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 March 31, 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 April 21, 2023 was 361,516,949.

VALERO ENERGY CORPORATION

TABLE OF CONTENTS

	Page
PART I – FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
Consolidated Balance Sheets as of March 31, 2023 and December 31, 2022	1
Consolidated Statements of Income for the Three Months Ended March 31, 2023 and 2022	2
Consolidated Statements of Comprehensive Income for the Three Months Ended March 31, 2023 and 2022	3
Consolidated Statements of Equity for the Three Months Ended March 31, 2023 and 2022	4
Consolidated Statements of Cash Flows for the Three Months Ended March 31, 2023 and 2022	5
Condensed Notes to Consolidated Financial Statements	6
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	28
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	49
ITEM 4. CONTROLS AND PROCEDURES	50
PART II – OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS	50
ITEM 1A. RISK FACTORS	50
ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS	51
ITEM 6. EXHIBITS	52
SIGNATURE	53

i

PART I – FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

VALERO ENERGY CORPORATION

CONSOLIDATED BALANCE SHEETS

(millions of dollars, except par value)

	March 31, 2023		December 31, 2022
	(unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	5,521	$	4,862
Receivables, net	9,688		11,919
Inventories	7,455		6,752
Prepaid expenses and other	671		600
Total current assets	23,335		24,133
Property, plant, and equipment, at cost	50,828		50,576
Accumulated depreciation	(20,048)		(19,598)
Property, plant, and equipment, net	30,780		30,978
Deferred charges and other assets, net	6,062		5,871
Total assets	$	60,177	$	60,982
LIABILITIES AND EQUITY
Current liabilities:
Current portion of debt and finance lease obligations	$	1,258	$	1,109
Accounts payable	10,498		12,728
Accrued expenses	1,168		1,215
Taxes other than income taxes payable	1,574		1,568
Income taxes payable	867		841
Total current liabilities	15,365		17,461
Debt and finance lease obligations, less current portion	10,173		10,526
Deferred income tax liabilities	5,280		5,217
Other long-term liabilities	2,292		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	6,877		6,863
Treasury stock, at cost; 311,978,678 and 301,372,958 common shares	(21,637)		(20,197)
Retained earnings	40,935		38,247
Accumulated other comprehensive loss	(1,205)		(1,359)
Total Valero Energy Corporation stockholders’ equity	24,977		23,561
Noncontrolling interests	2,090		1,907
Total equity	27,067		25,468
Total liabilities and equity	$	60,177	$	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 March 31,
	2023		2022
Revenues (a)	$	36,439	$	38,542
Cost of sales:
Cost of materials and other	30,005		34,949
Operating expenses (excluding depreciation and amortization expense reflected below)	1,477		1,379
Depreciation and amortization expense	650		595
Total cost of sales	32,132		36,923
Other operating expenses	10		19
General and administrative expenses (excluding depreciation and amortization expense reflected below)	244		205
Depreciation and amortization expense	10		11
Operating income	4,043		1,384
Other income (expense), net	129		(20)
Interest and debt expense, net of capitalized interest	(146)		(145)
Income before income tax expense	4,026		1,219
Income tax expense	880		252
Net income	3,146		967
Less: Net income attributable to noncontrolling interests	79		62
Net income attributable to Valero Energy Corporation stockholders	$	3,067	$	905
Earnings per common share	$	8.30	$	2.21
Weighted-average common shares outstanding (in millions)	369		408
Earnings per common share – assuming dilution	$	8.29	$	2.21
Weighted-average common shares outstanding – assuming dilution (in millions)	369		408
__________________________
Supplemental information:
(a) Includes excise taxes on sales by certain of our foreign operations	$	1,422	$	1,423

See Condensed Notes to Consolidated Financial Statements.

2

VALERO ENERGY CORPORATION

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(millions of dollars)

(unaudited)

	Three Months Ended March 31,
	2023		2022
Net income	$	3,146	$	967
Other comprehensive income (loss):
Foreign currency translation adjustment	134		13
Net gain (loss) on pension and other postretirement benefits	(7)		8
Net gain (loss) on cash flow hedges	57		(45)
Other comprehensive income (loss) before income tax expense	184		(24)
Income tax expense related to items of other comprehensive income (loss)	1		—
Other comprehensive income (loss)	183		(24)
Comprehensive income	3,329		943
Less: Comprehensive income attributable to noncontrolling interests	108		39
Comprehensive income attributable to Valero Energy Corporation stockholders	$	3,221	$	904

See Condensed Notes to Consolidated Financial Statements.

3

VALERO ENERGY CORPORATION

CONSOLIDATED STATEMENTS OF EQUITY

(millions of dollars)

(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	—		—		—		3,067		—		3,067		79		3,146
Dividends on common stock ($1.02 per share)	—		—		—		(379)		—		(379)		—		(379)
Stock-based compensation expense	—		39		—		—		—		39		—		39
Transactions in connection with stock-based compensation plans	—		(25)		25		—		—		—		—		—
Purchases of common stock for treasury	—		—		(1,465)		—		—		(1,465)		—		(1,465)
Contributions from noncontrolling interests	—		—		—		—		—		—		75		75
Other comprehensive income	—		—		—		—		154		154		29		183
Balance as of March 31, 2023	$	7	$	6,877	$	(21,637)	$	40,935	$	(1,205)	$	24,977	$	2,090	$	27,067
Balance as of December 31, 2021	$	7	$	6,827	$	(15,677)	$	28,281	$	(1,008)	$	18,430	$	1,387	$	19,817
Net income	—		—		—		905		—		905		62		967
Dividends on common stock ($0.98 per share)	—		—		—		(401)		—		(401)		—		(401)
Stock-based compensation expense	—		32		—		—		—		32		—		32
Transactions in connection with stock-based compensation plans	—		(27)		27		—		—		—		—		—
Purchases of common stock for treasury	—		—		(144)		—		—		(144)		—		(144)
Contributions from noncontrolling interests	—		—		—		—		—		—		165		165
Distributions to noncontrolling interests	—		—		—		—		—		—		(2)		(2)
Other comprehensive loss	—		—		—		—		(1)		(1)		(23)		(24)
Balance as of March 31, 2022	$	7	$	6,832	$	(15,794)	$	28,785	$	(1,009)	$	18,821	$	1,589	$	20,410

See Condensed Notes to Consolidated Financial Statements.

4

VALERO ENERGY CORPORATION

CONSOLIDATED STATEMENTS OF CASH FLOWS

(millions of dollars)

(unaudited)

	Three Months Ended March 31,
	2023		2022
Cash flows from operating activities:
Net income	$	3,146	$	967
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization expense	660		606
Loss (gain) on early retirement of debt, net	(11)		50
Deferred income tax expense (benefit)	54		(234)
Changes in current assets and current liabilities	(534)		(722)
Changes in deferred charges and credits and other operating activities, net	(145)		(79)
Net cash provided by operating activities	3,170		588
Cash flows from investing activities:
Capital expenditures (excluding variable interest entities (VIEs))	(175)		(152)
Capital expenditures of VIEs:
Diamond Green Diesel Holdings LLC (DGD)	(90)		(219)
Other VIEs	—		(13)
Deferred turnaround and catalyst cost expenditures (excluding VIEs)	(235)		(453)
Deferred turnaround and catalyst cost expenditures of DGD	(24)		(6)
Purchases of available-for-sale (AFS) debt securities	(100)		—
Proceeds from sales and maturities of AFS debt securities	71		—
Other investing activities, net	4		2
Net cash used in investing activities	(549)		(841)
Cash flows from financing activities:
Proceeds from debt issuances and borrowings (excluding VIEs)	750		939
Proceeds from borrowings of VIEs:
DGD	150		99
Other VIEs	14		28
Repayments of debt and finance lease obligations (excluding VIEs)	(973)		(1,738)
Repayments of debt and finance lease obligations of VIEs:
DGD	(156)		(102)
Other VIEs	(22)		(16)
Premiums paid on early retirement of debt	(5)		(48)
Purchases of common stock for treasury	(1,451)		(144)
Common stock dividend payments	(379)		(401)
Contributions from noncontrolling interests	75		165
Other financing activities, net	(1)		(10)
Net cash used in financing activities	(1,998)		(1,228)
Effect of foreign exchange rate changes on cash	36		(3)
Net increase (decrease) in cash and cash equivalents	659		(1,484)
Cash and cash equivalents at beginning of period	4,862		4,122
Cash and cash equivalents at end of period	$	5,521	$	2,638

See Condensed Notes to Consolidated Financial Statements.

5

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 period presented. All such adjustments are of a normal recurring nature unless disclosed otherwise. Operating results for the interim period 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, and we began the required monthly reporting for our two California refineries at that time.

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) authorizes 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 expands the reporting obligations under SB 1322 and the

6

VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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) creates the Division of Petroleum Market Oversight within the CEC to analyze the data provided under SBx 1-2, and (iv) authorizes the CEC to regulate the timing and other aspects of refinery turnaround and maintenance activities in certain instances. The provisions of SBx 1-2 are expected to become effective June 26, 2023. The CEC has not yet undertaken rulemaking with respect to SBx 1-2, including the establishment of any max margin, the imposition of a financial penalty, restrictions on turnaround and maintenance activities, or determining the format and manner in which the increased data is to be reported, and it is uncertain when or whether any such rulemaking will occur. The increased reporting is substantial, requiring 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. In addition, the required operational data will include our plans for turnaround and maintenance activities at our two California refineries and how we expect to address the potential impacts on feedstock and product inventories in California as a result of such turnaround and maintenance activities.

We are reviewing and analyzing 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, 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.

3.    INVENTORIES

Inventories consisted of the following (in millions):

	March 31, 2023		December 31, 2022
Refinery feedstocks	$	1,820	$	1,949
Refined petroleum products and blendstocks	4,120		3,579
Renewable diesel feedstocks and products	827		583
Ethanol feedstocks and products	366		328
Materials and supplies	322		313
Inventories	$	7,455	$	6,752

7

VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

As of March 31, 2023 and December 31, 2022, the replacement cost (market value) of last-in, first-out (LIFO) inventories exceeded their LIFO carrying amounts by $6.0 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 March 31, 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

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

8

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):

				March 31, 2023
	Facility Amount		Maturity Date	Outstanding Borrowings		Letters of Credit Issued (a)		Availability
Committed facilities:
Valero Revolver	$	4,000	November 2027	$	—	$	6	$	3,994
Canadian Revolver	C$	150	November 2023	C$	—	C$	5	C$	145
Accounts receivable sales facility	$	1,300	July 2023	$	—	n/a		$	1,300
Committed facilities of VIEs (b):
DGD Revolver (c)	$	400	March 2024	$	100	$	75	$	225
DGD Loan Agreement (d)	$	25	April 2023	$	25	n/a		$	—
IEnova Revolver (e)	$	830	February 2028	$	710	n/a		$	120
Uncommitted facilities:
Letter of credit facilities	n/a		n/a	n/a		$	158	n/a

________________________

(a)Letters of credit issued as of March 31, 2023 expire at various times in 2023 through 2024.

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

(c)The variable interest rate on the DGD Revolver was 6.460 percent and 5.880 percent as of March 31, 2023 and December 31, 2022, respectively.

(d)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. The variable interest rate on the DGD Loan Agreement was 7.173 percent and 6.672 percent as of March 31, 2023 and December 31, 2022, respectively. We expect this facility to be renewed prior to its maturity date.

(e)The variable interest rate on the IEnova Revolver was 8.443 percent and 7.393 percent as of March 31, 2023 and December 31, 2022, respectively.

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

	Three Months Ended March 31,
	2023		2022
Borrowings:
Accounts receivable sales facility	$	750	$	300
DGD Revolver	150		99
IEnova Revolver	14		28
Repayments:
Accounts receivable sales facility	(750)		(300)
DGD Revolver	(150)		(99)
IEnova Revolver	(21)		(15)

9

VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Other Disclosures

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

	Three Months Ended March 31,
	2023		2022
Interest and debt expense	$	152	$	157
Less: Capitalized interest	6		12
Interest and debt expense, net of capitalized interest	$	146	$	145

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 months ended March 31, 2023 and 2022, we purchased for treasury 10,993,341 shares and 1,545,873 shares, respectively. On October 26, 2022, our Board authorized our purchase of up to $2.5 billion of our outstanding common stock with no expiration date (the October 2022 Program). On February 23, 2023, our Board authorized our purchase of up to an additional $2.5 billion of our outstanding common stock with no expiration date (the 2023 Program),which is in addition to the amount remaining under the October 2022 Program. As of March 31, 2023, we had $899 million remaining available for purchase under the October 2022 Program and $2.5 billion available for purchase under the 2023 Program.

10

VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Accumulated Other Comprehensive Loss

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

	Three Months Ended March 31,
	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	137		—		37		174		13		(3)		(64)		(54)
Amounts reclassified from accumulated other comprehensive loss	—		(7)		(15)		(22)		—		7		46		53
Effect of exchange rates	—		2		—		2		—		—		—		—
Other comprehensive income (loss)	137		(5)		22		154		13		4		(18)		(1)
Balance as of end of period	$	(1,031)	$	(188)	$	14	$	(1,205)	$	(549)	$	(437)	$	(23)	$	(1,009)

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 March 31, 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.

11

VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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

	DGD		Central Mexico Terminals		Other		Total
March 31, 2023
Assets
Cash and cash equivalents	$	92	$	—	$	26	$	118
Other current assets	1,246		10		32		1,288
Property, plant, and equipment, net	3,759		676		77		4,512
Liabilities
Current liabilities, including current portion of debt and finance lease obligations	$	443	$	748	$	7	$	1,198
Debt and finance lease obligations, less current portion	686		—		12		698
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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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 March 31
Service cost	$	28	$	38	$	1	$	2
Interest cost	30		21		3		2
Expected return on plan assets	(50)		(48)		—		—
Amortization of:
Net actuarial (gain) loss	(2)		13		(1)		—
Prior service credit	(5)		(4)		(1)		(1)
Net periodic benefit cost	$	1	$	20	$	2	$	3

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 (expense), net.”

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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 March 31,
	2023		2022
Earnings per common share:
Net income attributable to Valero stockholders	$	3,067	$	905
Less: Income allocated to participating securities	10		3
Net income available to common stockholders	$	3,057	$	902
Weighted-average common shares outstanding	369		408
Earnings per common share	$	8.30	$	2.21
Earnings per common share – assuming dilution:
Net income attributable to Valero stockholders	$	3,067	$	905
Less: Income allocated to participating securities	10		3
Net income available to common stockholders	$	3,057	$	902
Weighted-average common shares outstanding	369		408
Effect of dilutive securities	—		—
Weighted-average common shares outstanding – assuming dilution	369		408
Earnings per common share – assuming dilution	$	8.29	$	2.21

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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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):

	March 31, 2023		December 31, 2022
Receivables from contracts with customers, included in receivables, net	$	6,073	$	7,189
Contract liabilities, included in accrued expenses	45		129

During the three months ended March 31, 2023 and 2022, we recognized as revenue $120 million and $69 million that was included in contract liabilities as of December 31, 2022 and 2021, respectively.

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 March 31, 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

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CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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 March 31, 2023
Revenues:
Revenues from external customers	$	34,407	$	935	$	1,097	$	—	$	36,439
Intersegment revenues	3		745		223		(971)		—
Total revenues	34,410		1,680		1,320		(971)		36,439
Cost of sales:
Cost of materials and other (a)	28,510		1,331		1,131		(967)		30,005
Operating expenses (excluding depreciation and amortization expense reflected below)	1,261		86		130		—		1,477
Depreciation and amortization expense	572		58		20		—		650
Total cost of sales	30,343		1,475		1,281		(967)		32,132
Other operating expenses	10		—		—		—		10
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		244		244
Depreciation and amortization expense	—		—		—		10		10
Operating income by segment	$	4,057	$	205	$	39	$	(258)	$	4,043
Three months ended March 31, 2022
Revenues:
Revenues from external customers	$	36,813	$	595	$	1,134	$	—	$	38,542
Intersegment revenues	4		386		127		(517)		—
Total revenues	36,817		981		1,261		(517)		38,542
Cost of sales:
Cost of materials and other (a)	33,606		755		1,104		(516)		34,949
Operating expenses (excluding depreciation and amortization expense reflected below)	1,193		51		135		—		1,379
Depreciation and amortization expense	549		26		20		—		595
Total cost of sales	35,348		832		1,259		(516)		36,923
Other operating expenses	18		—		1		—		19
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		205		205
Depreciation and amortization expense	—		—		—		11		11
Operating income by segment	$	1,451	$	149	$	1	$	(217)	$	1,384

________________________

(a)Cost of materials and other for our Renewable Diesel segment is net of the blender’s tax credit on qualified fuel mixtures of $246 million and $156 million for the three months ended March 31, 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 March 31,
	2023		2022
Refining:
Gasolines and blendstocks	$	15,048	$	15,560
Distillates	16,838		17,444
Other product revenues	2,521		3,809
Total refining revenues	34,407		36,813
Renewable Diesel:
Renewable diesel	876		595
Renewable naphtha	59		—
Total Renewable Diesel revenues	935		595
Ethanol:
Ethanol	763		875
Distillers grains	334		259
Total ethanol revenues	1,097		1,134
Revenues	$	36,439	$	38,542

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

	March 31, 2023		December 31, 2022
Refining	$	46,852	$	48,484
Renewable Diesel	5,390		5,217
Ethanol	1,628		1,551
Corporate and eliminations	6,307		5,730
Total assets	$	60,177	$	60,982

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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):

	Three Months Ended March 31,
	2023		2022
Decrease (increase) in current assets:
Receivables, net	$	2,381	$	(2,653)
Inventories	(641)		(940)
Prepaid expenses and other	(37)		(77)
Increase (decrease) in current liabilities:
Accounts payable	(2,269)		2,744
Accrued expenses	(61)		(120)
Taxes other than income taxes payable	(23)		36
Income taxes payable	116		288
Changes in current assets and current liabilities	$	(534)	$	(722)

Changes in current assets and current liabilities for the three months ended March 31, 2023 were primarily due to the following:

•The decrease in receivables was primarily due to a decrease in sales volumes in March 2023 compared to December 2022;

•The increase in inventories was due to an increase in inventory volumes valued at higher unit prices; and

•The decrease in accounts payable was due to a decrease in crude oil and other feedstock volumes purchased combined with a decrease in related prices in March 2023 compared to December 2022.

Changes in current assets and current liabilities for the three months ended March 31, 2022 were primarily due to the following:

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

•The increase in inventories was primarily due to an increase in inventory unit prices and higher inventory levels in March 2022 compared to December 2021; and

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

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

	Three Months Ended March 31,
	2023		2022
Interest paid in excess of amount capitalized, including interest on finance leases	$	82	$	93
Income taxes paid, net	616		204

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

	Three Months Ended March 31,
	2023				2022
	Operating Leases		Finance Leases		Operating Leases		Finance Leases
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows	$	102	$	27	$	97	$	20
Financing cash flows	—		49		—		41
Changes in lease balances resulting from new and modified leases	67		47		79		100

There were no significant noncash investing and financing activities during the three months ended March 31, 2023 or 2022, except as noted in the table above.

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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 March 31, 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.

	March 31, 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	$	616	$	—	$	—	$	616	$	(425)	$	(74)	$	117	$	—
Physical purchase contracts	—		2		—		2		n/a		n/a		2		n/a
Investments of certain benefit plans	71		—		6		77		n/a		n/a		77		n/a
Investments in AFS debt securities	85		139		—		224		n/a		n/a		224		n/a
Total	$	772	$	141	$	6	$	919	$	(425)	$	(74)	$	420
Liabilities
Commodity derivative contracts	$	425	$	—	$	—	$	425	$	(425)	$	—	$	—	$	(1)
Blending program obligations	—		46		—		46		n/a		n/a		46		n/a
Physical purchase contracts	—		5		—		5		n/a		n/a		5		n/a
Foreign currency contracts	9		—		—		9		n/a		n/a		9		n/a
Total	$	434	$	51	$	—	$	485	$	(425)	$	—	$	60

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	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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•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):

	March 31, 2023						December 31, 2022
	Level 1		Level 2		Total		Level 1		Level 2		Total
Cash and cash equivalents	$	7	$	91	$	98	$	—	$	125	$	125
Prepaid expenses and other	78		48		126		56		40		96
Investments in AFS debt securities	$	85	$	139	$	224	$	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 months ended March 31, 2023 and the year ended December 31, 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, 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 March 31, 2023 and December 31, 2022, except as noted above.

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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).

		March 31, 2023				December 31, 2022
	Fair Value Hierarchy	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Financial liabilities:
Debt (excluding finance lease obligations)	Level 2	$	9,037	$	8,862	$	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 income (loss) is summarized below under “Effect of Derivative Instruments on Income and Other Comprehensive Income (Loss).”

Risk Management Activities by Type of Risk

Commodity Price Risk

We are exposed to market risks related to the volatility in the price of feedstocks (primarily crude oil, waste and renewable feedstocks, and corn), the products we produce, and natural gas 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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•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 March 31, 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	3,596	—
Futures – short	10,298	—
Derivatives designated as economic hedges:
Crude oil and refined petroleum products:
Futures – long	63,657	1
Futures – short	66,797	—
Corn:
Futures – long	74,645	20
Futures – short	117,265	410
Physical contracts – long	36,409	388

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 March 31, 2023, we had foreign currency contracts to purchase $561 million of U.S. dollars. Of these commitments, $526 million matured on or before April 25, 2023 and the remaining $35 million will mature by April 28, 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

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CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

purchase compliance credits (primarily Renewable Identification Numbers (RINs)). The cost of meeting our credit obligations under the Renewable and Low-Carbon Fuel Programs was $413 million and $302 million for the three months ended March 31, 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 March 31, 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	March 31, 2023				December 31, 2022
		Asset Derivatives		Liability Derivatives		Asset Derivatives		Liability Derivatives
Derivatives designated as hedging instruments:
Commodity contracts	Receivables, net	$	117	$	42	$	61	$	44
Derivatives not designated as hedging instruments:
Commodity contracts	Receivables, net	$	499	$	383	$	769	$	661
Physical purchase contracts	Inventories	2		5		4		4
Foreign currency contracts	Receivables, net	—		—		—		—
Foreign currency contracts	Accrued expenses	—		9		—		2
Total		$	501	$	397	$	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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Effect of Derivative Instruments on Income and Other Comprehensive Income (Loss)

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

Derivatives in Cash Flow Hedging Relationships	Location of Gain (Loss) Recognized in Income on Derivatives	Three Months Ended March 31,
		2023		2022
Commodity contracts:
Gain (loss) recognized in other comprehensive income (loss)	n/a	$	95	$	(164)
Gain (loss) reclassified from accumulated other comprehensive loss into income	Revenues	38		(119)

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 months ended March 31, 2023 and 2022. For the three months ended March 31, 2023 and 2022, cash flow hedges primarily related to forward sales of renewable diesel. The estimated deferred after-tax gain that is expected to be reclassified into revenues within the next 12 months as a result of the hedged transactions that are forecasted to occur as of March 31, 2023 was not material. For the three months ended March 31, 2023 and 2022, there were no amounts reclassified from accumulated other comprehensive loss into income as a result of the discontinuance of cash flow hedge accounting. The changes in accumulated other comprehensive loss by component, net of tax, for the three months ended March 31, 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 March 31,
		2023		2022
Commodity contracts	Revenues	$	(7)	$	(4)
Commodity contracts	Cost of materials and other	83		(595)
Commodity contracts	Operating expenses (excluding depreciation and amortization expense)	1		3
Foreign currency contracts	Cost of materials and other	(3)		(2)
Foreign currency contracts	Other income (expense), net	—		34

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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 effects and impact of the emergence of new variants of the COVID-19 virus and government responses thereto;

•the effect, impact, potential duration or timing, or other implications of the Russia-Ukraine conflict;

•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, and timing with respect to, the production and operations at our existing refineries and plants, and projects under construction or under development;

•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 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 our ability to maintain sufficient 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, 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;

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

•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 growth strategy, publicly announced greenhouse gas (GHG) emissions reduction/displacement targets and our current 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 the Russia-Ukraine conflict, 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;

29

•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;

•accidents, unscheduled shutdowns, weather events, civil unrest, expropriation of assets, and other economic, diplomatic, legislative, 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 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, 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 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

30

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;

•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 (c) beginning on page 41 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 (c), we disclose the reasons why we believe our use of such non-GAAP financial measures provides useful information. See the table on page 47 for a reconciliation of capital investments attributable to Valero to its most directly comparable GAAP financial measure. Beginning on page 46, we disclose the reasons why we believe our use of this non-GAAP financial measure provides useful information.

