$ 1,213	$ 4,339	$ 3,890

[1] Includes excise taxes on sales by certain of our foreign operations of $1,468 million and $1,213 million for the three months ended September 30, 2023 and 2022, respectively, and $4,339 million and $3,890 million for the nine months ended September 30, 2023 and 2022, respectively.

[2] Cost of materials and other for our Renewable Diesel segment is net of the blender’s tax credit on qualified fuel mixtures of $266 million and $191 million for the three months ended September 30, 2023 and 2022, respectively, and $900 million and $545 million for the nine months ended September 30, 2023 and 2022, respectively.

XML

Consolidated Statements of Comprehensive Income (unaudited) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Net income	$ 2,663	$ 2,912	$ 7,931	$ 8,647
Other comprehensive income (loss):
Foreign currency translation adjustment	(314)	(606)	77	(1,035)
Net gain (loss) on pension and other postretirement benefits	(12)	8	(25)	25
Net gain (loss) on cash flow hedges	(78)	69	(68)	74
Other comprehensive loss before income tax expense (benefit)	(404)	(529)	(16)	(936)
Income tax expense (benefit) related to items of other comprehensive income (loss)	(11)	9	(16)	16
Other comprehensive income (loss)	(393)	(538)	0	(952)
Comprehensive income	2,270	2,374	7,931	7,695
Less: Comprehensive income attributable to noncontrolling interests	2	129	264	269
Comprehensive income attributable to Valero Energy Corporation stockholders	$ 2,268	$ 2,245	$ 7,667	$ 7,426

XML

Consolidated Statements of Equity (unaudited) - USD ($) $ in Millions	Total	Valero Energy Corporation Stockholders' Equity [Member]	Common Stock [Member]	Additional Paid-in Capital [Member]	Treasury Stock [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Loss [Member]	Non-controlling Interests [Member]
Balance as of beginning of period at Dec. 31, 2021	$ 19,817	$ 18,430	$ 7	$ 6,827	$ (15,677)	$ 28,281	$ (1,008)	$ 1,387
Increase (Decrease) in Stockholders' Equity Roll Forward
Net income	8,647	8,415				8,415		232
Dividends on common stock	(1,186)	(1,186)				(1,186)
Stock-based compensation expense	60	60		60
Transactions in connection with stock-based compensation plans	2	2		(29)	31
Purchases of common stock for treasury	(2,820)	(2,820)			(2,820)
Contributions from noncontrolling interests	240							240
Distributions to noncontrolling interests	(93)							(93)
Other comprehensive income (loss)	(952)	(989)					(989)	37
Balance as of end of period at Sep. 30, 2022	23,715	21,912	7	6,858	(18,466)	35,510	(1,997)	1,803
Balance as of beginning of period at Jun. 30, 2022	22,733	20,969	7	6,845	(17,537)	33,079	(1,425)	1,764
Increase (Decrease) in Stockholders' Equity Roll Forward
Net income	2,912	2,817				2,817		95
Dividends on common stock	(386)	(386)				(386)
Stock-based compensation expense	13	13		13
Transactions in connection with stock-based compensation plans	(1)	(1)			(1)
Purchases of common stock for treasury	(928)	(928)			(928)
Distributions to noncontrolling interests	(90)							(90)
Other comprehensive income (loss)	(538)	(572)					(572)	34
Balance as of end of period at Sep. 30, 2022	23,715	21,912	7	6,858	(18,466)	35,510	(1,997)	1,803
Balance as of beginning of period at Dec. 31, 2022	25,468	23,561	7	6,863	(20,197)	38,247	(1,359)	1,907
Increase (Decrease) in Stockholders' Equity Roll Forward
Net income	7,931	7,633				7,633		298
Dividends on common stock	(1,106)	(1,106)				(1,106)
Stock-based compensation expense	68	68		68
Transactions in connection with stock-based compensation plans	7	7		(31)	38
Purchases of common stock for treasury	(4,222)	(4,222)			(4,222)
Contributions from noncontrolling interests	75							75
Distributions to noncontrolling interests	(164)							(164)
Other comprehensive income (loss)	0	34					34	(34)
Balance as of end of period at Sep. 30, 2023	28,057	25,975	7	6,900	(24,381)	44,774	(1,325)	2,082
Balance as of beginning of period at Jun. 30, 2023	27,994	25,851	7	6,889	(22,586)	42,512	(971)	2,143
Increase (Decrease) in Stockholders' Equity Roll Forward
Net income	2,663	2,622				2,622		41
Dividends on common stock	(360)	(360)				(360)
Stock-based compensation expense	15	15		15
Transactions in connection with stock-based compensation plans	6	6		(4)	10
Purchases of common stock for treasury	(1,805)	(1,805)			(1,805)
Distributions to noncontrolling interests	(63)							(63)
Other comprehensive income (loss)	(393)	(354)					(354)	(39)
Balance as of end of period at Sep. 30, 2023	$ 28,057	$ 25,975	$ 7	$ 6,900	$ (24,381)	$ 44,774	$ (1,325)	$ 2,082

XML

Consolidated Statements of Equity (unaudited) (Parenthetical) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Common stock dividends:
Dividends on common stock (in dollars per share)	$ 1.02	$ 0.98	$ 3.06	$ 2.94

XML

Consolidated Statements of Cash Flows (unaudited) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
Cash flows from operating activities:
Net income	$ 7,931	$ 8,647
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization expense	2,011	1,840
Loss (gain) on early retirement of debt, net	(11)	24
Deferred income tax expense (benefit)	32	(161)
Changes in current assets and current liabilities	(1,695)	(1,617)
Changes in deferred charges and credits and other operating activities, net	(278)	(255)
Net cash provided by operating activities	7,990	8,478
Cash flows from investing activities:
Purchases of available-for-sale (AFS) debt securities	(237)	0
Proceeds from sales and maturities of AFS debt securities	220	0
Proceeds from sale of assets	0	32
Investments in nonconsolidated joint ventures	0	(1)
Other investing activities, net	11	(4)
Net cash used in investing activities	(1,382)	(2,070)
Cash flows from financing activities:
Premiums paid on early retirement of debt	(5)	(48)
Purchases of common stock for treasury	(4,180)	(2,769)
Common stock dividend payments	(1,106)	(1,186)
Contributions from noncontrolling interests	75	240
Distributions to noncontrolling interests	(164)	(93)
Other financing activities, net	3	(6)
Net cash used in financing activities	(5,645)	(6,269)
Effect of foreign exchange rate changes on cash	6	(292)
Net increase (decrease) in cash and cash equivalents	969	(153)
Cash and cash equivalents at beginning of period	4,862	4,122
Cash and cash equivalents at end of period	5,831	3,969
Excluding Variable Interest Entities (VIEs) [Member]
Cash flows from investing activities:
Capital expenditures	(468)	(552)
Deferred turnaround and catalyst cost expenditures	(665)	(820)
Cash flows from financing activities:
Proceeds from debt issuances and borrowings	1,750	1,839
Repayments of debt and finance lease obligations	(2,071)	(4,234)
Diamond Green Diesel Holdings LLC (DGD) [Member]
Cash flows from investing activities:
Capital expenditures	(183)	(682)
Deferred turnaround and catalyst cost expenditures	(56)	(13)
Cash flows from financing activities:
Proceeds from debt issuances and borrowings	500	684
Repayments of debt and finance lease obligations	(474)	(718)
Other VIEs [Member]
Cash flows from investing activities:
Capital expenditures	(4)	(30)
Cash flows from financing activities:
Proceeds from borrowings of other VIEs	86	73
Repayments of debt and finance lease obligations	$ (59)	$ (51)

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Basis of Presentation and Significant Accounting Policies

9 Months Ended

Sep. 30, 2023

Accounting Policies [Abstract]

BASIS OF PRESENTATION AND SIGNIFICANT ACCOUNTING POLICIES

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 disclosed otherwise. Operating results for the interim periods are not necessarily indicative of the results that may be expected for the year ending December 31, 2023. 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, 2022.

The balance sheet as of December 31, 2022 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, 2022.

Significant Accounting Policy

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.

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Uncertainty

9 Months Ended

Sep. 30, 2023

Risks and Uncertainties [Abstract]

UNCERTAINTY

2.    UNCERTAINTY

In September 2022, California adopted Senate Bill No. 1322 (SB 1322), which requires refineries in California to report monthly on the volume and cost of the crude oil they buy, the quantity and price of the wholesale gasoline they sell, and the gross gasoline margin per barrel, among other information. The provisions of SB 1322 were effective January 2023.

In March 2023, California adopted Senate Bill No. 2 (such statute, together with any regulations contemplated or issued thereunder, SBx 1-2), which, among other things, (i) authorized the establishment of a maximum gross gasoline refining margin (max margin) and the imposition of a financial penalty for profits above a max margin, (ii) significantly expanded the reporting obligations under SB 1322 and the Petroleum Industry Information Reporting Act of 1980, which include reporting requirements to the

California Energy Commission (CEC) for all participants in the petroleum industry supply chain in California (e.g., refiners, marketers, importers, transporters, terminals, producers, renewables producers, pipelines, and ports), (iii) created the Division of Petroleum Market Oversight within the CEC to analyze the data provided under SBx 1-2, and (iv) authorized the CEC to regulate the timing and other aspects of refinery turnaround and maintenance activities in certain instances. SBx 1-2 imposes increased and substantial reporting requirements, which include daily, weekly, monthly, and annual reporting of detailed operational and financial data on all aspects of our operations in California, much of it at the transaction level. The operational data includes our plans for turnaround and maintenance activities at our two California refineries and the manner in which we expect to address the potential impacts on feedstock and product inventories in California as a result of such turnaround and maintenance activities. The provisions of SBx 1-2 became effective June 26, 2023.

In September 2023, Governor Newsom directed the CEC to immediately begin the regulatory processes concerning the potential imposition of a penalty for exceeding a max margin and the timing of refinery turnarounds and maintenance. Consequently, the CEC adopted an order instituting an informational proceeding on a max margin and penalty under SBx 1-2, as well as an order initiating rulemaking activity under SBx 1-2. The CEC indicated the latter rulemaking process will be focused on refinery maintenance and turnarounds; however, it remains uncertain as to whether, when, and to what extent any regulations will address the remaining reporting requirements under SBx 1-2.

We continue to review and analyze the provisions of SBx 1-2 and the possible impacts to our refining and marketing operations in California. While the CEC has not yet established a max margin, imposed a financial penalty for profits above a max margin, or imposed restrictions on turnaround and maintenance activities, Governor Newsom’s direction to the CEC to begin the regulatory processes related to each of those matters, as described above, and the potential implementation of a financial penalty or any restrictions or delays on our ability to undertake turnaround or maintenance activities creates uncertainty due to the potential adverse effects on us. Any adverse effects on our operations or financial performance in California could indicate that the carrying value of our assets in California is not recoverable, which would result in an impairment loss that could be material. In addition, if the circumstances that trigger an impairment loss result in a reduction in the estimated useful lives of the assets, we may be required to recognize an asset retirement obligation that could be material. Other jurisdictions are contemplating similarly focused legislation or actions.

The ultimate timing and impacts of SBx 1-2 and any other similarly focused legislation or actions are subject to considerable uncertainty due to a number of factors, including technological and economic feasibility, legal challenges, and potential changes in law, regulation, or policy, and it is not currently possible to predict the ultimate effects of these matters and developments on us.

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Inventories

9 Months Ended

Sep. 30, 2023

Inventory Disclosure [Abstract]

INVENTORIES

3.    INVENTORIES

Inventories consisted of the following (in millions):

	September 30, 2023		December 31, 2022
Refinery feedstocks	$	1,878	$	1,949
Refined petroleum products and blendstocks	4,232		3,579
Renewable diesel feedstocks and products	797		583
Ethanol feedstocks and products	270		328
Materials and supplies	336		313
Inventories	$	7,513	$	6,752

As of September 30, 2023 and December 31, 2022, the replacement cost (market value) of last-in, first-out (LIFO) inventories exceeded their LIFO carrying amounts by $6.1 billion and $6.3 billion, respectively. Our non-LIFO inventories accounted for $1.3 billion and $1.6 billion of our total inventories as of September 30, 2023 and December 31, 2022, respectively.

