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, 2021

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	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 23, 2021 was 408,760,165.

VALERO ENERGY CORPORATION

TABLE OF CONTENTS

	Page
PART I – FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
Consolidated Balance Sheets as of March 31, 2021 and December 31, 2020	1
Consolidated Statements of Income for the Three Months Ended March 31, 2021 and 2020	2
Consolidated Statements of Comprehensive Income for the Three Months Ended March 31, 2021 and 2020	3
Consolidated Statements of Equity for the Three Months Ended March 31, 2021 and 2020	4
Consolidated Statements of Cash Flows for the Three Months Ended March 31, 2021 and 2020	5
Condensed Notes to Consolidated Financial Statements	6
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	27
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	49
ITEM 4. CONTROLS AND PROCEDURES	51
PART II – OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS	52
ITEM 1A. RISK FACTORS	52
ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS	53
ITEM 6. EXHIBITS	54
SIGNATURE	55

i

PART I – FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

VALERO ENERGY CORPORATION

CONSOLIDATED BALANCE SHEETS

(millions of dollars, except par value)

	March 31, 2021		December 31, 2020
	(unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	2,254	$	3,313
Receivables, net	9,014		6,109
Inventories	5,881		6,038
Prepaid expenses and other	442		384
Total current assets	17,591		15,844
Property, plant, and equipment, at cost	47,370		46,967
Accumulated depreciation	(16,991)		(16,578)
Property, plant, and equipment, net	30,379		30,389
Deferred charges and other assets, net	5,644		5,541
Total assets	$	53,614	$	51,774
LIABILITIES AND EQUITY
Current liabilities:
Current portion of debt and finance lease obligations	$	734	$	723
Accounts payable	9,113		6,082
Accrued expenses	1,087		994
Taxes other than income taxes payable	1,233		1,372
Income taxes payable	140		112
Total current liabilities	12,307		9,283
Debt and finance lease obligations, less current portion	13,930		13,954
Deferred income tax liabilities	5,034		5,275
Other long-term liabilities	3,616		3,620
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	6,810		6,814
Treasury stock, at cost; 264,741,072 and 265,096,171 common shares	(15,700)		(15,719)
Retained earnings	27,849		28,953
Accumulated other comprehensive loss	(1,165)		(1,254)
Total Valero Energy Corporation stockholders’ equity	17,801		18,801
Noncontrolling interests	926		841
Total equity	18,727		19,642
Total liabilities and equity	$	53,614	$	51,774

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,
	2021		2020
Revenues (a)	$	20,806	$	22,102
Cost of sales:
Cost of materials and other	18,992		19,952
Lower of cost or market (LCM) inventory valuation adjustment	—		2,542
Operating expenses (excluding depreciation and amortization expense reflected below)	1,656		1,124
Depreciation and amortization expense	566		569
Total cost of sales	21,214		24,187
Other operating expenses	38		2
General and administrative expenses (excluding depreciation and amortization expense reflected below)	208		177
Depreciation and amortization expense	12		13
Operating loss	(666)		(2,277)
Other income, net	45		32
Interest and debt expense, net of capitalized interest	(149)		(125)
Loss before income tax benefit	(770)		(2,370)
Income tax benefit	(148)		(616)
Net loss	(622)		(1,754)
Less: Net income attributable to noncontrolling interests	82		97
Net loss attributable to Valero Energy Corporation stockholders	$	(704)	$	(1,851)
Loss per common share	$	(1.73)	$	(4.54)
Weighted-average common shares outstanding (in millions)	407		408
Loss per common share – assuming dilution	$	(1.73)	$	(4.54)
Weighted-average common shares outstanding – assuming dilution (in millions)	407		408
__________________________
Supplemental information:
(a) Includes excise taxes on sales by certain of our international operations	$	1,120	$	1,368

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,
	2021		2020
Net loss	$	(622)	$	(1,754)
Other comprehensive income (loss):
Foreign currency translation adjustment	76		(607)
Net gain on pension and other postretirement benefits	15		12
Net gain on cash flow hedges	10		29
Other comprehensive income (loss) before income tax expense	101		(566)
Income tax expense related to items of other comprehensive income (loss)	7		6
Other comprehensive income (loss)	94		(572)
Comprehensive loss	(528)		(2,326)
Less: Comprehensive income attributable to noncontrolling interests	87		111
Comprehensive loss attributable to Valero Energy Corporation stockholders	$	(615)	$	(2,437)

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, 2020	$	7	$	6,814	$	(15,719)	$	28,953	$	(1,254)	$	18,801	$	841	$	19,642
Net income (loss)	—		—		—		(704)		—		(704)		82		(622)
Dividends on common stock ($0.98 per share)	—		—		—		(400)		—		(400)		—		(400)
Stock-based compensation expense	—		28		—		—		—		28		—		28
Transactions in connection with stock-based compensation plans	—		(32)		19		—		—		(13)		—		(13)
Distributions to noncontrolling interests	—		—		—		—		—		—		(2)		(2)
Other comprehensive income	—		—		—		—		89		89		5		94
Balance as of March 31, 2021	$	7	$	6,810	$	(15,700)	$	27,849	$	(1,165)	$	17,801	$	926	$	18,727
Balance as of December 31, 2019	$	7	$	6,821	$	(15,648)	$	31,974	$	(1,351)	$	21,803	$	733	$	22,536
Net income (loss)	—		—		—		(1,851)		—		(1,851)		97		(1,754)
Dividends on common stock ($0.98 per share)	—		—		—		(401)		—		(401)		—		(401)
Stock-based compensation expense	—		24		—		—		—		24		—		24
Transactions in connection with stock-based compensation plans	—		(31)		14		—		—		(17)		—		(17)
Open market stock purchases	—		—		(130)		—		—		(130)		—		(130)
Distributions to noncontrolling interests	—		—		—		—		—		—		(1)		(1)
Other comprehensive income (loss)	—		—		—		—		(586)		(586)		14		(572)
Balance as of March 31, 2020	$	7	$	6,814	$	(15,764)	$	29,722	$	(1,937)	$	18,842	$	843	$	19,685

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,
	2021		2020
Cash flows from operating activities:
Net loss	$	(622)	$	(1,754)
Adjustments to reconcile net loss to net cash used in operating activities:
Depreciation and amortization expense	578		582
LCM inventory valuation adjustment	—		2,542
Deferred income tax benefit	(239)		(162)
Changes in current assets and current liabilities	184		(1,107)
Changes in deferred charges and credits and other operating activities, net	47		(150)
Net cash used in operating activities	(52)		(49)
Cash flows from investing activities:
Capital expenditures (excluding variable interest entities (VIEs))	(160)		(299)
Capital expenditures of VIEs:
Diamond Green Diesel Holdings LLC (DGD)	(153)		(74)
Other VIEs	(26)		(62)
Deferred turnaround and catalyst cost expenditures (excluding VIEs)	(230)		(309)
Deferred turnaround and catalyst cost expenditures of DGD	(1)		(4)
Investments in unconsolidated joint ventures	(12)		(19)
Other investing activities, net	2		10
Net cash used in investing activities	(580)		(757)
Cash flows from financing activities:
Proceeds from debt issuances and borrowings (excluding VIEs)	—		300
Proceeds from borrowings of VIEs	8		70
Repayments of debt and finance lease obligations (excluding VIEs)	(31)		(15)
Repayments of debt of VIEs	(1)		(1)
Purchases of common stock for treasury	(14)		(147)
Common stock dividend payments	(400)		(401)
Other financing activities, net	(1)		(1)
Net cash used in financing activities	(439)		(195)
Effect of foreign exchange rate changes on cash	12		(67)
Net decrease in cash and cash equivalents	(1,059)		(1,068)
Cash and cash equivalents at beginning of period	3,313		2,583
Cash and cash equivalents at end of period	$	2,254	$	1,515

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.

These unaudited financial statements have been prepared in accordance 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 U.S. GAAP for complete financial statements. In the opinion of management, all adjustments considered necessary for a fair presentation of our results for the three months ended March 31, 2021 have been included. All such adjustments are of a normal recurring nature unless disclosed otherwise. Operating results for the three months ended March 31, 2021 are not necessarily indicative of the results that may be expected for the year ending December 31, 2021. The financial statements presented herein should be read in conjunction with the financial statements included in our annual report on Form 10-K for the year ended December 31, 2020.

As discussed in Note 2, the outbreak of COVID-19 and its development into a pandemic in March 2020 resulted in significant economic disruption globally. Developments with respect to COVID-19 have been occurring at a rapid pace and the risk remains that circumstances could change. Demand for and market prices of most of our products began to improve during the latter half of 2020 and continued to improve throughout the first quarter of 2021. These improvements resulted primarily from the lifting or easing of restrictions by many governmental authorities, especially those in our U.S. Gulf Coast and U.S. Mid-Continent regions, in response to decreasing COVID-19 infection rates and increasing numbers of people receiving COVID-19 vaccines, which were approved by a number of regulators throughout the world in late 2020 and early 2021. While many governmental authorities in areas located in our U.S. West Coast and North Atlantic regions, such as California, Canada, and the United Kingdom (U.K.), continue to impose restrictions, some of these restrictions have been or are soon expected to be moderately lifted. The ongoing distribution of vaccines may result in the continued lifting of restrictions and may be seen as a key factor in helping to restore public confidence, and thus stimulate and increase economic activity, potentially to pre-pandemic levels; however, the risk remains that the vaccines may not be distributed widely on a timely basis, they may not be effective against new variants of the COVID-19 virus, the distribution of some or all of the vaccines may be paused or withdrawn due to concerns with potential side effects, and/or the level of individuals’ willingness to receive a vaccine may not be as strong or as timely as needed. Based on these and other circumstances that cannot be predicted, the broader implications of the pandemic on our results of operations and financial position remain uncertain.

The balance sheet as of December 31, 2020 has been derived from our audited financial statements as of that date. For further information, refer to our financial statements and notes thereto included in our annual report on Form 10-K for the year ended December 31, 2020.

6

VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Reclassifications

Certain prior year amounts presented in Note 11 have been reclassified to conform to the 2021 presentation. The change was due to the reclassification of amounts for income taxes receivable from prepaid expenses and other to “receivables, net.”

Significant Accounting Policies

Use of Estimates

The preparation of financial statements in conformity with U.S. GAAP requires us to make estimates and assumptions that affect the amounts reported in the 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.

Adoption of Accounting Pronouncement

The following Financial Accounting Standards Board (FASB) Accounting Standards Update (ASU) was issued and adopted by us on January 7, 2021. Our adoption of this ASU did not have a material impact on our financial statements or related disclosures.

ASU		Basis of Adoption
2021-01	Reference Rate Reform (Topic 848): Scope	Prospectively

2.    UNCERTAINTIES

The outbreak of COVID-19 and its development into a pandemic in March 2020 resulted in significant economic disruption globally as governmental authorities imposed restrictions, such as stay-at-home orders and other social distancing measures, to slow the spread of COVID-19. These actions significantly reduced global economic activity and negatively impacted many businesses, including our business. We took a number of actions since March 2020 to respond to the impacts from the pandemic on our business, such as reducing transportation fuel production at our refineries and ethanol plants to align with demand. During the three months ended March 31, 2021, our business showed signs of recovery and improvement in demand for and market prices of gasoline and diesel, with both factors reaching near pre-pandemic levels in March 2021. Also, jet fuel has seen improved market indicators, although at a slower pace than other products we produce relative to pre-pandemic levels.

While our business has improved as a result of the increasing demand for and market prices of most of the products that we produce, many uncertainties remain with respect to the pandemic, including its resulting economic effects. Therefore, we are unable to predict the ultimate economic impacts from the pandemic on our business and how quickly national economies can recover once the pandemic subsides, the timing or effectiveness of vaccine distributions or vaccination levels, whether improvements experienced by us so far may reverse, or whether other setbacks may occur. As a result, the adverse impacts of the economic effects of the pandemic on our company may likely continue to be significant. We believe we have proactively responded to many of the known impacts of the COVID-19 pandemic on our business to the extent practicable and we strive to continue to do so, but there can be no assurance that any measures we have taken or may take will be fully effective.

7

VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

3.    INVENTORIES

Inventories consisted of the following (in millions):

	March 31, 2021		December 31, 2020
Refinery feedstocks	$	1,947	$	1,979
Refined petroleum products and blendstocks	3,284		3,425
Renewable diesel feedstocks and products	64		50
Ethanol feedstocks and products	297		297
Materials and supplies	289		287
Inventories	$	5,881	$	6,038

We compare the market value of inventories to their cost on an aggregate basis, excluding materials and supplies. In determining the market value of our inventories, we assume that feedstocks are converted into refined products, which requires us to make estimates regarding the refined products expected to be produced from those feedstocks and the conversion costs required to convert those feedstocks into refined products. We also estimate the usual and customary transportation costs required to move the inventory from our plants to the appropriate points of sale. We then apply an estimated selling price to our inventories. If the aggregate market value is less than the aggregate cost, we recognize a loss for the difference in our statements of income. To the extent the aggregate market value of our last-in, first-out (LIFO) inventories subsequently increases, we recognize an increase to the value of our inventories (not to exceed cost) and a gain in our statements of income.

The market value of our LIFO inventories fell below their LIFO inventory carrying amounts as of March 31, 2020, and as a result, we recorded an LCM inventory valuation reserve of $2.5 billion in order to state our inventories at market. As of March 31, 2021 and December 31, 2020, the replacement cost (market value) of LIFO inventories exceeded their LIFO carrying amounts by $2.7 billion and $1.3 billion, respectively.

Our non-LIFO inventories accounted for $1.2 billion and $918 million of our total inventories as of March 31, 2021 and December 31, 2020, respectively.

8

VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

4.    DEBT

Public Debt

During the three months ended March 31, 2021 and 2020, there was no issuance or redemption activity related to our public debt.

Credit Facilities

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, 2021
	Facility Amount		Maturity Date	Outstanding Borrowings		Letters of Credit Issued (a)		Availability
Committed facilities:
Valero Revolver	$	4,000	March 2024	$	—	$	118	$	3,882
364-day Revolving Credit Facility (b)	$	875	April 2021	$	—	n/a		$	875
Canadian Revolver	C$	150	November 2021	C$	—	C$	5	C$	145
Accounts receivable sales facility	$	1,000	July 2021	$	—	n/a		$	1,000
Letter of credit facility	$	50	November 2021	n/a		$	—	$	50
Committed facilities of VIEs (c):
DGD Revolver	$	400	March 2024	$	—	$	—	$	400
IEnova Revolver (d)	$	660	February 2028	$	606	n/a		$	54
Uncommitted facilities:
Letter of credit facilities	n/a		n/a	n/a		$	330	n/a

________________________

(a)Letters of credit issued as of March 31, 2021 expire at various times in 2021 through 2023.

(b)This facility matured on April 12, 2021 and was not renewed.

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

(d)As of March 31, 2021 and December 31, 2020, the variable interest rate on the IEnova Revolver was 3.888 percent and 3.870 percent, respectively.

Activities under our credit facilities were as follows (in millions):

	Three Months Ended March 31,
	2021		2020
Borrowings:
Accounts receivable sales facility	$	—	$	300
IEnova Revolver	8		70

9

VALERO ENERGY CORPORATION

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

DGD Revolver

In March 2021, DGD (as described in Note 6) entered into a $400 million unsecured revolving credit facility (the DGD Revolver) that matures in March 2024. DGD has the option to increase the aggregate commitments under the DGD Revolver to $550 million, subject to certain restrictions. The DGD Revolver also provides for the issuance of letters of credit of up to $10 million. The DGD Revolver is available only to the operations of DGD, and the creditors of DGD do not have recourse against us.

Outstanding borrowings under the DGD Revolver generally bear interest, at DGD’s option, at either (i) an alternate base rate plus the applicable margin or (ii) an adjusted LIBOR rate for the applicable interest period in effect from time to time plus the applicable margin. The DGD Revolver also requires payments for customary fees, including unused commitment fees, letter of credit fees, and administrative agent fees.

During the three months ended March 31, 2021, there were no borrowings or repayments under the DGD Revolver.