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OVERVIEW AND OUTLOOK

Overview

Business Operations Update

Our results for the first quarter 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 supply and demand imbalance has continued to contribute to strong refining margins.

The strong demand for our products and the increase in refining margins were the primary contributors to us reporting $3.1 billion of net income attributable to Valero stockholders for the first quarter of 2023. Our operating results, including operating results by segment, are described in the following summary under “First Quarter Results,” with more detailed descriptions found under “RESULTS OF OPERATIONS” beginning on page 34.

Our operations generated $3.2 billion of cash during the first quarter of 2023. This cash was used to make $524 million of capital investments in our business and return $1.8 billion to our stockholders through purchases of common stock for treasury and dividend payments. In addition, we continued to reduce our outstanding debt through the purchase of approximately $199 million of our public debt during the first quarter of 2023. As a result of this and other activity, our cash and cash equivalents increased by $659 million, from $4.9 billion as of December 31, 2022 to $5.5 billion as of March 31, 2023. We had $10.8 billion in liquidity as of March 31, 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 44.

First Quarter Results

For the first quarter of 2023, we reported net income attributable to Valero stockholders of $3.1 billion compared to $905 million for the first quarter of 2022. The increase of $2.2 billion was primarily due to an increase in operating income of $2.7 billion, partially offset by an increase in income tax expense of $628 million. The details of our operating income and adjusted operating income by segment and in total are reflected on the following page. Adjusted operating income excludes the adjustment reflected in the table in note (c) on page 43.

	Three Months Ended March 31,
	2023		2022		Change
Refining segment:
Operating income	$	4,057	$	1,451	$	2,606
Adjusted operating income	4,067		1,469		2,598
Renewable Diesel segment:
Operating income	205		149		56
Ethanol segment:
Operating income	39		1		38
Adjusted operating income	39		2		37
Total company:
Operating income	4,043		1,384		2,659
Adjusted operating income	4,053		1,403		2,650

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While our operating income increased by $2.7 billion in the first quarter of 2023 compared to the first quarter of 2022, adjusted operating income also increased by $2.7 billion primarily due to the following:

•Refining segment. Refining segment adjusted operating income increased by $2.6 billion primarily due to higher gasoline and distillate (primarily diesel) margins, higher discounts on crude oils, and an increase in throughput volumes, partially offset by higher operating expenses (excluding depreciation and amortization expense).

•Renewable Diesel segment. Renewable Diesel segment operating income increased by $56 million primarily due to higher sales volumes, partially offset by lower renewable diesel prices, higher operating expenses (excluding depreciation and amortization expense), and higher depreciation and amortization expense.

•Ethanol segment. Ethanol segment adjusted operating income increased by $37 million primarily due to higher corn related co-product prices and higher production volumes, partially offset by lower ethanol 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 may have on us, we have noted several factors below that have impacted or may impact our results of operations during the second quarter of 2023.

•Gasoline and diesel demand have returned to near pre-pandemic levels and are expected to follow typical seasonal patterns. Jet fuel demand continues to improve, but remains below pre-pandemic levels.

•Light product (gasoline, diesel, and jet fuel) inventories in the U.S. and Europe are below historical levels and should support continued high utilization of refining capacity.

•Crude oil discounts have narrowed with reduced sour crude oil production from suppliers in OPEC+ but are expected to remain near current levels absent further changes in crude oil supply or availability.

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

•Ethanol demand is expected to follow typical seasonal patterns.

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RESULTS OF OPERATIONS

The following tables, including the reconciliations of non-GAAP financial measures to their most directly comparable GAAP financial measures in note (c) beginning on page 41, 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 41 through 43.

First Quarter Results -

Financial Highlights By Segment and Total Company

(millions of dollars)

	Three Months Ended March 31, 2023
	Refining		Renewable Diesel		Ethanol		Corporate and Eliminations		Total
Revenues:
Revenues from external customers	$	34,407	$	935	$	1,097	$	—	$	36,439
Intersegment revenues	3		745		223		(971)		—
Total revenues	34,410		1,680		1,320		(971)		36,439
Cost of sales:
Cost of materials and other	28,510		1,331		1,131		(967)		30,005
Operating expenses (excluding depreciation and amortization expense reflected below)	1,261		86		130		—		1,477
Depreciation and amortization expense	572		58		20		—		650
Total cost of sales	30,343		1,475		1,281		(967)		32,132
Other operating expenses	10		—		—		—		10
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		244		244
Depreciation and amortization expense	—		—		—		10		10
Operating income by segment	$	4,057	$	205	$	39	$	(258)	4,043
Other income, net (a)									129
Interest and debt expense, net of capitalized interest									(146)
Income before income tax expense									4,026
Income tax expense									880
Net income									3,146
Less: Net income attributable to noncontrolling interests									79
Net income attributable to Valero Energy Corporation stockholders									$	3,067

34

First Quarter Results -

Financial Highlights By Segment and Total Company (continued)

(millions of dollars)

	Three Months Ended March 31, 2022
	Refining		Renewable Diesel		Ethanol		Corporate and Eliminations		Total
Revenues:
Revenues from external customers	$	36,813	$	595	$	1,134	$	—	$	38,542
Intersegment revenues	4		386		127		(517)		—
Total revenues	36,817		981		1,261		(517)		38,542
Cost of sales:
Cost of materials and other	33,606		755		1,104		(516)		34,949
Operating expenses (excluding depreciation and amortization expense reflected below)	1,193		51		135		—		1,379
Depreciation and amortization expense	549		26		20		—		595
Total cost of sales	35,348		832		1,259		(516)		36,923
Other operating expenses	18		—		1		—		19
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		205		205
Depreciation and amortization expense	—		—		—		11		11
Operating income by segment	$	1,451	$	149	$	1	$	(217)	1,384
Other expense, net (a)									(20)
Interest and debt expense, net of capitalized interest									(145)
Income before income tax expense									1,219
Income tax expense									252
Net income									967
Less: Net income attributable to noncontrolling interests									62
Net income attributable to Valero Energy Corporation stockholders									$	905

35

First Quarter Results -

Average Market Reference Prices and Differentials

	Three Months Ended March 31,
	2023		2022
Refining
Feedstocks (dollars per barrel)
Brent crude oil	$	82.20	$	97.34
Brent less West Texas Intermediate (WTI) crude oil	6.09		2.88
Brent less WTI Houston crude oil	4.29		1.31
Brent less Dated Brent crude oil	0.92		(3.90)
Brent less Argus Sour Crude Index crude oil	8.41		4.93
Brent less Maya crude oil	19.39		8.50
Brent less Western Canadian Select Houston crude oil	17.36		9.65
WTI crude oil	76.11		94.46
Natural gas (dollars per million British Thermal Units)	2.25		4.32
Renewable volume obligation (RVO) (dollars per barrel) (b)	8.20		6.44
Product margins (RVO adjusted unless otherwise noted) (dollars per barrel)
U.S. Gulf Coast:
Conventional Blendstock of Oxygenate Blending (CBOB) gasoline less Brent	10.03		9.23
Ultra-low-sulfur (ULS) diesel less Brent	30.27		21.51
Propylene less Brent (not RVO adjusted)	(42.21)		(28.82)
U.S. Mid-Continent:
CBOB gasoline less WTI	17.70		9.58
ULS diesel less WTI	34.10		20.83
North Atlantic:
CBOB gasoline less Brent	11.32		11.24
ULS diesel less Brent	33.30		26.03
U.S. West Coast:
California Reformulated Gasoline Blendstock of Oxygenate Blending 87 gasoline less Brent	24.71		20.29
California Air Resources Board diesel less Brent	31.83		24.10

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First Quarter Results -

Average Market Reference Prices and Differentials (continued)

	Three Months Ended March 31,
	2023		2022
Renewable Diesel
New York Mercantile Exchange ULS diesel (dollars per gallon)	$	2.93	$	3.04
Biodiesel RIN (dollars per RIN)	1.63		1.43
California Low-Carbon Fuel Standard carbon credit (dollars per metric ton)	65.68		138.63
U.S. Gulf Coast (USGC) used cooking oil (dollars per pound)	0.62		0.78
USGC distillers corn oil (dollars per pound)	0.63		0.77
USGC fancy bleachable tallow (dollars per pound)	0.60		0.71
Ethanol
Chicago Board of Trade corn (dollars per bushel)	6.60		6.70
New York Harbor ethanol (dollars per gallon)	2.30		2.39

Total Company, Corporate, and Other

The following table includes selected financial data for the total company, corporate, and other for the first 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 March 31,
	2023		2022		Change
Revenues	$	36,439	$	38,542	$	(2,103)
Cost of sales	32,132		36,923		(4,791)
General and administrative expenses (excluding depreciation and amortization expense)	244		205		39
Operating income	4,043		1,384		2,659
Adjusted operating income (see note (c))	4,053		1,403		2,650
Other income (expense), net (see note (a))	129		(20)		149
Income tax expense	880		252		628

Revenues decreased by $2.1 billion in the first quarter of 2023 compared to the first 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, along with an increase in general and administrative expenses (excluding depreciation and amortization expense) of $39 million primarily due to an increase in certain employee compensation expenses, was more than offset by a decrease in cost of sales of $4.8 billion, which was primarily due to decreases in crude oil and other feedstock costs. These changes resulted in a $2.7 billion increase in operating income, from $1.4 billion in the first quarter of 2022 to $4.0 billion in the first quarter of 2023.

Adjusted operating income also increased by $2.7 billion, from $1.4 billion in the first quarter of 2022 to $4.1 billion in the first quarter of 2023. The components of this $2.7 billion increase in adjusted operating income are discussed by segment in the segment analyses that follow.

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“Other income (expense), net” increased by $149 million in the first quarter of 2023 compared to the first quarter of 2022 due to the items noted in the following table (in millions):

	Three Months Ended March 31,
	2023		2022		Change
Interest income on cash	$	61	$	3	$	58
Net gain (loss) from early retirement of debt (see note (a))	11		(50)		61
Equity income on joint ventures and other	57		27		30
Other income (expense), net	$	129	$	(20)	$	149

Income tax expense increased by $628 million in the first quarter of 2023 compared to the first quarter of 2022 primarily as a result of higher income before income tax expense.

Refining Segment Results

The following table includes selected financial and operating data of our Refining segment for the first 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 March 31,
	2023		2022		Change
Operating income	$	4,057	$	1,451	$	2,606
Adjusted operating income (see note (c))	4,067		1,469		2,598
Refining margin (see note (c))	5,900		3,211		2,689
Operating expenses (excluding depreciation and amortization expense reflected below)	1,261		1,193		68
Depreciation and amortization expense	572		549		23
Throughput volumes (thousand barrels per day) (see note (d))	2,930		2,800		130

Refining segment operating income increased by $2.6 billion in the first quarter of 2023 compared to the first quarter of 2022. Refining segment adjusted operating income, which excludes the adjustment in the table in note (c), also increased by $2.6 billion in the first quarter of 2023 compared to the first quarter of 2022. The components of this increase in the adjusted results, along with the reasons for the changes in those components, are outlined below.

•Refining segment margin increased by $2.7 billion in the first quarter of 2023 compared to the first 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 36 reflects market reference prices and differentials that we believe had a material impact on the change in our Refining segment margin in the first quarter of 2023 compared to the first quarter of 2022.

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

◦An increase in distillate (primarily diesel) margins had a favorable impact of approximately $1.0 billion.

◦Higher discounts on crude oils had a favorable impact of approximately $676 million.

◦An increase in gasoline margins had a favorable impact of approximately $506 million.

◦An increase in throughput volumes of 130,000 barrels per day had a favorable impact of approximately $262 million.

•Refining segment operating expenses (excluding depreciation and amortization expense) increased by $68 million primarily due to increases in chemicals and catalyst costs of $50 million, certain employee compensation costs of $24 million, and maintenance expense of $19 million, partially offset by a decrease in energy costs of $50 million.

Renewable Diesel Segment Results

The following table includes selected financial and operating data of our Renewable Diesel segment for the first 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 March 31,
	2023		2022		Change
Operating income	$	205	$	149	$	56
Renewable Diesel margin (see note (c))	349		226		123
Operating expenses (excluding depreciation and amortization expense reflected below)	86		51		35
Depreciation and amortization expense	58		26		32
Sales volumes (thousand gallons per day) (see note (d))	2,988		1,738		1,250

Renewable Diesel segment operating income increased by $56 million in the first quarter of 2023 compared to the first quarter 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 $123 million in the first quarter of 2023 compared to the first 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 37 reflects market reference prices that we believe had a material impact on the change in our Renewable Diesel segment margin in the first quarter of 2023 compared to the first quarter of 2022.

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

◦An increase in sales volumes of 1.3 million gallons per day had a favorable impact of approximately $259 million. The increase in sales volumes was primarily due to the

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additional production capacity resulting from the completion of the new DGD Port Arthur Plant that commenced operations in the fourth quarter of 2022.

◦Lower renewable diesel prices had an unfavorable impact of approximately $152 million.

•Renewable Diesel segment operating expenses (excluding depreciation and amortization expense) increased by $35 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 $32 million primarily due to depreciation expense of $16 million associated with the new DGD Port Arthur Plant that commenced operations in the fourth quarter of 2022, higher turnaround and catalyst amortization expense at the DGD St. Charles Plant of $8 million, and an increase in depreciation expense of $6 million associated with finance leases.

Ethanol Segment Results

The following table includes selected financial and operating data of our Ethanol segment for the first 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 March 31,
	2023		2022		Change
Operating income	$	39	$	1	$	38
Adjusted operating income (see note (c))	39		2		37
Ethanol margin (see note (c))	189		157		32
Operating expenses (excluding depreciation and amortization expense reflected below)	130		135		(5)
Depreciation and amortization expense	20		20		—
Production volumes (thousand gallons per day) (see note (d))	4,183		4,045		138

Ethanol segment operating income increased by $38 million in the first quarter of 2023 compared to the first quarter of 2022; however, Ethanol segment adjusted operating income, which excludes the adjustment in the table in note (c), increased by $37 million in the first quarter of 2023 compared to the first quarter of 2022. This increase was primarily due to higher Ethanol segment margin.

Ethanol segment margin increased by $32 million in the first quarter of 2023 compared to the first 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 37 reflects market reference prices that we believe had a material impact on the change in our Ethanol segment margin in the first quarter of 2023 compared to the first quarter of 2022.

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

•Higher prices for the co-products that we produce, primarily dry distillers grains, had a favorable impact of approximately $31 million.

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•An increase in production volumes of 138,000 gallons per day had a favorable impact of approximately $17 million.

•Lower ethanol prices had an unfavorable impact of approximately $18 million.

________________________

The following notes relate to references on pages 34 through 40.

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

◦a net gain of $11 million in the three months ended March 31, 2023 related to the early retirement of approximately $199 million aggregate principal amount of various series of our senior notes; and

◦a charge of $50 million in the three months ended March 31, 2022 related to the early retirement of approximately $1.4 billion aggregate principal amount of various series of our senior notes.

(b)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.

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

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

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Non-GAAP measures are as follows:

◦Refining margin is defined as Refining 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 March 31,
	2023		2022
Reconciliation of Refining operating income to Refining margin
Refining operating income	$	4,057	$	1,451
Adjustments:
Operating expenses (excluding depreciation and amortization expense)	1,261		1,193
Depreciation and amortization expense	572		549
Other operating expenses	10		18
Refining margin	$	5,900	$	3,211

◦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 March 31,
	2023		2022
Reconciliation of Renewable Diesel operating income to Renewable Diesel margin
Renewable Diesel operating income	$	205	$	149
Adjustments:
Operating expenses (excluding depreciation and amortization expense)	86		51
Depreciation and amortization expense	58		26
Renewable Diesel margin	$	349	$	226

◦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 March 31,
	2023		2022
Reconciliation of Ethanol operating income to Ethanol margin
Ethanol operating income	$	39	$	1
Adjustments:
Operating expenses (excluding depreciation and amortization expense)	130		135
Depreciation and amortization expense	20		20
Other operating expenses	—		1
Ethanol margin	$	189	$	157

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

	Three Months Ended March 31,
	2023		2022
Reconciliation of Refining operating income to adjusted Refining operating income
Refining operating income	$	4,057	$	1,451
Adjustment: Other operating expenses	10		18
Adjusted Refining operating income	$	4,067	$	1,469

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

	Three Months Ended March 31,
	2023		2022
Reconciliation of Ethanol operating income to adjusted Ethanol operating income
Ethanol operating income	$	39	$	1
Adjustment: Other operating expenses	—		1
Adjusted Ethanol operating income	$	39	$	2

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

	Three Months Ended March 31,
	2023		2022
Reconciliation of total company operating income to adjusted operating income
Total company operating income	$	4,043	$	1,384
Adjustment: Other operating expenses	10		19
Adjusted operating income	$	4,053	$	1,403

(d)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 March 31, 2023 (in millions):

Available capacity from our committed facilities (a):
Valero Revolver	$	3,994
Canadian Revolver (b)	107
Accounts receivable sales facility	1,300
Total available capacity	5,401
Cash and cash equivalents (c)	5,403
Total liquidity	$	10,804

________________________

(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 March 31, 2023 in Canadian dollars was C$145 million.

(c)Excludes $118 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):

	Three Months Ended March 31,
	2023		2022
Cash flows provided by (used in):
Operating activities	$	3,170	$	588
Investing activities	(549)		(841)
Financing activities:
Debt issuances and borrowings	914		1,066
Repayments of debt and finance lease obligations (including premiums paid on early retirement of debt)	(1,156)		(1,904)
Return to stockholders:
Purchases of common stock for treasury	(1,451)		(144)
Common stock dividend payments	(379)		(401)
Return to stockholders	(1,830)		(545)
Other financing activities	74		155
Financing activities	(1,998)		(1,228)
Effect of foreign exchange rate changes on cash	36		(3)
Net increase (decrease) in cash and cash equivalents	$	659	$	(1,484)

Cash Flows for the Three Months Ended March 31, 2023

In the first quarter of 2023, we used the $3.2 billion of cash generated by our operations and the $914 million in debt borrowings to make $549 million of investments in our business, repay $1.2 billion of debt and finance lease obligations (including premiums paid on the early retirement of debt), return $1.8 billion to our stockholders through purchases of our common stock for treasury and dividend payments, and increase our available cash on hand by $659 million. The debt borrowings and repayments are described in Note 4 of Condensed Notes to Consolidated Financial Statements.

As previously noted, our operations generated $3.2 billion of cash in the first quarter of 2023, driven primarily by net income of $3.1 billion and noncash charges to income of $558 million, partially offset by an unfavorable change in working capital of $534 million. Noncash charges primarily included $660 million of depreciation and amortization expense and $54 million of deferred income tax 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 of $549 million primarily consisted of $524 million in capital investments, as defined below under “Capital Investments,” of which $114 million related to capital investments made by DGD.

Other financing activities of $74 million consisted primarily of $75 million in contributions from the other joint venture member in DGD.

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Cash Flows for the Three Months Ended March 31, 2022

In the first quarter of 2022, we used the $588 million of cash generated by our operations, $1.5 billion of cash on hand, and the $1.1 billion in debt issuances and borrowings to make $841 million of investments in our business, repay $1.9 billion of debt and finance lease obligations (including premiums paid on the early retirement of debt), and return $545 million 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.

As previously noted, our operations generated $588 million of cash in the first quarter of 2022, driven primarily by net income of $967 million and noncash charges to income of $343 million, partially offset by an unfavorable change in working capital of $722 million. Noncash charges primarily included $606 million of depreciation and amortization expense and a $50 million loss on the early retirement of debt, partially offset by a $234 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 of $841 million consisted of $843 million in capital investments, of which $225 million related to capital investments made by DGD and $13 million related to capital expenditures of VIEs other than DGD.

Other financing activities of $155 million consisted primarily of $165 million in contributions from the other joint venture member in DGD.

Our Capital Resources

Our material cash requirements as of March 31, 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 5. 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.

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We are a 50 percent joint venture member in DGD and consolidate its financial statements. 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.

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.

	Three Months Ended March 31,
	2023		2022
Reconciliation of capital investments to capital investments attributable to Valero
Capital expenditures (excluding VIEs)	$	175	$	152
Capital expenditures of VIEs:
DGD	90		219
Other VIEs	—		13
Deferred turnaround and catalyst cost expenditures (excluding VIEs)	235		453
Deferred turnaround and catalyst cost expenditures of DGD	24		6
Capital investments	524		843
Adjustments:
DGD’s capital investments attributable to the other joint venture member	(57)		(112)
Capital expenditures of other VIEs	—		(13)
Capital investments attributable to Valero	$	467	$	718

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 over 40 percent is allocated to expanding our low-carbon businesses.

Contractual Obligations

As of March 31, 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

47

three months ended March 31, 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 three months ended March 31, 2023.

During the three months ended March 31, 2023, we used cash on hand to purchase and retire approximately $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 months ended March 31, 2023, we purchased for treasury 10,993,341 of our shares for $1.5 billion. See Note 5 of Condensed Notes to Consolidated Financial Statements for additional information related to our stock purchase programs. As of March 31, 2023, we had $899 million remaining available for purchase under the October 2022 Program and $2.5 billion available for purchase under the 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. No significant contributions were made during the three months ended March 31, 2023.

Cash Held by Our Foreign Subsidiaries

As of March 31, 2023, $4.3 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 refining and marketing 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 to 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.

	March 31, 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		$	8,010
Average interest rate	—		%	1.2		%	3.2		%	4.2		%	2.2		%	5.3		%	4.8		%
Floating rate	$	839		$	13		$	—		$	—		$	—		$	—		$	852		$	852
Average interest rate	8.1		%	3.9		%	—		%	—		%	—		%	—		%	8.1		%
	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 March 31, 2023.

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ITEM 4. CONTROLS AND PROCEDURES

(a)Evaluation of disclosure controls and procedures.

Our management has evaluated, with the participation of our principal executive officer and principal financial officer, the effectiveness of our disclosure controls and procedures (as defined in Rule 13a-15(e) under the Securities Exchange Act of 1934) as of the end of the period covered by this report, and has concluded that our disclosure controls and procedures were effective as of March 31, 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 material developments in a proceeding that we reported in our annual report on Form 10-K for the year ended December 31, 2022. There were no new proceedings during the three months ended March 31, 2023 that we reasonably believe have the potential to exceed the monetary threshold noted below.

Environmental Enforcement Matters

We are reporting this proceeding to comply with SEC regulations, which require us to disclose certain information about proceedings arising under U.S. federal, state, or local provisions regulating the discharge of materials into the environment or protecting the environment if we reasonably believe that such proceedings have the potential to result in monetary sanctions of $300,000 or more.

EPA (Benicia Refinery). In our annual report on Form 10-K for the year ended December 31, 2022, we reported that the EPA had issued a Notice of Potential Violations and Opportunity to Confer related to a series of inspections conducted by the EPA arising out of a 2019 emissions event at our Benicia Refinery. On March 30, 2023, we entered into a Consent Agreement and Final Order with the EPA resolving this matter.

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.

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

Issuer Purchases of Equity Securities

The following table discloses purchases of shares of our common stock made by us or on our behalf during the first quarter of 2023.