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Debt

9 Months Ended

Sep. 30, 2023

Debt Disclosure [Abstract]

DEBT

4.    DEBT

Public Debt

In February 2023, we used cash on hand to purchase and retire a portion of the following notes (in millions):

Debt Purchased and Retired	Principal Amount
6.625% Senior Notes due 2037	$	62
3.650% Senior Notes due 2051	26
4.000% Senior Notes due 2052	45
Various other Valero and Valero Energy Partners (VLP) Senior Notes	66
Total	$	199

During the nine months ended September 30, 2022, the following activity occurred:

•In September 2022, we used cash on hand to purchase and retire a portion of the following notes in connection with cash tender offers that we publicly announced in August 2022 and completed in September 2022 (in millions):

Debt Purchased and Retired	Principal Amount
3.65% Senior Notes due 2025	$	48
2.850% Senior Notes due 2025	291
4.375% VLP Senior Notes due 2026	62
3.400% Senior Notes due 2026	166
4.350% Senior Notes due 2028	131
4.000% Senior Notes due 2029	552
Total	$	1,250

•In June 2022, we reduced our debt through the acquisition of the $300 million of 4.00 percent Gulf Opportunity Zone Revenue Bonds Series 2010 that are due December 1, 2040, but were subject to mandatory tender on June 1, 2022. We have the option to effectuate a remarketing of these bonds.

•In February 2022, we issued $650 million of 4.000 percent Senior Notes due June 1, 2052. Proceeds from this debt issuance totaled $639 million before deducting the underwriting discount and other debt issuance costs. The proceeds and cash on hand were used to purchase and retire a portion of the following notes in connection with cash tender offers that we publicly announced and completed in February 2022 (in millions):

Debt Purchased and Retired	Principal Amount
3.65% Senior Notes due 2025	$	72
2.850% Senior Notes due 2025	507
4.375% VLP Senior Notes due 2026	168
3.400% Senior Notes due 2026	653
Total	$	1,400

Credit Facilities

We had outstanding borrowings, letters of credit issued, and availability under our credit facilities as follows (amounts in millions and currency in U.S. dollars, except as noted):

				September 30, 2023
	Facility Amount		Maturity Date	Outstanding Borrowings		Letters of Credit Issued (a)		Availability
Committed facilities:
Valero Revolver	$	4,000	November 2027	$	—	$	4	$	3,996
Canadian Revolver (b)	C$	150	November 2023	C$	—	C$	5	C$	145
Accounts receivable sales facility	$	1,300	July 2024	$	—	n/a		$	1,300
Committed facilities of VIEs (c):
DGD Revolver (d)	$	400	June 2026	$	200	$	106	$	94
DGD Loan Agreement (e)	$	100	June 2026	$	—	n/a		$	100
IEnova Revolver (f)	$	830	February 2028	$	748	n/a		$	82
Uncommitted facilities:
Letter of credit facilities	n/a		n/a	n/a		$	177	n/a

________________________

(a)Letters of credit issued as of September 30, 2023 expire at various times in 2023 through 2026.

(b)On October 24, 2023, we amended this facility to (i) extend the maturity date to February 2024 and (ii) reduce the facility amount so that, effective October 31, 2023, the facility amount will equal the amount of the outstanding letters of credit thereunder, and will not permit further borrowings other than certain deemed borrowings to satisfy the reimbursement obligations under such letters of credit.

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

(d)In June 2023, DGD amended this facility to (i) extend the maturity date to June 2026 and (ii) transition the benchmark reference interest rate previously based on the London Interbank Offered Rate (LIBOR) to a secured overnight financing rate (SOFR). The variable interest rate on the DGD Revolver was 7.173 percent and 5.880 percent as of September 30, 2023 and December 31, 2022, respectively.

(e)The amounts shown for this facility 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. In April 2023, DGD extended the maturity date of this agreement to June 2023. In June 2023, DGD entered into a new unsecured revolving loan agreement that replaced and superseded the previous agreement. The new agreement includes the following modifications from the previous agreement: (i) extends the maturity date to June 2026, (ii) increases each member’s commitment from $25 million to $100 million, resulting in an increase in aggregate commitments from $50 million to $200 million, and (iii) transitions the benchmark reference interest rate previously based on the LIBOR to Term SOFR. The variable interest rate on the DGD Loan Agreement was 6.672 percent as of December 31, 2022.

(f)Both parties to this facility have agreed to use a SOFR as the interest rate applied to outstanding borrowings. The variable interest rate on the IEnova Revolver was 9.097 percent and 7.393 percent as of September 30, 2023 and December 31, 2022, respectively.

Activity under our credit facilities was as follows (in millions):

	Nine Months Ended September 30,
	2023		2022
Borrowings:
Accounts receivable sales facility	$	1,750	$	1,200
DGD Revolver	500		659
DGD Loan Agreement	—		25
IEnova Revolver	86		73
Repayments:
Accounts receivable sales facility	(1,750)		(1,200)
DGD Revolver	(400)		(659)
DGD Loan Agreement	(25)		(50)
IEnova Revolver	(55)		(47)

Other Disclosures

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

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Interest and debt expense	$	153	$	154	$	456	$	467
Less: Capitalized interest	4		16		13		42
Interest and debt expense, net of capitalized interest	$	149	$	138	$	443	$	425

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Equity

9 Months Ended

Sep. 30, 2023

Equity [Abstract]

EQUITY

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 below) and with respect to our employee stock-based compensation plans.

During the three and nine months ended September 30, 2023, we purchased for treasury 12,805,162 shares and 32,219,955 shares, respectively. During the three and nine months ended September 30, 2022, we purchased for treasury 8,444,754 shares and 24,202,035 shares, respectively. On October 26, 2022, 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, and we completed all authorized share purchases under that program during the second quarter of 2023. On February 23, 2023, 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 (the February 2023 Program). As of September 30, 2023, we had $649 million remaining available for purchase under the February 2023 Program. On September 15, 2023, 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 2023 Program.

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,
	2023								2022
	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	$	(774)	$	(193)	$	(4)	$	(971)	$	(991)	$	(430)	$	(4)	$	(1,425)
Other comprehensive income (loss) before reclassifications	(315)		—		(77)		(392)		(606)		—		30		(576)
Amounts reclassified from accumulated other comprehensive loss	—		(7)		47		40		—		7		(3)		4
Effect of exchange rates	—		(2)		—		(2)		—		—		—		—
Other comprehensive income (loss)	(315)		(9)		(30)		(354)		(606)		7		27		(572)
Balance as of end of period	$	(1,089)	$	(202)	$	(34)	$	(1,325)	$	(1,597)	$	(423)	$	23	$	(1,997)

	Nine Months Ended September 30,
	2023								2022
	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	$	(1,168)	$	(183)	$	(8)	$	(1,359)	$	(562)	$	(441)	$	(5)	$	(1,008)
Other comprehensive income (loss) before reclassifications	79		—		(28)		51		(1,035)		(2)		(84)		(1,121)
Amounts reclassified from accumulated other comprehensive loss	—		(20)		2		(18)		—		18		112		130
Effect of exchange rates	—		1		—		1		—		2		—		2
Other comprehensive income (loss)	79		(19)		(26)		34		(1,035)		18		28		(989)
Balance as of end of period	$	(1,089)	$	(202)	$	(34)	$	(1,325)	$	(1,597)	$	(423)	$	23	$	(1,997)

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Variable Interest Entities

9 Months Ended

Sep. 30, 2023

Organization, Consolidation and Presentation of Financial Statements [Abstract]

VARIABLE INTEREST ENTITIES

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, 2023, 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 (predominately animal fats, used cooking oils, and inedible distillers corn oils) into renewable diesel and renewable naphtha; 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, these transactions are eliminated in consolidation. Our financial position, results of operations, and cash flows are impacted by the performance of the consolidated VIEs, net of intercompany eliminations, to the extent of our ownership interest in each VIE.

The following tables present 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, 2023
Assets
Cash and cash equivalents	$	198	$	—	$	25	$	223
Other current assets	1,387		8		30		1,425
Property, plant, and equipment, net	3,764		668		71		4,503
Liabilities
Current liabilities, including current portion of debt and finance lease obligations	$	549	$	799	$	18	$	1,366
Debt and finance lease obligations, less current portion	676		—		—		676

	DGD		Central Mexico Terminals		Other		Total
December 31, 2022
Assets
Cash and cash equivalents	$	133	$	—	$	16	$	149
Other current assets	1,106		7		32		1,145
Property, plant, and equipment, net	3,785		681		79		4,545
Liabilities
Current liabilities, including current portion of debt and finance lease obligations	$	626	$	737	$	21	$	1,384
Debt and finance lease obligations, less current portion	693		—		—		693

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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Employee Benefit Plans

9 Months Ended

Sep. 30, 2023

Retirement Benefits [Abstract]

EMPLOYEE BENEFIT PLANS

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
	2023		2022		2023		2022
Three months ended September 30
Service cost	$	28	$	37	$	1	$	1
Interest cost	30		22		3		2
Expected return on plan assets	(50)		(48)		—		—
Amortization of:
Net actuarial (gain) loss	(2)		14		(1)		—
Prior service credit	(5)		(5)		(1)		(1)
Settlement loss	—		12		—		—
Net periodic benefit cost	$	1	$	32	$	2	$	2
Nine months ended September 30
Service cost	$	84	$	114	$	3	$	4
Interest cost	90		64		9		6
Expected return on plan assets	(151)		(144)		—		—
Amortization of:
Net actuarial (gain) loss	(5)		40		(4)		—
Prior service credit	(14)		(14)		(3)		(3)
Settlement loss	—		12		—		—
Net periodic benefit cost	$	4	$	72	$	5	$	7

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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Earnings Per Common Share

9 Months Ended

Sep. 30, 2023

Earnings Per Share [Abstract]

EARNINGS PER COMMON SHARE

8.    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,
	2023		2022		2023		2022
Earnings per common share:
Net income attributable to Valero stockholders	$	2,622	$	2,817	$	7,633	$	8,415
Less: Income allocated to participating securities	8		11		24		31
Net income available to common stockholders	$	2,614	$	2,806	$	7,609	$	8,384
Weighted-average common shares outstanding	349		390		359		400
Earnings per common share	$	7.49	$	7.20	$	21.22	$	20.94
Earnings per common share – assuming dilution:
Net income attributable to Valero stockholders	$	2,622	$	2,817	$	7,633	$	8,415
Less: Income allocated to participating securities	8		11		24		31
Net income available to common stockholders	$	2,614	$	2,806	$	7,609	$	8,384
Weighted-average common shares outstanding	349		390		359		400
Effect of dilutive securities	—		—		—		1
Weighted-average common shares outstanding – assuming dilution	349		390		359		401
Earnings per common share – assuming dilution	$	7.49	$	7.19	$	21.21	$	20.93

Participating securities include restricted stock and performance awards granted under our 2020 Omnibus Stock Incentive Plan (OSIP) or our 2011 OSIP. Dilutive securities include participating securities as well as outstanding stock options.

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Revenues and Segment Information

9 Months Ended

Sep. 30, 2023

Segment Reporting [Abstract]

REVENUES AND SEGMENT INFORMATION

9.    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, 2023		December 31, 2022
Receivables from contracts with customers, included in receivables, net	$	7,451	$	7,189
Contract liabilities, included in accrued expenses	38		129

During the nine months ended September 30, 2023 and 2022, we recognized as revenue $125 million and $74 million that was included in contract liabilities as of December 31, 2022 and 2021, respectively. Revenue recognized related to contract liabilities during the three months ended September 30, 2023 and 2022 was not material.

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, 2023, 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 renewable diesel and renewable naphtha. The principal products manufactured by DGD and sold by this segment are renewable diesel and renewable naphtha. This segment sells some renewable diesel to the Refining segment, which is then sold to that segment’s customers.

•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.

The following tables reflect information about our operating income by reportable segment (in millions):

	Refining		Renewable Diesel		Ethanol		Corporate and Eliminations		Total
Three months ended September 30, 2023
Revenues:
Revenues from external customers	$	36,521	$	759	$	1,124	$	—	$	38,404
Intersegment revenues	8		672		310		(990)		—
Total revenues	36,529		1,431		1,434		(990)		38,404
Cost of sales:
Cost of materials and other (a)	31,115		1,169		1,092		(991)		32,385
Operating expenses (excluding depreciation and amortization expense reflected below)	1,366		84		125		3		1,578
Depreciation and amortization expense	597		55		20		(1)		671
Total cost of sales	33,078		1,308		1,237		(989)		34,634
Other operating expenses	6		—		—		—		6
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		250		250
Depreciation and amortization expense	—		—		—		11		11
Operating income by segment	$	3,445	$	123	$	197	$	(262)	$	3,503
Three months ended September 30, 2022
Revenues:
Revenues from external customers	$	42,280	$	967	$	1,207	$	—	$	44,454
Intersegment revenues	9		508		179		(696)		—
Total revenues	42,289		1,475		1,386		(696)		44,454
Cost of sales:
Cost of materials and other (a)	36,389		1,161		1,203		(689)		38,064
Operating expenses (excluding depreciation and amortization expense reflected below)	1,516		69		162		(1)		1,746
Depreciation and amortization expense	568		33		20		—		621
Total cost of sales	38,473		1,263		1,385		(690)		40,431
Other operating expenses	6		—		—		—		6
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		214		214
Depreciation and amortization expense	—		—		—		11		11
Operating income by segment	$	3,810	$	212	$	1	$	(231)	$	3,792

________________________

See note (a) on page 21.