Other Disclosures

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

	Three Months Ended March 31,
	2021		2020
Interest and debt expense	$	164	$	145
Less: Capitalized interest	15		20
Interest and debt expense, net of capitalized interest	$	149	$	125

5.    EQUITY

Share Activity

There was no significant share activity during the three months ended March 31, 2021 and 2020.

Common Stock Dividends

On April 16, 2021, our board of directors declared a quarterly cash dividend of $0.98 per common share payable on June 8, 2021 to holders of record at the close of business on May 17, 2021.

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,
	2021								2020
	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	$	(515)	$	(737)	$	(2)	$	(1,254)	$	(676)	$	(672)	$	(3)	$	(1,351)
Other comprehensive income (loss) before reclassifications	76		1		(5)		72		(606)		—		21		(585)
Amounts reclassified from accumulated other comprehensive loss	—		8		9		17		—		9		(10)		(1)
Other comprehensive income (loss)	76		9		4		89		(606)		9		11		(586)
Balance as of end of period	$	(439)	$	(728)	$	2	$	(1,165)	$	(1,282)	$	(663)	$	8	$	(1,937)

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, 2021, our significant consolidated VIEs included:

•DGD, a joint venture with a subsidiary of Darling Ingredients Inc., which owns and operates a plant that processes rendered and recycled materials, including animal fats, used cooking oils, and other vegetable oils, into renewable diesel; and

•Central Mexico Terminals, which is a collective group of three subsidiaries of Infraestructura Energetica Nova, S.A.B. de C.V. (IEnova), a Mexican company and 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 our VIEs can only be used to settle their own obligations and the creditors of our VIEs have no recourse to our other assets. We do not provide financial guarantees to our VIEs. Although we have provided credit facilities to some of our 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 our 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 tables present summarized balance sheet information for the significant assets and liabilities of our consolidated VIEs, which are included in our balance sheets (in millions):

	March 31, 2021
	DGD		Central Mexico Terminals		Other		Total
Assets
Cash and cash equivalents	$	191	$	—	$	19	$	210
Other current assets	272		10		10		292
Property, plant, and equipment, net	1,431		614		94		2,139
Liabilities
Current liabilities, including current portion of debt and finance lease obligations	$	166	$	632	$	8	$	806
Debt and finance lease obligations, less current portion	1		—		24		25

	December 31, 2020
	DGD		Central Mexico Terminals		Other		Total
Assets
Cash and cash equivalents	$	144	$	1	$	16	$	161
Other current assets	219		24		8		251
Property, plant, and equipment, net	1,232		590		96		1,918
Liabilities
Current liabilities, including current portion of debt and finance lease obligations	$	90	$	620	$	8	$	718
Debt and finance lease obligations, less current portion	1		—		25		26

Non-Consolidated VIEs

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

On April 19, 2021, we sold a 24.99 percent membership interest in MVP Terminalling, LLC (MVP), an unconsolidated joint venture with a subsidiary of Magellan Midstream Partners LP (Magellan), for $270 million. MVP owns and operates a marine terminal located adjacent to the Houston Ship Channel in Pasadena, Texas. We retained a 25.01 percent membership interest in MVP.

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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
	2021		2020		2021		2020
Three months ended March 31
Service cost	$	40	$	35	$	2	$	1
Interest cost	18		21		2		2
Expected return on plan assets	(48)		(44)		—		—
Amortization of:
Net actuarial loss	20		18		—		—
Prior service credit	(4)		(5)		(2)		(1)
Net periodic benefit cost	$	26	$	25	$	2	$	2

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

As previously disclosed in our annual report on Form 10-K for the year ended December 31, 2020, we plan to contribute approximately $128 million to our pension plans and $22 million to our other postretirement benefit plans during 2021. During the three months ended March 31, 2021 and 2020, we contributed $21 million and $12 million, respectively, to our pension plans and $3 million and $4 million, respectively, to our other postretirement benefit plans.

8.    INCOME TAXES

On March 27, 2020, the Coronavirus Aid, Relief and Economic Security (CARES) Act was enacted, which resulted in significant changes to the U.S. Internal Revenue Code of 1986, as amended. We recognized an overall income tax benefit of $616 million for the three months ended March 31, 2020, of which $110 million was attributable to the tax net operating loss (NOL) carryback provided for under the CARES Act of our 2020 tax NOL to our 2015 income tax year in which we paid federal income tax at a 35 percent tax rate. In addition, we were not limited in the amount of interest expense we could deduct. The remaining income tax benefit was primarily due to the LCM inventory valuation adjustment that resulted in a tax benefit of $551 million.

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9.    EARNINGS (LOSS) PER COMMON SHARE

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

	Three Months Ended March 31,
	2021		2020
Loss per common share
Net loss attributable to Valero stockholders	$	(704)	$	(1,851)
Less: Income allocated to participating securities	1		1
Net loss available to common stockholders	$	(705)	$	(1,852)
Weighted-average common shares outstanding	407		408
Loss per common share	$	(1.73)	$	(4.54)
Loss per common share – assuming dilution
Net loss attributable to Valero stockholders	$	(704)	$	(1,851)
Less: Income allocated to participating securities	1		—
Net loss available to common stockholders	$	(705)	$	(1,851)
Weighted-average common shares outstanding – assuming dilution	407		408
Loss per common share – assuming dilution	$	(1.73)	$	(4.54)

Participating securities include restricted stock and performance awards granted under our 2020 Omnibus Stock Incentive Plan (OSIP) or our 2011 OSIP.

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10.    REVENUES AND SEGMENT INFORMATION

Revenue from Contracts with Customers

Disaggregation of Revenue

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

Contract Balances

Contract balances were as follows (in millions):

	March 31, 2021		December 31, 2020		Increase
Receivables from contracts with customers, included in receivables, net	$	4,701	$	3,642	$	1,059
Contract liabilities, included in accrued expenses	104		55		49

Receivables from contracts with customers is a component of “receivables, net” as presented on the balance sheet. The increase in “receivables, net” is described in Note 11.

For the three months ended March 31, 2021 and 2020, we recognized as revenue $37 million and $52 million, respectively, that was included in contract liabilities as of December 31, 2020 and 2019, 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, 2021, 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 marketing activities, and logistics assets that support our refining operations. The principal

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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, our consolidated joint venture as discussed in Note 6. The principal product manufactured by DGD and sold by this segment is renewable diesel. 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, the associated marketing activities, and logistics assets that support our ethanol operations. 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 (loss) by reportable segment (in millions):

	Refining		Renewable Diesel		Ethanol		Corporate and Eliminations		Total
Three months ended March 31, 2021
Revenues:
Revenues from external customers	$	19,469	$	352	$	985	$	—	$	20,806
Intersegment revenues	3		79		60		(142)		—
Total revenues	19,472		431		1,045		(142)		20,806
Cost of sales:
Cost of materials and other	18,022		187		924		(141)		18,992
Operating expenses (excluding depreciation and amortization expense reflected below)	1,471		29		156		—		1,656
Depreciation and amortization expense	533		12		21		—		566
Total cost of sales	20,026		228		1,101		(141)		21,214
Other operating expenses	38		—		—		—		38
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		208		208
Depreciation and amortization expense	—		—		—		12		12
Operating income (loss) by segment	$	(592)	$	203	$	(56)	$	(221)	$	(666)

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	Refining		Renewable Diesel		Ethanol		Corporate and Eliminations		Total
Three months ended March 31, 2020
Revenues:
Revenues from external customers	$	20,985	$	306	$	811	$	—	$	22,102
Intersegment revenues	2		53		64		(119)		—
Total revenues	20,987		359		875		(119)		22,102
Cost of sales:
Cost of materials and other	19,127		130		813		(118)		19,952
LCM inventory valuation adjustment	2,414		—		128		—		2,542
Operating expenses (excluding depreciation and amortization expense reflected below)	995		20		109		—		1,124
Depreciation and amortization expense	536		11		22		—		569
Total cost of sales	23,072		161		1,072		(118)		24,187
Other operating expenses	2		—		—		—		2
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		177		177
Depreciation and amortization expense	—		—		—		13		13
Operating income (loss) by segment	$	(2,087)	$	198	$	(197)	$	(191)	$	(2,277)

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,
	2021		2020
Refining:
Gasolines and blendstocks	$	8,729	$	8,244
Distillates	8,581		10,663
Other product revenues	2,159		2,078
Total refining revenues	19,469		20,985
Renewable diesel:
Renewable diesel	352		306
Ethanol:
Ethanol	752		629
Distillers grains	233		182
Total ethanol revenues	985		811
Revenues	$	20,806	$	22,102

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

	March 31, 2021		December 31, 2020
Refining	$	45,649	$	42,939
Renewable diesel	1,948		1,659
Ethanol	1,736		1,728
Corporate and eliminations	4,281		5,448
Total assets	$	53,614	$	51,774

11.    SUPPLEMENTAL CASH FLOW INFORMATION

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

	Three Months Ended March 31,
	2021		2020
Decrease (increase) in current assets:
Receivables, net	$	(2,946)	$	2,968
Inventories	175		627
Prepaid expenses and other	(24)		(8)
Increase (decrease) in current liabilities:
Accounts payable	2,992		(4,222)
Accrued expenses	105		(79)
Taxes other than income taxes payable	(144)		(241)
Income taxes payable	26		(152)
Changes in current assets and current liabilities	$	184	$	(1,107)

Changes in current assets and current liabilities for the three months ended March 31, 2021 were primarily due to the following:

•the increase in receivables was primarily due to an increase in commodity prices in March 2021 compared to December 2020 combined with an increase in sales volumes;

•the decrease in inventories was primarily due to lower inventory levels in March 2021 compared to December 2020; and

•the increase in accounts payable was due to an increase in commodity prices in March 2021 compared to December 2020 combined with an increase in crude oil and other feedstock volumes purchased.

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Changes in current assets and current liabilities for the three months ended March 31, 2020 were primarily due to the following:

•the decrease in receivables was due to (i) a decrease of $3.4 billion as a result of a decrease in commodity prices in March 2020 compared to December 2019 combined with a decrease in sales volumes and (ii) an increase in income taxes receivable of $430 million primarily due to the recognition of the current portion of the income tax benefit described in Note 8;

•the decrease in inventories was due to a decrease in commodity prices in March 2020 compared to December 2019 combined with lower inventory levels;

•the decrease in accounts payable was due to a decrease in commodity prices in March 2020 compared to December 2019 combined with a decrease in crude oil and other feedstock volumes purchased; and

•the decrease in taxes other than income taxes payable was mainly due to the payment of ad valorem, value-added, and motor fuel taxes.

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

	Three Months Ended March 31,
	2021		2020
Interest paid in excess of amount capitalized, including interest on finance leases	$	103	$	88
Income taxes paid, net	36		121

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

	Three Months Ended March 31,
	2021				2020
	Operating Leases		Finance Leases		Operating Leases		Finance Leases
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows	$	100	$	18	$	106	$	22
Financing cash flows	—		31		—		15
Changes in lease balances resulting from new and modified leases (a)	72		7		92		1,441

________________________

(a)Noncash activity for the three months ended March 31, 2020 primarily included $1.4 billion for a finance lease right-of-use asset and related liability recognized in connection with the terminaling agreement with MVP.

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There were no significant noncash investing and financing activities during the three months ended March 31, 2021 and 2020, except as noted in the table above.

12.    FAIR VALUE MEASUREMENTS

Recurring Fair Value Measurements

The following tables present information (in millions) about our assets and liabilities recognized at their fair values in our balance sheets categorized according to the fair value hierarchy of the inputs utilized by us to determine the fair values as of March 31, 2021 and December 31, 2020.

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, 2021
							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	$	386	$	—	$	—	$	386	$	(386)	$	—	$	—	$	—
Physical purchase contracts	—		10		—		10		n/a		n/a		10		n/a
Foreign currency contracts	10		—		—		10		n/a		n/a		10		n/a
Investments of certain benefit plans	75		—		8		83		n/a		n/a		83		n/a
Total	$	471	$	10	$	8	$	489	$	(386)	$	—	$	103
Liabilities
Commodity derivative contracts	$	444	$	—	$	—	$	444	$	(386)	$	(58)	$	—	$	(120)
Environmental credit obligations	—		62		—		62		n/a		n/a		62		n/a
Total	$	444	$	62	$	—	$	506	$	(386)	$	(58)	$	62

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	December 31, 2020
							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	$	403	$	—	$	—	$	403	$	(373)	$	(18)	$	12	$	—
Physical purchase contracts	—		13		—		13		n/a		n/a		13		n/a
Investments of certain benefit plans	74		—		8		82		n/a		n/a		82		n/a
Total	$	477	$	13	$	8	$	498	$	(373)	$	(18)	$	107
Liabilities
Commodity derivative contracts	$	405	$	—	$	—	$	405	$	(373)	$	(32)	$	—	$	(44)
Environmental credit obligations	—		96		—		96		n/a		n/a		96		n/a
Foreign currency contracts	4		—		—		4		n/a		n/a		4		n/a
Total	$	409	$	96	$	—	$	505	$	(373)	$	(32)	$	100

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

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

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

•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.

•Foreign currency contracts consist of foreign currency exchange and purchase contracts and foreign currency swap agreements related to our international operations to manage our exposure to exchange rate fluctuations on transactions denominated in currencies other than the local

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(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.

•Environmental credit obligations represent our liability for the purchase of (i) biofuel credits (primarily Renewable Identification Numbers (RINs) in the U.S.) needed to satisfy our obligation to blend biofuels into the products we produce and (ii) emission credits under the California Global Warming Solutions Act (the California cap-and-trade system, also known as AB 32) and similar programs (collectively, the cap-and-trade systems). To the degree we are unable to blend biofuels (such as ethanol and biodiesel) at percentages required under the biofuel programs, we must purchase biofuel credits to comply with these programs. Under the cap-and-trade systems, we must purchase emission credits to comply with these systems. These programs are described in Note 13 under “Risk Management Activities by Type of Risk—Environmental Compliance Program Price Risk.” The liability for environmental credits is based on our deficit for such credits as of the balance sheet date, if any, after considering any credits acquired or under contract, and is equal to the product of the credits deficit and the market price of these credits as of the balance sheet date. The environmental credit 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.

Nonrecurring Fair Value Measurements

There were no assets or liabilities that were measured at fair value on a nonrecurring basis as of March 31, 2021 and December 31, 2020.

Other Financial Instruments

Financial instruments that we recognize in our balance sheets at their carrying amounts are shown in the following table along with their associated fair values (in millions):

		March 31, 2021				December 31, 2020
	Fair Value Hierarchy	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Financial assets
Cash and cash equivalents	Level 1	$	2,254	$	2,254	$	3,313	$	3,313
Financial liabilities
Debt (excluding finance leases)	Level 2	13,024		14,776		13,013		15,103

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13.    PRICE RISK MANAGEMENT ACTIVITIES

General

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

Risk Management Activities by Type of Risk

Commodity Price Risk

We are exposed to market risks related to the volatility in the price of feedstocks (primarily crude oil and corn), the products we produce (primarily refined petroleum products), 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 of directors.

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

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

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

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As of March 31, 2021, 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
	2021	2022
Derivatives designated as cash flow hedges
Refined petroleum products:
Futures – long	427	—
Futures – short	1,605	—
Derivatives designated as economic hedges
Crude oil and refined petroleum products:
Futures – long	66,513	64
Futures – short	56,880	22
Corn:
Futures – long	63,630	10
Futures – short	90,395	365
Physical contracts – long	26,563	351

Foreign Currency Risk

We are exposed to exchange rate fluctuations on transactions related to our international 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 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, 2021, we had foreign currency contracts to purchase $245 million of U.S. dollars and $2.8 billion of U.S. dollar equivalent Canadian dollars. Of these commitments, $1.0 billion matured on or before April 27, 2021 and the remaining $2.0 billion will mature by July 15, 2021.