Period	Total Number of Shares Purchased (a)	Average Price Paid per Share		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 (b)
January 2023	3,823	$	126.62	—	$2.3 billion
February 2023	2,981,903	$	132.89	2,771,055	$4.5 billion
March 2023	8,007,615	$	131.69	8,001,081	$3.4 billion
Total	10,993,341	$	132.01	10,772,136	$3.4 billion

________________________

(a)The shares reported in this column include 221,205 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)On October 26, 2022, our Board authorized our purchase of up to $2.5 billion of our outstanding common stock with no expiration date. On February 23, 2023, our Board authorized our purchase of up to an additional $2.5 billion of our outstanding common stock with no expiration date, which is in addition to the amount remaining under the October 2022 Program. As of March 31, 2023, we had $899 million remaining available for purchase under the October 2022 Program and $2.5 billion available for purchase under the 2023 Program.

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ITEM 6. EXHIBITS

Exhibit No.	Description
*+10.01	Form of Amended and Restated Performance Share Agreement (2021 grant–third tranche).
*+10.02	Form of Amended and Restated Performance Share Agreement (2022 grant–second and third tranches).
*+10.03	Form of Performance Share Agreement (2023 grant and current).
*+10.04	Form of Aircraft Time Sharing Agreement.
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.

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SIGNATURE

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

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

Date: April 27, 2023

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EX-10.01

Exhibit 10.01

AMENDED AND RESTATED PERFORMANCE SHARE AGREEMENT

This Amended and Restated Performance Share Agreement (the “Agreement”), by and between Valero Energy Corporation, a Delaware corporation (“Valero”), and _______, a participant (the “Participant”) in Valero’s 2020 Omnibus Stock Incentive Plan (as may be amended, the “Plan”), is entered into effective February 23, 2023 pursuant to and subject to the provisions of the Plan, and amends and restates that certain Performance Share Agreement dated February 23, 2021, between Valero and the Participant to amend and restate the terms and conditions of the award of Performance Shares granted to Participant as of February 23, 2021. The terms “Committee” and “Compensation Committee” in this Agreement refer to the Board’s Human Resources and Compensation Committee.

1.Grant of Performance Shares. Valero grants to Participant_________Performance Shares pursuant to Section 6.7 of the Plan. The Performance Shares represent rights to receive shares of Common Stock of Valero, subject to the terms and conditions of this Agreement and the Plan.

2.Vesting and Delivery of Shares.

A.Vesting. The Performance Shares granted hereunder shall vest over a period of three years in equal, one-third increments with the first increment vesting on the date of the regularly scheduled meeting of the Board’s Compensation Committee in January 2022, and the second and third increments vesting on the Committee’s meeting dates in January 2023 and January 2024, respectively (each of these vesting dates is referred to as a “Normal Vesting Date”); any shares of Common Stock to be issued in connection with such vesting are subject to the Compensation Committee’s verification of attainment of the Performance Goals described in Section 4 below. If the Committee is unable to meet in January of a given year, then the Normal Vesting Date for that year will be a date not later than two-and-one-half months following the end of the year as selected by the Compensation Committee.

B.Rights. Until shares of Common Stock are actually issued to Participant (or his or her estate) in settlement of the Performance Shares, neither Participant nor any person claiming by, through or under Participant shall have any rights as a stockholder of Valero (including, without limitation, voting rights or any right to receive dividends or other distributions except as expressly provided in this Agreement) with respect to such shares.

C.Distribution. Any shares of Common Stock to be distributed under the terms of this Agreement shall be distributed as soon as administratively practicable after Performance Goals described in Section 4 below have been verified by the Compensation Committee, but not later than two-and-one-half months following the end of the year in which such verification occurred.

3.Performance Period. Except as provided below with respect to a Change of Control (as defined in the Plan), the “Performance Period” for any Performance Shares eligible to vest on any Normal Vesting Date shall be as follows:

A.First Segment. The Performance Period for the first one-third vesting of Performance Shares (those vesting on the Normal Vesting Date in January 2022) shall be the calendar year ending on December 31, 2021.

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B.Second Segment. The Performance Period for the second one-third vesting of Performance Shares (those vesting on the Normal Vesting Date in January 2023) shall be the two calendar years ending December 31, 2022.

C.Third Segment. The Performance Period for the final one-third vesting of Performance Shares (those vesting on the Normal Vesting Date in January 2024) shall be the three calendar years ending December 31, 2023.

4.Performance Goals. On each Normal Vesting Date, Valero’s performance will be measured against Valero’s total shareholder return (“TSR”) compared to its peers. Following the determination of Valero’s ranking with respect to TSR, the payout percentage (described below) will be subject to an increase or decrease based on Valero’s performance against the Energy Transition measures described below.

A.Total Shareholder Return (TSR).

(i)TSR will be compiled for a peer group of companies approved by the Compensation Committee (the “Target Group”) for the Performance Period immediately preceding each Normal Vesting Date. TSR for each such company is measured by dividing (A) the sum of (i) the dividends on the common stock of such company during the Performance Period, assuming dividend reinvestment, and (ii) the difference between the average closing price of a share of such company’s common stock for the 15 trading days ending December 31 at the end of the Performance Period and the average closing price of such shares for the 15 trading days ending December 31 immediately prior to the beginning of the Performance Period (appropriately adjusted for any stock dividend, stock split, spin-off, merger or other similar corporate events), by (B) the average closing price of a share of such company’s common stock for the 15 trading days ending December 31 immediately prior to the beginning of the Performance Period.

(ii)For each Performance Period, the TSR for Valero and each company in the Target Group shall be arranged by rank from highest performer to lowest performer according to the TSR achieved by each company. Shares of Common Stock will be awarded to Participant in accordance with Valero’s percentile ranking within the Target Group. The number of shares of Common Stock, if any, that Participant will be entitled to receive in settlement of the vested Performance Shares will be determined on each Normal Vesting Date, and subject to the provisions of the Plan and this Agreement, on such Normal Vesting Date, the vesting Performance Shares will be awarded as shares of Common Stock to the Participant per the payout percentages

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listed below when Valero’s TSR during the Performance Period falls within the following percentiles (“Percentiles”):

Ranking	Percentile	Payout
1	100.0%	200.0%
2	90.0%	200.0%
3	80.0%	175.0%
4	70.0%	150.0%
5	60.0%	125.0%
6	50.0%	100.0%
7	40.0%	75.0%
8	30.0%	50.0%
9	20.0%	25.0%
10	10.0%	0.0%
11	0.0%	0.0%

B.Energy Transition performance measure. After Valero’s TSR performance has been determined, the resulting payout percentage score will be subject to an increase or decrease of up to 25 percentage points, hereafter referred to as the “Energy Transition performance measure.”

(i)The Energy Transition performance measure has two equally weighted components (12.5 percentage points each): (1) Valero’s annual progress versus a target in achieving Valero’s publicly announced greenhouse gas emissions reduction/displacement target(s), and (2) the percentage of Valero’s growth capital expenditures deployed for low-carbon initiatives versus a target. All such targets shall be approved annually by the Committee.

(ii)If Valero meets or exceeds the targets for each of the Energy Transition performance components, Valero’s TSR score will be increased by 25 percentage points (e.g., a TSR score of 125% would be increased by 25 points to 150%), subject at all times to a maximum payout cap of 200%. If, however, Valero does not meet the targets for each of the Energy Transition performance components, then Valero’s TSR score will be reduced by 25 percentage points (e.g., a TSR score of 125% would be reduced by 25 points to 100%). Meeting the target for one of the Energy Transition performance components but not the other results in a modifier of zero, and therefore does not alter the TSR score. Notwithstanding the foregoing, the Committee may provide with respect to the annual target for either component that performance must exceed the target in order for such target to be deemed met, and if performance equals the target, then no adjustment will be made to Valero’s TSR score for such component either up or down; performance below the target would still result in a reduction of points for such component as described above.

C.Example of Vesting and Payout. Assume that 12,000 Performance Shares are vesting on a Normal Vesting Date. Assume the following for Valero’s performance:

•TSR achievement at 70th percentile (150% payout).

•Energy Transition assessment results in Valero meeting each metric’s target (+25 percentage points).

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Calculation of shares of Common Stock to be awarded for Valero performance:

•150% (TSR) plus 25% points (Energy Transition) = 175%

•175% x 12,000 performance shares = 21,000 shares of Common Stock

D.Unearned Shares. Any Performance Shares not awarded as shares of Common Stock on a Normal Vesting Date will expire and be forfeited; such Performance Shares may not be carried forward for any additional Performance Period.

5.Dividend Equivalent Award. In addition to the Performance Shares granted in Section 1, the Participant is granted a Dividend Equivalent Award payable in shares of Common Stock, as provided herein. On each Normal Vesting Date (or Trigger Date, defined below), the amount of dividends paid to holders of Common Stock during the applicable Performance Period shall be determined with respect to the Participant’s Performance Shares that are vesting on that Normal Vesting Date — calculated as if the Performance Shares were outstanding shares of Common Stock (the resulting value being hereafter referred to as the “Target Dividend Equivalent Value” or “TDEV”). The TDEV is equal to (a) the number of Performance Shares vesting, times (b) the amount of accumulated dividends per share during the Performance Period.

The number of shares of Common Stock payable to Participant with respect to the Dividend Equivalent Award is equal to (1) divided by (2), where:

(1) is equal to:

(a) TDEV times (b) the TSR percentage payout plus or minus any Energy Transition measure adjustment; and

(2) is equal to the Fair Market Value per share of Common Stock on the vesting date.

Such shares of Common Stock shall be distributed to Participant contemporaneously with the distribution of the shares of Common Stock issued pursuant to Section 4. See Exhibit A for an example of this calculation.

6.Termination of Employment.

A.Voluntary Termination, Termination for “Cause,” and Early Retirement. If Participant’s employment is

(i)voluntarily terminated by the Participant (other than through retirement at age 60+, death or disability), including termination in connection with Participant’s voluntary early retirement (i.e., prior to age 60),

(ii)terminated by Valero for “cause” (as defined pursuant to the Plan),

then those Performance Shares that are outstanding and have not vested as of the effective date of termination shall thereupon be forfeited.

B.Retirement. If a Participant’s employment is terminated through his or her retirement when the Participant is age 60 or older, then any Performance Shares that (i) have not theretofore vested or been forfeited, and (ii) were granted at least one year prior to the Participant’s effective date of retirement, shall continue to remain outstanding and shall vest on the Normal Vesting Dates according to their original vesting schedule.

But any outstanding Performance Shares that were granted within one year of such Participant’s effective date of retirement shall be prorated based on the number of months worked from the date of grant to the Participant’s retirement date (rounding upward), and the prorated number of Performance Shares shall thereafter vest on the Normal Vesting Dates

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according to their original vesting schedule, and shall be distributed at the time(s) provided for under Section 2.C. above. Example:

•87,750 Performance Shares granted on February 23, 2021,

•Participant retires at age 60+ effective July 31, 2021,

•working period is calculated as 6 months (5 full months plus partial month rounding upward to 6 months),

•original grant is adjusted by 6/12ths (50%) resulting in 43,875 Performance Shares to vest according to their original vesting schedule.

C.Death, Disability, Involuntary Termination Other Than for “Cause,” and Change of Control. If a Participant’s employment is terminated (i) through death or disability, or (ii) by Valero other than for cause (as determined pursuant to the Plan), or (iii) as a result of a Change of Control (as described in the Plan) (each of the foregoing is hereafter referred to as a “Trigger Date”), then each Performance Period with respect to any Performance Shares that have not vested or been forfeited shall be terminated effective as of such Trigger Date. The (i) TSR for Valero and for each company in the Target Group and (ii) the Energy Transition performance measures shall be determined for each such shortened Performance Period and the percentage of Performance Shares to be awarded as shares of Common Stock for each such shortened Performance Period shall be determined in accordance with Section 4 and Section 5 and shall be distributed as soon as administratively practicable thereafter, and in any event within 90 days following such termination of employment.

(i)For purposes of determining the number of Performance Shares to be received as of any Trigger Date, the Target Group as most recently determined by the Compensation Committee prior to the Trigger Date shall be used.

(ii)If the Trigger Date is the result of a Change of Control, then the number of shares of Common Stock to be awarded to the Participant shall be prorated commensurate with the length of service of the Participant during each Performance Period. See Exhibit B for an example of this calculation.

7.Cash Payment Election. Effective on any Normal Vesting Date (or Trigger Date under Section 6.C.), the Participant (or the Participant’s estate under Section 6.C) may elect to receive up to 50% of the after-tax value of the aggregate number of shares of Common Stock earned on such Normal Vesting Date (or Trigger Date) in cash, with the remainder paid in shares of Common Stock. Example:

•following the calculation of Valero’s performance for the two-year performance period ending December 31, 2022, it is determined that the Participant is entitled to receive 8,000 shares of Common Stock on the Normal Vesting Date occurring in January 2023 (the “2023 Normal Vesting Date”),

•assume that the 8,000 shares have an aggregate tax value of $600,000 (8,000 shares times an assumed $75 FMV per share on the 2023 Normal Vesting Date), and the Participant has made a tax withholding election of 39.6%,

•the after-tax value of the 8,000 shares of Common Stock awarded on the 2023 Normal Vesting Date is $362,400 ($600,000 times 60.4%),

•the Participant may elect to receive up to $181,200 ($362,400 times 50%) in cash on the 2023 Normal Vesting Date.

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8.Plan Incorporated by Reference. The Plan is incorporated into this Agreement by this reference and is made a part hereof for all purposes. Capitalized terms not otherwise defined in this Agreement shall have the meaning specified in the Plan.

9.No Assignment. This Agreement and the Participant’s interest in the Performance Shares granted by this Agreement are of a personal nature, and, except as expressly permitted under the Plan, Participant’s rights with respect thereto may not be sold, mortgaged, pledged, assigned, transferred, conveyed or disposed of in any manner by Participant, except by an executor or beneficiary pursuant to a will or pursuant to the laws of descent and distribution. Any such attempted sale, mortgage, pledge, assignment, transfer, conveyance or disposition is void, and Valero will not be bound thereby.

10.Integration. This Agreement constitutes the entire agreement of the parties relating to the transactions contemplated hereby, and supersedes all provisions and concepts contained in all prior contracts or agreements between the Participant and Valero, including that certain Change of Control Severance Agreement (“COC Agreement”) between Participant and Valero. For avoidance of doubt, Participant acknowledges that in the context of a Change of Control of Valero, the terms of this Agreement shall prevail over the terms of the COC Agreement with respect to the vesting of the Performance Shares granted under this Agreement.

11.Successors. This Agreement shall be binding upon any successors of Valero and upon the beneficiaries, legatees, heirs, administrators, executors, legal representatives, successors and permitted assigns of Participant.

12.Code Section 409A. This Agreement is intended to comply, and shall be administered consistently in all respects, with Section 409A of the Internal Revenue Code of 1986, as amended (the “Code”), and the regulations and additional guidance promulgated thereunder to the extent applicable. Accordingly, Valero shall have the authority to take any action, or refrain from taking any action, with respect to this Agreement that is reasonably necessary to ensure compliance with Code Section 409A (provided that Valero shall choose the action that best preserves the value of payments and benefits provided to Participant under this Agreement that is consistent with Code Section 409A), and the parties agree that this Agreement shall be interpreted in a manner that is consistent with Code Section 409A. In furtherance, but not in limitation of the foregoing:

(a)in no event may Participant designate, directly or indirectly, the calendar year of any payment to be made hereunder;

(b)to the extent the Participant is a “specified employee” within the meaning of Code Section 409A, payments, if any, that constitute a “deferral of compensation” under Code Section 409A and that would otherwise become due during the first six months following Participant’s termination of employment shall be delayed and all such delayed payments shall be paid in full in the seventh month after such termination date, provided that the above delay shall not apply to any payment that is excepted from coverage by Code Section 409A, such as a payment covered by the short-term deferral exception described in Treasury Regulations Section 1.409A-1(b)(4);

(c)notwithstanding any other provision of this Agreement, a termination, resignation or retirement of Participant’s employment hereunder shall mean and be interpreted consistent with a “separation from service” within the meaning of Code Section 409A;

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(d)terms defined in this section will have the meanings given such terms under Section 409A if and to the extent required to comply with Section 409A. Notwithstanding any other provision hereof, Valero makes no representations or warranties and will have no liability to Participant or any other person if any provision of or payment under this Agreement is determined to constitute deferred compensation subject to Section 409A but does not satisfy the conditions of Section 409A.

Executed effective as of the date first written above.

VALERO ENERGY CORPORATION

by:	/s/ Julia Rendon Reinhart
	JULIA RENDON REINHART,
	Senior Vice President & Chief Human
	Resources Officer
	, Participant

Page 7

Exhibit A

Example of Potential Payout of Dividend Equivalent Award in Shares of Common Stock

(per Section 5 of the Agreement)

Assumptions and Calculations (for illustration purposes only):

1.Assume the Participant was granted 36,000 Performance Shares on February 23, 2021.

2.Assume the Normal Vesting Date for the second segment of these Performance Shares is January 24, 2023. On that date 12,000 Performance Shares (36,000 / 3 = 12,000) vest with respect to the two-year Performance Period ending December 31, 2022.

3.Assume the cumulative amount of dividends paid to holders of Common Stock during the eight quarters of the Performance Period is $7.52 per share.

4.The “Target Dividend Equivalent Value” (“TDEV”) is $90,240 (12,000 Performance Shares vesting, multiplied by $7.52 accumulated dividends per share).

5.Valero’s TSR ranking for the Performance Period is determined (per Section 4.A) to generate a payout of 150%.

6.Valero’s Energy Transition performance is determined (per Section 4.B.) to generate an increase to the payout of 25 percentage points to a total payout percentage of 175%.

7.The Fair Market Value per share of Common Stock on the vesting date is $75.00.

8.Based on the foregoing, the number of shares of Common Stock earned by the Participant for the Dividend Equivalent Award is 2,106 shares (rounded up from 2,105.6). The calculation is illustrated below as (1) divided by (2), where:

(1) is $157,920, calculated as $90,240 (TDEV) times 175% (150% TSR score + 25% Energy Transition performance adjustment); and

(2) is $75.00, the Fair Market Value per share of Common Stock on the vesting date.

Exhibit A

Exhibit B

Example of Potential Payout in a Change of Control Context

(per Section 6.C.(ii) of the Agreement)

Assumptions and Calculations (for illustration purposes only):

1.Assume the Participant was granted 36,000 Performance Shares on February 23, 2021.

2.Assume Participant’s employment is terminated on June 30, 2021 as a result of a Change of Control.

3.Per Section 6.C. of the Agreement, all Performance Periods for all segments (First Segment, Second Segment, Third Segment (See Section 3)) are shortened to end on June 30, 2021.

4.Valero’s TSR ranking for each shortened Performance Period is determined to generate a payout of 150%.

5.Valero’s Energy Transition performance for each shortened Performance Period is determined to generate an adjustment of an increase of 25 percentage points for a total payout of 175%.

6.Assume the cumulative amount of dividends paid to holders of Common Stock during the 6-month shortened Performance Period is $1.96 per share. Therefore, the “Target Dividend Equivalent Value” (“TDEV”) is $70,560 (36,000 Performance Shares vesting, multiplied by $1.96 accumulated dividends per share).

7.Based on the foregoing, the number of shares of Common Stock earned by the Participant for the Dividend Equivalent Award is 1,647 shares (rounded up from 1,646.4). The calculation is illustrated below as (1) divided by (2), where:

(1) is $123,480, calculated as $70,560 (TDEV) times 175% (150% TSR score + 25% Energy Transition performance adjustment); and

(2) is $75.00, the assumed Fair Market Value per share of Common Stock on the vesting date.

8.Payout of common shares to the Participant is prorated based on the Participant’s length of service during the original Performance Periods.

First Segment calculation.

36,000 / 3 = 12,000 performance shares.

Calculation of shares of Common Stock to be awarded for Valero performance:

•12,000 x 175% payout = 21,000 common shares

Prorate for 6 months of service in the 12-month Performance Period.

21,000 common shares x 6/12 = 10,500    common shares

Second Segment calculation.

36,000 / 3 = 12,000 performance shares.

Calculation of shares of Common Stock to be awarded for Valero performance:

•12,000 x 175% payout = 21,000 common shares

Prorate for 6 months of service in the 24-month Performance Period.

21,000 common shares x 6/24 = 5,250    common shares

Third Segment calculation.

36,000 / 3 = 12,000 performance shares.

Calculation of shares of Common Stock to be awarded for Valero performance:

•12,000 x 175% payout = 21,000 common shares

Prorate for 6 months of service in the 36-month Performance Period.

21,000 common shares x 6/36 = 3,500    common shares

Add DEA shares		1,647    common shares
	Total	20,897    common shares

Exhibit B

EX-10.02

Exhibit 10.02

AMENDED AND RESTATED PERFORMANCE SHARE AGREEMENT

This Amended and Restated Performance Share Agreement (the “Agreement”), by and between Valero Energy Corporation, a Delaware corporation (“Valero”), and______, a participant (the “Participant”) in Valero’s 2020 Omnibus Stock Incentive Plan (as may be amended, the “Plan”), is entered into effective February 23, 2023 pursuant to and subject to the provisions of the Plan, and amends and restates that certain Performance Share Agreement dated February 22, 2022, between Valero and the Participant to amend and restate the terms and conditions of the award of Performance Shares granted to Participant as of February 22, 2022. The terms “Committee” and “Compensation Committee” in this Agreement refer to the Board’s Human Resources and Compensation Committee.

1.Grant of Performance Shares. Valero grants to Participant_____________Performance Shares pursuant to Section 6.7 of the Plan. The Performance Shares represent rights to receive shares of Common Stock of Valero, subject to the terms and conditions of this Agreement and the Plan.

2.Vesting and Delivery of Shares.

A.Vesting. The Performance Shares granted hereunder shall vest over a period of three years in equal, one-third increments with the first increment vesting on the date of the regularly scheduled meeting of the Board’s Compensation Committee in January 2023, and the second and third increments vesting on the Committee’s meeting dates in January 2024 and January 2025, respectively (each of these vesting dates is referred to as a “Normal Vesting Date”); any shares of Common Stock to be issued in connection with such vesting are subject to the Compensation Committee’s verification of attainment of the Performance Goals described in Section 4 below. If the Committee is unable to meet in January of a given year, then the Normal Vesting Date for that year will be a date not later than two-and-one-half months following the end of the year as selected by the Compensation Committee.

B.Rights. Until shares of Common Stock are actually issued to Participant (or his or her estate) in settlement of the Performance Shares, neither Participant nor any person claiming by, through or under Participant shall have any rights as a stockholder of Valero (including, without limitation, voting rights or any right to receive dividends or other distributions except as expressly provided in this Agreement) with respect to such shares.

C.Distribution. Any shares of Common Stock to be distributed under the terms of this Agreement shall be distributed as soon as administratively practicable after Performance Goals described in Section 4 below have been verified by the Compensation Committee, but not later than two-and-one-half months following the end of the year in which such verification occurred.

3.Performance Period. Except as provided below with respect to a Change of Control (as defined in the Plan), the “Performance Period” for any Performance Shares eligible to vest on any Normal Vesting Date shall be as follows:

A.First Segment. The Performance Period for the first one-third vesting of Performance Shares (those vesting on the Normal Vesting Date in January 2023) shall be the calendar year ending on December 31, 2022.

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B.Second Segment. The Performance Period for the second one-third vesting of Performance Shares (those vesting on the Normal Vesting Date in January 2024) shall be the two calendar years ending December 31, 2023.

C.Third Segment. The Performance Period for the final one-third vesting of Performance Shares (those vesting on the Normal Vesting Date in January 2025) shall be the three calendar years ending December 31, 2024.

4.Performance Goals. On each Normal Vesting Date, Valero’s performance will be measured against Valero’s total shareholder return (“TSR”) compared to its peers. Following the determination of Valero’s ranking with respect to TSR, the payout percentage (described below) will be subject to an increase or decrease based on Valero’s performance against the Energy Transition measures described below.

A.Total Shareholder Return (TSR).