	Refining		Renewable Diesel		Ethanol		Corporate and Eliminations		Total
Nine months ended September 30, 2023
Revenues:
Revenues from external customers	$	102,924	$	2,990	$	3,438	$	—	$	109,352
Intersegment revenues	8		2,367		790		(3,165)		—
Total revenues	102,932		5,357		4,228		(3,165)		109,352
Cost of sales:
Cost of materials and other (a)	87,398		4,143		3,422		(3,143)		91,820
Operating expenses (excluding depreciation and amortization expense reflected below)	3,832		274		383		6		4,495
Depreciation and amortization expense	1,751		172		59		(3)		1,979
Total cost of sales	92,981		4,589		3,864		(3,140)		98,294
Other operating expenses	17		—		1		—		18
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		703		703
Depreciation and amortization expense	—		—		—		32		32
Operating income by segment	$	9,934	$	768	$	363	$	(760)	$	10,305
Nine months ended September 30, 2022
Revenues:
Revenues from external customers	$	128,588	$	2,417	$	3,632	$	—	$	134,637
Intersegment revenues	24		1,490		507		(2,021)		—
Total revenues	128,612		3,907		4,139		(2,021)		134,637
Cost of sales:
Cost of materials and other (a)	111,308		3,129		3,533		(2,011)		115,959
Operating expenses (excluding depreciation and amortization expense reflected below)	4,111		178		464		(2)		4,751
Depreciation and amortization expense	1,682		87		37		—		1,806
Total cost of sales	117,101		3,394		4,034		(2,013)		122,516
Other operating expenses	38		—		2		—		40
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		652		652
Depreciation and amortization expense	—		—		—		34		34
Operating income by segment	$	11,473	$	513	$	103	$	(694)	$	11,395

________________________

(a)Cost of materials and other for our Renewable Diesel segment is net of the blender’s tax credit on qualified fuel mixtures of $266 million and $191 million for the three months ended September 30, 2023 and 2022, respectively, and $900 million and $545 million for the nine months ended September 30, 2023 and 2022, respectively.

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,
	2023		2022		2023		2022
Refining:
Gasolines and blendstocks	$	17,025	$	17,862	$	47,302	$	54,026
Distillates	16,392		20,481		47,222		62,352
Other product revenues	3,104		3,937		8,400		12,210
Total Refining revenues	36,521		42,280		102,924		128,588
Renewable Diesel:
Renewable diesel	739		899		2,864		2,311
Renewable naphtha	20		68		126		106
Total Renewable Diesel revenues	759		967		2,990		2,417
Ethanol:
Ethanol	861		966		2,522		2,820
Distillers grains	263		241		916		812
Total Ethanol revenues	1,124		1,207		3,438		3,632
Revenues	$	38,404	$	44,454	$	109,352	$	134,637

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

	September 30, 2023		December 31, 2022
Refining	$	49,171	$	48,484
Renewable Diesel	5,552		5,217
Ethanol	1,501		1,551
Corporate and eliminations	6,951		5,730
Total assets	$	63,175	$	60,982

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Supplemental Cash Flow Information

9 Months Ended

Sep. 30, 2023

Supplemental Cash Flow Information [Abstract]

SUPPLEMENTAL CASH FLOW INFORMATION

10.    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,
	2023		2022
Increase in current assets:
Receivables, net	$	(709)	$	(1,435)
Inventories	(720)		(703)
Prepaid expenses and other	(40)		(201)
Increase (decrease) in current liabilities:
Accounts payable	656		746
Accrued expenses	(31)		38
Taxes other than income taxes payable	(222)		(103)
Income taxes payable	(629)		41
Changes in current assets and current liabilities	$	(1,695)	$	(1,617)

Changes in current assets and current liabilities for the nine months ended September 30, 2023 were primarily due to the following:

•The increase in receivables was due to an increase in refined petroleum product prices in September 2023 compared to December 2022;

•The increase in inventories was due to an increase in inventory volumes in September 2023 compared to December 2022;

•The increase in accounts payable was due to an increase in crude oil and other feedstock prices in September 2023 compared to December 2022; and

•The decrease in income taxes payable was primarily due to income tax payments made during the nine months ended September 30, 2023.

Changes in current assets and current liabilities for the nine months ended September 30, 2022 were primarily due to the following:

•The increase in receivables was due to an increase in refined petroleum product prices in September 2022 compared to December 2021;

•The increase in inventories was due to an increase in inventory volumes valued at higher unit prices in September 2022 compared to December 2021; and

•The increase in accounts payable was due to an increase in crude oil and other feedstock prices in September 2022 compared to December 2021, partially offset by a decrease in related volumes purchased.

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

	Nine Months Ended September 30,
	2023		2022
Interest paid in excess of amount capitalized, including interest on finance leases	$	372	$	383
Income taxes paid, net	3,098		2,630

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

	Nine Months Ended September 30,
	2023				2022
	Operating Leases		Finance Leases		Operating Leases		Finance Leases
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows	$	316	$	81	$	296	$	59
Financing cash flows	—		190		—		129
Changes in lease balances resulting from new and modified leases	343		84		132		156

There were no significant noncash investing and financing activities during the nine months ended September 30, 2023 or 2022, except as noted in the table above.

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Fair Value Measurements

9 Months Ended

Sep. 30, 2023

Fair Value Disclosures [Abstract]

FAIR VALUE MEASUREMENTS

11.    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, 2023 and December 31, 2022.

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 on the balance sheet.

	September 30, 2023
							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	$	909	$	—	$	—	$	909	$	(907)	$	—	$	2	$	—
Foreign currency contracts	4		—		—		4		n/a		n/a		4		n/a
Investments of certain benefit plans	77		—		4		81		n/a		n/a		81		n/a
Investments in AFS debt securities	85		66		—		151		n/a		n/a		151		n/a
Total	$	1,075	$	66	$	4	$	1,145	$	(907)	$	—	$	238
Liabilities
Commodity derivative contracts	$	1,148	$	—	$	—	$	1,148	$	(907)	$	(241)	$	—	$	(141)
Blending program obligations	—		129		—		129		n/a		n/a		129		n/a
Physical purchase contracts	—		14		—		14		n/a		n/a		14		n/a
Total	$	1,148	$	143	$	—	$	1,291	$	(907)	$	(241)	$	143

	December 31, 2022
							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	$	830	$	—	$	—	$	830	$	(705)	$	(8)	$	117	$	—
Physical purchase contracts	—		4		—		4		n/a		n/a		4		n/a
Investments of certain benefit plans	72		—		6		78		n/a		n/a		78		n/a
Investments in AFS debt securities	56		165		—		221		n/a		n/a		221		n/a
Total	$	958	$	169	$	6	$	1,133	$	(705)	$	(8)	$	420
Liabilities
Commodity derivative contracts	$	705	$	—	$	—	$	705	$	(705)	$	—	$	—	$	(149)
Blending program obligations	—		55		—		55		n/a		n/a		55		n/a
Physical purchase contracts	—		4		—		4		n/a		n/a		4		n/a
Foreign currency contracts	2		—		—		2		n/a		n/a		2		n/a
Total	$	707	$	59	$	—	$	766	$	(705)	$	—	$	61

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 12. 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.

•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 were reflected in the following balance sheet line items, depending on their original maturities when acquired (in millions):

	September 30, 2023						December 31, 2022
	Level 1		Level 2		Total		Level 1		Level 2		Total
Cash and cash equivalents	$	—	$	33	$	33	$	—	$	125	$	125
Prepaid expenses and other	85		33		118		56		40		96
Investments in AFS debt securities	$	85	$	66	$	151	$	56	$	165	$	221

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, 2023. There were no AFS debt securities held as of and for the nine months ended September 30, 2022.

•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), the California Low Carbon Fuel Standard (LCFS), the Canada Clean Fuel Regulations, and similar programs in other jurisdictions in which we operate (collectively, the Renewable and Low-Carbon Fuel Programs). The blending program 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.

•Foreign currency contracts consist of foreign currency exchange and purchase contracts and foreign currency swap agreements 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

As previously disclosed in our annual report on Form 10-K for the year ended December 31, 2022, we concluded that our ethanol plant located in Lakota, Iowa (Lakota ethanol plant) was impaired as of December 31, 2022, which resulted in an asset impairment loss of $61 million. The fair value of the Lakota ethanol plant was determined using a combination of the income and market approaches and was classified in Level 3. We employed a probability-weighted approach to possible future cash flow scenarios, including the use of peer company metrics and comparison to a recent sales transaction.

There were no assets or liabilities that were measured at fair value on a nonrecurring basis as of September 30, 2023 and December 31, 2022, except as noted above.

Financial Instruments

Our financial instruments include cash and cash equivalents, 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, 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, 2023				December 31, 2022
	Fair Value Hierarchy	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Financial liabilities:
Debt (excluding finance lease obligations)	Level 2	$	9,150	$	8,549	$	9,241	$	8,902

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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Price Risk Management Activities

9 Months Ended

Sep. 30, 2023

Derivative Instruments and Hedging Activities Disclosure [Abstract]

PRICE RISK MANAGEMENT ACTIVITIES

12.    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 11), as summarized below under “Fair Values of Derivative Instruments.” The effect of these derivative instruments on our income and other comprehensive loss is summarized below under “Effect of Derivative Instruments on Income and Other Comprehensive 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 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 has been approved by our Board.

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.

As of September 30, 2023, 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
	2023	2024
Derivatives designated as cash flow hedges:
Refined petroleum products:
Futures – long	915	200
Futures – short	6,765	2,362
Derivatives designated as economic hedges:
Crude oil and refined petroleum products:
Futures – long	81,133	4,214
Futures – short	87,324	5,260
Corn:
Futures – long	66,695	90
Futures – short	82,415	3,290
Physical contracts – long	14,533	3,193

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, 2023, we had foreign currency contracts to purchase $630 million of U.S. dollars. All of these commitments matured on or before October 25, 2023.

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 $438 million and $461 million for the three months ended September 30, 2023 and 2022, respectively, and $1.2 billion and $984 million for the nine months ended September 30, 2023 and 2022, respectively. These amounts are reflected in cost of materials and other.

Fair Values of Derivative Instruments

The following table provides information about the fair values of our derivative instruments as of September 30, 2023 and December 31, 2022 (in millions) and the line items in the balance sheets in which the fair values are reflected. See Note 11 for additional information related to the fair values of our derivative instruments.

As indicated in Note 11, 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, 2023				December 31, 2022
		Asset Derivatives		Liability Derivatives		Asset Derivatives		Liability Derivatives
Derivatives designated as hedging instruments:
Commodity contracts	Receivables, net	$	10	$	19	$	61	$	44
Derivatives not designated as hedging instruments:
Commodity contracts	Receivables, net	$	899	$	1,129	$	769	$	661
Physical purchase contracts	Inventories	—		14		4		4
Foreign currency contracts	Receivables, net	4		—		—		—
Foreign currency contracts	Accrued expenses	—		—		—		2
Total		$	903	$	1,143	$	773	$	667

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 approved by our Board. 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.

Effect of Derivative Instruments on Income and Other Comprehensive Loss

The following table provides information about the gain (loss) recognized in income and other comprehensive 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,
		2023		2022		2023		2022
Commodity contracts:
Gain (loss) recognized in other comprehensive loss	n/a	$	(197)	$	79	$	(71)	$	(215)
Gain (loss) reclassified from accumulated other comprehensive loss into income	Revenues	(119)		10		(3)		(289)

For cash flow hedges, no component of any derivative instrument’s gains or losses was excluded from the assessment of hedge effectiveness for the three and nine months ended September 30, 2023 and 2022. For the three and nine months ended September 30, 2023 and 2022, cash flow hedges primarily related to forecasted sales of renewable diesel. As of September 30, 2023, the estimated deferred after-tax loss 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, 2023 and 2022 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 the 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,
		2023		2022		2023		2022
Commodity contracts	Revenues	$	(2)	$	(6)	$	(19)	$	(12)
Commodity contracts	Cost of materials and other	(48)		(109)		126		(976)
Commodity contracts	Operating expenses (excluding depreciation and amortization expense)	—		(18)		1		(9)
Foreign currency contracts	Cost of materials and other	19		57		(1)		104
Foreign currency contracts	Other income, net	—		(38)		—		(119)

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Pay vs Performance Disclosure - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Pay vs Performance Disclosure
Net income attributable to Valero stockholders	$ 2,622	$ 2,817	$ 7,633	$ 8,415

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Insider Trading Arrangements	3 Months Ended
	Sep. 30, 2023
Trading Arrangements, by Individual
Rule 10b5-1 Arrangement Adopted	false
Non-Rule 10b5-1 Arrangement Adopted	false
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false

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Basis of Presentation and Significant Accounting Policies (Policies)

9 Months Ended

Sep. 30, 2023

Accounting Policies [Abstract]

Basis of Presentation

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 disclosed otherwise. Operating results for the interim periods are not necessarily indicative of the results that may be expected for the year ending December 31, 2023. 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, 2022.