Environmental Compliance Program Price Risk

We are exposed to market risk related to the volatility in the price of credits needed to comply with various governmental and regulatory environmental compliance programs. To manage this risk, we enter into contracts to purchase these credits when prices are deemed favorable. Some of these contracts are derivative instruments; however, we elect the normal purchase exception and do not record these contracts at their fair values. Certain of these programs require us to blend biofuels into the products we produce, and we are subject to such programs in most of the countries in which we operate. These countries set annual quotas for the percentage of biofuels that must be blended into the motor fuels consumed in these countries. As a producer of motor fuels from petroleum, we are obligated to blend biofuels into the products we produce at a rate that is at least equal to the applicable quota. To the degree we are unable to blend at the applicable rate, we must purchase biofuel credits (primarily RINs in the U.S.). We are exposed to the volatility in the market price of these credits, and we manage that risk by purchasing biofuel credits when prices are deemed favorable. The cost of meeting our

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obligations under these compliance programs was $360 million and $112 million for the three months ended March 31, 2021 and 2020, respectively. These amounts are reflected in cost of materials and other.

We are subject to additional requirements under greenhouse gas (GHG) emission programs, including the cap-and-trade systems, as discussed in Note 12. Under these cap-and-trade systems, we purchase various GHG emission credits available on the open market. Therefore, we are exposed to the volatility in the market price of these credits. The cost to implement certain provisions of the cap-and-trade systems are significant; however, we recovered substantially all of these costs from our customers for the three months ended March 31, 2021 and 2020 and expect to continue to recover the majority of these costs in the future. For the three months ended March 31, 2021 and 2020, the net cost of meeting our obligations under these compliance programs was immaterial.

Fair Values of Derivative Instruments

The following tables provide information about the fair values of our derivative instruments as of March 31, 2021 and December 31, 2020 (in millions) and the line items in the balance sheets in which the fair values are reflected. See Note 12 for additional information related to the fair values of our derivative instruments.

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

	Balance Sheet Location	March 31, 2021				December 31, 2020
		Asset Derivatives		Liability Derivatives		Asset Derivatives		Liability Derivatives
Derivatives designated as hedging instruments
Commodity contracts	Receivables, net	$	5	$	10	$	4	$	17
Derivatives not designated as hedging instruments
Commodity contracts	Receivables, net	$	381	$	434	$	399	$	388
Physical purchase contracts	Inventories	10		—		13		—
Foreign currency contracts	Receivables, net	10		—		—		—
Foreign currency contracts	Accrued expenses	—		—		—		4
Total		$	401	$	434	$	412	$	392

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

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market risk on a daily basis in accordance with policies approved by our board of directors. 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,
		2021		2020
Commodity contracts
Gain (loss) recognized in other comprehensive income (loss) on derivatives	N/A	$	(13)	$	55
Gain (loss) reclassified from accumulated other comprehensive loss into income	Revenues	(23)		26

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, 2021 and 2020. For the three months ended March 31, 2021 and 2020, 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 over the next 12 months as a result of the hedged transactions that are forecasted to occur as of March 31, 2021 was immaterial. For the three months ended March 31, 2021 and 2020, 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, 2021 and 2020 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,
		2021		2020
Commodity contracts	Revenues	$	7	$	(8)
Commodity contracts	Cost of materials and other	(78)		(152)
Commodity contracts	Operating expenses (excluding depreciation and amortization expense)	1		(2)
Foreign currency contracts	Cost of materials and other	(8)		49
Foreign currency contracts	Other income, net	30		(165)

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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 the heading “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,” “will,” “may,” “strive,” “seek,” “potential,” “opportunity,” “aimed,” “considering,” “continue,” and similar expressions.

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

•the effect, impact, potential duration or timing, or other implications of the COVID-19 pandemic, government restrictions in response thereto, variants of the COVID-19 virus, vaccine distribution and administration levels, economic activity, and global crude oil production levels, and any expectations we may have with respect thereto, including with respect to our operations and the production levels of our assets;

•our expectations with respect to the frequency of large excess costs and expenses arising out of storms and other weather events, such as Winter Storm Uri;

•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, and operating expenses;

•anticipated levels of crude oil and refined petroleum product inventories and storage capacity;

•expectations regarding the levels of, and timing with respect to, the production and operations at our refineries and plants;

•our anticipated level of capital investments, including deferred turnaround and catalyst cost 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 results of operations;

•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 repurchase program;

•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 initiatives;

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

27

•expectations regarding adoptions of new, or changes to existing, low-carbon fuel standards or policies, blending credits, or efficiency standards that impact demand for renewable fuels; and

•expectations regarding several carbon transition projects, which are in early development.

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 or forecast in the forward-looking statements. Differences between actual performance or results and any future performance or results suggested in these forward-looking statements could result from a variety of factors, including the following:

•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, governmental and societal responses thereto, vaccine distribution and administration levels, and the adverse impacts of the foregoing on our business, financial condition, results of operations, and liquidity, including, but not limited to, our growth, operating costs, supply chain, labor availability, logistical capabilities, customer demand for our products, and industry demand generally, margins, production and throughput capacity, utilization, inventory value, cash position, taxes, the price of our securities and trading markets with respect thereto, our ability to access capital markets, 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, or to receive feedstocks;

•political and economic conditions in nations 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) to agree on and to maintain crude oil price and production controls;

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

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

•our ability to successfully integrate any acquired businesses into our operations;

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

•the actions taken by competitors, including both pricing and adjustments to refining capacity or renewable fuels production in response to market conditions;

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

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

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•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, 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 mandates or other policies with respect to, alternative fuels, alternative-fuel vehicles, and other low-carbon technologies or initiatives;

•the volatility in the market price of biofuel credits (primarily RINs needed to comply with the U.S. federal Renewable Fuel Standard (RFS)) and GHG emission credits needed to comply with the requirements of various GHG emission programs;

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

•earthquakes, hurricanes, tornadoes, and irregular weather, which can unforeseeably affect the price or availability of natural gas, crude oil, rendered and recycled materials, corn, and other feedstocks, 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 governmental authorities, including tariffs and tax and environmental regulations, such as changes to the corporate tax rate, actions implemented under the California cap-and-trade system and similar programs, changes to volume requirements or other obligations or exemptions under the RFS, and actions arising from the U.S. Environmental Protection Agency’s (EPA’s) or other governmental regulation of GHGs, which may adversely affect our business or operations;

•changing economic, regulatory, and political environments in the various countries in which we operate or otherwise do business;

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

•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;

•the costs, disruption, and diversion of management’s attention associated with campaigns and negative publicity commenced by investors, stakeholders, or other interested parties;

•overall economic conditions, including the stability and liquidity of financial markets; 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, 2020.

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 suggested in any forward-looking statements. We do not intend to update these statements unless we are required by the 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. 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.

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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 U.S. GAAP. These non-GAAP financial measures include adjusted operating income (loss) (including adjusted operating income (loss) 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 and to help assess our cash flows. See the tables in note (c) beginning on page 41 for reconciliations of adjusted operating income (loss) (including adjusted operating income (loss) for each of our reportable segments, as applicable) and refining, renewable diesel, and ethanol segment margin to their most directly comparable U.S. 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 U.S. 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.

OVERVIEW AND OUTLOOK

Overview

Business Operations Update

The outbreak of COVID-19 and its development into a pandemic in March 2020 resulted in significant economic disruption globally as governmental authorities imposed restrictions, such as stay-at-home orders and other social distancing measures, to slow the spread of COVID-19. These actions significantly reduced global economic activity and negatively impacted many businesses, including our business. We experienced a decline in the demand for most of the transportation fuels that we produce and sell, and thus also a decline in the market prices of those products, due to a decrease in the level of individual movement and travel resulting from the restrictions. There was also a decline in the global demand for crude oil, the primary feedstock for the products of our refining segment, resulting in a decline in crude oil prices and production levels. As a result of these factors, we generated a net loss attributable to Valero stockholders in 2020 and our operations generated significantly less cash in 2020 than in prior years. We took a number of actions since March 2020 to respond to the impacts from the pandemic on our business, such as reducing transportation fuel production at our refineries and ethanol plants to align with demand, deferring certain capital investments, deferring the payment of certain income and indirect taxes as permitted by legislation, and suspending purchases of our common stock under our stock purchase program. We also raised a total of $4.0 billion (before deducting the underwriting discounts and debt issuance costs) through two public debt offerings at attractive rates. The net proceeds from these offerings, along with the cash generated by our operations, allowed us to make most of our planned capital investments, pay dividends in each of the 2020 quarterly periods, and increase our cash and cash equivalents on hand as of December 31, 2020 compared to the prior year end.

For the first quarter of 2021, we reported a net loss attributable to Valero stockholders of $704 million. The factor primarily impacting these results was a significant increase in the cost of electricity and natural gas at certain of our refineries and ethanol plants arising out of Winter Storm Uri. We incurred excess energy costs estimated at $579 million, or $467 million after taxes, during the first quarter of 2021. Our results for the first quarter are more fully discussed in “First Quarter Results” below and in “RESULTS OF OPERATIONS” beginning on page 33.

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While the significant increase in energy costs was an event isolated to the first quarter of 2021, our business showed signs of recovery and improvement in the demand for and market prices of gasoline and diesel, with both factors reaching near pre-pandemic levels in March 2021. Jet fuel demand has seen improved market indicators, such as higher traveler throughput as reported by the Transportation Security Administration, although at a slower pace than other products we produce relative to pre-pandemic levels. These improvements resulted primarily from the lifting or easing of restrictions by many governmental authorities, especially those in our U.S. Gulf Coast and U.S. Mid-Continent regions, in response to decreasing COVID-19 infection rates and increasing numbers of people receiving COVID-19 vaccines, which were approved by a number of regulators throughout the world in late 2020 and early 2021. While many governmental authorities in areas located in our U.S. West Coast and North Atlantic regions, such as California, Canada, and the U.K., continue to impose restrictions, some of these restrictions have been or are soon expected to be moderately lifted. The ongoing distribution of vaccines may result in the continued lifting of restrictions and may be seen as a key factor in helping to restore public confidence, and thus stimulate and increase economic activity, potentially to pre-pandemic levels; however, the risk remains that the vaccines may not be distributed widely on a timely basis, they may not be effective against new variants of the COVID-19 virus, the distribution of some or all of the vaccines may be paused or withdrawn due to concerns with potential side effects, and/or the level of individuals’ willingness to receive a vaccine may not be as strong or as timely as needed. Based on these and other circumstances that cannot be predicted, the broader implications of the pandemic on our results of operations and financial position remain uncertain.

The improving, but lingering, impacts of the pandemic on our operations and the negative effects arising out of Winter Storm Uri on the energy costs at certain of our refineries and ethanol plants also impacted our liquidity during the first quarter of 2021. Our operations for the quarter used $52 million of cash largely due to the effect from estimated excess energy costs previously noted, the majority of which were paid by the end of the first quarter. We also made $582 million in capital investments and paid $400 million in dividends during the quarter. As a result, our cash and cash equivalents decreased by $1.0 billion, from $3.3 billion as of December 31, 2020 to $2.3 billion as of March 31, 2021. We did not issue any debt or make any borrowings under our credit facilities during the first quarter of 2021, and we had $8.0 billion in liquidity1 as of March 31, 2021. A summary of our cash flows is presented on page 45, and a description of our cash flows and other matters impacting our liquidity and capital resources, including measures we have taken to address the impacts of the COVID-19 pandemic on our liquidity, can be found under “LIQUIDITY AND CAPITAL RESOURCES” on pages 44 through 49.

While our business has improved as a result of the increasing demand for and market prices of most of the products that we produce, many uncertainties remain with respect to the pandemic, including its resulting economic effects. Therefore, we are unable to predict the ultimate economic impacts from the pandemic on our business and how quickly national economies can recover once the pandemic subsides, the timing or effectiveness of vaccine distributions or vaccination levels, whether improvements experienced by us so far may reverse, or whether other setbacks may occur. As a result, the adverse impacts of the economic effects of the pandemic on our company may likely continue to be significant. We believe we have proactively responded to many of the known impacts of the pandemic on our business to the extent practicable and we strive to continue to do so, but there can be no assurance that these or other measures will be fully effective.

1 See the components of our liquidity as of March 31, 2021 in the table on page 45 under “LIQUIDITY AND CAPITAL RESOURCES—Our Liquidity.”

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First Quarter Results

For the first quarter of 2021, we reported a net loss attributable to Valero stockholders of $704 million compared to a net loss attributable to Valero stockholders of $1.9 billion for the first quarter of 2020. The improvement of $1.1 billion was primarily due to a lower operating loss of $1.6 billion, partially offset by a lower income tax benefit of $468 million. The decrease in operating loss between the periods included the effect of a $2.5 billion LCM inventory valuation adjustment in the first quarter of 2020, which is described in Note 3 of Condensed Notes to Consolidated Financial Statements and in note (b) on page 41.

While our operating loss decreased by $1.6 billion in the first quarter of 2021 compared to the first quarter of 2020, adjusted operating income decreased by $895 million. Adjusted operating income excludes the adjustments reflected in the table in note (c) on page 44.

The $895 million decrease in adjusted operating income was primarily due to the following:

•Refining segment. Refining segment adjusted operating income decreased by $883 million primarily due to estimated excess energy costs arising out of Winter Storm Uri, lower distillate margins, lower throughput volumes, and higher cost of biofuel credits, partially offset by higher gasoline margins. This is more fully described on pages 37 and 38.

•Renewable diesel segment. Renewable diesel segment operating income increased by $5 million primarily due to higher renewable diesel prices, partially offset by higher feedstock costs and an unfavorable impact from commodity derivative instruments associated with our price risk management activities. This is more fully described on page 39.

•Ethanol segment. Ethanol segment adjusted operating loss decreased by $13 million primarily due to higher ethanol and corn related co-product prices, partially offset by higher corn prices, estimated excess energy costs arising out of Winter Storm Uri, and lower production volumes. This is more fully described on pages 40 and 41.

Outlook

As previously discussed, many uncertainties remain with respect to the COVID-19 pandemic, and while it is difficult to predict the ultimate economic impacts that the pandemic may have on us and how quickly we can recover once the pandemic subsides, we have noted several factors below that have impacted or may impact our results of operations during the second quarter of 2021.

•Gasoline, jet fuel, and diesel prices are expected to continue to improve with industry-wide inventory levels returning to historical levels and continued recovery in product demand.

•Sour crude oil discounts are expected to continue to improve as OPEC production increases in response to any further growth in global oil demand.

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

•Ethanol margins are expected to improve as domestic consumption increases.

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RESULTS OF OPERATIONS

The following tables, including the reconciliations of non-GAAP financial measures to their most directly comparable U.S. GAAP financial measures in note (c) beginning on page 41, highlight our results of operations, our operating performance, and market reference prices and margins that directly impact our operations.

First Quarter Results -

Financial Highlights By Segment and Total Company

(millions of dollars)

	Three Months Ended March 31, 2021
	Refining		Renewable Diesel		Ethanol		Corporate and Eliminations		Total
Revenues:
Revenues from external customers	$	19,469	$	352	$	985	$	—	$	20,806
Intersegment revenues	3		79		60		(142)		—
Total revenues	19,472		431		1,045		(142)		20,806
Cost of sales:
Cost of materials and other (a)	18,022		187		924		(141)		18,992
Operating expenses (excluding depreciation and amortization expense reflected below) (a)	1,471		29		156		—		1,656
Depreciation and amortization expense	533		12		21		—		566
Total cost of sales	20,026		228		1,101		(141)		21,214
Other operating expenses	38		—		—		—		38
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		208		208
Depreciation and amortization expense	—		—		—		12		12
Operating income (loss) by segment	$	(592)	$	203	$	(56)	$	(221)	(666)
Other income, net									45
Interest and debt expense, net of capitalized interest									(149)
Loss before income tax benefit									(770)
Income tax benefit									(148)
Net loss									(622)
Less: Net income attributable to noncontrolling interests									82
Net loss attributable to Valero Energy Corporation stockholders									$	(704)

________________________

See note references on pages 41 through 44.