(i)TSR will be compiled for a peer group of companies approved by the Compensation Committee (the “Target Group”) for the Performance Period immediately preceding each Normal Vesting Date. TSR for each such company is measured by dividing (A) the sum of (i) the dividends on the common stock of such company during the Performance Period, assuming dividend reinvestment, and (ii) the difference between the average closing price of a share of such company’s common stock for the 15 trading days ending December 31 at the end of the Performance Period and the average closing price of such shares for the 15 trading days ending December 31 immediately prior to the beginning of the Performance Period (appropriately adjusted for any stock dividend, stock split, spin-off, merger or other similar corporate events), by (B) the average closing price of a share of such company’s common stock for the 15 trading days ending December 31 immediately prior to the beginning of the Performance Period.

(ii)For each Performance Period, the TSR for Valero and each company in the Target Group shall be arranged by rank from highest performer to lowest performer according to the TSR achieved by each company. Shares of Common Stock will be awarded to Participant in accordance with Valero’s percentile ranking within the Target Group. The number of shares of Common Stock, if any, that Participant will be entitled to receive in settlement of the vested Performance Shares will be determined on each Normal Vesting Date, and subject to the provisions of the Plan and this Agreement, on such Normal Vesting Date, the vesting Performance Shares will be awarded as shares of Common Stock to the Participant per the payout percentages

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listed below when Valero’s TSR during the Performance Period falls within the following percentiles (“Percentiles”):

Ranking	Percentile	Payout
1	100.0%	200.0%
2	90.0%	200.0%
3	80.0%	175.0%
4	70.0%	150.0%
5	60.0%	125.0%
6	50.0%	100.0%
7	40.0%	75.0%
8	30.0%	50.0%
9	20.0%	25.0%
10	10.0%	0.0%
11	0.0%	0.0%

B.Energy Transition performance measure. After Valero’s TSR performance has been determined, the resulting payout percentage score will be subject to an increase or decrease of up to 25 percentage points, hereafter referred to as the “Energy Transition performance measure.”

(i)The Energy Transition performance measure has two equally weighted components (12.5 percentage points each): (1) Valero’s annual progress versus a target in achieving Valero’s publicly announced greenhouse gas emissions reduction/displacement target(s), and (2) the percentage of Valero’s growth capital expenditures deployed for low-carbon initiatives versus a target. All such targets shall be approved annually by the Committee.

(ii)If Valero meets or exceeds the targets for each of the Energy Transition performance components, Valero’s TSR score will be increased by 25 percentage points (e.g., a TSR score of 125% would be increased by 25 points to 150%), subject at all times to a maximum payout cap of 200%. If, however, Valero does not meet the targets for each of the Energy Transition performance components, then Valero’s TSR score will be reduced by 25 percentage points (e.g., a TSR score of 125% would be reduced by 25 points to 100%). Meeting the target for one of the Energy Transition performance components but not the other results in a modifier of zero, and therefore does not alter the TSR score. Notwithstanding the foregoing, the Committee may provide with respect to the annual target for either component that performance must exceed the target in order for such target to be deemed met, and if performance equals the target, then no adjustment will be made to Valero’s TSR score for such component either up or down; performance below the target would still result in a reduction of points for such component as described above.

C.Example of Vesting and Payout. Assume that 12,000 Performance Shares are vesting on a Normal Vesting Date. Assume the following for Valero’s performance:

•TSR achievement at 70th percentile (150% payout).

•Energy Transition assessment results in Valero meeting each metric’s target (+25 percentage points).

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Calculation of shares of Common Stock to be awarded for Valero performance:

•150% (TSR) plus 25% points (Energy Transition) = 175%

•175% x 12,000 performance shares = 21,000 shares of Common Stock

D.Unearned Shares. Any Performance Shares not awarded as shares of Common Stock on a Normal Vesting Date will expire and be forfeited; such Performance Shares may not be carried forward for any additional Performance Period.

5.Dividend Equivalent Award. In addition to the Performance Shares granted in Section 1, the Participant is granted a Dividend Equivalent Award payable in shares of Common Stock, as provided herein. On each Normal Vesting Date (or Trigger Date, defined below), the amount of dividends paid to holders of Common Stock during the applicable Performance Period shall be determined with respect to the Participant’s Performance Shares that are vesting on that Normal Vesting Date — calculated as if the Performance Shares were outstanding shares of Common Stock (the resulting value being hereafter referred to as the “Target Dividend Equivalent Value” or “TDEV”). The TDEV is equal to (a) the number of Performance Shares vesting, times (b) the amount of accumulated dividends per share during the Performance Period.

The number of shares of Common Stock payable to Participant with respect to the Dividend Equivalent Award is equal to (1) divided by (2), where:

(1) is equal to:

(a) TDEV times (b) the TSR percentage payout plus or minus any Energy Transition measure adjustment; and

(2) is equal to the Fair Market Value per share of Common Stock on the vesting date.

Such shares of Common Stock shall be distributed to Participant contemporaneously with the distribution of the shares of Common Stock issued pursuant to Section 4. See Exhibit A for an example of this calculation.

6.Termination of Employment.

A.Voluntary Termination, Termination for “Cause,” and Early Retirement. If Participant’s employment is

(i)voluntarily terminated by the Participant (other than through retirement at age 60+, death or disability), including termination in connection with Participant’s voluntary early retirement (i.e., prior to age 60),

(ii)terminated by Valero for “cause” (as defined pursuant to the Plan),

then those Performance Shares that are outstanding and have not vested as of the effective date of termination shall thereupon be forfeited.

B.Retirement. If a Participant’s employment is terminated through his or her retirement when the Participant is age 60 or older, then any Performance Shares that (i) have not theretofore vested or been forfeited, and (ii) were granted at least one year prior to the Participant’s effective date of retirement, shall continue to remain outstanding and shall vest on the Normal Vesting Dates according to their original vesting schedule.

But any outstanding Performance Shares that were granted within one year of such Participant’s effective date of retirement shall be prorated based on the number of months worked from the date of grant to the Participant’s retirement date (rounding upward), and the prorated number of Performance Shares shall thereafter vest on the Normal Vesting Dates

Page 4

according to their original vesting schedule, and shall be distributed at the time(s) provided for under Section 2.C. above. Example:

•9,780 Performance Shares granted on February 22, 2022,

•Participant retires at age 60+ effective July 31, 2022,

•working period is calculated as 6 months (5 full months plus partial month rounding upward to 6 months),

•original grant is adjusted by 6/12ths (50%) resulting in 4,890 Performance Shares to vest according to their original vesting schedule.

C.Death, Disability, Involuntary Termination Other Than for “Cause,” and Change of Control. If a Participant’s employment is terminated (i) through death or disability, or (ii) by Valero other than for cause (as determined pursuant to the Plan), or (iii) as a result of a Change of Control (as described in the Plan) (each of the foregoing is hereafter referred to as a “Trigger Date”), then each Performance Period with respect to any Performance Shares that have not vested or been forfeited shall be terminated effective as of such Trigger Date. The (i) TSR for Valero and for each company in the Target Group and (ii) the Energy Transition performance measures shall be determined for each such shortened Performance Period and the percentage of Performance Shares to be awarded as shares of Common Stock for each such shortened Performance Period shall be determined in accordance with Section 4 and Section 5 and shall be distributed as soon as administratively practicable thereafter, and in any event within 90 days following such termination of employment.

(i)For purposes of determining the number of Performance Shares to be received as of any Trigger Date, the Target Group as most recently determined by the Compensation Committee prior to the Trigger Date shall be used.

(ii)If the Trigger Date is the result of a Change of Control, then the number of shares of Common Stock to be awarded to the Participant shall be prorated commensurate with the length of service of the Participant during each Performance Period. See Exhibit B for an example of this calculation.

7.Cash Payment Election. Effective on any Normal Vesting Date (or Trigger Date under Section 6.C.), the Participant (or the Participant’s estate under Section 6.C) may elect to receive up to 50% of the after-tax value of the aggregate number of shares of Common Stock earned on such Normal Vesting Date (or Trigger Date) in cash, with the remainder paid in shares of Common Stock. Example:

•following the calculation of Valero’s performance for the two-year performance period ending December 31, 2023, it is determined that the Participant is entitled to receive 8,000 shares of Common Stock on the Normal Vesting Date occurring in January 2024 (the “2024 Normal Vesting Date”),

•assume that the 8,000 shares have an aggregate tax value of $600,000 (8,000 shares times an assumed $75 FMV per share on the 2024 Normal Vesting Date), and the Participant has made a tax withholding election of 39.6%,

•the after-tax value of the 8,000 shares of Common Stock awarded on the 2024 Normal Vesting Date is $362,400 ($600,000 times 60.4%),

•the Participant may elect to receive up to $181,200 ($362,400 times 50%) in cash on the 2024 Normal Vesting Date.

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8.Plan Incorporated by Reference. The Plan is incorporated into this Agreement by this reference and is made a part hereof for all purposes. Capitalized terms not otherwise defined in this Agreement shall have the meaning specified in the Plan.

9.No Assignment. This Agreement and the Participant’s interest in the Performance Shares granted by this Agreement are of a personal nature, and, except as expressly permitted under the Plan, Participant’s rights with respect thereto may not be sold, mortgaged, pledged, assigned, transferred, conveyed or disposed of in any manner by Participant, except by an executor or beneficiary pursuant to a will or pursuant to the laws of descent and distribution. Any such attempted sale, mortgage, pledge, assignment, transfer, conveyance or disposition is void, and Valero will not be bound thereby.

10.Integration. This Agreement constitutes the entire agreement of the parties relating to the transactions contemplated hereby, and supersedes all provisions and concepts contained in all prior contracts or agreements between the Participant and Valero, including that certain Change of Control Severance Agreement (“COC Agreement”) between Participant and Valero. For avoidance of doubt, Participant acknowledges that in the context of a Change of Control of Valero, the terms of this Agreement shall prevail over the terms of the COC Agreement with respect to the vesting of the Performance Shares granted under this Agreement.

11.Successors. This Agreement shall be binding upon any successors of Valero and upon the beneficiaries, legatees, heirs, administrators, executors, legal representatives, successors and permitted assigns of Participant.

12.Code Section 409A. This Agreement is intended to comply, and shall be administered consistently in all respects, with Section 409A of the Internal Revenue Code of 1986, as amended (the “Code”), and the regulations and additional guidance promulgated thereunder to the extent applicable. Accordingly, Valero shall have the authority to take any action, or refrain from taking any action, with respect to this Agreement that is reasonably necessary to ensure compliance with Code Section 409A (provided that Valero shall choose the action that best preserves the value of payments and benefits provided to Participant under this Agreement that is consistent with Code Section 409A), and the parties agree that this Agreement shall be interpreted in a manner that is consistent with Code Section 409A. In furtherance, but not in limitation of the foregoing:

(a)in no event may Participant designate, directly or indirectly, the calendar year of any payment to be made hereunder;

(b)to the extent the Participant is a “specified employee” within the meaning of Code Section 409A, payments, if any, that constitute a “deferral of compensation” under Code Section 409A and that would otherwise become due during the first six months following Participant’s termination of employment shall be delayed and all such delayed payments shall be paid in full in the seventh month after such termination date, provided that the above delay shall not apply to any payment that is excepted from coverage by Code Section 409A, such as a payment covered by the short-term deferral exception described in Treasury Regulations Section 1.409A-1(b)(4);

(c)notwithstanding any other provision of this Agreement, a termination, resignation or retirement of Participant’s employment hereunder shall mean and be interpreted consistent with a “separation from service” within the meaning of Code Section 409A;

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(d)terms defined in this section will have the meanings given such terms under Section 409A if and to the extent required to comply with Section 409A. Notwithstanding any other provision hereof, Valero makes no representations or warranties and will have no liability to Participant or any other person if any provision of or payment under this Agreement is determined to constitute deferred compensation subject to Section 409A but does not satisfy the conditions of Section 409A.

Executed effective as of the date first written above.

VALERO ENERGY CORPORATION

by:	/s/ Julia Rendon Reinhart
	JULIA RENDON REINHART,
	Senior Vice President & Chief Human
	Resources Officer
	, Participant

Page 7

Exhibit A

Example of Potential Payout of Dividend Equivalent Award in Shares of Common Stock

(per Section 5 of the Agreement)

Assumptions and Calculations (for illustration purposes only):

1.Assume the Participant was granted 36,000 Performance Shares on February 22, 2022.

2.Assume the Normal Vesting Date for the second segment of these Performance Shares is January 24, 2024. On that date 12,000 Performance Shares (36,000 / 3 = 12,000) vest with respect to the two-year Performance Period ending December 31, 2023.

3.Assume the cumulative amount of dividends paid to holders of Common Stock during the eight quarters of the Performance Period is $7.52 per share.

4.The “Target Dividend Equivalent Value” (“TDEV”) is $90,240 (12,000 Performance Shares vesting, multiplied by $7.52 accumulated dividends per share).

5.Valero’s TSR ranking for the Performance Period is determined (per Section 4.A) to generate a payout of 150%.

6.Valero’s Energy Transition performance is determined (per Section 4.B.) to generate an increase to the payout of 25 percentage points to a total payout percentage of 175%.

7.The Fair Market Value per share of Common Stock on the vesting date is $75.00.

8.Based on the foregoing, the number of shares of Common Stock earned by the Participant for the Dividend Equivalent Award is 2,106 shares (rounded up from 2,105.6). The calculation is illustrated below as (1) divided by (2), where:

(1) is $157,920, calculated as $90,240 (TDEV) times 175% (150% TSR score + 25% Energy Transition performance adjustment); and

(2) is $75.00, the Fair Market Value per share of Common Stock on the vesting date.

Exhibit A

Exhibit B

Example of Potential Payout in a Change of Control Context

(per Section 6.C.(ii) of the Agreement)

Assumptions and Calculations (for illustration purposes only):

1.Assume the Participant was granted 36,000 Performance Shares on February 22, 2022.

2.Assume Participant’s employment is terminated on June 30, 2022 as a result of a Change of Control.

3.Per Section 6.C. of the Agreement, all Performance Periods for all segments (First Segment, Second Segment, Third Segment (See Section 3)) are shortened to end on June 30, 2022.

4.Valero’s TSR ranking for each shortened Performance Period is determined to generate a payout of 150%.

5.Valero’s Energy Transition performance for each shortened Performance Period is determined to generate an adjustment of an increase of 25 percentage points for a total payout of 175%.

6.Assume the cumulative amount of dividends paid to holders of Common Stock during the 6-month shortened Performance Period is $1.96 per share. Therefore, the “Target Dividend Equivalent Value” (“TDEV”) is $70,560 (36,000 Performance Shares vesting, multiplied by $1.96 accumulated dividends per share).

7.Based on the foregoing, the number of shares of Common Stock earned by the Participant for the Dividend Equivalent Award is 1,647 shares (rounded up from 1,646.4). The calculation is illustrated below as (1) divided by (2), where:

(1) is $123,480, calculated as $70,560 (TDEV) times 175% (150% TSR score + 25% Energy Transition performance adjustment); and

(2) is $75.00, the assumed Fair Market Value per share of Common Stock on the vesting date.

8.Payout of common shares to the Participant is prorated based on the Participant’s length of service during the original Performance Periods.

First Segment calculation.

36,000 / 3 = 12,000 performance shares.

Calculation of shares of Common Stock to be awarded for Valero performance:

•12,000 x 175% payout = 21,000 common shares

Prorate for 6 months of service in the 12-month Performance Period.

21,000 common shares x 6/12 = 10,500    common shares

Second Segment calculation.

36,000 / 3 = 12,000 performance shares.

Calculation of shares of Common Stock to be awarded for Valero performance:

•12,000 x 175% payout = 21,000 common shares

Prorate for 6 months of service in the 24-month Performance Period.

21,000 common shares x 6/24 = 5,250    common shares

Third Segment calculation.

36,000 / 3 = 12,000 performance shares.

Calculation of shares of Common Stock to be awarded for Valero performance:

•12,000 x 175% payout = 21,000 common shares

Prorate for 6 months of service in the 36-month Performance Period.

21,000 common shares x 6/36 = 3,500    common shares

Add DEA shares		1,647    common shares
	Total	20,897    common shares

Exhibit B

EX-10.03

Exhibit 10.03

PERFORMANCE SHARE AGREEMENT

This Performance Share Agreement (the “Agreement”), by and between Valero Energy Corporation, a Delaware corporation (“Valero”), and________________, a participant (the “Participant”) in Valero’s 2020 Omnibus Stock Incentive Plan (as may be amended, the “Plan”), is entered into pursuant to and subject to the provisions of the Plan, to set forth the terms and conditions of the award of Performance Shares granted to Participant as of February 23, 2023. The terms “Committee” and “Compensation Committee” in this Agreement refer to the Board’s Human Resources and Compensation Committee.

1.Grant of Performance Shares. Valero grants to Participant_______Performance Shares pursuant to Section 6.7 of the Plan. The Performance Shares represent rights to receive shares of Common Stock of Valero, subject to the terms and conditions of this Agreement and the Plan.

2.Vesting and Delivery of Shares.

A.Vesting. The Performance Shares granted hereunder shall vest over a period of three years in equal, one-third increments with the first increment vesting on the date of the regularly scheduled meeting of the Board’s Compensation Committee in January 2024, and the second and third increments vesting on the Committee’s meeting dates in January 2025 and January 2026, respectively (each of these vesting dates is referred to as a “Normal Vesting Date”); any shares of Common Stock to be issued in connection with such vesting are subject to the Compensation Committee’s verification of attainment of the Performance Goals described in Section 4 below. If the Committee is unable to meet in January of a given year, then the Normal Vesting Date for that year will be a date not later than two-and-one-half months following the end of the year as selected by the Compensation Committee.

B.Rights. Until shares of Common Stock are actually issued to Participant (or his or her estate) in settlement of the Performance Shares, neither Participant nor any person claiming by, through or under Participant shall have any rights as a stockholder of Valero (including, without limitation, voting rights or any right to receive dividends or other distributions except as expressly provided in this Agreement) with respect to such shares.

C.Distribution. Any shares of Common Stock to be distributed under the terms of this Agreement shall be distributed as soon as administratively practicable after Performance Goals described in Section 4 below have been verified by the Compensation Committee, but not later than two-and-one-half months following the end of the year in which such verification occurred.

3.Performance Period. Except as provided below with respect to a Change of Control (as defined in the Plan), the “Performance Period” for any Performance Shares eligible to vest on any Normal Vesting Date shall be as follows:

A.First Segment. The Performance Period for the first one-third vesting of Performance Shares (those vesting on the Normal Vesting Date in January 2024) shall be the calendar year ending on December 31, 2023.

B.Second Segment. The Performance Period for the second one-third vesting of Performance Shares (those vesting on the Normal Vesting Date in January 2025) shall be the two calendar years ending December 31, 2024.

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C.Third Segment. The Performance Period for the final one-third vesting of Performance Shares (those vesting on the Normal Vesting Date in January 2026) shall be the three calendar years ending December 31, 2025.

4.Performance Goals. On each Normal Vesting Date, Valero’s performance will be measured against Valero’s total shareholder return (“TSR”) compared to its peers. Following the determination of Valero’s ranking with respect to TSR, the payout percentage (described below) will be subject to an increase or decrease based on Valero’s performance against the Energy Transition measures described below.

A.Total Shareholder Return (TSR).

(i)TSR will be compiled for a peer group of companies approved by the Compensation Committee (the “Target Group”) for the Performance Period immediately preceding each Normal Vesting Date. TSR for each such company is measured by dividing (A) the sum of (i) the dividends on the common stock of such company during the Performance Period, assuming dividend reinvestment, and (ii) the difference between the average closing price of a share of such company’s common stock for the 15 trading days ending December 31 at the end of the Performance Period and the average closing price of such shares for the 15 trading days ending December 31 immediately prior to the beginning of the Performance Period (appropriately adjusted for any stock dividend, stock split, spin-off, merger or other similar corporate events), by (B) the average closing price of a share of such company’s common stock for the 15 trading days ending December 31 immediately prior to the beginning of the Performance Period.

(ii)For each Performance Period, the TSR for Valero and each company in the Target Group shall be arranged by rank from highest performer to lowest performer according to the TSR achieved by each company. Shares of Common Stock will be awarded to Participant in accordance with Valero’s percentile ranking within the Target Group. The number of shares of Common Stock, if any, that Participant will be entitled to receive in settlement of the vested Performance Shares will be determined on each Normal Vesting Date, and subject to the provisions of the Plan and this Agreement, on such Normal Vesting Date, the vesting Performance Shares will be awarded as shares of Common Stock to the Participant per the payout percentages

Page 2

listed below when Valero’s TSR during the Performance Period falls within the following percentiles (“Percentiles”):

Ranking	Percentile	Payout
1	100.0%	200.0%
2	90.9%	200.0%
3	81.8%	175.0%
4	72.7%	150.0%
5	63.6%	125.0%
6	54.5%	100.0%
7	45.5%	85.0%
8	36.4%	65.0%
9	27.3%	45.0%
10	18.2%	25.0%
11	9.1%	0.0%
12	0.0%	0.0%

(iii)Notwithstanding anything in this Agreement to the contrary, in the event Valero’s TSR over the Performance Period is negative, then the total payout with respect to such Performance Period, inclusive of any modification under Section 4.B., will be capped at target (100%).

B.Energy Transition performance measure. After Valero’s TSR performance has been determined, the resulting payout percentage score will be subject to an increase or decrease of up to 25 percentage points, hereafter referred to as the “Energy Transition performance measure.”

(i)The Energy Transition performance measure has two equally weighted components (12.5 percentage points each): (1) Valero’s annual progress versus a target in achieving Valero’s publicly announced greenhouse gas emissions reduction/displacement target(s), and (2) the percentage of Valero’s growth capital expenditures deployed for low-carbon initiatives versus a target. All such targets shall be approved annually by the Committee.

(ii)If Valero meets or exceeds the targets for each of the Energy Transition performance components, Valero’s TSR score will be increased by 25 percentage points (e.g., a TSR score of 125% would be increased by 25 points to 150%), subject at all times to a maximum payout cap of 200% and the negative TSR cap discussed in Section 4.A.(iii) above. If, however, Valero does not meet the targets for each of the Energy Transition performance components, then Valero’s TSR score will be reduced by 25 percentage points (e.g., a TSR score of 125% would be reduced by 25 points to 100%). Meeting the target for one of the Energy Transition performance components but not the other results in a modifier of zero, and therefore does not alter the TSR score. Notwithstanding the foregoing, the Committee may provide with respect to the annual target for either component that performance must exceed the target in order for such target to be deemed met, and if performance equals the target, then no adjustment will be made to Valero’s TSR score for such component either up or down; performance below the target would still result in a reduction of points for such component as described above.

Page 3

C.Example of Vesting and Payout. Assume that 12,000 Performance Shares are vesting on a Normal Vesting Date. Assume the following for Valero’s performance:

•TSR achievement at 72.7th percentile (150% payout).

•Energy Transition assessment results in Valero meeting each metric’s target (+25 percentage points).

Calculation of shares of Common Stock to be awarded for Valero performance:

•150% (TSR) plus 25% points (Energy Transition) = 175%

•175% x 12,000 performance shares = 21,000 shares of Common Stock

D.Unearned Shares. Any Performance Shares not awarded as shares of Common Stock on a Normal Vesting Date will expire and be forfeited; such Performance Shares may not be carried forward for any additional Performance Period.

5.Dividend Equivalent Award. In addition to the Performance Shares granted in Section 1, the Participant is granted a Dividend Equivalent Award payable in shares of Common Stock, as provided herein. On each Normal Vesting Date (or Trigger Date, defined below), the amount of dividends paid to holders of Common Stock during the applicable Performance Period shall be determined with respect to the Participant’s Performance Shares that are vesting on that Normal Vesting Date — calculated as if the Performance Shares were outstanding shares of Common Stock (the resulting value being hereafter referred to as the “Target Dividend Equivalent Value” or “TDEV”). The TDEV is equal to (a) the number of Performance Shares vesting, times (b) the amount of accumulated dividends per share during the Performance Period.

The number of shares of Common Stock payable to Participant with respect to the Dividend Equivalent Award is equal to (1) divided by (2), where:

(1) is equal to:

(a) TDEV times (b) the TSR percentage payout plus or minus any Energy Transition measure adjustment; and

(2) is equal to the Fair Market Value per share of Common Stock on the vesting date.