The balance sheet as of December 31, 2022 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, 2022.

Use of Estimates

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.

Variable interest entities

We consolidate a VIE when we have a variable interest in an entity for which we are the primary beneficiary.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.

Offsetting fair value amounts of commodity derivative contracts

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 on the balance sheet.

Derivatives

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 11), as summarized below under “Fair Values of Derivative Instruments.” The effect of these derivative instruments on our income and other comprehensive loss is summarized below under “Effect of Derivative Instruments on Income and Other Comprehensive Loss.”

Derivative instruments collateral requirements

We do not require any collateral or other security to support derivative instruments into which we enter.

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Inventories (Tables)

9 Months Ended

Sep. 30, 2023

Inventory Disclosure [Abstract]

Schedule of inventories

Inventories consisted of the following (in millions):

	September 30, 2023		December 31, 2022
Refinery feedstocks	$	1,878	$	1,949
Refined petroleum products and blendstocks	4,232		3,579
Renewable diesel feedstocks and products	797		583
Ethanol feedstocks and products	270		328
Materials and supplies	336		313
Inventories	$	7,513	$	6,752

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Debt (Tables)

9 Months Ended

Sep. 30, 2023

Debt Disclosure [Abstract]

Debt purchased and retired

In February 2023, we used cash on hand to purchase and retire a portion of the following notes (in millions):

Debt Purchased and Retired	Principal Amount
6.625% Senior Notes due 2037	$	62
3.650% Senior Notes due 2051	26
4.000% Senior Notes due 2052	45
Various other Valero and Valero Energy Partners (VLP) Senior Notes	66
Total	$	199

In September 2022, we used cash on hand to purchase and retire a portion of the following notes in connection with cash tender offers that we publicly announced in August 2022 and completed in September 2022 (in millions):

Debt Purchased and Retired	Principal Amount
3.65% Senior Notes due 2025	$	48
2.850% Senior Notes due 2025	291
4.375% VLP Senior Notes due 2026	62
3.400% Senior Notes due 2026	166
4.350% Senior Notes due 2028	131
4.000% Senior Notes due 2029	552
Total	$	1,250

The proceeds and cash on hand were used to purchase and retire a portion of the following notes in connection with cash tender offers that we publicly announced and completed in February 2022 (in millions):

Debt Purchased and Retired	Principal Amount
3.65% Senior Notes due 2025	$	72
2.850% Senior Notes due 2025	507
4.375% VLP Senior Notes due 2026	168
3.400% Senior Notes due 2026	653
Total	$	1,400

Summary of credit facilities

We had outstanding borrowings, letters of credit issued, and availability under our credit facilities as follows (amounts in millions and currency in U.S. dollars, except as noted):

				September 30, 2023
	Facility Amount		Maturity Date	Outstanding Borrowings		Letters of Credit Issued (a)		Availability
Committed facilities:
Valero Revolver	$	4,000	November 2027	$	—	$	4	$	3,996
Canadian Revolver (b)	C$	150	November 2023	C$	—	C$	5	C$	145
Accounts receivable sales facility	$	1,300	July 2024	$	—	n/a		$	1,300
Committed facilities of VIEs (c):
DGD Revolver (d)	$	400	June 2026	$	200	$	106	$	94
DGD Loan Agreement (e)	$	100	June 2026	$	—	n/a		$	100
IEnova Revolver (f)	$	830	February 2028	$	748	n/a		$	82
Uncommitted facilities:
Letter of credit facilities	n/a		n/a	n/a		$	177	n/a

________________________

(a)Letters of credit issued as of September 30, 2023 expire at various times in 2023 through 2026.

(b)On October 24, 2023, we amended this facility to (i) extend the maturity date to February 2024 and (ii) reduce the facility amount so that, effective October 31, 2023, the facility amount will equal the amount of the outstanding letters of credit thereunder, and will not permit further borrowings other than certain deemed borrowings to satisfy the reimbursement obligations under such letters of credit.

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

(d)In June 2023, DGD amended this facility to (i) extend the maturity date to June 2026 and (ii) transition the benchmark reference interest rate previously based on the London Interbank Offered Rate (LIBOR) to a secured overnight financing rate (SOFR). The variable interest rate on the DGD Revolver was 7.173 percent and 5.880 percent as of September 30, 2023 and December 31, 2022, respectively.

(e)The amounts shown for this facility 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. In April 2023, DGD extended the maturity date of this agreement to June 2023. In June 2023, DGD entered into a new unsecured revolving loan agreement that replaced and superseded the previous agreement. The new agreement includes the following modifications from the previous agreement: (i) extends the maturity date to June 2026, (ii) increases each member’s commitment from $25 million to $100 million, resulting in an increase in aggregate commitments from $50 million to $200 million, and (iii) transitions the benchmark reference interest rate previously based on the LIBOR to Term SOFR. The variable interest rate on the DGD Loan Agreement was 6.672 percent as of December 31, 2022.

(f)Both parties to this facility have agreed to use a SOFR as the interest rate applied to outstanding borrowings. The variable interest rate on the IEnova Revolver was 9.097 percent and 7.393 percent as of September 30, 2023 and December 31, 2022, respectively.

Activity under our credit facilities was as follows (in millions):

	Nine Months Ended September 30,
	2023		2022
Borrowings:
Accounts receivable sales facility	$	1,750	$	1,200
DGD Revolver	500		659
DGD Loan Agreement	—		25
IEnova Revolver	86		73
Repayments:
Accounts receivable sales facility	(1,750)		(1,200)
DGD Revolver	(400)		(659)
DGD Loan Agreement	(25)		(50)
IEnova Revolver	(55)		(47)

Interest and debt expense, net of capitalized interest

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

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Interest and debt expense	$	153	$	154	$	456	$	467
Less: Capitalized interest	4		16		13		42
Interest and debt expense, net of capitalized interest	$	149	$	138	$	443	$	425

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Equity (Tables)

9 Months Ended

Sep. 30, 2023

Equity [Abstract]

Changes in components of 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,
	2023								2022
	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	$	(774)	$	(193)	$	(4)	$	(971)	$	(991)	$	(430)	$	(4)	$	(1,425)
Other comprehensive income (loss) before reclassifications	(315)		—		(77)		(392)		(606)		—		30		(576)
Amounts reclassified from accumulated other comprehensive loss	—		(7)		47		40		—		7		(3)		4
Effect of exchange rates	—		(2)		—		(2)		—		—		—		—
Other comprehensive income (loss)	(315)		(9)		(30)		(354)		(606)		7		27		(572)
Balance as of end of period	$	(1,089)	$	(202)	$	(34)	$	(1,325)	$	(1,597)	$	(423)	$	23	$	(1,997)

	Nine Months Ended September 30,
	2023								2022
	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	$	(1,168)	$	(183)	$	(8)	$	(1,359)	$	(562)	$	(441)	$	(5)	$	(1,008)
Other comprehensive income (loss) before reclassifications	79		—		(28)		51		(1,035)		(2)		(84)		(1,121)
Amounts reclassified from accumulated other comprehensive loss	—		(20)		2		(18)		—		18		112		130
Effect of exchange rates	—		1		—		1		—		2		—		2
Other comprehensive income (loss)	79		(19)		(26)		34		(1,035)		18		28		(989)
Balance as of end of period	$	(1,089)	$	(202)	$	(34)	$	(1,325)	$	(1,597)	$	(423)	$	23	$	(1,997)

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Variable Interest Entities (Tables)

9 Months Ended

Sep. 30, 2023

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Summarized balance sheet information of consolidated VIEs

The following tables present 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, 2023
Assets
Cash and cash equivalents	$	198	$	—	$	25	$	223
Other current assets	1,387		8		30		1,425
Property, plant, and equipment, net	3,764		668		71		4,503
Liabilities
Current liabilities, including current portion of debt and finance lease obligations	$	549	$	799	$	18	$	1,366
Debt and finance lease obligations, less current portion	676		—		—		676

	DGD		Central Mexico Terminals		Other		Total
December 31, 2022
Assets
Cash and cash equivalents	$	133	$	—	$	16	$	149
Other current assets	1,106		7		32		1,145
Property, plant, and equipment, net	3,785		681		79		4,545
Liabilities
Current liabilities, including current portion of debt and finance lease obligations	$	626	$	737	$	21	$	1,384
Debt and finance lease obligations, less current portion	693		—		—		693

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Employee Benefit Plans (Tables)

9 Months Ended

Sep. 30, 2023

Retirement Benefits [Abstract]

Periodic benefit cost related to our defined benefit plans, net

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

	Pension Plans				Other Postretirement Benefit Plans
	2023		2022		2023		2022
Three months ended September 30
Service cost	$	28	$	37	$	1	$	1
Interest cost	30		22		3		2
Expected return on plan assets	(50)		(48)		—		—
Amortization of:
Net actuarial (gain) loss	(2)		14		(1)		—
Prior service credit	(5)		(5)		(1)		(1)
Settlement loss	—		12		—		—
Net periodic benefit cost	$	1	$	32	$	2	$	2
Nine months ended September 30
Service cost	$	84	$	114	$	3	$	4
Interest cost	90		64		9		6
Expected return on plan assets	(151)		(144)		—		—
Amortization of:
Net actuarial (gain) loss	(5)		40		(4)		—
Prior service credit	(14)		(14)		(3)		(3)
Settlement loss	—		12		—		—
Net periodic benefit cost	$	4	$	72	$	5	$	7

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Earnings Per Common Share (Tables)

9 Months Ended

Sep. 30, 2023

Earnings Per Share [Abstract]

Schedule of earnings per common share, basic and diluted

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,
	2023		2022		2023		2022
Earnings per common share:
Net income attributable to Valero stockholders	$	2,622	$	2,817	$	7,633	$	8,415
Less: Income allocated to participating securities	8		11		24		31
Net income available to common stockholders	$	2,614	$	2,806	$	7,609	$	8,384
Weighted-average common shares outstanding	349		390		359		400
Earnings per common share	$	7.49	$	7.20	$	21.22	$	20.94
Earnings per common share – assuming dilution:
Net income attributable to Valero stockholders	$	2,622	$	2,817	$	7,633	$	8,415
Less: Income allocated to participating securities	8		11		24		31
Net income available to common stockholders	$	2,614	$	2,806	$	7,609	$	8,384
Weighted-average common shares outstanding	349		390		359		400
Effect of dilutive securities	—		—		—		1
Weighted-average common shares outstanding – assuming dilution	349		390		359		401
Earnings per common share – assuming dilution	$	7.49	$	7.19	$	21.21	$	20.93

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Revenues and Segment Information (Tables)

9 Months Ended

Sep. 30, 2023

Segment Reporting [Abstract]

Schedule of contract balances

Contract balances were as follows (in millions):

	September 30, 2023		December 31, 2022
Receivables from contracts with customers, included in receivables, net	$	7,451	$	7,189
Contract liabilities, included in accrued expenses	38		129

Segment information for our reportable segments

The following tables reflect information about our operating income by reportable segment (in millions):

	Refining		Renewable Diesel		Ethanol		Corporate and Eliminations		Total
Three months ended September 30, 2023
Revenues:
Revenues from external customers	$	36,521	$	759	$	1,124	$	—	$	38,404
Intersegment revenues	8		672		310		(990)		—
Total revenues	36,529		1,431		1,434		(990)		38,404
Cost of sales:
Cost of materials and other (a)	31,115		1,169		1,092		(991)		32,385
Operating expenses (excluding depreciation and amortization expense reflected below)	1,366		84		125		3		1,578
Depreciation and amortization expense	597		55		20		(1)		671
Total cost of sales	33,078		1,308		1,237		(989)		34,634
Other operating expenses	6		—		—		—		6
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		250		250
Depreciation and amortization expense	—		—		—		11		11
Operating income by segment	$	3,445	$	123	$	197	$	(262)	$	3,503
Three months ended September 30, 2022
Revenues:
Revenues from external customers	$	42,280	$	967	$	1,207	$	—	$	44,454
Intersegment revenues	9		508		179		(696)		—
Total revenues	42,289		1,475		1,386		(696)		44,454
Cost of sales:
Cost of materials and other (a)	36,389		1,161		1,203		(689)		38,064
Operating expenses (excluding depreciation and amortization expense reflected below)	1,516		69		162		(1)		1,746
Depreciation and amortization expense	568		33		20		—		621
Total cost of sales	38,473		1,263		1,385		(690)		40,431
Other operating expenses	6		—		—		—		6
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		214		214
Depreciation and amortization expense	—		—		—		11		11
Operating income by segment	$	3,810	$	212	$	1	$	(231)	$	3,792

________________________

See note (a) on page 21.