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First Quarter Results -

Financial Highlights By Segment and Total Company (continued)

(millions of dollars)

	Three Months Ended March 31, 2020
	Refining		Renewable Diesel		Ethanol		Corporate and Eliminations		Total
Revenues:
Revenues from external customers	$	20,985	$	306	$	811	$	—	$	22,102
Intersegment revenues	2		53		64		(119)		—
Total revenues	20,987		359		875		(119)		22,102
Cost of sales:
Cost of materials and other	19,127		130		813		(118)		19,952
LCM inventory valuation adjustment (b)	2,414		—		128		—		2,542
Operating expenses (excluding depreciation and amortization expense reflected below)	995		20		109		—		1,124
Depreciation and amortization expense	536		11		22		—		569
Total cost of sales	23,072		161		1,072		(118)		24,187
Other operating expenses	2		—		—		—		2
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		177		177
Depreciation and amortization expense	—		—		—		13		13
Operating income (loss) by segment	$	(2,087)	$	198	$	(197)	$	(191)	(2,277)
Other income, net									32
Interest and debt expense, net of capitalized interest									(125)
Loss before income tax benefit									(2,370)
Income tax benefit									(616)
Net loss									(1,754)
Less: Net income attributable to noncontrolling interests									97
Net loss attributable to Valero Energy Corporation stockholders									$	(1,851)

________________________

See note references on pages 41 through 44.

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First Quarter Results -

Average Market Reference Prices and Differentials

	Three Months Ended March 31,
	2021		2020		Change
Refining
Feedstocks (dollars per barrel)
Brent crude oil	$	61.09	$	50.90	$	10.19
Brent less West Texas Intermediate (WTI) crude oil	3.26		4.92		(1.66)
Brent less Alaska North Slope (ANS) crude oil	0.33		(0.50)		0.83
Brent less Louisiana Light Sweet (LLS) crude oil	1.11		2.76		(1.65)
Brent less Argus Sour Crude Index (ASCI) crude oil	2.99		5.01		(2.02)
Brent less Maya crude oil	4.70		9.74		(5.04)
LLS crude oil	59.98		48.14		11.84
LLS less ASCI crude oil	1.88		2.25		(0.37)
LLS less Maya crude oil	3.59		6.98		(3.39)
WTI crude oil	57.84		45.98		11.86
Natural gas (dollars per million British Thermal Units)	19.66		1.82		17.84
Product margins (dollars per barrel)
U.S. Gulf Coast:
Conventional Blendstock of Oxygenate Blending (CBOB) gasoline less Brent	10.12		2.37		7.75
Ultra-low-sulfur (ULS) diesel less Brent	10.19		11.26		(1.07)
Propylene less Brent	18.50		(21.04)		39.54
CBOB gasoline less LLS	11.23		5.13		6.10
ULS diesel less LLS	11.30		14.02		(2.72)
Propylene less LLS	19.61		(18.28)		37.89
U.S. Mid-Continent:
CBOB gasoline less WTI	14.82		7.69		7.13
ULS diesel less WTI	17.21		17.31		(0.10)
North Atlantic:
CBOB gasoline less Brent	11.56		4.28		7.28
ULS diesel less Brent	11.89		14.29		(2.40)
U.S. West Coast:
California Reformulated Gasoline Blendstock of Oxygenate Blending (CARBOB) 87 gasoline less ANS	14.56		7.82		6.74
California Air Resources Board (CARB) diesel less ANS	14.14		17.22		(3.08)
CARBOB 87 gasoline less WTI	17.49		13.24		4.25
CARB diesel less WTI	17.07		22.64		(5.57)

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First Quarter Results -

Average Market Reference Prices and Differentials, (continued)

	Three Months Ended March 31,
	2021		2020		Change
Renewable diesel
New York Mercantile Exchange ULS diesel (dollars per gallon)	$	1.74	$	1.55	$	0.19
Biodiesel RIN (dollars per RIN)	1.18		0.46		0.72
California Low-Carbon Fuel Standard (dollars per metric ton)	195.30		206.03		(10.73)
Chicago Board of Trade (CBOT) soybean oil (dollars per pound)	0.48		0.30		0.18
Ethanol
CBOT corn (dollars per bushel)	5.39		3.74		1.65
New York Harbor ethanol (dollars per gallon)	1.78		1.33		0.45

Total Company, Corporate, and Other

The following table includes selected financial data for the total company, corporate, and other for the first quarter of 2021 and 2020. The selected financial data is derived from the Financial Highlights by Segment and Total Company tables on pages 33 and 34, unless otherwise noted.

	Three Months Ended March 31,
	2021		2020		Change
Revenues	$	20,806	$	22,102	$	(1,296)
Cost of sales (see notes (a) and (b) on page 41)	21,214		24,187		(2,973)
Operating expenses (excluding depreciation and amortization expense) (see note (a) on page 41)	1,656		1,124		532
General and administrative expenses (excluding depreciation and amortization expense)	208		177		31
LCM inventory valuation adjustment (see note (b) on page 41)	—		2,542		(2,542)
Operating loss	(666)		(2,277)		1,611
Adjusted operating income (loss) (see note (c) on page 44)	(628)		267		(895)
Interest and debt expense, net of capitalized interest	(149)		(125)		(24)
Income tax benefit	(148)		(616)		468

Revenues decreased by $1.3 billion in the first quarter of 2021 compared to the first quarter of 2020 primarily due to a decrease in the volume of refined petroleum products sold by our refining segment. This decrease in revenues, along with an increase in general and administrative expenses (excluding depreciation and amortization expense) of $31 million, was more than offset by a decrease in cost of sales of $3.0 billion, which resulted in a $1.6 billion decrease in operating loss, from $2.3 billion in the first quarter of 2020 to $666 million in the first quarter of 2021. The decrease in cost of sales was primarily due to the effect of the $2.5 billion LCM inventory valuation adjustment in the first quarter of 2020 and lower production volumes resulting in lower crude oil and other feedstock costs in the first quarter of 2021, partially offset by a $532 million increase in operating expenses (excluding depreciation and amortization expense).

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Adjusted operating income decreased by $895 million, from $267 million of adjusted operating income in the first quarter of 2020 to an adjusted operating loss of $628 million in the first quarter of 2021. The $895 million decrease includes a $31 million increase in general and administrative expenses (excluding depreciation and amortization expense) associated with our corporate activities, and this increase is discussed below. The remaining components of the decrease in adjusted operating income are discussed by segment in the segment analyses that follow.

General and administrative expenses (excluding depreciation and amortization expense) increased by $31 million in the first quarter of 2021 compared to the first quarter of 2020 primarily due to an increase in certain employee compensation expenses of $23 million and higher advertising expenses of $7 million.

“Interest and debt expense, net of capitalized interest” increased by $24 million in the first quarter of 2021 compared to the first quarter of 2020 primarily due to interest expense associated with public debt offerings in 2020.

Income tax benefit decreased by $468 million in the first quarter of 2021 compared to the first quarter of 2020 primarily as a result of a lower loss before income tax benefit. Our effective tax rate was 19 percent for the first quarter of 2021 compared to 26 percent for the first quarter of 2020. The effective tax rate for the first quarter of 2020 was impacted by the U.S. federal tax NOL for 2020, which was carried back to 2015 when the U.S. federal statutory rate was 35 percent, as described in Note 8 of Condensed Notes to Consolidated Financial Statements.

Refining Segment Results

The following table includes selected financial and operating data of our refining segment for the first quarter of 2021 and 2020. The selected financial data is derived from the Financial Highlights by Segment and Total Company tables on pages 33 and 34, respectively, unless otherwise noted.

	Three Months Ended March 31,
	2021		2020		Change
Operating loss	$	(592)	$	(2,087)	$	1,495
Adjusted operating income (loss) (see note (c) on page 43)	(554)		329		(883)
Refining margin (see note (c) on page 42)	$	1,450	$	1,860	$	(410)
Operating expenses (excluding depreciation and amortization expense reflected below) (see note (a) on page 41)	1,471		995		476
Depreciation and amortization expense	533		536		(3)
Throughput volumes (thousand barrels per day) (see note (d) on page 44)	2,410		2,824		(414)

Refining segment operating loss decreased by $1.5 billion in the first quarter of 2021; however, refining segment adjusted operating income, which excludes the adjustments in the table in note (c) on page 43, decreased by $883 million in the first quarter of 2021 compared to the first quarter of 2020. The

37

components of this decrease, along with the reasons for the changes in those components, are outlined below.

•Refining segment margin decreased by $410 million in the first quarter of 2021 compared to the first quarter of 2020.

Refining segment margin is primarily affected by the prices of the refined petroleum products that we sell and the cost of crude oil and other feedstocks that we process. The table on page 35 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 2021 compared to the first quarter of 2020.

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

◦A decrease in distillate (primarily diesel) margins had an unfavorable impact of approximately $280 million.

◦A decrease in throughput volumes of 414,000 barrels per day had an unfavorable impact of $249 million. As noted in “OVERVIEW AND OUTLOOK—Overview—Business Operations Update” on pages 30 through 31, the COVID-19 pandemic resulted in global economic disruption and a significant decline in the demand for the transportation fuels we produce, and as a result, we reduced production of transportation fuel products beginning late in the first quarter of 2020. We have since increased the production of most of our products to align with improvements in demand, which reached near pre-pandemic levels in March 2021.

◦An increase in the cost of biofuel credits (primarily RINs in the U.S.) had an unfavorable impact of $248 million. See Note 13 of Condensed Notes to Consolidated Financial Statements for additional information on our government and regulatory compliance program.

◦Lower discounts on feedstocks other than crude oil had an unfavorable impact of approximately $167 million.

◦Estimated excess energy costs arising out of Winter Storm Uri had an unfavorable impact of $47 million (see note (a) on page 41).

◦An increase in gasoline margins had a favorable impact of approximately $557 million.

•Refining segment operating expenses (excluding depreciation and amortization expense) increased by $476 million primarily due to estimated excess energy costs arising out of Winter Storm Uri of $478 million (see note (a) on page 41).

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Renewable Diesel Segment Results

The following table includes selected financial and operating data of our renewable diesel segment for the first quarter of 2021 and 2020. The selected financial data is derived from the Financial Highlights by Segment and Total Company tables on pages 33 and 34, respectively, unless otherwise noted.

	Three Months Ended March 31,
	2021		2020		Change
Operating income	$	203	$	198	$	5
Renewable diesel margin (see note (c) on page 42)	$	244	$	229	$	15
Operating expenses (excluding depreciation and amortization expense reflected below)	29		20		9
Depreciation and amortization expense	12		11		1
Sales volumes (thousand gallons per day) (see note (d) on page 44)	867		867		—

Renewable diesel segment operating income increased by $5 million in the first quarter of 2021. The increase was primarily due to higher renewable diesel segment margin.

Renewable diesel segment margin increased by $15 million in the first quarter of 2021 compared to the first quarter of 2020. Renewable diesel segment margin is primarily affected by the price of the renewable diesel that we sell and the cost of the feedstocks that we process. The table on page 36 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 2021 compared to the first quarter of 2020.

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

•Higher renewable diesel prices had a favorable impact of approximately $121 million.

•An increase in the cost of the feedstocks we process had an unfavorable impact of approximately $59 million.

•Price risk management activities had an unfavorable impact of $49 million. We recognized a hedge loss of $23 million in the first quarter of 2021 compared to a hedge gain of $26 million in the first quarter of 2020.

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Ethanol Segment Results

The following table includes selected financial and operating data of our ethanol segment for the first quarter of 2021 and 2020. The selected financial data is derived from the Financial Highlights by Segment and Total Company tables on pages 33 and 34, respectively, unless otherwise noted.

	Three Months Ended March 31,
	2021		2020		Change
Operating loss	$	(56)	$	(197)	$	141
Adjusted operating loss (see note (c) on page 43)	(56)		(69)		13
Ethanol margin (see note (c) on page 43)	$	121	$	62	$	59
Operating expenses (excluding depreciation and amortization expense reflected below) (see note (a) on page 41)	156		109		47
Depreciation and amortization expense	21		22		(1)
Production volumes (thousand gallons per day) (see note (d) on page 44)	3,562		4,103		(541)

Ethanol segment operating loss decreased by $141 million in the first quarter of 2021; however, ethanol segment adjusted operating loss, which excludes the adjustment in the table in note (c) on page 43, decreased by $13 million in the first quarter of 2021 compared to the first quarter of 2020. The components of this decrease, along with the reasons for the changes in those components, are outlined below.

•Ethanol segment margin increased by $59 million in the first quarter of 2021 compared to the first quarter of 2020.

Ethanol segment margin is primarily affected by prices of the ethanol and corn related co-products that we sell and the cost of corn that we process. The table on page 36 reflects market reference prices that we believe had a material impact on the change in our ethanol segment margin in the first quarter of 2021 compared to the first quarter of 2020.

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

◦Higher ethanol prices had a favorable impact of approximately $178 million.

◦Higher prices on the co-products that we produce, primarily distillers grains, had a favorable impact of approximately $94 million.

◦Higher corn prices had an unfavorable impact of approximately $188 million.

◦A decrease in production volumes of 541,000 gallons per day had an unfavorable impact of approximately $24 million. As noted in “OVERVIEW AND OUTLOOK—Overview—Business Operations Update” on pages 30 through 31, the COVID-19 pandemic resulted in global economic disruption and a significant decline in demand for ethanol, and as a result, we reduced production beginning late in the first quarter of 2020. We have since increased the production of ethanol at most of our plants to align with improvements in demand.

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•Ethanol segment operating expenses (excluding depreciation and amortization expense) increased by $47 million primarily due to estimated excess energy costs arising out of Winter Storm Uri of $54 million (see note (a) on page 41), partially offset by lower chemical and catalyst costs of $6 million.

________________________

The following notes relate to references on pages 30 through 41.

(a)In mid-February 2021, many of our refineries and plants were impacted to varying extents by the severe cold, utility disruptions, and higher energy costs arising out of Winter Storm Uri. The higher energy costs resulted from an increase in the prices of natural gas and electricity that significantly exceeded rates that we consider normal, such as the average rates we incurred the month preceding the storm. As a result, our operating loss for the three months ended March 31, 2021 includes estimated excess energy costs of $579 million.

The above-mentioned pre-tax estimated excess energy charge is reflected in our statement of income line items and attributable to our reportable segments as follows (in millions):

	Refining		Renewable Diesel		Ethanol		Total
Cost of materials and other	$	47	$	—	$	—	$	47
Operating expenses (excluding depreciation and amortization expense)	478		—		54		532
Total estimated excess energy costs	$	525	$	—	$	54	$	579

(b)The market value of our inventories accounted for under the LIFO method fell below their historical cost on an aggregate basis as of March 31, 2020. As a result, we recorded an LCM inventory valuation adjustment of $2.5 billion in March 2020. Of the $2.5 billion adjustment, $2.4 billion and $128 million are attributable to our refining and ethanol segments, respectively.

(c)We use certain financial measures (as noted below) that are not defined under U.S. 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 our adjusted operating income measures (including for our refining and ethanol segments) are useful to assess our ongoing financial performance because, when reconciled to their most comparable U.S. GAAP measures, they provide improved comparability between periods through the exclusion of certain items that we believe are not indicative of our core operating performance and that may obscure our underlying business results and trends. We believe our refining margin, renewable diesel margin, and ethanol margin, as applicable, are important measures of the relevant segment’s operating and financial performance because, with respect to such segment, it is the most comparable measure to the industry’s market reference product margins, which are used by industry analysts, investors, and others to evaluate our performance. These non-GAAP measures should not be considered as alternatives to their most comparable U.S. GAAP measures nor should they be considered in isolation or as a substitute for an analysis of our results of operations as reported under U.S. 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 loss excluding the LCM inventory valuation adjustment, operating expenses (excluding depreciation and amortization expense), depreciation and amortization expense, and other operating expenses, as reflected in the table below.

	Three Months Ended March 31,
	2021		2020
Reconciliation of refining operating loss to refining margin
Refining operating loss	$	(592)	$	(2,087)
Adjustments:
LCM inventory valuation adjustment (see note (b))	—		2,414
Operating expenses (excluding depreciation and amortization expense) (see note (a))	1,471		995
Depreciation and amortization expense	533		536
Other operating expenses	38		2
Refining margin	$	1,450	$	1,860

◦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,
	2021		2020
Reconciliation of renewable diesel operating income to renewable diesel margin
Renewable diesel operating income	$	203	$	198
Adjustments:
Operating expenses (excluding depreciation and amortization expense)	29		20
Depreciation and amortization expense	12		11
Renewable diesel margin	$	244	$	229

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◦Ethanol margin is defined as ethanol segment operating loss excluding the LCM inventory valuation adjustment, operating expenses (excluding depreciation and amortization expense), and depreciation and amortization expense, as reflected in the table below.