Such shares of Common Stock shall be distributed to Participant contemporaneously with the distribution of the shares of Common Stock issued pursuant to Section 4. See Exhibit A for an example of this calculation.

6.Termination of Employment.

A.Voluntary Termination, Termination for “Cause,” and Early Retirement. If Participant’s employment is

(i)voluntarily terminated by the Participant (other than through retirement at age 60+, death or disability), including termination in connection with Participant’s voluntary early retirement (i.e., prior to age 60),

(ii)terminated by Valero for “cause” (as defined pursuant to the Plan),

then those Performance Shares that are outstanding and have not vested as of the effective date of termination shall thereupon be forfeited.

B.Retirement. If a Participant’s employment is terminated through his or her retirement when the Participant is age 60 or older, then any Performance Shares that (i) have not theretofore vested or been forfeited, and (ii) were granted at least one year prior to the Participant’s

Page 4

effective date of retirement, shall continue to remain outstanding and shall vest on the Normal Vesting Dates according to their original vesting schedule.

But any outstanding Performance Shares that were granted within one year of such Participant’s effective date of retirement shall be prorated based on the number of months worked from the date of grant to the Participant’s retirement date (rounding upward), and the prorated number of Performance Shares shall thereafter vest on the Normal Vesting Dates according to their original vesting schedule, and shall be distributed at the time(s) provided for under Section 2.C. above. Example:

•9,780 Performance Shares granted on February 23, 2023,

•Participant retires at age 60+ effective July 31, 2023,

•working period is calculated as 6 months (5 full months plus partial month rounding upward to 6 months),

•original grant is adjusted by 6/12ths (50%) resulting in 4,890 Performance Shares to vest according to their original vesting schedule.

C.Death, Disability, Involuntary Termination Other Than for “Cause,” and Change of Control. If a Participant’s employment is terminated (i) through death or disability, or (ii) by Valero other than for cause (as determined pursuant to the Plan), or (iii) as a result of a Change of Control (as described in the Plan) (each of the foregoing is hereafter referred to as a “Trigger Date”), then each Performance Period with respect to any Performance Shares that have not vested or been forfeited shall be terminated effective as of such Trigger Date. The (i) TSR for Valero and for each company in the Target Group and (ii) the Energy Transition performance measures shall be determined for each such shortened Performance Period and the percentage of Performance Shares to be awarded as shares of Common Stock for each such shortened Performance Period shall be determined in accordance with Section 4 and Section 5 and shall be distributed as soon as administratively practicable thereafter, and in any event within 90 days following such termination of employment.

(i)For purposes of determining the number of Performance Shares to be received as of any Trigger Date, the Target Group as most recently determined by the Compensation Committee prior to the Trigger Date shall be used.

(ii)If the Trigger Date is the result of a Change of Control, then the number of shares of Common Stock to be awarded to the Participant shall be prorated commensurate with the length of service of the Participant during each Performance Period. See Exhibit B for an example of this calculation.

7.Cash Payment Election. Effective on any Normal Vesting Date (or Trigger Date under Section 6.C.), the Participant (or the Participant’s estate under Section 6.C) may elect to receive up to 50% of the after-tax value of the aggregate number of shares of Common Stock earned on such Normal Vesting Date (or Trigger Date) in cash, with the remainder paid in shares of Common Stock. Example:

•following the calculation of Valero’s performance for the two-year performance period ending December 31, 2024, it is determined that the Participant is entitled to receive 8,000 shares of Common Stock on the Normal Vesting Date occurring in January 2025 (the “2025 Normal Vesting Date”),

•assume that the 8,000 shares have an aggregate tax value of $600,000 (8,000 shares times an assumed $75 FMV per share on the 2025 Normal Vesting Date), and the Participant has made a tax withholding election of 39.6%,

Page 5

•the after-tax value of the 8,000 shares of Common Stock awarded on the 2025 Normal Vesting Date is $362,400 ($600,000 times 60.4%),

•the Participant may elect to receive up to $181,200 ($362,400 times 50%) in cash on the 2025 Normal Vesting Date.

8.Plan Incorporated by Reference. The Plan is incorporated into this Agreement by this reference and is made a part hereof for all purposes. Capitalized terms not otherwise defined in this Agreement shall have the meaning specified in the Plan.

9.No Assignment. This Agreement and the Participant’s interest in the Performance Shares granted by this Agreement are of a personal nature, and, except as expressly permitted under the Plan, Participant’s rights with respect thereto may not be sold, mortgaged, pledged, assigned, transferred, conveyed or disposed of in any manner by Participant, except by an executor or beneficiary pursuant to a will or pursuant to the laws of descent and distribution. Any such attempted sale, mortgage, pledge, assignment, transfer, conveyance or disposition is void, and Valero will not be bound thereby.

10.Integration. This Agreement constitutes the entire agreement of the parties relating to the transactions contemplated hereby, and supersedes all provisions and concepts contained in all prior contracts or agreements between the Participant and Valero, including that certain Change of Control Severance Agreement (“COC Agreement”) between Participant and Valero. For avoidance of doubt, Participant acknowledges that in the context of a Change of Control of Valero, the terms of this Agreement shall prevail over the terms of the COC Agreement with respect to the vesting of the Performance Shares granted under this Agreement.

11.Successors. This Agreement shall be binding upon any successors of Valero and upon the beneficiaries, legatees, heirs, administrators, executors, legal representatives, successors and permitted assigns of Participant.

12.Code Section 409A. This Agreement is intended to comply, and shall be administered consistently in all respects, with Section 409A of the Internal Revenue Code of 1986, as amended (the “Code”), and the regulations and additional guidance promulgated thereunder to the extent applicable. Accordingly, Valero shall have the authority to take any action, or refrain from taking any action, with respect to this Agreement that is reasonably necessary to ensure compliance with Code Section 409A (provided that Valero shall choose the action that best preserves the value of payments and benefits provided to Participant under this Agreement that is consistent with Code Section 409A), and the parties agree that this Agreement shall be interpreted in a manner that is consistent with Code Section 409A. In furtherance, but not in limitation of the foregoing:

(a)in no event may Participant designate, directly or indirectly, the calendar year of any payment to be made hereunder;

(b)to the extent the Participant is a “specified employee” within the meaning of Code Section 409A, payments, if any, that constitute a “deferral of compensation” under Code Section 409A and that would otherwise become due during the first six months following Participant’s termination of employment shall be delayed and all such delayed payments shall be paid in full in the seventh month after such termination date, provided that the above delay shall not apply to any payment that is excepted from coverage by Code Section 409A, such as a payment covered by the short-term deferral exception described in Treasury Regulations Section 1.409A-1(b)(4);

Page 6

(c)notwithstanding any other provision of this Agreement, a termination, resignation or retirement of Participant’s employment hereunder shall mean and be interpreted consistent with a “separation from service” within the meaning of Code Section 409A;

(d)terms defined in this section will have the meanings given such terms under Section 409A if and to the extent required to comply with Section 409A. Notwithstanding any other provision hereof, Valero makes no representations or warranties and will have no liability to Participant or any other person if any provision of or payment under this Agreement is determined to constitute deferred compensation subject to Section 409A but does not satisfy the conditions of Section 409A.

Executed effective as of the date first written above.

VALERO ENERGY CORPORATION

by:	/s/ Julia Rendon Reinhart
	JULIA RENDON REINHART,
	Senior Vice President & Chief Human
	Resources Officer
	, Participant

Page 7

Exhibit A

Example of Potential Payout of Dividend Equivalent Award in Shares of Common Stock

(per Section 5 of the Agreement)

Assumptions and Calculations (for illustration purposes only):

1.Assume the Participant was granted 36,000 Performance Shares on February 23, 2023.

2.Assume the Normal Vesting Date for the second segment of these Performance Shares is January 24, 2025. On that date 12,000 Performance Shares (36,000 / 3 = 12,000) vest with respect to the two-year Performance Period ending December 31, 2024.

3.Assume the cumulative amount of dividends paid to holders of Common Stock during the eight quarters of the Performance Period is $7.52 per share.

4.The “Target Dividend Equivalent Value” (“TDEV”) is $90,240 (12,000 Performance Shares vesting, multiplied by $7.52 accumulated dividends per share).

5.Valero’s TSR ranking for the Performance Period is determined (per Section 4.A) to generate a payout of 150%.

6.Valero’s Energy Transition performance is determined (per Section 4.B.) to generate an increase to the payout of 25 percentage points to a total payout percentage of 175%.

7.The Fair Market Value per share of Common Stock on the vesting date is $75.00.

8.Based on the foregoing, the number of shares of Common Stock earned by the Participant for the Dividend Equivalent Award is 2,106 shares (rounded up from 2,105.6). The calculation is illustrated below as (1) divided by (2), where:

(1) is $157,920, calculated as $90,240 (TDEV) times 175% (150% TSR score + 25% Energy Transition performance adjustment); and

(2) is $75.00, the Fair Market Value per share of Common Stock on the vesting date.

Exhibit A

Exhibit B

Example of Potential Payout in a Change of Control Context

(per Section 6.C.(ii) of the Agreement)

Assumptions and Calculations (for illustration purposes only):

1.Assume the Participant was granted 36,000 Performance Shares on February 23, 2023.

2.Assume Participant’s employment is terminated on June 30, 2023 as a result of a Change of Control.

3.Per Section 6.C. of the Agreement, all Performance Periods for all segments (First Segment, Second Segment, Third Segment (See Section 3)) are shortened to end on June 30, 2023.

4.Valero’s TSR ranking for each shortened Performance Period is determined to generate a payout of 150%.

5.Valero’s Energy Transition performance for each shortened Performance Period is determined to generate an adjustment of an increase of 25 percentage points for a total payout of 175%.

6.Assume the cumulative amount of dividends paid to holders of Common Stock during the 6-month shortened Performance Period is $1.96 per share. Therefore, the “Target Dividend Equivalent Value” (“TDEV”) is $70,560 (36,000 Performance Shares vesting, multiplied by $1.96 accumulated dividends per share).

7.Based on the foregoing, the number of shares of Common Stock earned by the Participant for the Dividend Equivalent Award is 1,647 shares (rounded up from 1,646.4). The calculation is illustrated below as (1) divided by (2), where:

(1) is $123,480, calculated as $70,560 (TDEV) times 175% (150% TSR score + 25% Energy Transition performance adjustment); and

(2) is $75.00, the assumed Fair Market Value per share of Common Stock on the vesting date.

8.Payout of common shares to the Participant is prorated based on the Participant’s length of service during the original Performance Periods.

First Segment calculation.

36,000 / 3 = 12,000 performance shares.

Calculation of shares of Common Stock to be awarded for Valero performance:

•12,000 x 175% payout = 21,000 common shares

Prorate for 6 months of service in the 12-month Performance Period.

21,000 common shares x 6/12 = 10,500    common shares

Second Segment calculation.

36,000 / 3 = 12,000 performance shares.

Calculation of shares of Common Stock to be awarded for Valero performance:

•12,000 x 175% payout = 21,000 common shares

Prorate for 6 months of service in the 24-month Performance Period.

21,000 common shares x 6/24 = 5,250    common shares

Third Segment calculation.

36,000 / 3 = 12,000 performance shares.

Calculation of shares of Common Stock to be awarded for Valero performance:

•12,000 x 175% payout = 21,000 common shares

Prorate for 6 months of service in the 36-month Performance Period.

21,000 common shares x 6/36 = 3,500    common shares

Add DEA shares		1,647    common shares
	Total	20,897    common shares

Exhibit B

EX-10.04

Exhibit 10.04

AIRCRAFT TIME SHARING AGREEMENT

This AIRCRAFT TIME SHARING AGREEMENT (the “Agreement”) is entered into on [Month] [Day], [Year], by and between Valero Services, Inc., a Delaware corporation (the “Company”), and [Executive], an individual (the “Executive”), and shall be effective commencing [Month] [Day], [Year] (the “Effective Date”).

W I T N E S E T H:

WHEREAS,the Company owns, leases or operates certain aircraft identified on Exhibit A (individually and collectively as the context requires, the “Aircraft”) and operates the Aircraft for business use in accordance with the FAR (as hereinafter defined) and Valero Energy Corporation’s, a Delaware corporation (“Parent”), policies regarding use of the Aircraft (as may be amended from time to time, the “Aircraft Policy”);

WHEREAS,in order to provide for the safety and security of the Executive in his capacity as [Title] of the Company and the [Title] of the Parent, and to maximize the Executive’s ability to carry out his responsibilities thereto, the Company has determined it is appropriate for the Company to make the Aircraft available to the Executive for personal use, subject to the terms and conditions set forth in this Agreement;

WHEREAS, the Executive desires to have the Company operate the Aircraft for him from time to time on a non-exclusive time sharing basis in accordance with the provisions of Sections 91.501(b)(6), 91.501(c)(1) and 91.501(d) of the FAR;

WHEREAS, the Company is willing to provide the Aircraft to the Executive from time to time in accordance with the Aircraft Policy, on a non-exclusive time sharing basis; and

WHEREAS, during the Term (as hereinafter defined) of this Agreement, the Aircraft will be subject to use by or at the direction of the Company.

NOW, THEREFORE, in consideration of the mutual promises herein contained and other good and valid consideration, the receipt and sufficiency of which are hereby acknowledged, the parties agree as follows:

1.Definitions. The following terms shall have the following meanings for all purposes of this Agreement:

“Applicable Law” means, without limitation, all applicable laws, treaties, international agreements, decisions and orders of any court, arbitration or governmental agency or authority and rules, regulations, orders, directives, licenses and permits of any governmental body, instrumentality, agency or authority, including, without limitation, the FAR and 49 U.S.C. § 41101, et seq., as amended.

“FAA” means the Federal Aviation Administration or any successor agency.

“FAR” means, collectively, the Federal Aviation Regulations issued by the FAA, as codified at Title 14, Parts 1 to 199 of the United States Code of Federal Regulations, as from time to time amended.

“Operational Control” has the same meaning given the term in Section 1.1 of the FAR.

“Pilot in Command” has the same meaning given the term in Section 1.1 of the FAR.

“Taxes” means all taxes, charges and fees, including federal air transportation excise taxes pursuant to Section 4261 of the Internal Revenue Code of 1986, as amended, and international departure/arrival fees, as applicable, that are required to be collected from passengers and remitted by an aircraft operator regardless of whether any flight is considered “noncommercial” under the FAR.

“Term” means the entire period from the Effective Date to the date this Agreement is terminated pursuant to Section 3 (Term).

2.Provision of the Aircraft.

2.1.Time Sharing. The Company agrees to allow the Executive to use the Aircraft for personal travel from time to time on an “as needed and as available” time sharing basis in accordance with the Aircraft Policy and the terms and conditions of this Agreement.

2.2.Automatic Removal of Aircraft. In the event that the Company returns, transfers or otherwise disposes of any individual Aircraft listed on Exhibit A, such Aircraft shall be deemed immediately removed from the applicability of this Agreement regardless of whether such Aircraft is specifically removed from Exhibit A, and this Agreement shall be terminated as to such Aircraft but shall remain in full force and effect with respect to each of the other Aircraft identified thereon, if any. No such termination shall affect any of the rights and obligations of the parties accrued or incurred prior to such termination. If the Company becomes the owner and/or operator of any aircraft not listed on Exhibit A, Exhibit A shall be modified to include such aircraft as an Aircraft covered by this Agreement, and thereafter this Agreement shall remain in full force and effect with respect to such Aircraft and each of the other Aircraft identified thereon, if any.

2.3.No Liability. The Company shall not be liable to the Executive or any other person for loss, injury, or damage occasioned by the delay or failure to furnish the Aircraft and crew pursuant to this Agreement for any reason.

3.Term.

3.1.Term. This Agreement shall commence on the Effective Date and shall continue until terminated pursuant to Section 3.2 (Termination) of this Agreement.

3.2.Termination.

3.2.1.Each party shall have the right to terminate this Agreement at any time with or without cause on 10 days’ written notice to the other party; provided, however, that this Agreement may be terminated by the Company on such shorter notice as may be required for the Company to comply with Applicable Law, regulations, the requirements of any financial institution with a security or other interest

in the Aircraft, insurance requirements, or in the event the insurance required hereunder is not in full force and effect.

3.2.2.In the event that the Executive no longer serves as [Title] of Parent, the Agreement shall terminate concurrent with the Executive’s departure from the role of Chairman of the board of directors of Parent.

4.Applicable Regulations. The parties intend this Agreement to constitute, and this Agreement shall be interpreted as, a Time Sharing Agreement as defined in Section 91.501(c)(1) and authorized by Section 91.501(b)(6) of the FAR. The parties agree that the Aircraft shall be operated by the Company under the pertinent provisions of Part 91 of the FAR for all flights under this Agreement. If any provision of this Agreement is determined to be inconsistent with any of the requirements of Part 91 of the FAR, this Agreement shall be deemed amended in any respect necessary to bring it into compliance with such requirements.

5.Charges. For any flight conducted under this Agreement (excluding any deadhead flights required for repositioning), the Executive shall pay the Company an amount as agreed to by the Executive and the Company, not to exceed the expenses of operating such flight that may be charged pursuant to Section 91.501(d) of the FAR, which expenses are limited to:

5.1.fuel, oil, lubricants, and other additives;

5.2.travel expenses of the crew, including food, lodging, and ground transportation;

5.3.hangar and tie-down costs away from the Base (as defined in Section 9 (Aircraft Maintenance and Base of Operations) of this Agreement) of the Aircraft being used on the relevant flight;

5.4.insurance obtained for the specific flight;

5.5.landing fees, airport taxes, and similar assessments;

5.6.customs, foreign permit, and similar fees directly related to the flight;

5.7.in flight food and beverages;

5.8.passenger ground transportation;

5.9.flight planning and weather contract services; and

5.10.an additional charge equal to 100% of the expenses listed in Section 5.1 of this Agreement.

6.Invoices and Payment. The Company will initially pay, or cause to be paid, all expenses related to the operation of the Aircraft hereunder in the ordinary course. For each flight operated under this Agreement for which the Company seeks reimbursement, the Company shall provide an invoice to the Executive for certain or all of the agreed upon charges listed in Section 5 (Charges) of this Agreement and the Aircraft Policy as soon as administratively practicable (and in any event within 90 days) after the flight took place. In the event some charges are invoiced based on estimates, as such charges are not accurately or definitively known in their entirety at the time of invoicing (such estimates to be reconciled against the actual costs when known), or a determination is made by the Company after the end of the calendar year to seek additional reimbursements from the Executive for amounts permitted under FAR

Section 91.501(d) that were not previously invoiced or paid, the Company can, as soon as administratively practicable (and in any event within 90 days) after the end of the calendar year in which the flights took place, invoice the Executive for a portion or all of the charges incurred during the calendar year but not yet invoiced. The Executive shall remit the full amount of any such invoice, together with any applicable Taxes under Section 7 (Taxes), to the Company within 30 days after receipt of the invoice, as applicable.

7.Taxes. The Executive shall be responsible for all Taxes which may be assessed or levied as a result of the Executive’s use of the Aircraft under this time sharing arrangement and the Aircraft Policy. The Executive shall, as applicable, remit to the Company all such Taxes together with each payment made pursuant to Section 6 (Invoices and Payment).

8.Scheduling Flights.

8.1.Flight Requests. The Executive will provide the Company with requests for flight time and proposed flight schedules in accordance with the Aircraft Policy. Requests for flight time shall be in a form, whether written or oral, mutually convenient to, and agreed upon by the parties and in accordance with the Aircraft Policy.

8.2.Approval of Flight Requests. The Company may approve or deny any flight scheduling request in its sole discretion and in accordance with the Aircraft Policy.

9.Aircraft Maintenance and Base of Operations. The Company shall be solely responsible for maintenance, preventive maintenance and required or otherwise necessary inspections of each Aircraft, and shall take such requirements into account in scheduling the Aircraft. No period of maintenance, preventative maintenance, or inspection shall be delayed or postponed for the purpose of scheduling the Aircraft, unless such maintenance or inspection can be safely conducted at a later time in compliance with all Applicable Laws and regulations as determined by the director of maintenance (or similar title) or a supervisory aircraft maintenance technician (or, in each case, his/her designee) and within the sound discretion of the Pilot in Command. For purposes of this Agreement, the base of operations (“Base”) of the Aircraft shall be as set forth in Exhibit A; provided, however, that Base may be changed upon notice from the Company to the Executive.

10.Flight Crews. The Company shall provide a qualified flight crew for each flight conducted under this Agreement. The members of any such flight crew may be either employees or independent contractors of the Company. In either event, any flight crew shall be and remain under the exclusive command and control of the Company in all phases of all flights conducted under this Agreement.

11.Operational Control. THE PARTIES EXPRESSLY AGREE THAT THE COMPANY SHALL HAVE AND MAINTAIN OPERATIONAL CONTROL (AS DEFINED IN SECTION 1.1 OF THE FAR) OF ALL AIRCRAFT FOR ALL FLIGHTS OPERATED UNDER THIS AGREEMENT. The Company shall exercise exclusive authority over initiating, conducting, or terminating any flight conducted on behalf of the Executive pursuant to this Agreement.

12.Authority of Pilot In Command. Notwithstanding that the Company shall have Operational Control of the Aircraft during any flight conducted pursuant to this Agreement, the Company and the Executive expressly agree that the Pilot in Command shall have absolute discretion in all matters concerning the preparation of the Aircraft for flight and any flight itself and may terminate any flight, refuse to commence any flight, or take any other flight-related action (including, without limitation, the route to be flown, the place where landings shall be made, and all other matters relating to operation of the Aircraft) which in the judgment of the Pilot in Command is necessary to ensure the safety and security

of the Aircraft, the flight crew, the passengers, and persons and property on the ground. The Pilot in Command shall have final and complete authority to postpone or cancel any flight for any reason or condition that in his or her judgment could compromise the safety or security of the flight and to take any other action that in the sole judgment of the Pilot in Command is necessitated by considerations of safety. No such action of the Pilot in Command shall create or support any liability of the Company to the Executive, his invitees and guests for loss, injury, damage or delay related to such decisions or the results of such decisions.

13.Insurance.

13.1.Liability. In connection with any use of the Aircraft, for the benefit of the Company and the Executive, the Company shall maintain, or cause to be maintained, bodily injury and property damage, liability insurance in an amount customary in the industry for similar aircraft and operations. Such policy shall be an occurrence policy naming the Company as Named Insured, and the Executive as an Additional Insured.

13.2.Hull. The Company shall maintain, or cause to be maintained, all risks aircraft hull insurance for each Aircraft in amounts determined from time to time by agreement of Company and the provider of the insurance.

13.3.Additional Insurance. The Company shall use reasonable efforts to provide such additional insurance coverage as the Executive may request or require. The Executive acknowledges that any trips scheduled to areas not currently covered by existing policies may require the Company to purchase additional insurance to comply with applicable regulations, and the Company shall be required to maintain or cause to be maintained such additional insurance.

13.4.Insurance Certificates. The Company will provide a copy of its Certificate of Insurance to the Executive from time to time as requested by the Executive.

14.Representations and Warranties. The Executive represents and warrants that:

14.1.The Executive will use the Aircraft solely for his own use and the use of his family and guests, and the Executive will not use any Aircraft for the purpose of providing transportation of passengers or cargo for compensation or hire.

14.2.The Executive shall not incur any mechanic’s or other liens on the Aircraft nor do anything or take any action that might mature into such a lien. The Executive shall not attempt to convey, mortgage, assign, lease, sublease, or in any way alienate any Aircraft or the Company’s rights hereunder.

14.3.During the Term of this Agreement, the Executive will (and will cause his invitee(s) and guest(s) to) abide by and conform to all Applicable Laws, governmental and airport orders, rules and regulations, as shall from time to time be in effect relating in any way to the operation and use of any Aircraft under this Agreement.

15.No Assignments. Neither this Agreement nor any party’s interest herein shall be assignable to any other party. This Agreement shall inure to the benefit of and be binding upon the parties hereto, and their respective representatives and successors.