	Refining		Renewable Diesel		Ethanol		Corporate and Eliminations		Total
Nine months ended September 30, 2023
Revenues:
Revenues from external customers	$	102,924	$	2,990	$	3,438	$	—	$	109,352
Intersegment revenues	8		2,367		790		(3,165)		—
Total revenues	102,932		5,357		4,228		(3,165)		109,352
Cost of sales:
Cost of materials and other (a)	87,398		4,143		3,422		(3,143)		91,820
Operating expenses (excluding depreciation and amortization expense reflected below)	3,832		274		383		6		4,495
Depreciation and amortization expense	1,751		172		59		(3)		1,979
Total cost of sales	92,981		4,589		3,864		(3,140)		98,294
Other operating expenses	17		—		1		—		18
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		703		703
Depreciation and amortization expense	—		—		—		32		32
Operating income by segment	$	9,934	$	768	$	363	$	(760)	$	10,305
Nine months ended September 30, 2022
Revenues:
Revenues from external customers	$	128,588	$	2,417	$	3,632	$	—	$	134,637
Intersegment revenues	24		1,490		507		(2,021)		—
Total revenues	128,612		3,907		4,139		(2,021)		134,637
Cost of sales:
Cost of materials and other (a)	111,308		3,129		3,533		(2,011)		115,959
Operating expenses (excluding depreciation and amortization expense reflected below)	4,111		178		464		(2)		4,751
Depreciation and amortization expense	1,682		87		37		—		1,806
Total cost of sales	117,101		3,394		4,034		(2,013)		122,516
Other operating expenses	38		—		2		—		40
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		652		652
Depreciation and amortization expense	—		—		—		34		34
Operating income by segment	$	11,473	$	513	$	103	$	(694)	$	11,395

________________________

(a)Cost of materials and other for our Renewable Diesel segment is net of the blender’s tax credit on qualified fuel mixtures of $266 million and $191 million for the three months ended September 30, 2023 and 2022, respectively, and $900 million and $545 million for the nine months ended September 30, 2023 and 2022, respectively.

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,
	2023		2022		2023		2022
Refining:
Gasolines and blendstocks	$	17,025	$	17,862	$	47,302	$	54,026
Distillates	16,392		20,481		47,222		62,352
Other product revenues	3,104		3,937		8,400		12,210
Total Refining revenues	36,521		42,280		102,924		128,588
Renewable Diesel:
Renewable diesel	739		899		2,864		2,311
Renewable naphtha	20		68		126		106
Total Renewable Diesel revenues	759		967		2,990		2,417
Ethanol:
Ethanol	861		966		2,522		2,820
Distillers grains	263		241		916		812
Total Ethanol revenues	1,124		1,207		3,438		3,632
Revenues	$	38,404	$	44,454	$	109,352	$	134,637

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

	September 30, 2023		December 31, 2022
Refining	$	49,171	$	48,484
Renewable Diesel	5,552		5,217
Ethanol	1,501		1,551
Corporate and eliminations	6,951		5,730
Total assets	$	63,175	$	60,982

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Supplemental Cash Flow Information (Tables)

9 Months Ended

Sep. 30, 2023

Supplemental Cash Flow Information [Abstract]

Schedule of cash flows, supplemental disclosures

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,
	2023		2022
Increase in current assets:
Receivables, net	$	(709)	$	(1,435)
Inventories	(720)		(703)
Prepaid expenses and other	(40)		(201)
Increase (decrease) in current liabilities:
Accounts payable	656		746
Accrued expenses	(31)		38
Taxes other than income taxes payable	(222)		(103)
Income taxes payable	(629)		41
Changes in current assets and current liabilities	$	(1,695)	$	(1,617)

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

	Nine Months Ended September 30,
	2023		2022
Interest paid in excess of amount capitalized, including interest on finance leases	$	372	$	383
Income taxes paid, net	3,098		2,630

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

	Nine Months Ended September 30,
	2023				2022
	Operating Leases		Finance Leases		Operating Leases		Finance Leases
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows	$	316	$	81	$	296	$	59
Financing cash flows	—		190		—		129
Changes in lease balances resulting from new and modified leases	343		84		132		156

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Fair Value Measurements (Tables)

9 Months Ended

Sep. 30, 2023

Fair Value Disclosures [Abstract]

Fair value of assets and liabilities measured on recurring basis

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, 2023 and December 31, 2022.

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 on the balance sheet.

	September 30, 2023
							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	$	909	$	—	$	—	$	909	$	(907)	$	—	$	2	$	—
Foreign currency contracts	4		—		—		4		n/a		n/a		4		n/a
Investments of certain benefit plans	77		—		4		81		n/a		n/a		81		n/a
Investments in AFS debt securities	85		66		—		151		n/a		n/a		151		n/a
Total	$	1,075	$	66	$	4	$	1,145	$	(907)	$	—	$	238
Liabilities
Commodity derivative contracts	$	1,148	$	—	$	—	$	1,148	$	(907)	$	(241)	$	—	$	(141)
Blending program obligations	—		129		—		129		n/a		n/a		129		n/a
Physical purchase contracts	—		14		—		14		n/a		n/a		14		n/a
Total	$	1,148	$	143	$	—	$	1,291	$	(907)	$	(241)	$	143

	December 31, 2022
							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	$	830	$	—	$	—	$	830	$	(705)	$	(8)	$	117	$	—
Physical purchase contracts	—		4		—		4		n/a		n/a		4		n/a
Investments of certain benefit plans	72		—		6		78		n/a		n/a		78		n/a
Investments in AFS debt securities	56		165		—		221		n/a		n/a		221		n/a
Total	$	958	$	169	$	6	$	1,133	$	(705)	$	(8)	$	420
Liabilities
Commodity derivative contracts	$	705	$	—	$	—	$	705	$	(705)	$	—	$	—	$	(149)
Blending program obligations	—		55		—		55		n/a		n/a		55		n/a
Physical purchase contracts	—		4		—		4		n/a		n/a		4		n/a
Foreign currency contracts	2		—		—		2		n/a		n/a		2		n/a
Total	$	707	$	59	$	—	$	766	$	(705)	$	—	$	61

The securities were reflected in the following balance sheet line items, depending on their original maturities when acquired (in millions):

	September 30, 2023						December 31, 2022
	Level 1		Level 2		Total		Level 1		Level 2		Total
Cash and cash equivalents	$	—	$	33	$	33	$	—	$	125	$	125
Prepaid expenses and other	85		33		118		56		40		96
Investments in AFS debt securities	$	85	$	66	$	151	$	56	$	165	$	221

Carrying amount and estimated fair value of financial instruments

The estimated fair values of cash and cash equivalents, 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, 2023				December 31, 2022
	Fair Value Hierarchy	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Financial liabilities:
Debt (excluding finance lease obligations)	Level 2	$	9,150	$	8,549	$	9,241	$	8,902

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Price Risk Management Activities (Tables)

9 Months Ended

Sep. 30, 2023

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Risk management activities by type of risk

As of September 30, 2023, 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
	2023	2024
Derivatives designated as cash flow hedges:
Refined petroleum products:
Futures – long	915	200
Futures – short	6,765	2,362
Derivatives designated as economic hedges:
Crude oil and refined petroleum products:
Futures – long	81,133	4,214
Futures – short	87,324	5,260
Corn:
Futures – long	66,695	90
Futures – short	82,415	3,290
Physical contracts – long	14,533	3,193

Fair values of derivative instruments

The following table provides information about the fair values of our derivative instruments as of September 30, 2023 and December 31, 2022 (in millions) and the line items in the balance sheets in which the fair values are reflected. See Note 11 for additional information related to the fair values of our derivative instruments.

As indicated in Note 11, 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, 2023				December 31, 2022
		Asset Derivatives		Liability Derivatives		Asset Derivatives		Liability Derivatives
Derivatives designated as hedging instruments:
Commodity contracts	Receivables, net	$	10	$	19	$	61	$	44
Derivatives not designated as hedging instruments:
Commodity contracts	Receivables, net	$	899	$	1,129	$	769	$	661
Physical purchase contracts	Inventories	—		14		4		4
Foreign currency contracts	Receivables, net	4		—		—		—
Foreign currency contracts	Accrued expenses	—		—		—		2
Total		$	903	$	1,143	$	773	$	667

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 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,
		2023		2022		2023		2022
Commodity contracts:
Gain (loss) recognized in other comprehensive loss	n/a	$	(197)	$	79	$	(71)	$	(215)
Gain (loss) reclassified from accumulated other comprehensive loss into income	Revenues	(119)		10		(3)		(289)

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 the 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,
		2023		2022		2023		2022
Commodity contracts	Revenues	$	(2)	$	(6)	$	(19)	$	(12)
Commodity contracts	Cost of materials and other	(48)		(109)		126		(976)
Commodity contracts	Operating expenses (excluding depreciation and amortization expense)	—		(18)		1		(9)
Foreign currency contracts	Cost of materials and other	19		57		(1)		104
Foreign currency contracts	Other income, net	—		(38)		—		(119)

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Uncertainty (Details)	9 Months Ended
	Sep. 30, 2023 refinery
California [Member]
Uncertainty (Textual)
Number of refineries	2

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Inventories (Details) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Schedule of Inventories
Refinery feedstocks	$ 1,878	$ 1,949
Refined petroleum products and blendstocks	4,232	3,579
Renewable diesel feedstocks and products	797	583
Ethanol feedstocks and products	270	328
Materials and supplies	336	313
Inventories	$ 7,513	$ 6,752

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Inventories (Details) (Narrative) - USD ($) $ in Billions	Sep. 30, 2023	Dec. 31, 2022
Inventories (Textual)
Excess of market value over carrying amount of LIFO inventories	$ 6.1	$ 6.3
Amount of non-LIFO inventory	$ 1.3	$ 1.6

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Debt, Public Debt (Details) - USD ($)	1 Months Ended
	Feb. 28, 2023	Sep. 30, 2022	Jun. 30, 2022	Feb. 28, 2022
Senior Notes [Member]
Debt Purchased and Retired
Debt purchased and retired amount	$ 199,000,000	$ 1,250,000,000		$ 1,400,000,000
Senior Notes [Member] | 6.625% Valero Senior Notes due 2037 [Member]
Debt Purchased and Retired
Interest rate of notes (percent)	6.625%
Debt purchased and retired amount	$ 62,000,000
Senior Notes [Member] | 3.650% Valero Senior Notes due 2051 [Member]
Debt Purchased and Retired
Interest rate of notes (percent)	3.65%
Debt purchased and retired amount	$ 26,000,000
Senior Notes [Member] | 4.000% Valero Senior Notes due 2052 [Member]
Debt Purchased and Retired
Interest rate of notes (percent)	4.00%			4.00%
Debt purchased and retired amount	$ 45,000,000
Public Debt (Textual)
Face amount of long-term debt issuance				$ 650,000,000
Proceeds from issuance of senior long-term debt				$ 639,000,000
Senior Notes [Member] | Various other Valero and Valero Energy Partners (VLP) Senior Notes [Member]
Debt Purchased and Retired
Debt purchased and retired amount	$ 66,000,000
Senior Notes [Member] | 3.65% Valero Senior Notes due 2025 [Member]
Debt Purchased and Retired
Interest rate of notes (percent)		3.65%		3.65%
Debt purchased and retired amount		$ 48,000,000		$ 72,000,000
Senior Notes [Member] | 2.850% Valero Senior Notes due 2025 [Member]
Debt Purchased and Retired
Interest rate of notes (percent)		2.85%		2.85%
Debt purchased and retired amount		$ 291,000,000		$ 507,000,000
Senior Notes [Member] | 4.375% VLP Senior Notes due 2026 [Member]
Debt Purchased and Retired
Interest rate of notes (percent)		4.375%		4.375%
Debt purchased and retired amount		$ 62,000,000		$ 168,000,000
Senior Notes [Member] | 3.400% Valero Senior Notes due 2026 [Member]
Debt Purchased and Retired
Interest rate of notes (percent)		3.40%		3.40%
Debt purchased and retired amount		$ 166,000,000		$ 653,000,000
Senior Notes [Member] | 4.350% Valero Senior Notes due 2028 [Member]
Debt Purchased and Retired
Interest rate of notes (percent)		4.35%
Debt purchased and retired amount		$ 131,000,000
Senior Notes [Member] | 4.000% Valero Senior Notes due 2029 [Member]
Debt Purchased and Retired
Interest rate of notes (percent)		4.00%
Debt purchased and retired amount		$ 552,000,000
Revenue Bonds [Member] | Gulf Opportunity Zone Revenue Bonds Series 2010 due 2040 [Member]
Debt Purchased and Retired
Interest rate of notes (percent)			4.00%
Public Debt (Textual)
Repayments of long-term debt			$ 300,000,000