	Three Months Ended March 31,
	2021		2020
Reconciliation of ethanol operating loss to ethanol margin
Ethanol operating loss	$	(56)	$	(197)
Adjustments:
LCM inventory valuation adjustment (see note (b))	—		128
Operating expenses (excluding depreciation and amortization expense) (see note (a))	156		109
Depreciation and amortization expense	21		22
Ethanol margin	$	121	$	62

◦Adjusted refining operating income (loss) is defined as refining segment operating loss excluding the LCM inventory valuation adjustment and other operating expenses, as reflected in the table below.

	Three Months Ended March 31,
	2021		2020
Reconciliation of refining operating loss to adjusted refining operating income (loss)
Refining operating loss	$	(592)	$	(2,087)
Adjustments:
LCM inventory valuation adjustment (see note (b))	—		2,414
Other operating expenses	38		2
Adjusted refining operating income (loss)	$	(554)	$	329

◦Adjusted ethanol operating loss is defined as ethanol segment operating loss excluding the LCM inventory valuation adjustment, as reflected in the table below.

	Three Months Ended March 31,
	2021		2020
Reconciliation of ethanol operating loss to adjusted ethanol operating loss
Ethanol operating loss	$	(56)	$	(197)
Adjustments:
LCM inventory valuation adjustment (see note (b))	—		128
Adjusted ethanol operating loss	$	(56)	$	(69)

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◦Adjusted operating income (loss) is defined as total company operating loss excluding the LCM inventory valuation adjustment and other operating expenses, as reflected in the table below.

	Three Months Ended March 31,
	2021		2020
Reconciliation of total company operating loss to adjusted operating income (loss)
Total company operating loss	$	(666)	$	(2,277)
Adjustments:
Other operating expenses	38		2
LCM inventory valuation adjustment (see note (b))	—		2,542
Adjusted operating income (loss)	$	(628)	$	267

(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.

LIQUIDITY AND CAPITAL RESOURCES

Overview

During the first quarter of 2021, our liquidity was negatively impacted by the ongoing impacts of the COVID-19 pandemic and the negative effects arising out of Winter Storm Uri on energy costs at certain of our refineries and ethanol plants during mid-February 2021, as described in “OVERVIEW AND OUTLOOK—Overview—Business Operations Update.” The actions that we took throughout 2020, and have continued to take in 2021, to respond to the impacts from the pandemic on our business improved our liquidity position. Among the actions taken were the deferral of certain capital investments, the deferral of certain income and indirect tax payments, and the suspension of share repurchases. See discussion of these deferrals and the suspension of share repurchases and their impact on our liquidity in 2021 within the discussion of matters impacting our liquidity and capital resources below.

In March 2021, DGD entered into the DGD Revolver, as described in Note 4 of Condensed Notes to Consolidated Financial Statements, to be used for general corporate purposes. As of March 31, 2021 and April 29, 2021, DGD had no outstanding borrowings under this facility.

We believe that we have sufficient funds from operations and from borrowings under our credit facilities to fund our ongoing operating requirements and other commitments. 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.

On April 19, 2021, we sold a 24.99 percent membership interest in MVP for $270 million, as described in Note 6 of Condensed Notes to Consolidated Financial Statements. We retained a 25.01 percent interest in MVP.

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Our Liquidity

Our liquidity consisted of the following as of March 31, 2021 (in millions):

Available borrowing capacity from committed facilities(a):
Valero Revolver	$	3,882
364-day Revolving Credit Facility(b)	875
Canadian Revolver(c)	116
Accounts receivable sales facility	1,000
Letter of credit facility	50
Total available borrowing capacity	5,923
Cash and cash equivalents(d)	2,044
Total liquidity	$	7,967

________________________

(a)Excludes the committed facilities of our VIEs.

(b)The 364-day Revolving Credit Facility matured on April 12, 2021 and was not renewed.

(c)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, 2021 in Canadian dollars was C$145 million.

(d)Excludes $210 million of cash and cash equivalents related to our VIEs that is available for use only by our VIEs.

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.

Cash Flows

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

	Three Months Ended March 31,
	2021		2020
Cash flows provided by (used in):
Operating activities	$	(52)	$	(49)
Investing activities	(580)		(757)
Financing activities:
Borrowings	8		370
Other financing activities	(447)		(565)
Financing activities	(439)		(195)
Effect of foreign exchange rate changes on cash	12		(67)
Net decrease in cash and cash equivalents	$	(1,059)	$	(1,068)

Cash Flows for the Three Months Ended March 31, 2021

In the first quarter of 2021, we used $1.1 billion of our cash on hand to fund our operations by $52 million, make $580 million of investments in our business, and fund $447 million of other financing activities.

Our operations typically generate positive net cash flows; however, in the first quarter of 2021, we used $52 million of cash to fund our operations that was largely driven by a significant increase in energy costs at certain of our refineries and ethanol plants due to effects arising out of Winter Storm Uri, as described

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in “OVERVIEW AND OUTLOOK—Overview—Business Operations Update,” partially offset by noncash charges to income of $339 million, and a positive change in working capital of $184 million. Noncash charges included $578 million of depreciation and amortization expense, partially offset by a $239 million deferred income tax benefit. Details regarding the components of the change in working capital, along with the reasons for the changes in those components, are described in Note 11 of Condensed Notes to Consolidated Financial Statements. In addition, see “RESULTS OF OPERATIONS” for an analysis of our net loss.

Our investing activities of $580 million consisted of $582 million in capital investments, as defined below, of which $154 million related to self-funded capital investments by DGD, and $26 million was related to capital expenditures of VIEs other than DGD.

Other financing activities of $447 million consisted primarily of $400 million in dividend payments, $31 million of payments of debt and finance lease obligations, and $14 million for the purchase of common stock for treasury in connection with stock-based compensation plans.

Cash Flows for the Three Months Ended March 31, 2020

In the first quarter of 2020, we used $1.1 billion of cash on hand and $370 million in borrowings to fund our operations by $49 million, make $757 million of investments in our business, and fund $565 million of other financing activities. The borrowings are described in Note 4 of Condensed Notes to Consolidated Financial Statements.

Our operations typically generate positive net cash flows; however, in the first quarter of 2020, we used $49 million of cash to fund our operations due primarily to a negative change in working capital of $1.1 billion. While we incurred a net loss of $1.8 billion in the first quarter of 2020, that net loss was driven by $3.0 billion of noncash charges consisting of $582 million of depreciation and amortization expense and the $2.5 billion LCM inventory valuation adjustment. The negative change in working capital was largely the result of rapidly falling market prices for the products that we sell. Cash generated by our product sales is typically greater than the cash we use to pay for crude oil and other feedstocks that we process and other costs that we incur. However, because daily product sales follow the market prices on that day, rapid increases or decreases in product market prices can significantly impact our working capital positively or negatively, respectively. Market prices declined rapidly in the latter half of March 2020 and this rapid decline resulted in a significant use of cash to pay for our crude oil and other feedstock purchases that were purchased earlier in the quarter before market prices for those feedstocks declined. Details regarding the components of the change in working capital, along with the reasons for the changes in those components, are described in Note 11 of Condensed Notes to Consolidated Financial Statements. In addition, see “RESULTS OF OPERATIONS” for an analysis of our net loss.

Our investing activities of $757 million consisted of $767 million in capital investments, as defined below, of which $78 million related to self-funded capital investments by DGD, and $62 million was related to capital expenditures of VIEs other than DGD.

Other financing activities of $565 million consisted primarily of $401 million in dividend payments, $147 million for the purchase of common stock for treasury, and $15 million of payments of debt and finance lease obligations.

Capital Investments

Our capital investments include capital expenditures, deferred turnaround and catalyst cost expenditures, and investments in unconsolidated joint ventures. Capital investments attributable to Valero, which is a

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non-GAAP financial measure, reflects our net share of capital investments and is defined as all capital expenditures, deferred turnaround and catalyst cost expenditures, and investments in unconsolidated joint ventures presented in our consolidated statements of cash flows, excluding the portion of DGD’s capital investments attributable to our joint venture partner and all of the capital expenditures of other VIEs.

We are a 50/50 joint venture partner in DGD and consolidate DGD’s 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 partners 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 partner, only 50 percent of DGD’s capital investments should be attributed to our net share of capital investments. We also exclude the capital expenditures of our other consolidated VIEs because we do not operate those VIEs. 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, its most comparable U.S. GAAP measure, nor should it be considered in isolation or as a substitute for an analysis of our cash flows as reported under U.S. 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,
	2021		2020
Reconciliation of capital investments to capital investments attributable to Valero
Capital expenditures (excluding VIEs)	$	160	$	299
Capital expenditures of VIEs:
DGD	153		74
Other VIEs	26		62
Deferred turnaround and catalyst cost expenditures (excluding VIEs)	230		309
Deferred turnaround and catalyst cost expenditures of DGD	1		4
Investments in unconsolidated joint ventures	12		19
Capital investments	582		767
Adjustments:
DGD’s capital investments attributable to our joint venture partner	(77)		(39)
Capital expenditures of other VIEs	(26)		(62)
Capital investments attributable to Valero	$	479	$	666

As previously disclosed in our annual report on Form 10-K for the year ended December 31, 2020, we expect to incur $2.0 billion for capital investments attributable to Valero during 2021. Approximately 60 percent of the capital investments attributable to Valero are for sustaining the business and 40 percent are for growth strategies, over half of which is allocated to expanding the renewable diesel business. However, we continuously evaluate our capital budget and make changes as conditions warrant. The

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capital investment estimate for 2021 includes $200 million of the approximately $500 million of capital investments that were deferred in 2020 and excludes strategic acquisitions, if any.

Other Matters Impacting Liquidity and Capital Resources

Stock Purchase Program

As of March 31, 2021, we had $1.4 billion available for purchase under our stock purchase program, which has no expiration date. We have not purchased any shares of our common stock under our stock purchase program since mid-March 2020, and we will evaluate the timing of repurchases when appropriate. We have no obligation to make purchases under this program.

Pension Plan Funding

As previously disclosed in our annual report on Form 10-K for the year ended December 31, 2020, we plan to contribute approximately $128 million to our pension plans and $22 million to our other postretirement benefit plans during 2021.

Environmental Matters

Our operations are subject to extensive environmental regulations by governmental authorities relating to the discharge of materials into the environment, waste management, pollution prevention measures, GHG emissions, and characteristics and composition of gasolines and distillates. 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 expenditures required for environmental matters could increase in the future. In addition, any major upgrades in any of our refineries or plants could require material additional expenditures to comply with environmental laws and regulations.

Tax Matters

Under deferrals provided by recently passed legislation, such as the CARES Act in the U.S. and by various taxing authorities under other existing legislation, we deferred approximately $250 million of income and indirect (e.g., VAT and motor fuel taxes) tax payments that were due in 2020. Of this amount, approximately 90 percent will be paid in 2021 and 10 percent in 2022. No deferred payments were made in the first quarter of 2021.

Cash Held by Our International Subsidiaries

As of March 31, 2021, $1.3 billion of our cash and cash equivalents was held by our international subsidiaries. Cash held by our international subsidiaries can be repatriated to us without any U.S. federal income tax consequences, but certain other taxes may apply, including, but not limited to, withholding taxes imposed by certain international jurisdictions and U.S. state income taxes. Therefore, there is a cost to repatriate cash held by certain of our international subsidiaries to us, but we believe that such amount is not material to our financial position or liquidity.

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 the COVID-19 pandemic and volatility in the global 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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Contractual Obligations

As of March 31, 2021, our contractual obligations included debt, finance lease obligations, operating lease obligations, purchase obligations, and other long-term liabilities. In the ordinary course of business, we had debt-related activities during the three months ended March 31, 2021, 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, 2021.

CRITICAL ACCOUNTING ESTIMATES

The preparation of financial statements in conformity with U.S. 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. As of March 31, 2021, there were no significant changes to our critical accounting estimates since the date our annual report on Form 10-K for the year ended December 31, 2020 was filed.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

COMMODITY PRICE RISK

We are exposed to market risks related to the volatility in the price of feedstocks (primarily crude oil and corn), the products we produce (primarily refined petroleum products), 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, including futures and options to manage the volatility of:

•inventories and firm commitments to purchase inventories generally for amounts by which our current year inventory levels (determined on a LIFO basis) differ from our previous year-end LIFO inventory levels; and

•forecasted purchases and/or product sales in order to lock-in such forecasted transactions at existing market prices that we deem favorable.

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 of directors.

As of March 31, 2021 and December 31, 2020, the amount of gain or loss that would have resulted from a 10 percent increase or decrease in the underlying price for all of our commodity derivative instruments entered into for purposes other than trading with which we have market risk was not material. See Note 13 of Condensed Notes to Consolidated Financial Statements for notional volumes associated with these derivative contracts as of March 31, 2021.

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COMPLIANCE PROGRAM PRICE RISK

We are exposed to market risk related to the volatility in the price of credits needed to comply with various governmental and regulatory environmental compliance programs. To manage this risk, we enter into contracts to purchase these credits when prices are deemed favorable. As of March 31, 2021 and December 31, 2020, the amount of gain or loss in the fair value of derivative instruments that would have resulted from a 10 percent increase or decrease in the underlying price of the contracts was not material. See Note 13 of Condensed Notes to Consolidated Financial Statements for a discussion about these compliance programs.

INTEREST RATE RISK

The following table provides information about our debt instruments (dollars in millions), the fair values of which are sensitive to changes in interest rates. 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, 2021 (a)
	Expected Maturity Dates
	Remainder of 2021 (b)			2022			2023			2024			2025			There- after			Total			Fair Value
Fixed rate	$	—		$	—		$	850		$	925		$	1,650		$	8,474		$	11,899		$	13,565
Average interest rate	—		%	—		%	2.7		%	1.2		%	3.1		%	5.1		%	4.4		%
Floating rate (c)	$	610		$	6		$	595		$	—		$	—		$	—		$	1,211		$	1,211
Average interest rate	3.9		%	3.9		%	1.4		%	—		%	—		%	—		%	2.7		%
	December 31, 2020 (a)
	Expected Maturity Dates
	2021 (b)			2022			2023			2024			2025			There- after			Total			Fair Value
Fixed rate	$	—		$	—		$	850		$	925		$	1,650		$	8,474		$	11,899		$	13,899
Average interest rate	—		%	—		%	2.7		%	1.2		%	3.1		%	5.1		%	4.4		%
Floating rate (c)	$	603		$	6		$	595		$	—		$	—		$	—		$	1,204		$	1,204
Average interest rate	3.9		%	3.0		%	1.4		%	—		%	—		%	—		%	2.7		%

________________________

(a)Excludes unamortized discounts and debt issuance costs.

(b)As of March 31, 2021 and December 31, 2020, our floating rate debt includes $606 million and $598 million, respectively, associated with borrowings under the IEnova Revolver for the construction of terminals in Mexico by Central Mexico Terminals. The IEnova Revolver is only available to the operations of Central Mexico Terminals, and its creditors do not have recourse against us.

(c)As of March 31, 2021 and December 31, 2020, we had an interest rate swap associated with $30 million and $31 million, respectively, of our floating rate debt resulting in an effective interest rate of 3.85 percent as of each of those reporting dates. The fair value of the swap was immaterial for all periods presented.

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FOREIGN CURRENCY RISK

We are exposed to exchange rate fluctuations on transactions related to our international operations that are denominated in currencies other than the local (functional) currencies of those operations. To manage our exposure to these exchange rate fluctuations, we use foreign currency contracts. The following table provides information about our foreign currency contracts (dollars in millions) that, as of the dates set forth below, mature in 2021, the fair values of which are sensitive to changes in foreign currency exchange rates. Currency abbreviations presented below are as follows: U.S. dollars (USD), Canadian dollars (CAD), and pounds sterling (GBP).