16.Administration and Amendment Modification; Further Acts. This Agreement may not be modified, altered, or amended except by written agreement executed by both parties; provided, however, that the Executive hereby acknowledges and agrees that the Company may amend Exhibit A to add or remove Aircraft without his consent or written agreement. The Company and the Executive shall from

time to time perform such other and further acts and execute such other and further instruments as may be required by law or may be reasonably necessary (i) to carry out the intent and purpose of this Agreement, and (ii) to establish, maintain and protect the respective rights and remedies of each party.

17.Headings. The section headings in this Agreement are for convenience of reference only and shall not modify, define, expand, or limit any of the terms or provisions hereof.

18.Notices. All notices and communications required or permitted by this Agreement (except for notices made purely for flight scheduling, which are governed by the provisions of Section 8 (Scheduling Flights) of this Agreement) shall be in writing and shall be deemed to have been duly given or made when delivered personally or transmitted electronically by e-mail, receipt of which must be acknowledged to be received, or in the case of documented overnight delivery service or registered or certified mail, return receipt requested, delivery charge or postage prepaid, on the date shown on the receipt therefor, in each case at the address set forth below:

If to the Company:	Valero Services, Inc.
	One Valero Way, San Antonio, Tx, 78249
	Attention:	Richard J. Walsh, Senior Vice President, General Counsel and Secretary
		(Rich.Walsh@valero.com); with copy to:
		Julia R. Reinhart, Senior Vice President (Julia.Reinhart@valero.com)

If to the Executive: At his home address listed in the records of the Company and the Parent.

19.Governing Law. This Agreement shall be governed by the laws of the State of Texas, without regard to its choice of law principles.

20.Limitation of Liability. THE COMPANY (IN ITS OWN RIGHT AND ON BEHALF OF ITS AFFILIATES AND THEIR RESPECTIVE OFFICERS, DIRECTORS, MANAGERS, EMPLOYEES AND AGENTS) HEREBY DISCLAIMS, AND THE EXECUTIVE (IN HIS OWN RIGHT AND ON BEHALF OF HIS INVITEES AND GUESTS) HEREBY WAIVES, ANY LIABILITY, DUTY FOR INDEMNIFICATION OR CONTRIBUTION TO EXECUTIVE OR EXECUTIVE’S GUESTS FOR ANY CLAIMED LIABILITIES, LOSSES, OR DIRECT, INDIRECT, SPECIAL, CONSEQUENTIAL, EXEMPLARY AND/OR PUNITIVE DAMAGES OF ANY KIND OR NATURE UNDER ANY CIRCUMSTANCES OR FOR ANY REASON RESULTING FROM OR ARISING OUT OF THE USE OR OPERATION OF THE AIRCRAFT PURSUANT TO THIS AGREEMENT (INCLUDING ANY DELAY OR FAILURE TO FURNISH THE AIRCRAFT OR CAUSED OR OCCASIONED BY THE PERFORMANCE OR NON-PERFORMANCE OF ANY SERVICES COVERED BY THIS AGREEMENT) (ALTOGETHER, THE “LOSSES”), REGARDLESS OF WHETHER SUCH LOSSES ARISE OUT OF OR ARE CAUSED BY, IN WHOLE OR IN PART, COMPANY’S NEGLIGENCE, GROSS NEGLIGENCE, OR STRICT LIABILITY OR WHETHER COMPANY KNEW OR SHOULD HAVE KNOWN OF THE POSSIBILITY OF SUCH LOSSES.

21.Sole Recourse. The Executive agrees in his own right and on behalf of his invitees and guests that the proceeds of the insurance required by Section 13 (Insurance) shall provide the sole recourse for all claims, losses, liabilities, obligations, demands, suits, judgments or causes of action, penalties, fines, costs and expenses of any nature whatsoever, including attorneys' fees and expenses for or on account of or arising out of, or in any way connected with the use of the Aircraft by the Executive and his invitees and guests, including property damage, bodily injury to or death of any persons, including the Executive

and his invitees and guests which may result from or arise out of the use or operation or maintenance of the Aircraft during the term of this Agreement.

22.Counterparts. This Agreement may be executed by the parties hereto in separate counterparts, each and all of which when so executed and delivered shall be an original, and all of which shall together constitute one and the same instrument. This Agreement may be signed manually or digitally and the counterparts may be delivered in person, by mail, overnight courier, fax, emailed as a pdf, through a digital signature application or any other electronic means that reproduces an image of the actual executed signature page and such counterpart shall be effective as if it was a manually executed counterpart hereof.

23.Severability. If any provision of this Agreement is held to be illegal, invalid or unenforceable in any jurisdiction, such provision shall, as to such jurisdiction, be ineffective to the extent of such prohibition or unenforceability without invalidating the remaining provisions hereof. To the extent permitted by Applicable Law, each party waives any provision of law that renders any provision hereof prohibited or unenforceable in any respect.

24.Waivers. The failure or delay on the part of any party hereto to insist upon or enforce strict performance of any provision of this Agreement by any other party hereto, or to exercise any right, power or remedy under this Agreement, shall not be deemed or construed as a waiver thereof nor shall it be deemed or construed as a general waiver thereof or of any other provision or rights thereunder.

25.Force Majeure. The Company shall not be liable for delay or failure to furnish the Aircraft and crew pursuant to this Agreement when scheduled when such failure is caused by government regulation or authority, mechanical difficulty or breakdown, war, terrorism, civil commotion, strikes or labor disputes, pandemics or quarantines, weather conditions, acts of God, or other circumstances beyond the Company’s reasonable control.

26.Entire Agreement. This Agreement constitutes the entire agreement of the parties as of the Effective Date and supersedes all prior or independent, oral or written agreements, understandings, statements, representations, commitments, promises, and warranties made with respect to the subject matter of this Agreement.

27.No Third Party Beneficiary. No party, other than the parties expressly named herein, is intended to be a beneficiary of any provision of this Agreement.

28.Survival. The provisions of Sections 3.2.2, 6, 7, 8.2, 12, 16, 20 and 21 shall survive termination of this Agreement.

[Agreement Continued on the Next Page]

29.Truth In Leasing Statement Under Section 91.23 of the Federal Aviation Regulations.

WITHIN THE 12 MONTH PERIOD PRECEDING THE DATE OF THIS AGREEMENT, EACH AIRCRAFT HAS BEEN INSPECTED AND MAINTAINED IN ACCORDANCE WITH THE PROVISIONS OF FAR PART 91.

THE PARTIES HERETO CERTIFY THAT DURING THE TERM OF THIS AGREEMENT AND FOR OPERATIONS CONDUCTED HEREUNDER, EACH AIRCRAFT WILL BE MAINTAINED AND INSPECTED IN ACCORDANCE WITH THE PROVISIONS OF FAR PART 91.

THE COMPANY (WHOSE ADDRESS APPEARS IN SECTION 18 (NOTICES) ABOVE) ACKNOWLEDGES (AND CERTIFIES BY ITS SIGNATURE BELOW) THAT (i) THE AIRCRAFT ARE IN COMPLIANCE WITH APPLICABLE MAINTENANCE AND INSPECTION REQUIREMENTS UNDER PART 91 OF THE FEDERAL AVIATION REGULATIONS, (ii) WHEN IT OPERATES ANY AIRCRAFT UNDER THIS AGREEMENT, THE COMPANY SHALL BE KNOWN AS, CONSIDERED, AND IN FACT WILL BE THE OPERATOR OF, AND SHALL HAVE OPERATIONAL CONTROL OF, THE AIRCRAFT.

EACH PARTY HERETO CERTIFIES THAT IT UNDERSTANDS THE EXTENT OF ITS RESPONSIBILITIES, SET FORTH IN THIS AGREEMENT FOR COMPLIANCE WITH APPLICABLE FEDERAL AVIATION REGULATIONS.

AN EXPLANATION OF FACTORS BEARING ON OPERATIONAL CONTROL AND THE PERTINENT FEDERAL AVIATION REGULATIONS CAN BE OBTAINED FROM THE NEAREST FAA FLIGHT STANDARDS OFFICE.

THE PARTIES HERETO CERTIFY THAT A TRUE COPY OF THIS AGREEMENT SHALL BE CARRIED ON EACH AIRCRAFT AT ALL TIMES, AND SHALL BE MADE AVAILABLE FOR INSPECTION UPON REQUEST BY AN APPROPRIATELY CONSTITUTED AND IDENTIFIED REPRESENTATIVE OF THE ADMINISTRATOR OF THE FAA.

THE COMPANY, ON BEHALF OF THE EXECUTIVE, SHALL TAKE THE STEPS SET FORTH ON EXHIBIT B TO COMPLY WITH THE TRUTH-IN-LEASING REQUIREMENTS.

IN WITNESS WHEREOF, the parties have executed this AIRCRAFT TIME SHARING AGREEMENT as of the date and year first written above.

THE COMPANY:		THE EXECUTIVE:
Valero Services, Inc.
By:	/s/ Julia Rendon Reinhart
	Name: Julia Rendon Reinhart	, Individually Date/Time:
	Title: Senior Vice President & Chief Human Resources Officer Date/Time:

EX-31.01

Exhibit 31.01

CERTIFICATION PURSUANT TO SECTION 302

OF THE SARBANES-OXLEY ACT OF 2002

I, Joseph W. Gorder, 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: April 27, 2023

/s/ Joseph W. Gorder

Joseph W. Gorder
Chief Executive Officer

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: April 27, 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 March 31, 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/ Joseph W. Gorder

Joseph W. Gorder

Chief Executive Officer

April 27, 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 March 31, 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

April 27, 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	3 Months Ended
	Mar. 31, 2023	Apr. 21, 2023
Cover [Abstract]
Document type	10-Q
Document quarterly report	true
Document period end date	Mar. 31, 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		361,516,949
Entity central index key	0001035002
Amendment flag	false
Document fiscal year focus	2023
Document fiscal period focus	Q1
Current fiscal year end date	--12-31

XML

Consolidated Balance Sheets - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Current assets:
Cash and cash equivalents	$ 5,521	$ 4,862
Receivables, net	9,688	11,919
Inventories	7,455	6,752
Prepaid expenses and other	671	600
Total current assets	23,335	24,133
Property, plant, and equipment, at cost	50,828	50,576
Accumulated depreciation	(20,048)	(19,598)
Property, plant, and equipment, net	30,780	30,978
Deferred charges and other assets, net	6,062	5,871
Total assets	60,177	60,982
Current liabilities:
Current portion of debt and finance lease obligations	1,258	1,109
Accounts payable	10,498	12,728
Accrued expenses	1,168	1,215
Taxes other than income taxes payable	1,574	1,568
Income taxes payable	867	841
Total current liabilities	15,365	17,461
Debt and finance lease obligations, less current portion	10,173	10,526
Deferred income tax liabilities	5,280	5,217
Other long-term liabilities	2,292	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	6,877	6,863
Treasury stock, at cost; 311,978,678 and 301,372,958 common shares	(21,637)	(20,197)
Retained earnings	40,935	38,247
Accumulated other comprehensive loss	(1,205)	(1,359)
Total Valero Energy Corporation stockholders’ equity	24,977	23,561
Noncontrolling interests	2,090	1,907
Total equity	27,067	25,468
Total liabilities and equity	$ 60,177	$ 60,982

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Consolidated Balance Sheets (Parenthetical) - $ / shares	Mar. 31, 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	1,200,000,000	1,200,000,000
Common stock, shares issued	673,501,593	673,501,593
Treasury stock, common shares	311,978,678	301,372,958

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Consolidated Statements of Income (unaudited) - USD ($) shares in Millions, $ in Millions		3 Months Ended
		Mar. 31, 2023	Mar. 31, 2022
Revenues	[1]	$ 36,439	$ 38,542
Cost of sales:
Cost of materials and other	[2]	30,005	34,949
Operating expenses (excluding depreciation and amortization expense reflected below)		1,477	1,379
Depreciation and amortization expense		650	595
Total cost of sales		32,132	36,923
Other operating expenses		10	19
General and administrative expenses (excluding depreciation and amortization expense reflected below)		244	205
Depreciation and amortization expense		10	11
Operating income		4,043	1,384
Other income (expense), net		129	(20)
Interest and debt expense, net of capitalized interest		(146)	(145)
Income before income tax expense		4,026	1,219
Income tax expense		880	252
Net income		3,146	967
Less: Net income attributable to noncontrolling interests		79	62
Net income attributable to Valero Energy Corporation stockholders		$ 3,067	$ 905
Earnings (loss) per common share (in dollars per share)		$ 8.30	$ 2.21
Weighted-average common shares outstanding (in shares)		369	408
Earnings (loss) per common share – assuming dilution (in dollars per share)		$ 8.29	$ 2.21
Weighted-average common shares outstanding – assuming dilution (in shares)		369	408
Supplemental information:
Includes excise taxes on sales by certain of our foreign operations		$ 1,422	$ 1,423

[1] Includes excise taxes on sales by certain of our foreign operations of $1,422 million and $1,423 million for the three months ended March 31, 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 $246 million and $156 million for the three months ended March 31, 2023 and 2022, respectively.

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Consolidated Statements of Comprehensive Income (unaudited) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Net income	$ 3,146	$ 967
Other comprehensive income (loss):
Foreign currency translation adjustment	134	13
Net gain (loss) on pension and other postretirement benefits	(7)	8
Net gain (loss) on cash flow hedges	57	(45)
Other comprehensive income (loss) before income tax expense	184	(24)
Income tax expense related to items of other comprehensive income (loss)	1	0
Other comprehensive income (loss)	183	(24)
Comprehensive income	3,329	943
Less: Comprehensive income attributable to noncontrolling interests	108	39
Comprehensive income attributable to Valero Energy Corporation stockholders	$ 3,221	$ 904

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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	967	905				905		62
Dividends on common stock	(401)	(401)				(401)
Stock-based compensation expense	32	32		32
Transactions in connection with stock-based compensation plans	0	0		(27)	27
Purchases of common stock for treasury	(144)	(144)			(144)
Contributions from noncontrolling interests	165							165
Distributions to noncontrolling interests	(2)							(2)
Other comprehensive income (loss)	(24)	(1)					(1)	(23)
Balance as of end of period at Mar. 31, 2022	20,410	18,821	7	6,832	(15,794)	28,785	(1,009)	1,589
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	3,146	3,067				3,067		79
Dividends on common stock	(379)	(379)				(379)
Stock-based compensation expense	39	39		39
Transactions in connection with stock-based compensation plans	0	0		(25)	25
Purchases of common stock for treasury	(1,465)	(1,465)			(1,465)
Contributions from noncontrolling interests	75							75
Other comprehensive income (loss)	183	154					154	29
Balance as of end of period at Mar. 31, 2023	$ 27,067	$ 24,977	$ 7	$ 6,877	$ (21,637)	$ 40,935	$ (1,205)	$ 2,090

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Consolidated Statements of Equity (unaudited) (Parenthetical) - $ / shares	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Common stock dividends:
Dividends on common stock (in dollars per share)	$ 1.02	$ 0.98

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Consolidated Statements of Cash Flows (unaudited) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Cash flows from operating activities:
Net income	$ 3,146	$ 967
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization expense	660	606
Loss (gain) on early retirement of debt, net	(11)	50
Deferred income tax expense (benefit)	54	(234)
Changes in current assets and current liabilities	(534)	(722)
Changes in deferred charges and credits and other operating activities, net	(145)	(79)
Net cash provided by operating activities	3,170	588
Cash flows from investing activities:
Purchases of available-for-sale (AFS) debt securities	(100)	0
Proceeds from sales and maturities of AFS debt securities	71	0
Other investing activities, net	4	2
Net cash used in investing activities	(549)	(841)
Cash flows from financing activities:
Premiums paid on early retirement of debt	(5)	(48)
Purchases of common stock for treasury	(1,451)	(144)
Common stock dividend payments	(379)	(401)
Contributions from noncontrolling interests	75	165
Other financing activities, net	(1)	(10)
Net cash used in financing activities	(1,998)	(1,228)
Effect of foreign exchange rate changes on cash	36	(3)
Net increase (decrease) in cash and cash equivalents	659	(1,484)
Cash and cash equivalents at beginning of period	4,862	4,122
Cash and cash equivalents at end of period	5,521	2,638
Excluding Variable Interest Entities (VIEs) [Member]
Cash flows from investing activities:
Capital expenditures	(175)	(152)
Deferred turnaround and catalyst cost expenditures	(235)	(453)
Cash flows from financing activities:
Proceeds from debt issuances and borrowings	750	939
Repayments of debt and finance lease obligations	(973)	(1,738)
Diamond Green Diesel Holdings LLC (DGD) [Member]
Cash flows from investing activities:
Capital expenditures	(90)	(219)
Deferred turnaround and catalyst cost expenditures	(24)	(6)
Cash flows from financing activities:
Proceeds from debt issuances and borrowings	150	99
Repayments of debt and finance lease obligations	(156)	(102)
Other VIEs [Member]
Cash flows from investing activities:
Capital expenditures	0	(13)
Cash flows from financing activities:
Proceeds from borrowings of other VIEs	14	28
Repayments of debt and finance lease obligations	$ (22)	$ (16)

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Basis of Presentation and Significant Accounting Policies

3 Months Ended

Mar. 31, 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 period presented. All such adjustments are of a normal recurring nature unless disclosed otherwise. Operating results for the interim period 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

3 Months Ended

Mar. 31, 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, and we began the required monthly reporting for our two California refineries at that time.

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) authorizes 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 expands 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) creates the Division of Petroleum Market Oversight within the CEC to analyze the data provided under SBx 1-2, and (iv) authorizes the CEC to regulate the timing and other aspects of refinery turnaround and maintenance activities in certain instances. The provisions of SBx 1-2 are expected to become effective June 26, 2023. The CEC has not yet undertaken rulemaking with respect to SBx 1-2, including the establishment of any max margin, the imposition of a financial penalty, restrictions on turnaround and maintenance activities, or determining the format and manner in which the increased data is to be reported, and it is uncertain when or whether any such rulemaking will occur. The increased reporting is substantial, requiring 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. In addition, the required operational data will include our plans for turnaround and maintenance activities at our two California refineries and how we expect to address the potential impacts on feedstock and product inventories in California as a result of such turnaround and maintenance activities.

We are reviewing and analyzing 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, 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

3 Months Ended

Mar. 31, 2023

Inventory Disclosure [Abstract]

INVENTORIES

3.    INVENTORIES

Inventories consisted of the following (in millions):

	March 31, 2023		December 31, 2022
Refinery feedstocks	$	1,820	$	1,949
Refined petroleum products and blendstocks	4,120		3,579
Renewable diesel feedstocks and products	827		583
Ethanol feedstocks and products	366		328
Materials and supplies	322		313
Inventories	$	7,455	$	6,752

As of March 31, 2023 and December 31, 2022, the replacement cost (market value) of last-in, first-out (LIFO) inventories exceeded their LIFO carrying amounts by $6.0 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 March 31, 2023 and December 31, 2022, respectively.

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Debt

3 Months Ended

Mar. 31, 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

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):

				March 31, 2023
	Facility Amount		Maturity Date	Outstanding Borrowings		Letters of Credit Issued (a)		Availability
Committed facilities:
Valero Revolver	$	4,000	November 2027	$	—	$	6	$	3,994
Canadian Revolver	C$	150	November 2023	C$	—	C$	5	C$	145
Accounts receivable sales facility	$	1,300	July 2023	$	—	n/a		$	1,300
Committed facilities of VIEs (b):
DGD Revolver (c)	$	400	March 2024	$	100	$	75	$	225
DGD Loan Agreement (d)	$	25	April 2023	$	25	n/a		$	—
IEnova Revolver (e)	$	830	February 2028	$	710	n/a		$	120
Uncommitted facilities:
Letter of credit facilities	n/a		n/a	n/a		$	158	n/a

________________________

(a)Letters of credit issued as of March 31, 2023 expire at various times in 2023 through 2024.

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

(c)The variable interest rate on the DGD Revolver was 6.460 percent and 5.880 percent as of March 31, 2023 and December 31, 2022, respectively.

(d)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. The variable interest rate on the DGD Loan Agreement was 7.173 percent and 6.672 percent as of March 31, 2023 and December 31, 2022, respectively. We expect this facility to be renewed prior to its maturity date.

(e)The variable interest rate on the IEnova Revolver was 8.443 percent and 7.393 percent as of March 31, 2023 and December 31, 2022, respectively.

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

	Three Months Ended March 31,
	2023		2022
Borrowings:
Accounts receivable sales facility	$	750	$	300
DGD Revolver	150		99
IEnova Revolver	14		28
Repayments:
Accounts receivable sales facility	(750)		(300)
DGD Revolver	(150)		(99)
IEnova Revolver	(21)		(15)

Other Disclosures

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

	Three Months Ended March 31,
	2023		2022
Interest and debt expense	$	152	$	157
Less: Capitalized interest	6		12
Interest and debt expense, net of capitalized interest	$	146	$	145

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Equity

3 Months Ended

Mar. 31, 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 months ended March 31, 2023 and 2022, we purchased for treasury 10,993,341 shares and 1,545,873 shares, respectively. On October 26, 2022, our Board authorized our purchase of up to $2.5 billion of our outstanding common stock with no expiration date (the October 2022 Program). On February 23, 2023, our Board authorized our purchase of up to an additional $2.5 billion of our outstanding common stock with no expiration date (the 2023 Program),which is in addition to the amount remaining under the October 2022 Program. As of March 31, 2023, we had $899 million remaining available for purchase under the October 2022 Program and $2.5 billion available for purchase under the 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 March 31,
	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	137		—		37		174		13		(3)		(64)		(54)
Amounts reclassified from accumulated other comprehensive loss	—		(7)		(15)		(22)		—		7		46		53
Effect of exchange rates	—		2		—		2		—		—		—		—
Other comprehensive income (loss)	137		(5)		22		154		13		4		(18)		(1)
Balance as of end of period	$	(1,031)	$	(188)	$	14	$	(1,205)	$	(549)	$	(437)	$	(23)	$	(1,009)

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Variable Interest Entities

3 Months Ended

Mar. 31, 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 March 31, 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 table presents summarized balance sheet information for the significant assets and liabilities of the consolidated VIEs, which are included in our balance sheets (in millions):

	DGD		Central Mexico Terminals		Other		Total
March 31, 2023
Assets
Cash and cash equivalents	$	92	$	—	$	26	$	118
Other current assets	1,246		10		32		1,288
Property, plant, and equipment, net	3,759		676		77		4,512
Liabilities
Current liabilities, including current portion of debt and finance lease obligations	$	443	$	748	$	7	$	1,198
Debt and finance lease obligations, less current portion	686		—		12		698
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

3 Months Ended

Mar. 31, 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 March 31
Service cost	$	28	$	38	$	1	$	2
Interest cost	30		21		3		2
Expected return on plan assets	(50)		(48)		—		—
Amortization of:
Net actuarial (gain) loss	(2)		13		(1)		—
Prior service credit	(5)		(4)		(1)		(1)
Net periodic benefit cost	$	1	$	20	$	2	$	3

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 (expense), net.”

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Earnings Per Common Share

3 Months Ended

Mar. 31, 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 March 31,
	2023		2022
Earnings per common share:
Net income attributable to Valero stockholders	$	3,067	$	905
Less: Income allocated to participating securities	10		3
Net income available to common stockholders	$	3,057	$	902
Weighted-average common shares outstanding	369		408
Earnings per common share	$	8.30	$	2.21
Earnings per common share – assuming dilution:
Net income attributable to Valero stockholders	$	3,067	$	905
Less: Income allocated to participating securities	10		3
Net income available to common stockholders	$	3,057	$	902
Weighted-average common shares outstanding	369		408
Effect of dilutive securities	—		—
Weighted-average common shares outstanding – assuming dilution	369		408
Earnings per common share – assuming dilution	$	8.29	$	2.21

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

3 Months Ended

Mar. 31, 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):

	March 31, 2023		December 31, 2022
Receivables from contracts with customers, included in receivables, net	$	6,073	$	7,189
Contract liabilities, included in accrued expenses	45		129

During the three months ended March 31, 2023 and 2022, we recognized as revenue $120 million and $69 million that was included in contract liabilities as of December 31, 2022 and 2021, respectively.