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Debt, Credit Facilities (Details)		Sep. 30, 2023 USD ($)		Sep. 30, 2023 CAD ($)	Jun. 30, 2023 USD ($)	May 31, 2023 USD ($)	Dec. 31, 2022
Valero Revolver [Member] | Credit Facilities [Member]
Line of Credit Facility
Facility amount		$ 4,000,000,000
Outstanding borrowings, long term		0
Availability		3,996,000,000
Valero Revolver Letter of Credit [Member] | Credit Facilities [Member]
Line of Credit Facility
Letters of credit issued	[1]	4,000,000
Canadian Revolver [Member] | Credit Facilities [Member]
Line of Credit Facility
Facility amount	[2]			$ 150,000,000
Outstanding borrowings, short-term	[2]			0
Availability	[2]			145,000,000
Canadian Revolver Letter of Credit [Member] | Credit Facilities [Member]
Line of Credit Facility
Letters of credit issued	[1],[2]			$ 5,000,000
Accounts Receivable Sales Facility [Member] | Credit Facilities [Member]
Line of Credit Facility
Facility amount		1,300,000,000
Outstanding borrowings, short-term		0
Availability		1,300,000,000
DGD Revolver [Member] | Credit Facilities [Member] | Diamond Green Diesel Holdings LLC [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Line of Credit Facility
Facility amount	[3],[4]	400,000,000
Outstanding borrowings, long term	[3],[4]	200,000,000
Availability	[3],[4]	$ 94,000,000
Interest rate at period end (percent)		7.173%		7.173%			5.88%
DGD Revolver Letter Of Credit [Member] | Credit Facilities [Member] | Diamond Green Diesel Holdings LLC [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Line of Credit Facility
Letters of credit issued	[1],[3],[4]	$ 106,000,000
DGD Loan Agreement [Member] | Credit Facilities [Member] | Diamond Green Diesel Holdings LLC [Member] | Darling Ingredients Inc. [Member]
Line of Credit Facility
Facility amount						$ 25,000,000
DGD Loan Agreement [Member] | Credit Facilities [Member] | Diamond Green Diesel Holdings LLC [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Line of Credit Facility
Facility amount						50,000,000
Interest rate at period end (percent)							6.672%
DGD Loan Agreement [Member] | Credit Facilities [Member] | Diamond Green Diesel Holdings LLC [Member] | Variable Interest Entity, Primary Beneficiary [Member] | Valero Energy Corporation [Member]
Line of Credit Facility
Facility amount						$ 25,000,000
DGD Loan Agreement [Member] | Credit Facilities [Member] | Diamond Green Diesel Holdings LLC [Member] | Darling Ingredients Inc. [Member]
Line of Credit Facility
Facility amount		100,000,000			$ 100,000,000
DGD Loan Agreement [Member] | Credit Facilities [Member] | Diamond Green Diesel Holdings LLC [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Line of Credit Facility
Facility amount					200,000,000
DGD Loan Agreement [Member] | Credit Facilities [Member] | Diamond Green Diesel Holdings LLC [Member] | Variable Interest Entity, Primary Beneficiary [Member] | Valero Energy Corporation [Member]
Line of Credit Facility
Facility amount		100,000,000	[3],[5]		$ 100,000,000
Outstanding borrowings, long term	[3],[5]	0
Availability	[3],[5]	100,000,000
IEnova Revolver [Member] | Credit Facilities [Member] | Central Mexico Terminals [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Line of Credit Facility
Facility amount	[3],[6]	830,000,000
Outstanding borrowings, long term	[3],[6]	748,000,000
Availability	[3],[6]	$ 82,000,000
Interest rate at period end (percent)		9.097%		9.097%			7.393%
Uncommitted Letter of Credit Facility [Member] | Credit Facilities [Member]
Line of Credit Facility
Letters of credit issued	[1]	$ 177,000,000

[1] Letters of credit issued as of September 30, 2023 expire at various times in 2023 through 2026.

[2] On October 24, 2023, we amended this facility to (i) extend the maturity date to February 2024 and (ii) reduce the facility amount so that, effective October 31, 2023, the facility amount will equal the amount of the outstanding letters of credit thereunder, and will not permit further borrowings other than certain deemed borrowings to satisfy the reimbursement obligations under such letters of credit.

[3] Creditors of the VIEs do not have recourse against us.

[4] In June 2023, DGD amended this facility to (i) extend the maturity date to June 2026 and (ii) transition the benchmark reference interest rate previously based on the London Interbank Offered Rate (LIBOR) to a secured overnight financing rate (SOFR). The variable interest rate on the DGD Revolver was 7.173 percent and 5.880 percent as of September 30, 2023 and December 31, 2022, respectively.

[5] The amounts shown for this facility 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. In April 2023, DGD extended the maturity date of this agreement to June 2023. In June 2023, DGD entered into a new unsecured revolving loan agreement that replaced and superseded the previous agreement. The new agreement includes the following modifications from the previous agreement: (i) extends the maturity date to June 2026, (ii) increases each member’s commitment from $25 million to $100 million, resulting in an increase in aggregate commitments from $50 million to $200 million, and (iii) transitions the benchmark reference interest rate previously based on the LIBOR to Term SOFR. The variable interest rate on the DGD Loan Agreement was 6.672 percent as of December 31, 2022.

[6] Both parties to this facility have agreed to use a SOFR as the interest rate applied to outstanding borrowings. The variable interest rate on the IEnova Revolver was 9.097 percent and 7.393 percent as of September 30, 2023 and December 31, 2022, respectively.

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Debt, Activity Under Credit Facilities (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
Accounts Receivable Sales Facility [Member] | Line of Credit [Member]
Line of Credit Facility
Borrowings, short-term credit facilities	$ 1,750	$ 1,200
Repayments, short-term credit facilities	(1,750)	(1,200)
DGD Revolver [Member] | Line of Credit [Member] | DGD [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Line of Credit Facility
Borrowings, long-term credit facilities	500	659
Repayments, long-term credit facilities	(400)	(659)
DGD Loan Agreement [Member] | Line of Credit [Member] | DGD [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Line of Credit Facility
Borrowings, long-term credit facilities	0	25
Repayments, long-term credit facilities	(25)	(50)
IEnova Revolver [Member] | Line of Credit [Member] | Central Mexico Terminals [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Line of Credit Facility
Borrowings, long-term credit facilities	86	73
Repayments, long-term credit facilities	$ (55)	$ (47)

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Debt, Interest Incurred (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Interest and Debt Expense, Net of Capitalized Interest
Interest and debt expense	$ 153	$ 154	$ 456	$ 467
Less: Capitalized interest	4	16	13	42
Interest and debt expense, net of capitalized interest	$ 149	$ 138	$ 443	$ 425

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Equity, Narrative (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022	Sep. 15, 2023	Feb. 23, 2023	Oct. 26, 2022
Stock Purchase Program Approved October 2022 [Member]
Equity (Textual)
Authorized amount under stock purchase programs							$ 2,500,000,000
Stock Purchase Program Approved February 2023 [Member]
Equity (Textual)
Authorized amount under stock purchase programs						$ 2,500,000,000
Remaining amount authorized under stock purchase program	$ 649,000,000		$ 649,000,000
Stock Purchase Program Approved September 2023 [Member]
Equity (Textual)
Authorized amount under stock purchase programs					$ 2,500,000,000
Treasury Stock [Member]
Equity (Textual)
Purchases of common stock for treasury (shares)	12,805,162	8,444,754	32,219,955	24,202,035

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Equity, Changes in Accumulated Other Comprehensive Loss (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Changes in Accumulated Other Comprehensive Loss, By Component, Net of Tax
Balance as of beginning of period	$ 27,994	$ 22,733	$ 25,468	$ 19,817
Other comprehensive income (loss)	(393)	(538)	0	(952)
Balance as of end of period	28,057	23,715	28,057	23,715
Accumulated Other Comprehensive Loss [Member]
Changes in Accumulated Other Comprehensive Loss, By Component, Net of Tax
Balance as of beginning of period	(971)	(1,425)	(1,359)	(1,008)
Other comprehensive income (loss) before reclassifications	(392)	(576)	51	(1,121)
Amounts reclassified from accumulated other comprehensive  loss	40	4	(18)	130
Effect of exchange rates	(2)	0	1	2
Other comprehensive income (loss)	(354)	(572)	34	(989)
Balance as of end of period	(1,325)	(1,997)	(1,325)	(1,997)
Foreign Currency Translation Adjustment [Member]
Changes in Accumulated Other Comprehensive Loss, By Component, Net of Tax
Balance as of beginning of period	(774)	(991)	(1,168)	(562)
Other comprehensive income (loss) before reclassifications	(315)	(606)	79	(1,035)
Amounts reclassified from accumulated other comprehensive  loss	0	0	0	0
Effect of exchange rates	0	0	0	0
Other comprehensive income (loss)	(315)	(606)	79	(1,035)
Balance as of end of period	(1,089)	(1,597)	(1,089)	(1,597)
Defined Benefit Plans Items [Member]
Changes in Accumulated Other Comprehensive Loss, By Component, Net of Tax
Balance as of beginning of period	(193)	(430)	(183)	(441)
Other comprehensive income (loss) before reclassifications	0	0	0	(2)
Amounts reclassified from accumulated other comprehensive  loss	(7)	7	(20)	18
Effect of exchange rates	(2)	0	1	2
Other comprehensive income (loss)	(9)	7	(19)	18
Balance as of end of period	(202)	(423)	(202)	(423)
Gains (Losses) on Cash Flow Hedges [Member]
Changes in Accumulated Other Comprehensive Loss, By Component, Net of Tax
Balance as of beginning of period	(4)	(4)	(8)	(5)
Other comprehensive income (loss) before reclassifications	(77)	30	(28)	(84)
Amounts reclassified from accumulated other comprehensive  loss	47	(3)	2	112
Effect of exchange rates	0	0	0	0
Other comprehensive income (loss)	(30)	27	(26)	28
Balance as of end of period	$ (34)	$ 23	$ (34)	$ 23

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Variable Interest Entities (Details) (Narrative)	Sep. 30, 2023 plant subsidiary
Diamond Green Diesel Holdings LLC (DGD) [Member]
Variable Interest Entity (Textual)
Number of renewable diesel plants owned by joint venture | plant	2
Central Mexico Terminals [Member]
Variable Interest Entity (Textual)
Number of subsidiaries | subsidiary	3

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Variable Interest Entities (Details) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Assets
Cash and cash equivalents	$ 5,831	$ 4,862
Property, plant, and equipment, net	30,253	30,978
Liabilities
Current liabilities, including current portion of debt and finance lease obligations	17,592	17,461
Debt and finance lease obligations, less current portion	10,107	10,526
Variable Interest Entity, Primary Beneficiary [Member]
Assets
Cash and cash equivalents	223	149
Other current assets	1,425	1,145
Property, plant, and equipment, net	4,503	4,545
Liabilities
Current liabilities, including current portion of debt and finance lease obligations	1,366	1,384
Debt and finance lease obligations, less current portion	676	693
Diamond Green Diesel Holdings LLC (DGD) [Member]
Assets
Cash and cash equivalents	198	133
Other current assets	1,387	1,106
Property, plant, and equipment, net	3,764	3,785
Liabilities
Current liabilities, including current portion of debt and finance lease obligations	549	626
Debt and finance lease obligations, less current portion	676	693
Central Mexico Terminals [Member]
Assets
Cash and cash equivalents	0	0
Other current assets	8	7
Property, plant, and equipment, net	668	681
Liabilities
Current liabilities, including current portion of debt and finance lease obligations	799	737
Debt and finance lease obligations, less current portion	0	0
Other VIEs [Member]
Assets
Cash and cash equivalents	25	16
Other current assets	30	32
Property, plant, and equipment, net	71	79
Liabilities
Current liabilities, including current portion of debt and finance lease obligations	18	21
Debt and finance lease obligations, less current portion	$ 0	$ 0