	Receive USD/ Pay CAD		Receive USD/ Pay GBP		Receive CAD/ Pay USD
March 31, 2021
Contract amount	$	160	$	85	$	2,800
Weighted-average contractual exchange rate	0.79625		1.37805		0.79271
Fair value asset	$	—	$	—	$	10
December 31, 2020
Contract amount	$	228	$	97	$	1,600
Weighted-average contractual exchange rate	0.78205		1.34454		0.78492
Fair value liability	$	(1)	$	(1)	$	(2)

See Note 13 of Condensed Notes to Consolidated Financial Statements for a discussion about our foreign currency risk management activities.

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, 2021.

(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.

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PART II – OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

The information below describes new proceedings or material developments in proceedings that we previously reported in our annual report on Form 10-K for the year ended December 31, 2020.

Environmental Enforcement Matters

While it is not possible to predict the outcome of the following environmental proceedings, if any one or more of them were decided against us, we believe that there would be no material effect on our financial position, results of operations, or liquidity. We are reporting these proceedings to comply with U.S. Securities and Exchange Commission (SEC) regulations, which require us to disclose certain information about proceedings arising under federal, state, or local provisions regulating the discharge of materials into the environment or protecting the environment if we reasonably believe that such proceedings may result in monetary sanctions of $300,000 or more.

U.S. EPA (Benicia Refinery). On December 11, 2020, our Benicia Refinery received a Notice of Potential Violation and Opportunity to Confer from the U.S. EPA, without penalty demand, related to a series of inspections the U.S. EPA Region 9 conducted in 2019 to determine the refinery’s compliance with various federal environmental laws. We are working with the U.S. EPA to resolve this matter, which we reasonably believe may result in penalties that are in excess of $300,000.

Bay Area Air Quality Management District (BAAQMD) (Benicia Refinery). On March 21, 2019, we received a Notice of Violation (VN) from the BAAQMD related to atmospheric emissions of hydrogen commingled with non-methane organic compounds at our Benicia Refinery. We are working with the BAAQMD to resolve the VN and related compliance issues, which we now reasonably believe may result in penalties that are in excess of $300,000.

ITEM 1A. RISK FACTORS

There have been no changes from the risk factors disclosed in our annual report on Form 10-K for the year December 31, 2020. However, to the extent the COVID-19 pandemic adversely affects our business, financial condition, results of operation, and liquidity, it may also have the effect of heightening many of the other risks described in such risk factors.

52

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

(a)Unregistered Sales of Equity Securities. Not applicable.

(b)Use of Proceeds. Not applicable.

(c)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 2021.

Period	Total Number of Shares Purchased	Average Price Paid per Share		Total Number of Shares Not Purchased as Part of Publicly Announced Plans or Programs (a)	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 2021	129,304	$	59.36	129,304	—	$1.4 billion
February 2021	82,040	$	74.06	82,040	—	$1.4 billion
March 2021	9,644	$	75.21	9,644	—	$1.4 billion
Total	220,988	$	65.51	220,988	—	$1.4 billion

________________________

(a)The shares reported in this column represent purchases settled in the first quarter of 2021 relating to (i) our purchases of shares in open-market transactions to meet our obligations under stock-based compensation plans and (ii) 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 January 23, 2018, we announced that our board of directors authorized our purchase of up to $2.5 billion of our outstanding common stock (the 2018 Program), with no expiration date. As of March 31, 2021, we had $1.4 billion remaining available for purchase under the 2018 Program. We have not purchased any shares of our common stock under the 2018 Program since mid-March 2020, and we will evaluate the timing of repurchases when appropriate. We have no obligation to make purchases under the 2018 Program.

53

ITEM 6. EXHIBITS

Exhibit No.	Description
*+10.01	Form of Amended and Restated Performance Share Agreement (2020 grant–second and third tranches).
*+10.02	Form of Performance Share Agreement (2021 grant).
*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 U.S. SEC all constituent agreements defining the rights of holders of our long-term debt not filed herewith.

54

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 30, 2021

55

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 2011 Omnibus Stock Incentive Plan (as may be amended, the “Plan”), is entered into pursuant to and subject to the provisions of the Plan, and amends and restates that certain Performance Share Agreement between Valero and Participant dated as of February 26, 2020, to amend and restate the terms and conditions of the award of Performance Shares granted to Participant as of February 26, 2020.

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 2021, and the second and third increments vesting on the Committee’s meeting dates in January 2022 and January 2023, 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 Objectives 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 Objectives 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 2021) shall be the calendar year ending on December 31, 2020.

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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 2022) shall be the two calendar years ending December 31, 2021.

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

4.Performance Objectives. On each Normal Vesting Date, Valero’s performance will be measured against: (A) Valero’s total shareholder return (“TSR”) compared to its peers; and (B) Valero’s Return on Invested Capital (“ROIC”) versus a target. On the vesting date for each tranche of the Performance Shares, 75% of the target award will be assessed against the relative TSR performance measure, and 25% will be assessed against the ROIC performance measure. The total number of shares of Common Stock that may be issued for each vesting tranche will be determined by combining the number of earned shares from each metric as determined through each metric’s unique performance criteria.

Following, the determination of Valero’s performance with respect to the TSR and ROIC metrics described herein, the payout percentage determined therefrom will be subject to an increase or decrease based on Valero’s performance against the Energy Transition measures described in Section 4.C. below.

A.Total Shareholder Return (TSR) – 75% weighting.

(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. Subject to the provisions of the Plan and this Agreement, on such Normal Vesting Date, 75% of the vesting Performance Shares will be awarded as shares of Common Stock to the Participant per the payout

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percentages 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.Return on Invested Capital (ROIC) – 25% weighting. For the ROIC metric, Valero’s trailing three-year average ROIC will be determined at the end of each Performance Period. 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. Subject to the provisions of the Plan and this Agreement, on such Normal Vesting Date, 25% of the vesting Performance Shares will be awarded as shares of Common Stock to the Participant per the payout percentages listed below based on Valero’s achievement of a three-year average ROIC per the following (straight-line interpolation will be used to determine shares for ROIC performance between the defined payout levels). The Target will be approved annually by the Committee.

	Payout
Maximum	200.0%
	150.0%
Target	100.0%
	50.0%
	0.0%

C.Energy Transition performance measure. After Valero’s TSR and ROIC performance has been determined, the resulting payout of shares of Common Stock will be subject to an increase or decrease of 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 absolute reduction/offset target, and (2) the percentage of Valero’s growth capital expenditures deployed for low-carbon initiatives versus an annual 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, the aggregate payout percentage for the Performance Period will be

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increased by 25 percentage points (e.g., a 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 the aggregate payout percentage for the Performance Period will be reduced by 25 percentage points (e.g., a 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 aggregate performance score.

D.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 80th percentile earning a 175% payout.

•ROIC performance at Target earning a 100% payout.

•Energy Transition performance meets each metric’s target, thus earning an additional 25 percentage points.

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

	perf sh				common sh
Maximum	12,000			200%	24,000
TSR	12,000	75%	9,000	175%	15,750
ROIC	12,000	25%	3,000	100%	3,000
Energy Transition	12,000			25%	3,000
Total shares of Common Stock					21,750

E.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 the TDEV times the aggregate payout percentage applicable to all performance metrics for the Performance Period; 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.

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

•7,460 Performance Shares granted on February 26, 2020,

•Participant retires at age 60+ effective July 31, 2020,

•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 3,730 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) Valero’s ROIC percentage, 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.

Page 5

(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 against the TSR and ROIC metrics for the two-year performance period ending December 31, 2021, it is determined that the Participant is entitled to receive 8,000 shares of Common Stock on the Normal Vesting Date occurring in January 2022 (the “2022 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 2022 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 2022 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 2022 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.

Page 6

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;

(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.

Amended and restated effective as of February 23, 2021.

VALERO ENERGY CORPORATION

by:	/s/ Julia R. 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 26, 2020.

2.Assume the Normal Vesting Date for the second segment of these Performance Shares is January 22, 2022. On that date 12,000 Performance Shares (36,000 / 3 = 12,000) vest with respect to the two-year Performance Period ending December 31, 2021.

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 performance scores for the Performance Period are the following:

	perf sh				common sh
TSR	12,000	75%	9,000	175%	15,750
ROIC	12,000	25%	3,000	100%	3,000
Energy Transition	12,000			25%	3,000
Total shares of Common Stock					21,750
effective payout rate					181.25%

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

7.Based on the foregoing, the total number of shares of Common Stock earned by the Participant for the Dividend Equivalent Award is 2,181 shares (rounded up from 2,180.8). The calculation is illustrated below as (1) divided by (2), where:

(1) is $163,560, calculated as $90,240 (TDEV) times 181.25% (effective payout rate); 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 26, 2020.

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 (Second Segment, Third Segment (See Section 3)) are shortened to end on June 30, 2021.

4.The first tranche of Performance Shares (12,000) vested on Jan. 26, 2021, resulting in 24,000 Performance Shares subject to vesting during the shortened Performance Periods.

5.Valero’s effective aggregate payout rate for all metrics for each shortened Performance Period is 150%.

6.Assume the cumulative amount of dividends paid to holders of Common Stock during the 18-month shortened Performance Period is $5.88 per share. Therefore, the “Target Dividend Equivalent Value” (“TDEV”) is $141,120 (24,000 Performance Shares vesting, multiplied by $5.88 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 (DEA) is 2,823 shares (rounded up from 2,822.4). The calculation is illustrated below as (1) divided by (2), where:

(1) is $211,680, calculated as $141,120 (TDEV) times 150%; 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.

n/a, as first tranche vested on Jan. 26, 2021.

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 150% payout = 18,000 common shares

Prorate for 18 months of service in the 24-month Performance Period.

18,000 common shares x 18/24 = 13,500  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 150% payout = 18,000 common shares

Prorate for 18 months of service in the 36-month Performance Period.

18,000 common shares x 18/36 =	9,000	common shares
Add DEA shares	2,823	common shares
Total	25,323	common shares

Exhibit B

EX-10.02

Exhibit 10.02

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, 2021.

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 Objectives 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 Objectives 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.

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.

Page 1

4.Performance Objectives. 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 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%

Page 2

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 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 absolute reduction/offset target, and (2) the percentage of Valero’s growth capital expenditures deployed for low-carbon initiatives versus an annual 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.

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).

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.

Page 3

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 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, 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 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

Page 4

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.

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

Page 5

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;

(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.

Page 6

Executed effective as of the date first written above.

VALERO ENERGY CORPORATION

by:	/s/ Julia R. 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-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 30, 2021

/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 30, 2021

/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, 2021, 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 30, 2021

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, 2021, 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 30, 2021

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, 2021	Apr. 23, 2021
Cover [Abstract]
Document type	10-Q
Document quarterly report	true
Document period end date	Mar. 31, 2021
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
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		408,760,165
Entity central index key	0001035002
Amendment flag	false
Document fiscal year focus	2021
Document fiscal period focus	Q1
Current fiscal year end date	--12-31

XML

Consolidated Balance Sheets - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Current assets:
Cash and cash equivalents	$ 2,254	$ 3,313
Receivables, net	9,014	6,109
Inventories	5,881	6,038
Prepaid expenses and other	442	384
Total current assets	17,591	15,844
Property, plant, and equipment, at cost	47,370	46,967
Accumulated depreciation	(16,991)	(16,578)
Property, plant, and equipment, net	30,379	30,389
Deferred charges and other assets, net	5,644	5,541
Total assets	53,614	51,774
Current liabilities:
Current portion of debt and finance lease obligations	734	723
Accounts payable	9,113	6,082
Accrued expenses	1,087	994
Taxes other than income taxes payable	1,233	1,372
Income taxes payable	140	112
Total current liabilities	12,307	9,283
Debt and finance lease obligations, less current portion	13,930	13,954
Deferred income tax liabilities	5,034	5,275
Other long-term liabilities	3,616	3,620
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	6,810	6,814
Treasury stock, at cost; 264,741,072 and 265,096,171 common shares	(15,700)	(15,719)
Retained earnings	27,849	28,953
Accumulated other comprehensive loss	(1,165)	(1,254)
Total Valero Energy Corporation stockholders’ equity	17,801	18,801
Noncontrolling interests	926	841
Total equity	18,727	19,642
Total liabilities and equity	$ 53,614	$ 51,774

XML

Consolidated Balance Sheets (Parenthetical) - $ / shares	Mar. 31, 2021	Dec. 31, 2020
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	264,741,072	265,096,171

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Consolidated Statements of Income (unaudited) - USD ($) shares in Millions, $ in Millions		3 Months Ended
		Mar. 31, 2021	Mar. 31, 2020
Revenues	[1]	$ 20,806	$ 22,102
Cost of sales:
Cost of materials and other		18,992	19,952
Lower of cost or market (LCM) inventory valuation adjustment		0	2,542
Operating expenses (excluding depreciation and amortization expense reflected below)		1,656	1,124
Depreciation and amortization expense		566	569
Total cost of sales		21,214	24,187
Other operating expenses		38	2
General and administrative expenses (excluding depreciation and amortization expense reflected below)		208	177
Depreciation and amortization expense		12	13
Operating loss		(666)	(2,277)
Other income, net		45	32
Interest and debt expense, net of capitalized interest		(149)	(125)
Loss before income tax benefit		(770)	(2,370)
Income tax benefit		(148)	(616)
Net loss		(622)	(1,754)
Less: Net income attributable to noncontrolling interests		82	97
Net loss attributable to Valero Energy Corporation stockholders		$ (704)	$ (1,851)
Loss per common share (in dollars per share)		$ (1.73)	$ (4.54)
Weighted-average common shares outstanding (in shares)		407	408
Loss per common share – assuming dilution (in dollars per share)		$ (1.73)	$ (4.54)
Weighted-average common shares outstanding – assuming dilution (in shares)		407	408
Supplemental information:
Includes excise taxes on sales by certain of our international operations		$ 1,120	$ 1,368

[1] Includes excise taxes on sales by certain of our international operations of $1,120 million and $1,368 million for the three months ended March 31, 2021 and 2020, respectively.