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 March 31, 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 March 31, 2023
Revenues:
Revenues from external customers	$	34,407	$	935	$	1,097	$	—	$	36,439
Intersegment revenues	3		745		223		(971)		—
Total revenues	34,410		1,680		1,320		(971)		36,439
Cost of sales:
Cost of materials and other (a)	28,510		1,331		1,131		(967)		30,005
Operating expenses (excluding depreciation and amortization expense reflected below)	1,261		86		130		—		1,477
Depreciation and amortization expense	572		58		20		—		650
Total cost of sales	30,343		1,475		1,281		(967)		32,132
Other operating expenses	10		—		—		—		10
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		244		244
Depreciation and amortization expense	—		—		—		10		10
Operating income by segment	$	4,057	$	205	$	39	$	(258)	$	4,043
Three months ended March 31, 2022
Revenues:
Revenues from external customers	$	36,813	$	595	$	1,134	$	—	$	38,542
Intersegment revenues	4		386		127		(517)		—
Total revenues	36,817		981		1,261		(517)		38,542
Cost of sales:
Cost of materials and other (a)	33,606		755		1,104		(516)		34,949
Operating expenses (excluding depreciation and amortization expense reflected below)	1,193		51		135		—		1,379
Depreciation and amortization expense	549		26		20		—		595
Total cost of sales	35,348		832		1,259		(516)		36,923
Other operating expenses	18		—		1		—		19
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		205		205
Depreciation and amortization expense	—		—		—		11		11
Operating income by segment	$	1,451	$	149	$	1	$	(217)	$	1,384

________________________

(a)Cost of materials and other for our Renewable Diesel segment is net of the blender’s tax credit on qualified fuel mixtures of $246 million and $156 million for the three months ended March 31, 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 March 31,
	2023		2022
Refining:
Gasolines and blendstocks	$	15,048	$	15,560
Distillates	16,838		17,444
Other product revenues	2,521		3,809
Total refining revenues	34,407		36,813
Renewable Diesel:
Renewable diesel	876		595
Renewable naphtha	59		—
Total Renewable Diesel revenues	935		595
Ethanol:
Ethanol	763		875
Distillers grains	334		259
Total ethanol revenues	1,097		1,134
Revenues	$	36,439	$	38,542

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

	March 31, 2023		December 31, 2022
Refining	$	46,852	$	48,484
Renewable Diesel	5,390		5,217
Ethanol	1,628		1,551
Corporate and eliminations	6,307		5,730
Total assets	$	60,177	$	60,982

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Supplemental Cash Flow Information

3 Months Ended

Mar. 31, 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):

	Three Months Ended March 31,
	2023		2022
Decrease (increase) in current assets:
Receivables, net	$	2,381	$	(2,653)
Inventories	(641)		(940)
Prepaid expenses and other	(37)		(77)
Increase (decrease) in current liabilities:
Accounts payable	(2,269)		2,744
Accrued expenses	(61)		(120)
Taxes other than income taxes payable	(23)		36
Income taxes payable	116		288
Changes in current assets and current liabilities	$	(534)	$	(722)

Changes in current assets and current liabilities for the three months ended March 31, 2023 were primarily due to the following:

•The decrease in receivables was primarily due to a decrease in sales volumes in March 2023 compared to December 2022;

•The increase in inventories was due to an increase in inventory volumes valued at higher unit prices; and

•The decrease in accounts payable was due to a decrease in crude oil and other feedstock volumes purchased combined with a decrease in related prices in March 2023 compared to December 2022.

Changes in current assets and current liabilities for the three months ended March 31, 2022 were primarily due to the following:

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

•The increase in inventories was primarily due to an increase in inventory unit prices and higher inventory levels in March 2022 compared to December 2021; and

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

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

	Three Months Ended March 31,
	2023		2022
Interest paid in excess of amount capitalized, including interest on finance leases	$	82	$	93
Income taxes paid, net	616		204

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

	Three Months Ended March 31,
	2023				2022
	Operating Leases		Finance Leases		Operating Leases		Finance Leases
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows	$	102	$	27	$	97	$	20
Financing cash flows	—		49		—		41
Changes in lease balances resulting from new and modified leases	67		47		79		100

There were no significant noncash investing and financing activities during the three months ended March 31, 2023 or 2022, except as noted in the table above.

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Fair Value Measurements

3 Months Ended

Mar. 31, 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 March 31, 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.

	March 31, 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	$	616	$	—	$	—	$	616	$	(425)	$	(74)	$	117	$	—
Physical purchase contracts	—		2		—		2		n/a		n/a		2		n/a
Investments of certain benefit plans	71		—		6		77		n/a		n/a		77		n/a
Investments in AFS debt securities	85		139		—		224		n/a		n/a		224		n/a
Total	$	772	$	141	$	6	$	919	$	(425)	$	(74)	$	420
Liabilities
Commodity derivative contracts	$	425	$	—	$	—	$	425	$	(425)	$	—	$	—	$	(1)
Blending program obligations	—		46		—		46		n/a		n/a		46		n/a
Physical purchase contracts	—		5		—		5		n/a		n/a		5		n/a
Foreign currency contracts	9		—		—		9		n/a		n/a		9		n/a
Total	$	434	$	51	$	—	$	485	$	(425)	$	—	$	60

	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):

	March 31, 2023						December 31, 2022
	Level 1		Level 2		Total		Level 1		Level 2		Total
Cash and cash equivalents	$	7	$	91	$	98	$	—	$	125	$	125
Prepaid expenses and other	78		48		126		56		40		96
Investments in AFS debt securities	$	85	$	139	$	224	$	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 months ended March 31, 2023 and the year ended December 31, 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, 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 March 31, 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).

		March 31, 2023				December 31, 2022
	Fair Value Hierarchy	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Financial liabilities:
Debt (excluding finance lease obligations)	Level 2	$	9,037	$	8,862	$	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

3 Months Ended

Mar. 31, 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 income (loss) is summarized below under “Effect of Derivative Instruments on Income and Other Comprehensive Income (Loss).”

Risk Management Activities by Type of Risk

Commodity Price Risk

We are exposed to market risks related to the volatility in the price of feedstocks (primarily crude oil, waste and renewable feedstocks, and corn), the products we produce, and natural gas 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 March 31, 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	3,596	—
Futures – short	10,298	—
Derivatives designated as economic hedges:
Crude oil and refined petroleum products:
Futures – long	63,657	1
Futures – short	66,797	—
Corn:
Futures – long	74,645	20
Futures – short	117,265	410
Physical contracts – long	36,409	388

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 March 31, 2023, we had foreign currency contracts to purchase $561 million of U.S. dollars. Of these commitments, $526 million matured on or before April 25, 2023 and the remaining $35 million will mature by April 28, 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 $413 million and $302 million for the three months ended March 31, 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 March 31, 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	March 31, 2023				December 31, 2022
		Asset Derivatives		Liability Derivatives		Asset Derivatives		Liability Derivatives
Derivatives designated as hedging instruments:
Commodity contracts	Receivables, net	$	117	$	42	$	61	$	44
Derivatives not designated as hedging instruments:
Commodity contracts	Receivables, net	$	499	$	383	$	769	$	661
Physical purchase contracts	Inventories	2		5		4		4
Foreign currency contracts	Receivables, net	—		—		—		—
Foreign currency contracts	Accrued expenses	—		9		—		2
Total		$	501	$	397	$	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 Income (Loss)

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

Derivatives in Cash Flow Hedging Relationships	Location of Gain (Loss) Recognized in Income on Derivatives	Three Months Ended March 31,
		2023		2022
Commodity contracts:
Gain (loss) recognized in other comprehensive income (loss)	n/a	$	95	$	(164)
Gain (loss) reclassified from accumulated other comprehensive loss into income	Revenues	38		(119)

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 months ended March 31, 2023 and 2022. For the three months ended March 31, 2023 and 2022, cash flow hedges primarily related to forward sales of renewable diesel. The estimated deferred after-tax gain that is expected to be reclassified into revenues within the next 12 months as a result of the hedged transactions that are forecasted to occur as of March 31, 2023 was not material. For the three months ended March 31, 2023 and 2022, there were no amounts reclassified from accumulated other comprehensive loss into income as a result of the discontinuance of cash flow hedge accounting. The changes in accumulated other comprehensive loss by component, net of tax, for the three months ended March 31, 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 March 31,
		2023		2022
Commodity contracts	Revenues	$	(7)	$	(4)
Commodity contracts	Cost of materials and other	83		(595)
Commodity contracts	Operating expenses (excluding depreciation and amortization expense)	1		3
Foreign currency contracts	Cost of materials and other	(3)		(2)
Foreign currency contracts	Other income (expense), net	—		34

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Basis of Presentation and Significant Accounting Policies (Policies)

3 Months Ended

Mar. 31, 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 period presented. All such adjustments are of a normal recurring nature unless disclosed otherwise. Operating results for the interim period 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 income (loss) is summarized below under “Effect of Derivative Instruments on Income and Other Comprehensive Income (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)

3 Months Ended

Mar. 31, 2023

Inventory Disclosure [Abstract]

Schedule of inventories

Inventories consisted of the following (in millions):

	March 31, 2023		December 31, 2022
Refinery feedstocks	$	1,820	$	1,949
Refined petroleum products and blendstocks	4,120		3,579
Renewable diesel feedstocks and products	827		583
Ethanol feedstocks and products	366		328
Materials and supplies	322		313
Inventories	$	7,455	$	6,752

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Debt (Tables)

3 Months Ended

Mar. 31, 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

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):

				March 31, 2023
	Facility Amount		Maturity Date	Outstanding Borrowings		Letters of Credit Issued (a)		Availability
Committed facilities:
Valero Revolver	$	4,000	November 2027	$	—	$	6	$	3,994
Canadian Revolver	C$	150	November 2023	C$	—	C$	5	C$	145
Accounts receivable sales facility	$	1,300	July 2023	$	—	n/a		$	1,300
Committed facilities of VIEs (b):
DGD Revolver (c)	$	400	March 2024	$	100	$	75	$	225
DGD Loan Agreement (d)	$	25	April 2023	$	25	n/a		$	—
IEnova Revolver (e)	$	830	February 2028	$	710	n/a		$	120
Uncommitted facilities:
Letter of credit facilities	n/a		n/a	n/a		$	158	n/a

________________________

(a)Letters of credit issued as of March 31, 2023 expire at various times in 2023 through 2024.

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

(c)The variable interest rate on the DGD Revolver was 6.460 percent and 5.880 percent as of March 31, 2023 and December 31, 2022, respectively.

(d)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. The variable interest rate on the DGD Loan Agreement was 7.173 percent and 6.672 percent as of March 31, 2023 and December 31, 2022, respectively. We expect this facility to be renewed prior to its maturity date.

(e)The variable interest rate on the IEnova Revolver was 8.443 percent and 7.393 percent as of March 31, 2023 and December 31, 2022, respectively.

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

	Three Months Ended March 31,
	2023		2022
Borrowings:
Accounts receivable sales facility	$	750	$	300
DGD Revolver	150		99
IEnova Revolver	14		28
Repayments:
Accounts receivable sales facility	(750)		(300)
DGD Revolver	(150)		(99)
IEnova Revolver	(21)		(15)

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 March 31,
	2023		2022
Interest and debt expense	$	152	$	157
Less: Capitalized interest	6		12
Interest and debt expense, net of capitalized interest	$	146	$	145

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Equity (Tables)

3 Months Ended

Mar. 31, 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 March 31,
	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	137		—		37		174		13		(3)		(64)		(54)
Amounts reclassified from accumulated other comprehensive loss	—		(7)		(15)		(22)		—		7		46		53
Effect of exchange rates	—		2		—		2		—		—		—		—
Other comprehensive income (loss)	137		(5)		22		154		13		4		(18)		(1)
Balance as of end of period	$	(1,031)	$	(188)	$	14	$	(1,205)	$	(549)	$	(437)	$	(23)	$	(1,009)

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Variable Interest Entities (Tables)

3 Months Ended

Mar. 31, 2023

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Summarized balance sheet information of consolidated VIEs

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

	DGD		Central Mexico Terminals		Other		Total
March 31, 2023
Assets
Cash and cash equivalents	$	92	$	—	$	26	$	118
Other current assets	1,246		10		32		1,288
Property, plant, and equipment, net	3,759		676		77		4,512
Liabilities
Current liabilities, including current portion of debt and finance lease obligations	$	443	$	748	$	7	$	1,198
Debt and finance lease obligations, less current portion	686		—		12		698
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)

3 Months Ended

Mar. 31, 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 March 31
Service cost	$	28	$	38	$	1	$	2
Interest cost	30		21		3		2
Expected return on plan assets	(50)		(48)		—		—
Amortization of:
Net actuarial (gain) loss	(2)		13		(1)		—
Prior service credit	(5)		(4)		(1)		(1)
Net periodic benefit cost	$	1	$	20	$	2	$	3

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Earnings Per Common Share (Tables)

3 Months Ended

Mar. 31, 2023

Earnings Per Share [Abstract]

Schedule of earnings (loss) 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 March 31,
	2023		2022
Earnings per common share:
Net income attributable to Valero stockholders	$	3,067	$	905
Less: Income allocated to participating securities	10		3
Net income available to common stockholders	$	3,057	$	902
Weighted-average common shares outstanding	369		408
Earnings per common share	$	8.30	$	2.21
Earnings per common share – assuming dilution:
Net income attributable to Valero stockholders	$	3,067	$	905
Less: Income allocated to participating securities	10		3
Net income available to common stockholders	$	3,057	$	902
Weighted-average common shares outstanding	369		408
Effect of dilutive securities	—		—
Weighted-average common shares outstanding – assuming dilution	369		408
Earnings per common share – assuming dilution	$	8.29	$	2.21

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Revenues and Segment Information (Tables)

3 Months Ended

Mar. 31, 2023

Segment Reporting [Abstract]

Schedule of contract balances

Contract balances were as follows (in millions):

	March 31, 2023		December 31, 2022
Receivables from contracts with customers, included in receivables, net	$	6,073	$	7,189
Contract liabilities, included in accrued expenses	45		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 March 31, 2023
Revenues:
Revenues from external customers	$	34,407	$	935	$	1,097	$	—	$	36,439
Intersegment revenues	3		745		223		(971)		—
Total revenues	34,410		1,680		1,320		(971)		36,439
Cost of sales:
Cost of materials and other (a)	28,510		1,331		1,131		(967)		30,005
Operating expenses (excluding depreciation and amortization expense reflected below)	1,261		86		130		—		1,477
Depreciation and amortization expense	572		58		20		—		650
Total cost of sales	30,343		1,475		1,281		(967)		32,132
Other operating expenses	10		—		—		—		10
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		244		244
Depreciation and amortization expense	—		—		—		10		10
Operating income by segment	$	4,057	$	205	$	39	$	(258)	$	4,043
Three months ended March 31, 2022
Revenues:
Revenues from external customers	$	36,813	$	595	$	1,134	$	—	$	38,542
Intersegment revenues	4		386		127		(517)		—
Total revenues	36,817		981		1,261		(517)		38,542
Cost of sales:
Cost of materials and other (a)	33,606		755		1,104		(516)		34,949
Operating expenses (excluding depreciation and amortization expense reflected below)	1,193		51		135		—		1,379
Depreciation and amortization expense	549		26		20		—		595
Total cost of sales	35,348		832		1,259		(516)		36,923
Other operating expenses	18		—		1		—		19
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		205		205
Depreciation and amortization expense	—		—		—		11		11
Operating income by segment	$	1,451	$	149	$	1	$	(217)	$	1,384

________________________

(a)Cost of materials and other for our Renewable Diesel segment is net of the blender’s tax credit on qualified fuel mixtures of $246 million and $156 million for the three months ended March 31, 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 March 31,
	2023		2022
Refining:
Gasolines and blendstocks	$	15,048	$	15,560
Distillates	16,838		17,444
Other product revenues	2,521		3,809
Total refining revenues	34,407		36,813
Renewable Diesel:
Renewable diesel	876		595
Renewable naphtha	59		—
Total Renewable Diesel revenues	935		595
Ethanol:
Ethanol	763		875
Distillers grains	334		259
Total ethanol revenues	1,097		1,134
Revenues	$	36,439	$	38,542

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

	March 31, 2023		December 31, 2022
Refining	$	46,852	$	48,484
Renewable Diesel	5,390		5,217
Ethanol	1,628		1,551
Corporate and eliminations	6,307		5,730
Total assets	$	60,177	$	60,982

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Supplemental Cash Flow Information (Tables)

3 Months Ended

Mar. 31, 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):

	Three Months Ended March 31,
	2023		2022
Decrease (increase) in current assets:
Receivables, net	$	2,381	$	(2,653)
Inventories	(641)		(940)
Prepaid expenses and other	(37)		(77)
Increase (decrease) in current liabilities:
Accounts payable	(2,269)		2,744
Accrued expenses	(61)		(120)
Taxes other than income taxes payable	(23)		36
Income taxes payable	116		288
Changes in current assets and current liabilities	$	(534)	$	(722)

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

	Three Months Ended March 31,
	2023		2022
Interest paid in excess of amount capitalized, including interest on finance leases	$	82	$	93
Income taxes paid, net	616		204

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

	Three Months Ended March 31,
	2023				2022
	Operating Leases		Finance Leases		Operating Leases		Finance Leases
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows	$	102	$	27	$	97	$	20
Financing cash flows	—		49		—		41
Changes in lease balances resulting from new and modified leases	67		47		79		100

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Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 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 March 31, 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.

	March 31, 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	$	616	$	—	$	—	$	616	$	(425)	$	(74)	$	117	$	—
Physical purchase contracts	—		2		—		2		n/a		n/a		2		n/a
Investments of certain benefit plans	71		—		6		77		n/a		n/a		77		n/a
Investments in AFS debt securities	85		139		—		224		n/a		n/a		224		n/a
Total	$	772	$	141	$	6	$	919	$	(425)	$	(74)	$	420
Liabilities
Commodity derivative contracts	$	425	$	—	$	—	$	425	$	(425)	$	—	$	—	$	(1)
Blending program obligations	—		46		—		46		n/a		n/a		46		n/a
Physical purchase contracts	—		5		—		5		n/a		n/a		5		n/a
Foreign currency contracts	9		—		—		9		n/a		n/a		9		n/a
Total	$	434	$	51	$	—	$	485	$	(425)	$	—	$	60

	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):

	March 31, 2023						December 31, 2022
	Level 1		Level 2		Total		Level 1		Level 2		Total
Cash and cash equivalents	$	7	$	91	$	98	$	—	$	125	$	125
Prepaid expenses and other	78		48		126		56		40		96
Investments in AFS debt securities	$	85	$	139	$	224	$	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).

		March 31, 2023				December 31, 2022
	Fair Value Hierarchy	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Financial liabilities:
Debt (excluding finance lease obligations)	Level 2	$	9,037	$	8,862	$	9,241	$	8,902

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Price Risk Management Activities (Tables)

3 Months Ended

Mar. 31, 2023

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Risk management activities by type of risk

As of March 31, 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	3,596	—
Futures – short	10,298	—
Derivatives designated as economic hedges:
Crude oil and refined petroleum products:
Futures – long	63,657	1
Futures – short	66,797	—
Corn:
Futures – long	74,645	20
Futures – short	117,265	410
Physical contracts – long	36,409	388

Fair values of derivative instruments

The following table provides information about the fair values of our derivative instruments as of March 31, 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	March 31, 2023				December 31, 2022
		Asset Derivatives		Liability Derivatives		Asset Derivatives		Liability Derivatives
Derivatives designated as hedging instruments:
Commodity contracts	Receivables, net	$	117	$	42	$	61	$	44
Derivatives not designated as hedging instruments:
Commodity contracts	Receivables, net	$	499	$	383	$	769	$	661
Physical purchase contracts	Inventories	2		5		4		4
Foreign currency contracts	Receivables, net	—		—		—		—
Foreign currency contracts	Accrued expenses	—		9		—		2
Total		$	501	$	397	$	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 income (loss) due to fair value adjustments of our cash flow hedges (in millions):

Derivatives in Cash Flow Hedging Relationships	Location of Gain (Loss) Recognized in Income on Derivatives	Three Months Ended March 31,
		2023		2022
Commodity contracts:
Gain (loss) recognized in other comprehensive income (loss)	n/a	$	95	$	(164)
Gain (loss) reclassified from accumulated other comprehensive loss into income	Revenues	38		(119)

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 March 31,
		2023		2022
Commodity contracts	Revenues	$	(7)	$	(4)
Commodity contracts	Cost of materials and other	83		(595)
Commodity contracts	Operating expenses (excluding depreciation and amortization expense)	1		3
Foreign currency contracts	Cost of materials and other	(3)		(2)
Foreign currency contracts	Other income (expense), net	—		34

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Uncertainty (Details)	3 Months Ended
	Mar. 31, 2023 refinery
California [Member]
Concentration Risk [Line Items]
Number of refineries	2

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Inventories (Details) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Schedule of Inventories
Refinery feedstocks	$ 1,820	$ 1,949
Refined petroleum products and blendstocks	4,120	3,579
Renewable diesel feedstocks and products	827	583
Ethanol feedstocks and products	366	328
Materials and supplies	322	313
Inventories	$ 7,455	$ 6,752

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Inventories (Details) (Narrative) - USD ($) $ in Billions	Mar. 31, 2023	Dec. 31, 2022
Inventories (Textual)
Excess of market value over carrying amount of LIFO inventories	$ 6.0	$ 6.3
Amount of non-LIFO inventory	$ 1.3	$ 1.6

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Debt, Public Debt (Details) - Senior Notes [Member] - USD ($)	1 Months Ended
	Feb. 28, 2023	Feb. 28, 2022
Debt Purchased and Retired
Debt purchased and retired amount	$ 199,000,000	$ 1,400,000,000
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
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
4.000% Valero Senior Notes due 2052 [Member]
Debt Purchased and Retired
Interest rate of notes (percent)	4.00%
Debt purchased and retired amount	$ 45,000,000
Various other Valero and Valero Energy Partners (VLP) Senior Notes [Member]
Debt Purchased and Retired
Debt purchased and retired amount	$ 66,000,000
4.000% Valero Senior Notes due June 1, 2052 [Member]
Debt Purchased and Retired
Interest rate of notes (percent)		4.00%
Public Debt (Textual)
Face amount of long-term debt issuance		$ 650,000,000
Proceeds from issuance of senior long-term debt		$ 639,000,000
3.65% Valero Senior Notes due 2025 [Member]
Debt Purchased and Retired
Interest rate of notes (percent)		3.65%
Debt purchased and retired amount		$ 72,000,000
2.850% Valero Senior Notes due 2025 [Member]
Debt Purchased and Retired
Interest rate of notes (percent)		2.85%
Debt purchased and retired amount		$ 507,000,000
4.375% VLP Senior Notes due 2026 [Member]
Debt Purchased and Retired
Interest rate of notes (percent)		4.375%
Debt purchased and retired amount		$ 168,000,000
3.400% Valero Senior Notes due 2026 [Member]
Debt Purchased and Retired
Interest rate of notes (percent)		3.40%
Debt purchased and retired amount		$ 653,000,000

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Debt, Credit Facilities (Details)		Mar. 31, 2023 USD ($)	Mar. 31, 2023 CAD ($)	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		3,994,000,000
Valero Revolver Letter of Credit [Member] | Credit Facilities [Member]
Line of Credit Facility
Letters of credit issued	[1]	6,000,000
Canadian Revolver [Member] | Credit Facilities [Member]
Line of Credit Facility
Facility amount			$ 150,000,000
Outstanding borrowings, short-term			0
Availability			145,000,000
Canadian Revolver Letter of Credit [Member] | Credit Facilities [Member]
Line of Credit Facility
Letters of credit issued	[1]		$ 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	[2],[3]	400,000,000
Outstanding borrowings, long term	[2],[3]	100,000,000
Availability	[2],[3]	$ 225,000,000
Interest rate at period end (percent)		6.46%	6.46%	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],[2],[3]	$ 75,000,000
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	[2],[4]	25,000,000
Outstanding borrowings, short-term	[2],[4]	25,000,000
Availability	[2],[4]	$ 0
Interest rate at period end (percent)		7.173%	7.173%	6.672%
IEnova Revolver [Member] | Credit Facilities [Member] | Central Mexico Terminals [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Line of Credit Facility
Facility amount	[2],[5]	$ 830,000,000
Outstanding borrowings, long term	[2],[5]	710,000,000
Availability	[2],[5]	$ 120,000,000
Interest rate at period end (percent)		8.443%	8.443%	7.393%
Uncommitted Letter of Credit Facility [Member] | Credit Facilities [Member]
Line of Credit Facility
Letters of credit issued	[1]	$ 158,000,000

[1] Letters of credit issued as of March 31, 2023 expire at various times in 2023 through 2024.