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Employee Benefit Plans (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Pension Plans [Member]
Components of net periodic benefit cost:
Service cost	$ 28	$ 37	$ 84	$ 114
Interest cost	30	22	90	64
Expected return on plan assets	(50)	(48)	(151)	(144)
Amortization of:
Net actuarial (gain) loss	(2)	14	(5)	40
Prior service credit	(5)	(5)	(14)	(14)
Settlement loss	0	12	0	12
Net periodic benefit cost	1	32	4	72
Other Postretirement Benefit Plans [Member]
Components of net periodic benefit cost:
Service cost	1	1	3	4
Interest cost	3	2	9	6
Expected return on plan assets	0	0	0	0
Amortization of:
Net actuarial (gain) loss	(1)	0	(4)	0
Prior service credit	(1)	(1)	(3)	(3)
Settlement loss	0	0	0	0
Net periodic benefit cost	$ 2	$ 2	$ 5	$ 7

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Earnings Per Common Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Earnings per common share:
Net income attributable to Valero stockholders	$ 2,622	$ 2,817	$ 7,633	$ 8,415
Less: Income allocated to participating securities	8	11	24	31
Net income available to common stockholders	$ 2,614	$ 2,806	$ 7,609	$ 8,384
Weighted-average common shares outstanding (in shares)	349	390	359	400
Earnings per common share (in dollars per share)	$ 7.49	$ 7.20	$ 21.22	$ 20.94
Earnings per common share – assuming dilution:
Net income attributable to Valero stockholders	$ 2,622	$ 2,817	$ 7,633	$ 8,415
Less: Income allocated to participating securities	8	11	24	31
Net income available to common stockholders	$ 2,614	$ 2,806	$ 7,609	$ 8,384
Weighted-average common shares outstanding (in shares)	349	390	359	400
Effect of dilutive securities (in shares)	0	0	0	1
Weighted-average common shares outstanding – assuming dilution (in shares)	349	390	359	401
Earnings per common share – assuming dilution (in dollars per share)	$ 7.49	$ 7.19	$ 21.21	$ 20.93

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Revenues and Segment Information, Contract Balances (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Dec. 31, 2022
Segment Reporting [Abstract]
Receivables from contracts with customers, included in receivables, net	$ 7,451		$ 7,189
Contract liabilities, included in accrued expenses	38		$ 129
Contract Balances (Textual)
Revenue recognized that was included in contract liabilities as of prior year end	$ 125	$ 74

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Revenues and Segment Information, Components of Operating Income (Loss) (Details) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2023 USD ($)	Sep. 30, 2022 USD ($)	Sep. 30, 2023 USD ($) segment	Sep. 30, 2022 USD ($)
Segment Information for our Reportable Segments
Revenues	[1]	$ 38,404	$ 44,454	$ 109,352	$ 134,637
Cost of sales:
Cost of materials and other	[2]	32,385	38,064	91,820	115,959
Operating expenses (excluding depreciation and amortization expense reflected below)		1,578	1,746	4,495	4,751
Depreciation and amortization expense		671	621	1,979	1,806
Total cost of sales		34,634	40,431	98,294	122,516
Other operating expenses		6	6	18	40
General and administrative expenses (excluding depreciation and amortization expense reflected below)		250	214	703	652
Depreciation and amortization expense		11	11	32	34
Operating income		3,503	3,792	$ 10,305	11,395
Segment Information (Textual)
Number of reportable segments | segment				3
Corporate, Reconciling Items And Eliminations [Member]
Segment Information for our Reportable Segments
Revenues		(990)	(696)	$ (3,165)	(2,021)
Cost of sales:
Operating income		(262)	(231)	(760)	(694)
Corporate [Member]
Segment Information for our Reportable Segments
Revenues		0	0	0	0
Cost of sales:
General and administrative expenses (excluding depreciation and amortization expense reflected below)		250	214	703	652
Depreciation and amortization expense		11	11	32	34
Intersegment Eliminations [Member]
Segment Information for our Reportable Segments
Revenues		(990)	(696)	(3,165)	(2,021)
Cost of sales:
Cost of materials and other	[2]	(991)	(689)	(3,143)	(2,011)
Operating expenses (excluding depreciation and amortization expense reflected below)		3	(1)	6	(2)
Depreciation and amortization expense		(1)	0	(3)	0
Total cost of sales		(989)	(690)	(3,140)	(2,013)
Other operating expenses		0	0	0	0
Refining [Member]
Segment Information for our Reportable Segments
Revenues		36,521	42,280	102,924	128,588
Refining [Member] | Operating Segments [Member]
Segment Information for our Reportable Segments
Revenues		36,529	42,289	102,932	128,612
Cost of sales:
Cost of materials and other	[2]	31,115	36,389	87,398	111,308
Operating expenses (excluding depreciation and amortization expense reflected below)		1,366	1,516	3,832	4,111
Depreciation and amortization expense		597	568	1,751	1,682
Total cost of sales		33,078	38,473	92,981	117,101
Other operating expenses		6	6	17	38
General and administrative expenses (excluding depreciation and amortization expense reflected below)		0	0	0	0
Depreciation and amortization expense		0	0	0	0
Operating income		3,445	3,810	9,934	11,473
Refining [Member] | Intersegment Eliminations [Member]
Segment Information for our Reportable Segments
Revenues		8	9	8	24
Renewable Diesel [Member]
Segment Information for our Reportable Segments
Revenues		759	967	2,990	2,417
Renewable Diesel [Member] | Operating Segments [Member]
Segment Information for our Reportable Segments
Revenues		1,431	1,475	5,357	3,907
Cost of sales:
Cost of materials and other	[2]	1,169	1,161	4,143	3,129
Operating expenses (excluding depreciation and amortization expense reflected below)		84	69	274	178
Depreciation and amortization expense		55	33	172	87
Total cost of sales		1,308	1,263	4,589	3,394
Other operating expenses		0	0	0	0
General and administrative expenses (excluding depreciation and amortization expense reflected below)		0	0	0	0
Depreciation and amortization expense		0	0	0	0
Operating income		123	212	768	513
Segment Information (Textual)
Blender's tax credit		266	191	900	545
Renewable Diesel [Member] | Intersegment Eliminations [Member]
Segment Information for our Reportable Segments
Revenues		672	508	2,367	1,490
Ethanol [Member]
Segment Information for our Reportable Segments
Revenues		1,124	1,207	3,438	3,632
Ethanol [Member] | Operating Segments [Member]
Segment Information for our Reportable Segments
Revenues		1,434	1,386	4,228	4,139
Cost of sales:
Cost of materials and other	[2]	1,092	1,203	3,422	3,533
Operating expenses (excluding depreciation and amortization expense reflected below)		125	162	383	464
Depreciation and amortization expense		20	20	59	37
Total cost of sales		1,237	1,385	3,864	4,034
Other operating expenses		0	0	1	2
General and administrative expenses (excluding depreciation and amortization expense reflected below)		0	0	0	0
Depreciation and amortization expense		0	0	0	0
Operating income		197	1	363	103
Ethanol [Member] | Intersegment Eliminations [Member]
Segment Information for our Reportable Segments
Revenues		$ 310	$ 179	$ 790	$ 507

[1] Includes excise taxes on sales by certain of our foreign operations of $1,468 million and $1,213 million for the three months ended September 30, 2023 and 2022, respectively, and $4,339 million and $3,890 million for the nine months ended September 30, 2023 and 2022, respectively.

[2] Cost of materials and other for our Renewable Diesel segment is net of the blender’s tax credit on qualified fuel mixtures of $266 million and $191 million for the three months ended September 30, 2023 and 2022, respectively, and $900 million and $545 million for the nine months ended September 30, 2023 and 2022, respectively.

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Revenues and Segment Information, Disaggregation of Revenue by Product (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Revenue by Segment
Revenues	[1]	$ 38,404	$ 44,454	$ 109,352	$ 134,637
Refining [Member]
Revenue by Segment
Revenues		36,521	42,280	102,924	128,588
Refining [Member] | Gasoline and Blendstocks [Member]
Revenue by Segment
Revenues		17,025	17,862	47,302	54,026
Refining [Member] | Distillates [Member]
Revenue by Segment
Revenues		16,392	20,481	47,222	62,352
Refining [Member] | Other Product Revenues [Member]
Revenue by Segment
Revenues		3,104	3,937	8,400	12,210
Renewable Diesel [Member]
Revenue by Segment
Revenues		759	967	2,990	2,417
Renewable Diesel [Member] | Renewable Diesel [Member]
Revenue by Segment
Revenues		739	899	2,864	2,311
Renewable Diesel [Member] | Renewable Naphtha [Member]
Revenue by Segment
Revenues		20	68	126	106
Ethanol [Member]
Revenue by Segment
Revenues		1,124	1,207	3,438	3,632
Ethanol [Member] | Ethanol [Member]
Revenue by Segment
Revenues		861	966	2,522	2,820
Ethanol [Member] | Distillers Grains [Member]
Revenue by Segment
Revenues		$ 263	$ 241	$ 916	$ 812

[1] Includes excise taxes on sales by certain of our foreign operations of $1,468 million and $1,213 million for the three months ended September 30, 2023 and 2022, respectively, and $4,339 million and $3,890 million for the nine months ended September 30, 2023 and 2022, respectively.

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Revenues and Segment Information, Assets (Details) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Total Assets by Reportable Segment
Reportable segment assets	$ 63,175	$ 60,982
Corporate and Eliminations [Member]
Total Assets by Reportable Segment
Reportable segment assets	6,951	5,730
Refining [Member] | Operating Segments [Member]
Total Assets by Reportable Segment
Reportable segment assets	49,171	48,484
Renewable Diesel [Member] | Operating Segments [Member]
Total Assets by Reportable Segment
Reportable segment assets	5,552	5,217
Ethanol [Member] | Operating Segments [Member]
Total Assets by Reportable Segment
Reportable segment assets	$ 1,501	$ 1,551

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Supplemental Cash Flow Information (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
Increase in current assets:
Receivables, net	$ (709)	$ (1,435)
Inventories	(720)	(703)
Prepaid expenses and other	(40)	(201)
Increase (decrease) in current liabilities:
Accounts payable	656	746
Accrued expenses	(31)	38
Taxes other than income taxes payable	(222)	(103)
Income taxes payable	(629)	41
Changes in current assets and current liabilities	(1,695)	(1,617)
Cash Flows Related to Interest and Income Taxes
Interest paid in excess of amount capitalized, including interest on finance leases	372	383
Income taxes paid, net	3,098	2,630
Operating cash flows
Operating Leases	316	296
Finance Leases	81	59
Financing cash flows
Finance Leases	190	129
Changes in lease balances resulting from new and modified leases, Operating Leases	343	132
Changes in lease balances resulting from new and modified leases, Finance Leases	$ 84	$ 156