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Consolidated Statements of Comprehensive Income (unaudited) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Net loss	$ (622)	$ (1,754)
Other comprehensive income (loss):
Foreign currency translation adjustment	76	(607)
Net gain on pension and other postretirement benefits	15	12
Net gain on cash flow hedges	10	29
Other comprehensive income (loss) before income tax expense	101	(566)
Income tax expense related to items of other comprehensive income (loss)	7	6
Other comprehensive income (loss)	94	(572)
Comprehensive loss	(528)	(2,326)
Less: Comprehensive income attributable to noncontrolling interests	87	111
Comprehensive loss attributable to Valero Energy Corporation stockholders	$ (615)	$ (2,437)

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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, 2019	$ 22,536	$ 21,803	$ 7	$ 6,821	$ (15,648)	$ 31,974	$ (1,351)	$ 733
Increase (Decrease) in Stockholders' Equity Roll Forward
Net loss	(1,754)	(1,851)				(1,851)		97
Dividends on common stock	(401)	(401)				(401)
Stock-based compensation expense	24	24		24
Transactions in connection with stock-based compensation plans	(17)	(17)		(31)	14
Open market stock purchases	(130)	(130)			(130)
Distributions to noncontrolling interests	(1)							(1)
Other comprehensive income (loss)	(572)	(586)					(586)	14
Balance as of end of period at Mar. 31, 2020	19,685	18,842	7	6,814	(15,764)	29,722	(1,937)	843
Balance as of beginning of period at Dec. 31, 2020	19,642	18,801	7	6,814	(15,719)	28,953	(1,254)	841
Increase (Decrease) in Stockholders' Equity Roll Forward
Net loss	(622)	(704)				(704)		82
Dividends on common stock	(400)	(400)				(400)
Stock-based compensation expense	28	28		28
Transactions in connection with stock-based compensation plans	(13)	(13)		(32)	19
Distributions to noncontrolling interests	(2)							(2)
Other comprehensive income (loss)	94	89					89	5
Balance as of end of period at Mar. 31, 2021	$ 18,727	$ 17,801	$ 7	$ 6,810	$ (15,700)	$ 27,849	$ (1,165)	$ 926

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Consolidated Statements of Equity (unaudited) (Parenthetical) - $ / shares	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Common stock dividends:
Dividends on common stock (in dollars per share)	$ 0.98	$ 0.98

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Consolidated Statements of Cash Flows (unaudited) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Cash flows from operating activities:
Net loss	$ (622)	$ (1,754)
Adjustments to reconcile net loss to net cash used in operating activities:
Depreciation and amortization expense	578	582
LCM inventory valuation adjustment	0	2,542
Deferred income tax benefit	(239)	(162)
Changes in current assets and current liabilities	184	(1,107)
Changes in deferred charges and credits and other operating activities, net	47	(150)
Net cash used in operating activities	(52)	(49)
Cash flows from investing activities:
Investments in unconsolidated joint ventures	(12)	(19)
Other investing activities, net	2	10
Net cash used in investing activities	(580)	(757)
Cash flows from financing activities:
Purchases of common stock for treasury	(14)	(147)
Common stock dividend payments	(400)	(401)
Other financing activities, net	(1)	(1)
Net cash used in financing activities	(439)	(195)
Effect of foreign exchange rate changes on cash	12	(67)
Net decrease in cash and cash equivalents	(1,059)	(1,068)
Cash and cash equivalents at beginning of period	3,313	2,583
Cash and cash equivalents at end of period	2,254	1,515
Excluding Variable Interest Entities (VIEs) [Member]
Cash flows from investing activities:
Capital expenditures	(160)	(299)
Deferred turnaround and catalyst cost expenditures	(230)	(309)
Cash flows from financing activities:
Proceeds from debt issuances and borrowings	0	300
Repayments of debt and finance lease obligations	(31)	(15)
Variable Interest Entities (VIEs) [Member]
Cash flows from financing activities:
Proceeds from debt issuances and borrowings	8	70
Repayments of debt and finance lease obligations	(1)	(1)
Diamond Green Diesel Holdings LLC (DGD) [Member]
Cash flows from investing activities:
Capital expenditures	(153)	(74)
Deferred turnaround and catalyst cost expenditures	(1)	(4)
Other VIEs [Member]
Cash flows from investing activities:
Capital expenditures	$ (26)	$ (62)

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Basis of Presentation and Significant Accounting Policies

3 Months Ended

Mar. 31, 2021

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.

These unaudited financial statements have been prepared in accordance 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 U.S. GAAP for complete financial statements. In the opinion of management, all adjustments considered necessary for a fair presentation of our results for the three months ended March 31, 2021 have been included. All such adjustments are of a normal recurring nature unless disclosed otherwise. Operating results for the three months ended March 31, 2021 are not necessarily indicative of the results that may be expected for the year ending December 31, 2021. The financial statements presented herein should be read in conjunction with the financial statements included in our annual report on Form 10-K for the year ended December 31, 2020.

As discussed in Note 2, the outbreak of COVID-19 and its development into a pandemic in March 2020 resulted in significant economic disruption globally. Developments with respect to COVID-19 have been occurring at a rapid pace and the risk remains that circumstances could change. Demand for and market prices of most of our products began to improve during the latter half of 2020 and continued to improve throughout the first quarter of 2021. These improvements resulted primarily from the lifting or easing of restrictions by many governmental authorities, especially those in our U.S. Gulf Coast and U.S. Mid-Continent regions, in response to decreasing COVID-19 infection rates and increasing numbers of people receiving COVID-19 vaccines, which were approved by a number of regulators throughout the world in late 2020 and early 2021. While many governmental authorities in areas located in our U.S. West Coast and North Atlantic regions, such as California, Canada, and the United Kingdom (U.K.), continue to impose restrictions, some of these restrictions have been or are soon expected to be moderately lifted. The ongoing distribution of vaccines may result in the continued lifting of restrictions and may be seen as a key factor in helping to restore public confidence, and thus stimulate and increase economic activity, potentially to pre-pandemic levels; however, the risk remains that the vaccines may not be distributed widely on a timely basis, they may not be effective against new variants of the COVID-19 virus, the distribution of some or all of the vaccines may be paused or withdrawn due to concerns with potential side effects, and/or the level of individuals’ willingness to receive a vaccine may not be as strong or as timely as needed. Based on these and other circumstances that cannot be predicted, the broader implications of the pandemic on our results of operations and financial position remain uncertain.

The balance sheet as of December 31, 2020 has been derived from our audited financial statements as of that date. For further information, refer to our financial statements and notes thereto included in our annual report on Form 10-K for the year ended December 31, 2020.

Reclassifications

Certain prior year amounts presented in Note 11 have been reclassified to conform to the 2021 presentation. The change was due to the reclassification of amounts for income taxes receivable from prepaid expenses and other to “receivables, net.”

Significant Accounting Policies

Use of Estimates

The preparation of financial statements in conformity with U.S. GAAP requires us to make estimates and assumptions that affect the amounts reported in the 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.

Adoption of Accounting Pronouncement

The following Financial Accounting Standards Board (FASB) Accounting Standards Update (ASU) was issued and adopted by us on January 7, 2021. Our adoption of this ASU did not have a material impact on our financial statements or related disclosures.

ASU		Basis of Adoption
2021-01	Reference Rate Reform (Topic 848): Scope	Prospectively

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Uncertainties

3 Months Ended

Mar. 31, 2021

Unusual or Infrequent Items, or Both [Abstract]

UNCERTAINTIES (COVID-19)

2.    UNCERTAINTIES

The outbreak of COVID-19 and its development into a pandemic in March 2020 resulted in significant economic disruption globally as governmental authorities imposed restrictions, such as stay-at-home orders and other social distancing measures, to slow the spread of COVID-19. These actions significantly reduced global economic activity and negatively impacted many businesses, including our business. We took a number of actions since March 2020 to respond to the impacts from the pandemic on our business, such as reducing transportation fuel production at our refineries and ethanol plants to align with demand. During the three months ended March 31, 2021, our business showed signs of recovery and improvement in demand for and market prices of gasoline and diesel, with both factors reaching near pre-pandemic levels in March 2021. Also, jet fuel has seen improved market indicators, although at a slower pace than other products we produce relative to pre-pandemic levels.

While our business has improved as a result of the increasing demand for and market prices of most of the products that we produce, many uncertainties remain with respect to the pandemic, including its resulting economic effects. Therefore, we are unable to predict the ultimate economic impacts from the pandemic on our business and how quickly national economies can recover once the pandemic subsides, the timing or effectiveness of vaccine distributions or vaccination levels, whether improvements experienced by us so far may reverse, or whether other setbacks may occur. As a result, the adverse impacts of the economic effects of the pandemic on our company may likely continue to be significant. We believe we have proactively responded to many of the known impacts of the COVID-19 pandemic on our business to the extent practicable and we strive to continue to do so, but there can be no assurance that any measures we have taken or may take will be fully effective.

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Inventories

3 Months Ended

Mar. 31, 2021

Inventory Disclosure [Abstract]

INVENTORIES

3.    INVENTORIES

Inventories consisted of the following (in millions):

	March 31, 2021		December 31, 2020
Refinery feedstocks	$	1,947	$	1,979
Refined petroleum products and blendstocks	3,284		3,425
Renewable diesel feedstocks and products	64		50
Ethanol feedstocks and products	297		297
Materials and supplies	289		287
Inventories	$	5,881	$	6,038

We compare the market value of inventories to their cost on an aggregate basis, excluding materials and supplies. In determining the market value of our inventories, we assume that feedstocks are converted into refined products, which requires us to make estimates regarding the refined products expected to be produced from those feedstocks and the conversion costs required to convert those feedstocks into refined products. We also estimate the usual and customary transportation costs required to move the inventory from our plants to the appropriate points of sale. We then apply an estimated selling price to our inventories. If the aggregate market value is less than the aggregate cost, we recognize a loss for the difference in our statements of income. To the extent the aggregate market value of our last-in, first-out (LIFO) inventories subsequently increases, we recognize an increase to the value of our inventories (not to exceed cost) and a gain in our statements of income.

The market value of our LIFO inventories fell below their LIFO inventory carrying amounts as of March 31, 2020, and as a result, we recorded an LCM inventory valuation reserve of $2.5 billion in order to state our inventories at market. As of March 31, 2021 and December 31, 2020, the replacement cost (market value) of LIFO inventories exceeded their LIFO carrying amounts by $2.7 billion and $1.3 billion, respectively.

Our non-LIFO inventories accounted for $1.2 billion and $918 million of our total inventories as of March 31, 2021 and December 31, 2020, respectively.

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Debt

3 Months Ended

Mar. 31, 2021

Debt Disclosure [Abstract]

DEBT

4.    DEBT

Public Debt

During the three months ended March 31, 2021 and 2020, there was no issuance or redemption activity related to our public debt.

Credit Facilities

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, 2021
	Facility Amount		Maturity Date	Outstanding Borrowings		Letters of Credit Issued (a)		Availability
Committed facilities:
Valero Revolver	$	4,000	March 2024	$	—	$	118	$	3,882
364-day Revolving Credit Facility (b)	$	875	April 2021	$	—	n/a		$	875
Canadian Revolver	C$	150	November 2021	C$	—	C$	5	C$	145
Accounts receivable sales facility	$	1,000	July 2021	$	—	n/a		$	1,000
Letter of credit facility	$	50	November 2021	n/a		$	—	$	50
Committed facilities of VIEs (c):
DGD Revolver	$	400	March 2024	$	—	$	—	$	400
IEnova Revolver (d)	$	660	February 2028	$	606	n/a		$	54
Uncommitted facilities:
Letter of credit facilities	n/a		n/a	n/a		$	330	n/a

________________________

(a)Letters of credit issued as of March 31, 2021 expire at various times in 2021 through 2023.

(b)This facility matured on April 12, 2021 and was not renewed.

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

(d)As of March 31, 2021 and December 31, 2020, the variable interest rate on the IEnova Revolver was 3.888 percent and 3.870 percent, respectively.

Activities under our credit facilities were as follows (in millions):

	Three Months Ended March 31,
	2021		2020
Borrowings:
Accounts receivable sales facility	$	—	$	300
IEnova Revolver	8		70

DGD Revolver

In March 2021, DGD (as described in Note 6) entered into a $400 million unsecured revolving credit facility (the DGD Revolver) that matures in March 2024. DGD has the option to increase the aggregate commitments under the DGD Revolver to $550 million, subject to certain restrictions. The DGD Revolver also provides for the issuance of letters of credit of up to $10 million. The DGD Revolver is available only to the operations of DGD, and the creditors of DGD do not have recourse against us.

Outstanding borrowings under the DGD Revolver generally bear interest, at DGD’s option, at either (i) an alternate base rate plus the applicable margin or (ii) an adjusted LIBOR rate for the applicable interest period in effect from time to time plus the applicable margin. The DGD Revolver also requires payments for customary fees, including unused commitment fees, letter of credit fees, and administrative agent fees.

During the three months ended March 31, 2021, there were no borrowings or repayments under the DGD Revolver.

Other Disclosures

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

	Three Months Ended March 31,
	2021		2020
Interest and debt expense	$	164	$	145
Less: Capitalized interest	15		20
Interest and debt expense, net of capitalized interest	$	149	$	125

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Equity

3 Months Ended

Mar. 31, 2021

Equity [Abstract]

EQUITY

5.    EQUITY

Share Activity

There was no significant share activity during the three months ended March 31, 2021 and 2020.

Common Stock Dividends

On April 16, 2021, our board of directors declared a quarterly cash dividend of $0.98 per common share payable on June 8, 2021 to holders of record at the close of business on May 17, 2021.

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,
	2021								2020
	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	$	(515)	$	(737)	$	(2)	$	(1,254)	$	(676)	$	(672)	$	(3)	$	(1,351)
Other comprehensive income (loss) before reclassifications	76		1		(5)		72		(606)		—		21		(585)
Amounts reclassified from accumulated other comprehensive loss	—		8		9		17		—		9		(10)		(1)
Other comprehensive income (loss)	76		9		4		89		(606)		9		11		(586)
Balance as of end of period	$	(439)	$	(728)	$	2	$	(1,165)	$	(1,282)	$	(663)	$	8	$	(1,937)

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Variable Interest Entities

3 Months Ended

Mar. 31, 2021

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, 2021, our significant consolidated VIEs included:

•DGD, a joint venture with a subsidiary of Darling Ingredients Inc., which owns and operates a plant that processes rendered and recycled materials, including animal fats, used cooking oils, and other vegetable oils, into renewable diesel; and

•Central Mexico Terminals, which is a collective group of three subsidiaries of Infraestructura Energetica Nova, S.A.B. de C.V. (IEnova), a Mexican company and 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 our VIEs can only be used to settle their own obligations and the creditors of our VIEs have no recourse to our other assets. We do not provide financial guarantees to our VIEs. Although we have provided credit facilities to some of our 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 our consolidated VIEs, net of intercompany eliminations, to the extent of our ownership interest in each VIE.

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

	March 31, 2021
	DGD		Central Mexico Terminals		Other		Total
Assets
Cash and cash equivalents	$	191	$	—	$	19	$	210
Other current assets	272		10		10		292
Property, plant, and equipment, net	1,431		614		94		2,139
Liabilities
Current liabilities, including current portion of debt and finance lease obligations	$	166	$	632	$	8	$	806
Debt and finance lease obligations, less current portion	1		—		24		25

	December 31, 2020
	DGD		Central Mexico Terminals		Other		Total
Assets
Cash and cash equivalents	$	144	$	1	$	16	$	161
Other current assets	219		24		8		251
Property, plant, and equipment, net	1,232		590		96		1,918
Liabilities
Current liabilities, including current portion of debt and finance lease obligations	$	90	$	620	$	8	$	718
Debt and finance lease obligations, less current portion	1		—		25		26

Non-Consolidated VIEs

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

On April 19, 2021, we sold a 24.99 percent membership interest in MVP Terminalling, LLC (MVP), an unconsolidated joint venture with a subsidiary of Magellan Midstream Partners LP (Magellan), for $270 million. MVP owns and operates a marine terminal located adjacent to the Houston Ship Channel in Pasadena, Texas. We retained a 25.01 percent membership interest in MVP.

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Employee Benefit Plans

3 Months Ended

Mar. 31, 2021

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
	2021		2020		2021		2020
Three months ended March 31
Service cost	$	40	$	35	$	2	$	1
Interest cost	18		21		2		2
Expected return on plan assets	(48)		(44)		—		—
Amortization of:
Net actuarial loss	20		18		—		—
Prior service credit	(4)		(5)		(2)		(1)
Net periodic benefit cost	$	26	$	25	$	2	$	2

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

As previously disclosed in our annual report on Form 10-K for the year ended December 31, 2020, we plan to contribute approximately $128 million to our pension plans and $22 million to our other postretirement benefit plans during 2021. During the three months ended March 31, 2021 and 2020, we contributed $21 million and $12 million, respectively, to our pension plans and $3 million and $4 million, respectively, to our other postretirement benefit plans.

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Income Taxes

3 Months Ended

Mar. 31, 2021

Income Tax Disclosure [Abstract]

INCOME TAXES

8.    INCOME TAXES

On March 27, 2020, the Coronavirus Aid, Relief and Economic Security (CARES) Act was enacted, which resulted in significant changes to the U.S. Internal Revenue Code of 1986, as amended. We recognized an overall income tax benefit of $616 million for the three months ended March 31, 2020, of which $110 million was attributable to the tax net operating loss (NOL) carryback provided for under the CARES Act of our 2020 tax NOL to our 2015 income tax year in which we paid federal income tax at a 35 percent tax rate. In addition, we were not limited in the amount of interest expense we could deduct. The remaining income tax benefit was primarily due to the LCM inventory valuation adjustment that resulted in a tax benefit of $551 million.