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

[3] The variable interest rate on the DGD Revolver was 6.460 percent and 5.880 percent as of March 31, 2023 and December 31, 2022, respectively.

[4] 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. The variable interest rate on the DGD Loan Agreement was 7.173 percent and 6.672 percent as of March 31, 2023 and December 31, 2022, respectively. We expect this facility to be renewed prior to its maturity date.

[5] The variable interest rate on the IEnova Revolver was 8.443 percent and 7.393 percent as of March 31, 2023 and December 31, 2022, respectively.

XML

Debt, Activity Under Credit Facilities (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Accounts Receivable Sales Facility [Member] | Line of Credit [Member]
Line of Credit Facility
Borrowings, short-term credit facilities	$ 750	$ 300
Repayments, short-term credit facilities	(750)	(300)
DGD Revolver [Member] | Line of Credit [Member] | DGD [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Line of Credit Facility
Borrowings, long-term credit facilities	150	99
Repayments, long-term credit facilities	(150)	(99)
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	14	28
Repayments, long-term credit facilities	$ (21)	$ (15)

XML

Debt, Interest Incurred (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Interest and Debt Expense, Net of Capitalized Interest
Interest and debt expense	$ 152	$ 157
Less: Capitalized interest	6	12
Interest and debt expense, net of capitalized interest	$ 146	$ 145

XML

Equity, Narrative (Details) - USD ($)	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022	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
Remaining amount authorized under stock purchase program	$ 899,000,000
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	$ 2,500,000,000
Treasury Stock [Member]
Equity (Textual)
Purchases of common stock for treasury (shares)	10,993,341	1,545,873

XML

Equity, Changes in Accumulated Other Comprehensive Loss (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Changes in Accumulated Other Comprehensive Loss, By Component, Net of Tax
Balance as of beginning of period	$ 25,468	$ 19,817
Other comprehensive income (loss)	183	(24)
Balance as of end of period	27,067	20,410
Accumulated Other Comprehensive Loss [Member]
Changes in Accumulated Other Comprehensive Loss, By Component, Net of Tax
Balance as of beginning of period	(1,359)	(1,008)
Other comprehensive income (loss) before reclassifications	174	(54)
Amounts reclassified from accumulated other comprehensive  loss	(22)	53
Effect of exchange rates	2	0
Other comprehensive income (loss)	154	(1)
Balance as of end of period	(1,205)	(1,009)
Foreign Currency Translation Adjustment [Member]
Changes in Accumulated Other Comprehensive Loss, By Component, Net of Tax
Balance as of beginning of period	(1,168)	(562)
Other comprehensive income (loss) before reclassifications	137	13
Amounts reclassified from accumulated other comprehensive  loss	0	0
Effect of exchange rates	0	0
Other comprehensive income (loss)	137	13
Balance as of end of period	(1,031)	(549)
Defined Benefit Plans Items [Member]
Changes in Accumulated Other Comprehensive Loss, By Component, Net of Tax
Balance as of beginning of period	(183)	(441)
Other comprehensive income (loss) before reclassifications	0	(3)
Amounts reclassified from accumulated other comprehensive  loss	(7)	7
Effect of exchange rates	2	0
Other comprehensive income (loss)	(5)	4
Balance as of end of period	(188)	(437)
Gains (Losses) on Cash Flow Hedges [Member]
Changes in Accumulated Other Comprehensive Loss, By Component, Net of Tax
Balance as of beginning of period	(8)	(5)
Other comprehensive income (loss) before reclassifications	37	(64)
Amounts reclassified from accumulated other comprehensive  loss	(15)	46
Effect of exchange rates	0	0
Other comprehensive income (loss)	22	(18)
Balance as of end of period	$ 14	$ (23)

XML

Variable Interest Entities (Details) (Narrative)	Mar. 31, 2023 plant
Diamond Green Diesel Holdings LLC (DGD) [Member]
Variable Interest Entity (Textual)
Number of renewable diesel plants owned by joint venture	2

XML

Variable Interest Entities (Details) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Assets
Cash and cash equivalents	$ 5,521	$ 4,862
Property, plant, and equipment, net	30,780	30,978
Liabilities
Current liabilities, including current portion of debt and finance lease obligations	15,365	17,461
Debt and finance lease obligations, less current portion	10,173	10,526
Variable Interest Entity, Primary Beneficiary [Member]
Assets
Cash and cash equivalents	118	149
Other current assets	1,288	1,145
Property, plant, and equipment, net	4,512	4,545
Liabilities
Current liabilities, including current portion of debt and finance lease obligations	1,198	1,384
Debt and finance lease obligations, less current portion	698	693
Diamond Green Diesel Holdings LLC (DGD) [Member]
Assets
Cash and cash equivalents	92	133
Other current assets	1,246	1,106
Property, plant, and equipment, net	3,759	3,785
Liabilities
Current liabilities, including current portion of debt and finance lease obligations	443	626
Debt and finance lease obligations, less current portion	686	693
Central Mexico Terminals [Member]
Assets
Cash and cash equivalents	0	0
Other current assets	10	7
Property, plant, and equipment, net	676	681
Liabilities
Current liabilities, including current portion of debt and finance lease obligations	748	737
Debt and finance lease obligations, less current portion	0	0
Other VIEs [Member]
Assets
Cash and cash equivalents	26	16
Other current assets	32	32
Property, plant, and equipment, net	77	79
Liabilities
Current liabilities, including current portion of debt and finance lease obligations	7	21
Debt and finance lease obligations, less current portion	$ 12	$ 0

XML

Employee Benefit Plans (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Pension Plans [Member]
Components of net periodic benefit cost:
Service cost	$ 28	$ 38
Interest cost	30	21
Expected return on plan assets	(50)	(48)
Amortization of:
Net actuarial (gain) loss	(2)	13
Prior service credit	(5)	(4)
Net periodic benefit cost	1	20
Other Postretirement Benefit Plans [Member]
Components of net periodic benefit cost:
Service cost	1	2
Interest cost	3	2
Expected return on plan assets	0	0
Amortization of:
Net actuarial (gain) loss	(1)	0
Prior service credit	(1)	(1)
Net periodic benefit cost	$ 2	$ 3

XML

Earnings Per Common Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Earnings per common share:
Net income attributable to Valero stockholders	$ 3,067	$ 905
Less: Income allocated to participating securities	10	3
Net income available to common stockholders	$ 3,057	$ 902
Weighted-average common shares outstanding (in shares)	369	408
Earnings (loss) per common share (in dollars per share)	$ 8.30	$ 2.21
Earnings per common share – assuming dilution:
Net income attributable to Valero stockholders	$ 3,067	$ 905
Less: Income allocated to participating securities	10	3
Net income available to common stockholders	$ 3,057	$ 902
Weighted-average common shares outstanding (in shares)	369	408
Effect of dilutive securities (in shares)	0	0
Weighted-average common shares outstanding – assuming dilution (in shares)	369	408
Earnings (loss) per common share – assuming dilution (in dollars per share)	$ 8.29	$ 2.21

XML

Revenues and Segment Information, Contract Balances (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022	Dec. 31, 2022
Segment Reporting [Abstract]
Receivables from contracts with customers, included in receivables, net	$ 6,073		$ 7,189
Contract liabilities, included in accrued expenses	45		$ 129
Contract Balances (Textual)
Revenue recognized that was included in contract liabilities as of prior year end	$ 120	$ 69

XML

Revenues and Segment Information, Components of Operating Income (Loss) (Details) $ in Millions		3 Months Ended
		Mar. 31, 2023 USD ($) segment	Mar. 31, 2022 USD ($)
Segment Information for our Reportable Segments
Revenues	[1]	$ 36,439	$ 38,542
Cost of sales:
Cost of materials and other	[2]	30,005	34,949
Operating expenses (excluding depreciation and amortization expense reflected below)		1,477	1,379
Depreciation and amortization expense		650	595
Total cost of sales		32,132	36,923
Other operating expenses		10	19
General and administrative expenses (excluding depreciation and amortization expense reflected below)		244	205
Depreciation and amortization expense		10	11
Operating income		$ 4,043	1,384
Segment Information (Textual)
Number of reportable segments | segment		3
Corporate, Reconciling Items And Eliminations [Member]
Segment Information for our Reportable Segments
Revenues		$ (971)	(517)
Cost of sales:
Operating income		(258)	(217)
Corporate [Member]
Segment Information for our Reportable Segments
Revenues		0	0
Cost of sales:
General and administrative expenses (excluding depreciation and amortization expense reflected below)		244	205
Depreciation and amortization expense		10	11
Intersegment Eliminations [Member]
Segment Information for our Reportable Segments
Revenues		(971)	(517)
Cost of sales:
Cost of materials and other	[2]	(967)	(516)
Operating expenses (excluding depreciation and amortization expense reflected below)		0	0
Depreciation and amortization expense		0	0
Total cost of sales		(967)	(516)
Other operating expenses		0	0
Refining [Member]
Segment Information for our Reportable Segments
Revenues		34,407	36,813
Refining [Member] | Operating Segments [Member]
Segment Information for our Reportable Segments
Revenues		34,410	36,817
Cost of sales:
Cost of materials and other	[2]	28,510	33,606
Operating expenses (excluding depreciation and amortization expense reflected below)		1,261	1,193
Depreciation and amortization expense		572	549
Total cost of sales		30,343	35,348
Other operating expenses		10	18
General and administrative expenses (excluding depreciation and amortization expense reflected below)		0	0
Depreciation and amortization expense		0	0
Operating income		4,057	1,451
Refining [Member] | Intersegment Eliminations [Member]
Segment Information for our Reportable Segments
Revenues		3	4
Renewable Diesel [Member]
Segment Information for our Reportable Segments
Revenues		935	595
Renewable Diesel [Member] | Operating Segments [Member]
Segment Information for our Reportable Segments
Revenues		1,680	981
Cost of sales:
Cost of materials and other	[2]	1,331	755
Operating expenses (excluding depreciation and amortization expense reflected below)		86	51
Depreciation and amortization expense		58	26
Total cost of sales		1,475	832
Other operating expenses		0	0
General and administrative expenses (excluding depreciation and amortization expense reflected below)		0	0
Depreciation and amortization expense		0	0
Operating income		205	149
Segment Information (Textual)
Blender's tax credit		246	156
Renewable Diesel [Member] | Intersegment Eliminations [Member]
Segment Information for our Reportable Segments
Revenues		745	386
Ethanol [Member]
Segment Information for our Reportable Segments
Revenues		1,097	1,134
Ethanol [Member] | Operating Segments [Member]
Segment Information for our Reportable Segments
Revenues		1,320	1,261
Cost of sales:
Cost of materials and other	[2]	1,131	1,104
Operating expenses (excluding depreciation and amortization expense reflected below)		130	135
Depreciation and amortization expense		20	20
Total cost of sales		1,281	1,259
Other operating expenses		0	1
General and administrative expenses (excluding depreciation and amortization expense reflected below)		0	0
Depreciation and amortization expense		0	0
Operating income		39	1
Ethanol [Member] | Intersegment Eliminations [Member]
Segment Information for our Reportable Segments
Revenues		$ 223	$ 127

[1] Includes excise taxes on sales by certain of our foreign operations of $1,422 million and $1,423 million for the three months ended March 31, 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 $246 million and $156 million for the three months ended March 31, 2023 and 2022, respectively.

XML

Revenues and Segment Information, Disaggregation of Revenue by Product (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2023	Mar. 31, 2022
Revenue by Segment
Revenues	[1]	$ 36,439	$ 38,542
Refining [Member]
Revenue by Segment
Revenues		34,407	36,813
Refining [Member] | Gasoline and Blendstocks [Member]
Revenue by Segment
Revenues		15,048	15,560
Refining [Member] | Distillates [Member]
Revenue by Segment
Revenues		16,838	17,444
Refining [Member] | Other Product Revenues [Member]
Revenue by Segment
Revenues		2,521	3,809
Renewable Diesel [Member]
Revenue by Segment
Revenues		935	595
Renewable Diesel [Member] | Renewable Diesel [Member]
Revenue by Segment
Revenues		876	595
Renewable Diesel [Member] | Renewable Naphtha [Member]
Revenue by Segment
Revenues		59	0
Ethanol [Member]
Revenue by Segment
Revenues		1,097	1,134
Ethanol [Member] | Ethanol [Member]
Revenue by Segment
Revenues		763	875
Ethanol [Member] | Distillers Grains [Member]
Revenue by Segment
Revenues		$ 334	$ 259

[1] Includes excise taxes on sales by certain of our foreign operations of $1,422 million and $1,423 million for the three months ended March 31, 2023 and 2022, respectively.

XML

Revenues and Segment Information, Assets (Details) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Total Assets by Reportable Segment
Reportable segment assets	$ 60,177	$ 60,982
Corporate and Eliminations [Member]
Total Assets by Reportable Segment
Reportable segment assets	6,307	5,730
Refining [Member] | Operating Segments [Member]
Total Assets by Reportable Segment
Reportable segment assets	46,852	48,484
Renewable Diesel [Member] | Operating Segments [Member]
Total Assets by Reportable Segment
Reportable segment assets	5,390	5,217
Ethanol [Member] | Operating Segments [Member]
Total Assets by Reportable Segment
Reportable segment assets	$ 1,628	$ 1,551

XML

Supplemental Cash Flow Information (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Decrease (increase) in current assets:
Receivables, net	$ 2,381	$ (2,653)
Inventories	(641)	(940)
Prepaid expenses and other	(37)	(77)
Increase (decrease) in current liabilities:
Accounts payable	(2,269)	2,744
Accrued expenses	(61)	(120)
Taxes other than income taxes payable	(23)	36
Income taxes payable	116	288
Changes in current assets and current liabilities	(534)	(722)
Cash Flows Related to Interest and Income Taxes
Interest paid in excess of amount capitalized, including interest on finance leases	82	93
Income taxes paid, net	616	204
Operating cash flows
Operating Leases	102	97
Finance Leases	27	20
Financing cash flows
Finance Leases	49	41
Changes in lease balances resulting from new and modified leases, Operating Leases	67	79
Changes in lease balances resulting from new and modified leases, Finance Leases	$ 47	$ 100

XML

Fair Value Measurements, Recurring (Details) - Fair Value, Recurring [Member] - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Assets
Investments in AFS debt securities	$ 224	$ 221
Total gross fair value, assets	919	1,133
Effect of counterparty netting	(425)	(705)
Effect of cash collateral netting	(74)	(8)
Net carrying value on Balance Sheet, assets	420	420
Liabilities
Blending program obligations	46	55
Total gross fair value, liabilities	485	766
Effect of counterparty netting	(425)	(705)
Effect of cash collateral netting	0	0
Net carrying value on Balance Sheet, liabilities	60	61
Cash and Cash Equivalents [Member]
Assets
Investments in AFS debt securities	98	125
Prepaid Expenses and Other [Member]
Assets
Investments in AFS debt securities	126	96
Assets Held in Trust [Member]
Assets
Investments of certain benefit plans	77	78
Commodity Contracts [Member]
Assets
Derivative contracts	616	830
Effect of counterparty netting	(425)	(705)
Effect of cash collateral netting	(74)	(8)
Derivative contracts, net assets	117	117
Cash collateral received not offset	0	0
Liabilities
Derivative contracts	425	705
Effect of counterparty netting	(425)	(705)
Effect of cash collateral netting	0	0
Derivative contracts, net liabilities	0	0
Cash collateral paid not offset	(1)	(149)
Physical Purchase Contracts [Member]
Assets
Derivative contracts, not subject to netting	2	4
Liabilities
Derivative contracts, not subject to netting	5	4
Foreign Currency Contracts [Member]
Liabilities
Derivative contracts, not subject to netting	9	2
Fair Value, Inputs, Level 1 [Member]
Assets
Investments in AFS debt securities	85	56
Total gross fair value, assets	772	958
Liabilities
Blending program obligations	0	0
Total gross fair value, liabilities	434	707
Fair Value, Inputs, Level 1 [Member] | Cash and Cash Equivalents [Member]
Assets
Investments in AFS debt securities	7	0
Fair Value, Inputs, Level 1 [Member] | Prepaid Expenses and Other [Member]
Assets
Investments in AFS debt securities	78	56
Fair Value, Inputs, Level 1 [Member] | Assets Held in Trust [Member]
Assets
Investments of certain benefit plans	71	72
Fair Value, Inputs, Level 1 [Member] | Commodity Contracts [Member]
Assets
Derivative contracts	616	830
Liabilities
Derivative contracts	425	705
Fair Value, Inputs, Level 1 [Member] | Physical Purchase Contracts [Member]
Assets
Derivative contracts, not subject to netting	0	0
Liabilities
Derivative contracts, not subject to netting	0	0
Fair Value, Inputs, Level 1 [Member] | Foreign Currency Contracts [Member]
Liabilities
Derivative contracts, not subject to netting	9	2
Fair Value, Inputs, Level 2 [Member]
Assets
Investments in AFS debt securities	139	165
Total gross fair value, assets	141	169
Liabilities
Blending program obligations	46	55
Total gross fair value, liabilities	51	59
Fair Value, Inputs, Level 2 [Member] | Cash and Cash Equivalents [Member]
Assets
Investments in AFS debt securities	91	125
Fair Value, Inputs, Level 2 [Member] | Prepaid Expenses and Other [Member]
Assets
Investments in AFS debt securities	48	40
Fair Value, Inputs, Level 2 [Member] | Assets Held in Trust [Member]
Assets
Investments of certain benefit plans	0	0
Fair Value, Inputs, Level 2 [Member] | Commodity Contracts [Member]
Assets
Derivative contracts	0	0
Liabilities
Derivative contracts	0	0
Fair Value, Inputs, Level 2 [Member] | Physical Purchase Contracts [Member]
Assets
Derivative contracts, not subject to netting	2	4
Liabilities
Derivative contracts, not subject to netting	5	4
Fair Value, Inputs, Level 2 [Member] | Foreign Currency Contracts [Member]
Liabilities
Derivative contracts, not subject to netting	0	0
Fair Value, Inputs, Level 3 [Member]
Assets
Investments in AFS debt securities	0	0
Total gross fair value, assets	6	6
Liabilities
Blending program obligations	0	0
Total gross fair value, liabilities	0	0
Fair Value, Inputs, Level 3 [Member] | Assets Held in Trust [Member]
Assets
Investments of certain benefit plans	6	6
Fair Value, Inputs, Level 3 [Member] | Commodity Contracts [Member]
Assets
Derivative contracts	0	0
Liabilities
Derivative contracts	0	0
Fair Value, Inputs, Level 3 [Member] | Physical Purchase Contracts [Member]
Assets
Derivative contracts, not subject to netting	0	0
Liabilities
Derivative contracts, not subject to netting	0	0
Fair Value, Inputs, Level 3 [Member] | Foreign Currency Contracts [Member]
Liabilities
Derivative contracts, not subject to netting	$ 0	$ 0

XML

Fair Value Measurements, Nonrecurring (Details) - USD ($)	12 Months Ended
	Dec. 31, 2022	Mar. 31, 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

XML

Fair Value Measurements, Financial Instruments (Details) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Financial liabilities:
Debt (excluding finance lease obligations), at carrying amount	$ 9,037	$ 9,241
Fair Value, Inputs, Level 2 [Member]
Financial liabilities:
Debt (excluding finance lease obligations), at fair value	$ 8,862	$ 8,902

XML

Price Risk Management Activities (Details) bu in Thousands, $ in Millions		3 Months Ended
		Mar. 31, 2023 USD ($) bu MBbls	Mar. 31, 2022 USD ($)
Price Risk Management Activities (Textual)
Compliance program costs | $	[1]	$ 30,005	$ 34,949
Renewable And Low-Carbon Fuel Programs [Member]
Price Risk Management Activities (Textual)
Compliance program costs | $		$ 413	$ 302
Derivatives Designated as Hedges [Member] | Cash Flow Hedges [Member] | Future, 2022 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		3,596
Derivatives Designated as Hedges [Member] | Cash Flow Hedges [Member] | Future, 2022 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		10,298
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		0
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		0
Derivatives Designated as Economic Hedges [Member] | Future, 2022 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		63,657
Derivatives Designated as Economic Hedges [Member] | Future, 2022 Maturity [Member] | Long (Purchases) [Member] | Corn (in thousands of bushels) [Member]
Volume of Outstanding Contracts
Nonmonetary notional amount of price risk derivatives, volume | bu		74,645
Derivatives Designated as Economic Hedges [Member] | Future, 2022 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		66,797
Derivatives Designated as Economic Hedges [Member] | Future, 2022 Maturity [Member] | Short (Sales) [Member] | Corn (in thousands of bushels) [Member]
Volume of Outstanding Contracts
Nonmonetary notional amount of price risk derivatives, volume | bu		117,265
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		1
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		20
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		0
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		410
Derivatives Designated as Economic Hedges [Member] | Physical Contracts, 2022 Maturity [Member] | Long (Purchases) [Member] | Corn (in thousands of bushels) [Member]
Volume of Outstanding Contracts
Nonmonetary notional amount of price risk derivatives, volume | bu		36,409
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		388
Derivatives Designated as Economic Hedges [Member] | Foreign Exchange Contract, US Dollars [Member]
Price Risk Management Activities (Textual)
Monetary notional amount of derivative liabilities | $		$ 561
Derivatives Designated as Economic Hedges [Member] | Foreign Exchange Contract, Maturity on or Before April 25, 2023 [Member]
Price Risk Management Activities (Textual)
Monetary notional amount of derivative liabilities | $		526
Derivatives Designated as Economic Hedges [Member] | Foreign Exchange Contract, Maturity by April 28, 2023 [Member]
Price Risk Management Activities (Textual)
Monetary notional amount of derivative liabilities | $		$ 35

[1] Cost of materials and other for our Renewable Diesel segment is net of the blender’s tax credit on qualified fuel mixtures of $246 million and $156 million for the three months ended March 31, 2023 and 2022, respectively.

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Price Risk Management Activities, Hedging Instruments by Consolidated Balance Sheet Location (Details) - USD ($) $ in Millions	Mar. 31, 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	$ 117	$ 61
Derivative liability, subject to netting	42	44
Derivatives Not Designated as Hedging Instruments [Member]
Fair Values of Derivative Instruments
Derivative asset, total	501	773
Derivative liability, total	397	667
Derivatives Not Designated as Hedging Instruments [Member] | Commodity Contracts [Member] | Receivable, Net [Member]
Fair Values of Derivative Instruments
Derivative asset, subject to netting	499	769
Derivative liability, subject to netting	383	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	2	4
Derivative liability, not subject to netting	5	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	0	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	$ 9	$ 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
	Mar. 31, 2023	Mar. 31, 2022
Commodity Contracts [Member]
Effect of Derivative Instruments on Income
Gain (loss) recognized in other comprehensive income (loss)	$ 95	$ (164)
Commodity Contracts [Member] | Revenues [Member]
Effect of Derivative Instruments on Income
Gain (loss) reclassified from accumulated other comprehensive loss into income	38	(119)
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	(7)	(4)
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	83	(595)
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	1	3
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	(3)	(2)
Foreign Currency Contracts [Member] | Other Income (Expense), Net [Member] | Derivatives Not Designated as Hedging Instruments [Member]
Effect of Derivative Instruments on Income
Gain (loss) recognized in income on derivatives	$ 0	$ 34