XML

Fair Value Measurements, Recurring (Details) - USD ($)	Sep. 30, 2023	Dec. 31, 2022	Sep. 30, 2022
Assets
Investments in AFS debt securities			$ 0
Fair Value, Recurring [Member]
Assets
Investments in AFS debt securities	$ 151,000,000	$ 221,000,000
Total gross fair value, assets	1,145,000,000	1,133,000,000
Effect of counterparty netting	(907,000,000)	(705,000,000)
Effect of cash collateral netting	0	(8,000,000)
Net carrying value on Balance Sheet, assets	238,000,000	420,000,000
Liabilities
Blending program obligations	129,000,000	55,000,000
Total gross fair value, liabilities	1,291,000,000	766,000,000
Effect of counterparty netting	(907,000,000)	(705,000,000)
Effect of cash collateral netting	(241,000,000)	0
Net carrying value on Balance Sheet, liabilities	143,000,000	61,000,000
Fair Value, Recurring [Member] | Cash and Cash Equivalents [Member]
Assets
Investments in AFS debt securities	33,000,000	125,000,000
Fair Value, Recurring [Member] | Prepaid Expenses and Other [Member]
Assets
Investments in AFS debt securities	118,000,000	96,000,000
Fair Value, Recurring [Member] | Assets Held in Trust [Member]
Assets
Investments of certain benefit plans	81,000,000	78,000,000
Fair Value, Recurring [Member] | Commodity Contracts [Member]
Assets
Derivative contracts	909,000,000	830,000,000
Effect of counterparty netting	(907,000,000)	(705,000,000)
Effect of cash collateral netting	0	(8,000,000)
Derivative contracts, net assets	2,000,000	117,000,000
Cash collateral received not offset	0	0
Liabilities
Derivative contracts	1,148,000,000	705,000,000
Effect of counterparty netting	(907,000,000)	(705,000,000)
Effect of cash collateral netting	(241,000,000)	0
Derivative contracts, net liabilities	0	0
Cash collateral paid not offset	(141,000,000)	(149,000,000)
Fair Value, Recurring [Member] | Foreign Currency Contracts [Member]
Assets
Derivative contracts, not subject to netting	4,000,000
Liabilities
Derivative contracts, not subject to netting		2,000,000
Fair Value, Recurring [Member] | Physical Purchase Contracts [Member]
Assets
Derivative contracts, not subject to netting		4,000,000
Liabilities
Derivative contracts, not subject to netting	14,000,000	4,000,000
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Assets
Investments in AFS debt securities	85,000,000	56,000,000
Total gross fair value, assets	1,075,000,000	958,000,000
Liabilities
Blending program obligations	0	0
Total gross fair value, liabilities	1,148,000,000	707,000,000
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Cash and Cash Equivalents [Member]
Assets
Investments in AFS debt securities	0	0
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Prepaid Expenses and Other [Member]
Assets
Investments in AFS debt securities	85,000,000	56,000,000
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Assets Held in Trust [Member]
Assets
Investments of certain benefit plans	77,000,000	72,000,000
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Commodity Contracts [Member]
Assets
Derivative contracts	909,000,000	830,000,000
Liabilities
Derivative contracts	1,148,000,000	705,000,000
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Foreign Currency Contracts [Member]
Assets
Derivative contracts, not subject to netting	4,000,000
Liabilities
Derivative contracts, not subject to netting		2,000,000
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Physical Purchase Contracts [Member]
Assets
Derivative contracts, not subject to netting		0
Liabilities
Derivative contracts, not subject to netting	0	0
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Assets
Investments in AFS debt securities	66,000,000	165,000,000
Total gross fair value, assets	66,000,000	169,000,000
Liabilities
Blending program obligations	129,000,000	55,000,000
Total gross fair value, liabilities	143,000,000	59,000,000
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Cash and Cash Equivalents [Member]
Assets
Investments in AFS debt securities	33,000,000	125,000,000
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Prepaid Expenses and Other [Member]
Assets
Investments in AFS debt securities	33,000,000	40,000,000
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Assets Held in Trust [Member]
Assets
Investments of certain benefit plans	0	0
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Commodity Contracts [Member]
Assets
Derivative contracts	0	0
Liabilities
Derivative contracts	0	0
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Foreign Currency Contracts [Member]
Assets
Derivative contracts, not subject to netting	0
Liabilities
Derivative contracts, not subject to netting		0
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Physical Purchase Contracts [Member]
Assets
Derivative contracts, not subject to netting		4,000,000
Liabilities
Derivative contracts, not subject to netting	14,000,000	4,000,000
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Assets
Investments in AFS debt securities	0	0
Total gross fair value, assets	4,000,000	6,000,000
Liabilities
Blending program obligations	0	0
Total gross fair value, liabilities	0	0
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Assets Held in Trust [Member]
Assets
Investments of certain benefit plans	4,000,000	6,000,000
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Commodity Contracts [Member]
Assets
Derivative contracts	0	0
Liabilities
Derivative contracts	0	0
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Foreign Currency Contracts [Member]
Assets
Derivative contracts, not subject to netting	0
Liabilities
Derivative contracts, not subject to netting		0
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Physical Purchase Contracts [Member]
Assets
Derivative contracts, not subject to netting		0
Liabilities
Derivative contracts, not subject to netting	$ 0	$ 0

XML

Fair Value Measurements, Nonrecurring (Details) - USD ($)	12 Months Ended
	Dec. 31, 2022	Sep. 30, 2023
Nonrecurring Fair Value Measurements (Textual)
Asset impairment loss	$ 61,000,000
Fair Value, Nonrecurring [Member]
Nonrecurring Fair Value Measurements (Textual)
Assets measured at fair value	0	$ 0
Liabilities measured at fair value	$ 0	$ 0

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Fair Value Measurements, Financial Instruments (Details) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Financial liabilities:
Debt (excluding finance lease obligations), at carrying amount	$ 9,150	$ 9,241
Fair Value, Inputs, Level 2 [Member]
Financial liabilities:
Debt (excluding finance lease obligations), at fair value	$ 8,549	$ 8,902

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Price Risk Management Activities (Details) bu in Thousands, $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2023 USD ($)	Sep. 30, 2022 USD ($)	Sep. 30, 2023 USD ($) MBbls bu	Sep. 30, 2022 USD ($)
Price Risk Management Activities (Textual)
Compliance program costs | $	[1]	$ 32,385	$ 38,064	$ 91,820	$ 115,959
Renewable And Low-Carbon Fuel Programs [Member]
Price Risk Management Activities (Textual)
Compliance program costs | $		438	$ 461	$ 1,200	$ 984
Derivatives Designated as Hedges [Member] | Cash Flow Hedges [Member] | Future, 2023 Maturity [Member] | Long (Purchases) [Member] | Refined Petroleum Products (in thousands of barrels) [Member]
Volume of Outstanding Contracts
Nonmonetary notional amount of price risk derivatives, volume				915
Derivatives Designated as Hedges [Member] | Cash Flow Hedges [Member] | Future, 2023 Maturity [Member] | Short (Sales) [Member] | Refined Petroleum Products (in thousands of barrels) [Member]
Volume of Outstanding Contracts
Nonmonetary notional amount of price risk derivatives, volume				6,765
Derivatives Designated as Hedges [Member] | Cash Flow Hedges [Member] | Future, 2024 Maturity [Member] | Long (Purchases) [Member] | Refined Petroleum Products (in thousands of barrels) [Member]
Volume of Outstanding Contracts
Nonmonetary notional amount of price risk derivatives, volume				200
Derivatives Designated as Hedges [Member] | Cash Flow Hedges [Member] | Future, 2024 Maturity [Member] | Short (Sales) [Member] | Refined Petroleum Products (in thousands of barrels) [Member]
Volume of Outstanding Contracts
Nonmonetary notional amount of price risk derivatives, volume				2,362
Derivatives Designated as Economic Hedges [Member] | Future, 2023 Maturity [Member] | Long (Purchases) [Member] | Crude Oil and Refined Petroleum Products (in thousands of barrels) [Member]
Volume of Outstanding Contracts
Nonmonetary notional amount of price risk derivatives, volume				81,133
Derivatives Designated as Economic Hedges [Member] | Future, 2023 Maturity [Member] | Long (Purchases) [Member] | Corn (in thousands of bushels) [Member]
Volume of Outstanding Contracts
Nonmonetary notional amount of price risk derivatives, volume | bu				66,695
Derivatives Designated as Economic Hedges [Member] | Future, 2023 Maturity [Member] | Short (Sales) [Member] | Crude Oil and Refined Petroleum Products (in thousands of barrels) [Member]
Volume of Outstanding Contracts
Nonmonetary notional amount of price risk derivatives, volume				87,324
Derivatives Designated as Economic Hedges [Member] | Future, 2023 Maturity [Member] | Short (Sales) [Member] | Corn (in thousands of bushels) [Member]
Volume of Outstanding Contracts
Nonmonetary notional amount of price risk derivatives, volume | bu				82,415
Derivatives Designated as Economic Hedges [Member] | Future, 2024 Maturity [Member] | Long (Purchases) [Member] | Crude Oil and Refined Petroleum Products (in thousands of barrels) [Member]
Volume of Outstanding Contracts
Nonmonetary notional amount of price risk derivatives, volume				4,214
Derivatives Designated as Economic Hedges [Member] | Future, 2024 Maturity [Member] | Long (Purchases) [Member] | Corn (in thousands of bushels) [Member]
Volume of Outstanding Contracts
Nonmonetary notional amount of price risk derivatives, volume | bu				90
Derivatives Designated as Economic Hedges [Member] | Future, 2024 Maturity [Member] | Short (Sales) [Member] | Crude Oil and Refined Petroleum Products (in thousands of barrels) [Member]
Volume of Outstanding Contracts
Nonmonetary notional amount of price risk derivatives, volume				5,260
Derivatives Designated as Economic Hedges [Member] | Future, 2024 Maturity [Member] | Short (Sales) [Member] | Corn (in thousands of bushels) [Member]
Volume of Outstanding Contracts
Nonmonetary notional amount of price risk derivatives, volume | bu				3,290
Derivatives Designated as Economic Hedges [Member] | Physical Contracts, 2023 Maturity [Member] | Long (Purchases) [Member] | Corn (in thousands of bushels) [Member]
Volume of Outstanding Contracts
Nonmonetary notional amount of price risk derivatives, volume | bu				14,533
Derivatives Designated as Economic Hedges [Member] | Physical Contracts, 2024 Maturity [Member] | Long (Purchases) [Member] | Corn (in thousands of bushels) [Member]
Volume of Outstanding Contracts
Nonmonetary notional amount of price risk derivatives, volume | bu				3,193
Derivatives Designated as Economic Hedges [Member] | Foreign Exchange Contract, US Dollars [Member]
Price Risk Management Activities (Textual)
Monetary notional amount of derivative liabilities | $		$ 630		$ 630

[1] Cost of materials and other for our Renewable Diesel segment is net of the blender’s tax credit on qualified fuel mixtures of $266 million and $191 million for the three months ended September 30, 2023 and 2022, respectively, and $900 million and $545 million for the nine months ended September 30, 2023 and 2022, respectively.

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Price Risk Management Activities, Hedging Instruments by Consolidated Balance Sheet Location (Details) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Derivatives Designated as Hedging Instruments [Member] | Commodity Contracts [Member] | Receivable, Net [Member]
Fair Values of Derivative Instruments
Derivative asset, subject to netting	$ 10	$ 61
Derivative liability, subject to netting	19	44
Derivatives Not Designated as Hedging Instruments [Member]
Fair Values of Derivative Instruments
Derivative asset, total	903	773
Derivative liability, total	1,143	667
Derivatives Not Designated as Hedging Instruments [Member] | Commodity Contracts [Member] | Receivable, Net [Member]
Fair Values of Derivative Instruments
Derivative asset, subject to netting	899	769
Derivative liability, subject to netting	1,129	661
Derivatives Not Designated as Hedging Instruments [Member] | Physical Purchase Contracts [Member] | Inventories [Member]
Fair Values of Derivative Instruments
Derivative asset, not subject to netting	0	4
Derivative liability, not subject to netting	14	4
Derivatives Not Designated as Hedging Instruments [Member] | Foreign Currency Contracts [Member] | Receivable, Net [Member]
Fair Values of Derivative Instruments
Derivative asset, not subject to netting	4	0
Derivative liability, not subject to netting	0	0
Derivatives Not Designated as Hedging Instruments [Member] | Foreign Currency Contracts [Member] | Accrued Expenses [Member]
Fair Values of Derivative Instruments
Derivative asset, not subject to netting	0	0
Derivative liability, not subject to netting	$ 0	$ 2

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Price Risk Management Activities, Effect of Derivative Instruments on Income and Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Commodity Contracts [Member]
Effect of Derivative Instruments on Income
Gain (loss) recognized in other comprehensive loss	$ (197)	$ 79	$ (71)	$ (215)
Commodity Contracts [Member] | Revenues [Member]
Effect of Derivative Instruments on Income
Gain (loss) reclassified from accumulated other comprehensive loss into income	(119)	10	(3)	(289)
Commodity Contracts [Member] | Revenues [Member] | Derivatives Not Designated as Hedging Instruments [Member]
Effect of Derivative Instruments on Income
Gain (loss) recognized in income on derivatives	(2)	(6)	(19)	(12)
Commodity Contracts [Member] | Cost of Materials and Other [Member] | Derivatives Not Designated as Hedging Instruments [Member]
Effect of Derivative Instruments on Income
Gain (loss) recognized in income on derivatives	(48)	(109)	126	(976)
Commodity Contracts [Member] | Operating Expenses (Excluding Depreciation and Amortization Expense) [Member] | Derivatives Not Designated as Hedging Instruments [Member]
Effect of Derivative Instruments on Income
Gain (loss) recognized in income on derivatives	0	(18)	1	(9)
Foreign Currency Contracts [Member] | Cost of Materials and Other [Member] | Derivatives Not Designated as Hedging Instruments [Member]
Effect of Derivative Instruments on Income
Gain (loss) recognized in income on derivatives	19	57	(1)	104
Foreign Currency Contracts [Member] | Other Income, Net [Member] | Derivatives Not Designated as Hedging Instruments [Member]
Effect of Derivative Instruments on Income
Gain (loss) recognized in income on derivatives	$ 0	$ (38)	$ 0	$ (119)