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Earnings (Loss) Per Common Share

3 Months Ended

Mar. 31, 2021

Earnings Per Share [Abstract]

EARNINGS (LOSS) PER COMMON SHARE

9.    EARNINGS (LOSS) PER COMMON SHARE

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

	Three Months Ended March 31,
	2021		2020
Loss per common share
Net loss attributable to Valero stockholders	$	(704)	$	(1,851)
Less: Income allocated to participating securities	1		1
Net loss available to common stockholders	$	(705)	$	(1,852)
Weighted-average common shares outstanding	407		408
Loss per common share	$	(1.73)	$	(4.54)
Loss per common share – assuming dilution
Net loss attributable to Valero stockholders	$	(704)	$	(1,851)
Less: Income allocated to participating securities	1		—
Net loss available to common stockholders	$	(705)	$	(1,851)
Weighted-average common shares outstanding – assuming dilution	407		408
Loss per common share – assuming dilution	$	(1.73)	$	(4.54)

Participating securities include restricted stock and performance awards granted under our 2020 Omnibus Stock Incentive Plan (OSIP) or our 2011 OSIP.

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Revenues and Segment Information

3 Months Ended

Mar. 31, 2021

Segment Reporting [Abstract]

REVENUES AND SEGMENT INFORMATION

10.    REVENUES AND SEGMENT INFORMATION

Revenue from Contracts with Customers

Disaggregation of Revenue

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

Contract Balances

Contract balances were as follows (in millions):

	March 31, 2021		December 31, 2020		Increase
Receivables from contracts with customers, included in receivables, net	$	4,701	$	3,642	$	1,059
Contract liabilities, included in accrued expenses	104		55		49

Receivables from contracts with customers is a component of “receivables, net” as presented on the balance sheet. The increase in “receivables, net” is described in Note 11.

For the three months ended March 31, 2021 and 2020, we recognized as revenue $37 million and $52 million, respectively, that was included in contract liabilities as of December 31, 2020 and 2019, 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, 2021, 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 marketing activities, and 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, our consolidated joint venture as discussed in Note 6. The principal product manufactured by DGD and sold by this segment is renewable diesel. 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, the associated marketing activities, and logistics assets that support our ethanol operations. 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 (loss) by reportable segment (in millions):

	Refining		Renewable Diesel		Ethanol		Corporate and Eliminations		Total
Three months ended March 31, 2021
Revenues:
Revenues from external customers	$	19,469	$	352	$	985	$	—	$	20,806
Intersegment revenues	3		79		60		(142)		—
Total revenues	19,472		431		1,045		(142)		20,806
Cost of sales:
Cost of materials and other	18,022		187		924		(141)		18,992
Operating expenses (excluding depreciation and amortization expense reflected below)	1,471		29		156		—		1,656
Depreciation and amortization expense	533		12		21		—		566
Total cost of sales	20,026		228		1,101		(141)		21,214
Other operating expenses	38		—		—		—		38
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		208		208
Depreciation and amortization expense	—		—		—		12		12
Operating income (loss) by segment	$	(592)	$	203	$	(56)	$	(221)	$	(666)

	Refining		Renewable Diesel		Ethanol		Corporate and Eliminations		Total
Three months ended March 31, 2020
Revenues:
Revenues from external customers	$	20,985	$	306	$	811	$	—	$	22,102
Intersegment revenues	2		53		64		(119)		—
Total revenues	20,987		359		875		(119)		22,102
Cost of sales:
Cost of materials and other	19,127		130		813		(118)		19,952
LCM inventory valuation adjustment	2,414		—		128		—		2,542
Operating expenses (excluding depreciation and amortization expense reflected below)	995		20		109		—		1,124
Depreciation and amortization expense	536		11		22		—		569
Total cost of sales	23,072		161		1,072		(118)		24,187
Other operating expenses	2		—		—		—		2
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		177		177
Depreciation and amortization expense	—		—		—		13		13
Operating income (loss) by segment	$	(2,087)	$	198	$	(197)	$	(191)	$	(2,277)

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,
	2021		2020
Refining:
Gasolines and blendstocks	$	8,729	$	8,244
Distillates	8,581		10,663
Other product revenues	2,159		2,078
Total refining revenues	19,469		20,985
Renewable diesel:
Renewable diesel	352		306
Ethanol:
Ethanol	752		629
Distillers grains	233		182
Total ethanol revenues	985		811
Revenues	$	20,806	$	22,102

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

	March 31, 2021		December 31, 2020
Refining	$	45,649	$	42,939
Renewable diesel	1,948		1,659
Ethanol	1,736		1,728
Corporate and eliminations	4,281		5,448
Total assets	$	53,614	$	51,774

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Supplemental Cash Flow Information

3 Months Ended

Mar. 31, 2021

Supplemental Cash Flow Information [Abstract]

SUPPLEMENTAL CASH FLOW INFORMATION

11.    SUPPLEMENTAL CASH FLOW INFORMATION

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

	Three Months Ended March 31,
	2021		2020
Decrease (increase) in current assets:
Receivables, net	$	(2,946)	$	2,968
Inventories	175		627
Prepaid expenses and other	(24)		(8)
Increase (decrease) in current liabilities:
Accounts payable	2,992		(4,222)
Accrued expenses	105		(79)
Taxes other than income taxes payable	(144)		(241)
Income taxes payable	26		(152)
Changes in current assets and current liabilities	$	184	$	(1,107)

Changes in current assets and current liabilities for the three months ended March 31, 2021 were primarily due to the following:

•the increase in receivables was primarily due to an increase in commodity prices in March 2021 compared to December 2020 combined with an increase in sales volumes;

•the decrease in inventories was primarily due to lower inventory levels in March 2021 compared to December 2020; and

•the increase in accounts payable was due to an increase in commodity prices in March 2021 compared to December 2020 combined with an increase in crude oil and other feedstock volumes purchased.

Changes in current assets and current liabilities for the three months ended March 31, 2020 were primarily due to the following:

•the decrease in receivables was due to (i) a decrease of $3.4 billion as a result of a decrease in commodity prices in March 2020 compared to December 2019 combined with a decrease in sales volumes and (ii) an increase in income taxes receivable of $430 million primarily due to the recognition of the current portion of the income tax benefit described in Note 8;

•the decrease in inventories was due to a decrease in commodity prices in March 2020 compared to December 2019 combined with lower inventory levels;

•the decrease in accounts payable was due to a decrease in commodity prices in March 2020 compared to December 2019 combined with a decrease in crude oil and other feedstock volumes purchased; and

•the decrease in taxes other than income taxes payable was mainly due to the payment of ad valorem, value-added, and motor fuel taxes.

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

	Three Months Ended March 31,
	2021		2020
Interest paid in excess of amount capitalized, including interest on finance leases	$	103	$	88
Income taxes paid, net	36		121

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

	Three Months Ended March 31,
	2021				2020
	Operating Leases		Finance Leases		Operating Leases		Finance Leases
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows	$	100	$	18	$	106	$	22
Financing cash flows	—		31		—		15
Changes in lease balances resulting from new and modified leases (a)	72		7		92		1,441

________________________

(a)Noncash activity for the three months ended March 31, 2020 primarily included $1.4 billion for a finance lease right-of-use asset and related liability recognized in connection with the terminaling agreement with MVP.

There were no significant noncash investing and financing activities during the three months ended March 31, 2021 and 2020, except as noted in the table above.

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Fair Value Measurements

3 Months Ended

Mar. 31, 2021

Fair Value Disclosures [Abstract]

FAIR VALUE MEASUREMENTS

12.    FAIR VALUE MEASUREMENTS

Recurring Fair Value Measurements

The following tables present information (in millions) about our assets and liabilities recognized at their fair values in our balance sheets categorized according to the fair value hierarchy of the inputs utilized by us to determine the fair values as of March 31, 2021 and December 31, 2020.

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, 2021
							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	$	386	$	—	$	—	$	386	$	(386)	$	—	$	—	$	—
Physical purchase contracts	—		10		—		10		n/a		n/a		10		n/a
Foreign currency contracts	10		—		—		10		n/a		n/a		10		n/a
Investments of certain benefit plans	75		—		8		83		n/a		n/a		83		n/a
Total	$	471	$	10	$	8	$	489	$	(386)	$	—	$	103
Liabilities
Commodity derivative contracts	$	444	$	—	$	—	$	444	$	(386)	$	(58)	$	—	$	(120)
Environmental credit obligations	—		62		—		62		n/a		n/a		62		n/a
Total	$	444	$	62	$	—	$	506	$	(386)	$	(58)	$	62

	December 31, 2020
							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	$	403	$	—	$	—	$	403	$	(373)	$	(18)	$	12	$	—
Physical purchase contracts	—		13		—		13		n/a		n/a		13		n/a
Investments of certain benefit plans	74		—		8		82		n/a		n/a		82		n/a
Total	$	477	$	13	$	8	$	498	$	(373)	$	(18)	$	107
Liabilities
Commodity derivative contracts	$	405	$	—	$	—	$	405	$	(373)	$	(32)	$	—	$	(44)
Environmental credit obligations	—		96		—		96		n/a		n/a		96		n/a
Foreign currency contracts	4		—		—		4		n/a		n/a		4		n/a
Total	$	409	$	96	$	—	$	505	$	(373)	$	(32)	$	100

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

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

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

•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.

•Foreign currency contracts consist of foreign currency exchange and purchase contracts and foreign currency swap agreements related to our international 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.

•Environmental credit obligations represent our liability for the purchase of (i) biofuel credits (primarily Renewable Identification Numbers (RINs) in the U.S.) needed to satisfy our obligation to blend biofuels into the products we produce and (ii) emission credits under the California Global Warming Solutions Act (the California cap-and-trade system, also known as AB 32) and similar programs (collectively, the cap-and-trade systems). To the degree we are unable to blend biofuels (such as ethanol and biodiesel) at percentages required under the biofuel programs, we must purchase biofuel credits to comply with these programs. Under the cap-and-trade systems, we must purchase emission credits to comply with these systems. These programs are described in Note 13 under “Risk Management Activities by Type of Risk—Environmental Compliance Program Price Risk.” The liability for environmental credits is based on our deficit for such credits as of the balance sheet date, if any, after considering any credits acquired or under contract, and is equal to the product of the credits deficit and the market price of these credits as of the balance sheet date. The environmental credit 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.

Nonrecurring Fair Value Measurements

There were no assets or liabilities that were measured at fair value on a nonrecurring basis as of March 31, 2021 and December 31, 2020.

Other Financial Instruments

Financial instruments that we recognize in our balance sheets at their carrying amounts are shown in the following table along with their associated fair values (in millions):

		March 31, 2021				December 31, 2020
	Fair Value Hierarchy	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Financial assets
Cash and cash equivalents	Level 1	$	2,254	$	2,254	$	3,313	$	3,313
Financial liabilities
Debt (excluding finance leases)	Level 2	13,024		14,776		13,013		15,103

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Price Risk Management Activities

3 Months Ended

Mar. 31, 2021

Derivative Instruments and Hedging Activities Disclosure [Abstract]

PRICE RISK MANAGEMENT ACTIVITIES

13.    PRICE RISK MANAGEMENT ACTIVITIES

General

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

Risk Management Activities by Type of Risk

Commodity Price Risk

We are exposed to market risks related to the volatility in the price of feedstocks (primarily crude oil and corn), the products we produce (primarily refined petroleum products), 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 of directors.

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, 2021, 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
	2021	2022
Derivatives designated as cash flow hedges
Refined petroleum products:
Futures – long	427	—
Futures – short	1,605	—
Derivatives designated as economic hedges
Crude oil and refined petroleum products:
Futures – long	66,513	64
Futures – short	56,880	22
Corn:
Futures – long	63,630	10
Futures – short	90,395	365
Physical contracts – long	26,563	351

Foreign Currency Risk

We are exposed to exchange rate fluctuations on transactions related to our international 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 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, 2021, we had foreign currency contracts to purchase $245 million of U.S. dollars and $2.8 billion of U.S. dollar equivalent Canadian dollars. Of these commitments, $1.0 billion matured on or before April 27, 2021 and the remaining $2.0 billion will mature by July 15, 2021.

Environmental Compliance Program Price Risk

We are exposed to market risk related to the volatility in the price of credits needed to comply with various governmental and regulatory environmental compliance programs. To manage this risk, we enter into contracts to purchase these credits when prices are deemed favorable. Some of these contracts are derivative instruments; however, we elect the normal purchase exception and do not record these contracts at their fair values. Certain of these programs require us to blend biofuels into the products we produce, and we are subject to such programs in most of the countries in which we operate. These countries set annual quotas for the percentage of biofuels that must be blended into the motor fuels consumed in these countries. As a producer of motor fuels from petroleum, we are obligated to blend biofuels into the products we produce at a rate that is at least equal to the applicable quota. To the degree we are unable to blend at the applicable rate, we must purchase biofuel credits (primarily RINs in the U.S.). We are exposed to the volatility in the market price of these credits, and we manage that risk by purchasing biofuel credits when prices are deemed favorable. The cost of meeting our

obligations under these compliance programs was $360 million and $112 million for the three months ended March 31, 2021 and 2020, respectively. These amounts are reflected in cost of materials and other.

We are subject to additional requirements under greenhouse gas (GHG) emission programs, including the cap-and-trade systems, as discussed in Note 12. Under these cap-and-trade systems, we purchase various GHG emission credits available on the open market. Therefore, we are exposed to the volatility in the market price of these credits. The cost to implement certain provisions of the cap-and-trade systems are significant; however, we recovered substantially all of these costs from our customers for the three months ended March 31, 2021 and 2020 and expect to continue to recover the majority of these costs in the future. For the three months ended March 31, 2021 and 2020, the net cost of meeting our obligations under these compliance programs was immaterial.

Fair Values of Derivative Instruments

The following tables provide information about the fair values of our derivative instruments as of March 31, 2021 and December 31, 2020 (in millions) and the line items in the balance sheets in which the fair values are reflected. See Note 12 for additional information related to the fair values of our derivative instruments.

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

	Balance Sheet Location	March 31, 2021				December 31, 2020
		Asset Derivatives		Liability Derivatives		Asset Derivatives		Liability Derivatives
Derivatives designated as hedging instruments
Commodity contracts	Receivables, net	$	5	$	10	$	4	$	17
Derivatives not designated as hedging instruments
Commodity contracts	Receivables, net	$	381	$	434	$	399	$	388
Physical purchase contracts	Inventories	10		—		13		—
Foreign currency contracts	Receivables, net	10		—		—		—
Foreign currency contracts	Accrued expenses	—		—		—		4
Total		$	401	$	434	$	412	$	392

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 of directors. 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,
		2021		2020
Commodity contracts
Gain (loss) recognized in other comprehensive income (loss) on derivatives	N/A	$	(13)	$	55
Gain (loss) reclassified from accumulated other comprehensive loss into income	Revenues	(23)		26

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, 2021 and 2020. For the three months ended March 31, 2021 and 2020, 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 over the next 12 months as a result of the hedged transactions that are forecasted to occur as of March 31, 2021 was immaterial. For the three months ended March 31, 2021 and 2020, 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, 2021 and 2020 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,
		2021		2020
Commodity contracts	Revenues	$	7	$	(8)
Commodity contracts	Cost of materials and other	(78)		(152)
Commodity contracts	Operating expenses (excluding depreciation and amortization expense)	1		(2)
Foreign currency contracts	Cost of materials and other	(8)		49
Foreign currency contracts	Other income, net	30		(165)

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Basis of Presentation and Significant Accounting Policies (Policies)

3 Months Ended

Mar. 31, 2021

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.

These unaudited financial statements have been prepared in accordance 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 U.S. GAAP for complete financial statements. In the opinion of management, all adjustments considered necessary for a fair presentation of our results for the three months ended March 31, 2021 have been included. All such adjustments are of a normal recurring nature unless disclosed otherwise. Operating results for the three months ended March 31, 2021 are not necessarily indicative of the results that may be expected for the year ending December 31, 2021. The financial statements presented herein should be read in conjunction with the financial statements included in our annual report on Form 10-K for the year ended December 31, 2020.

As discussed in Note 2, the outbreak of COVID-19 and its development into a pandemic in March 2020 resulted in significant economic disruption globally. Developments with respect to COVID-19 have been occurring at a rapid pace and the risk remains that circumstances could change. Demand for and market prices of most of our products began to improve during the latter half of 2020 and continued to improve throughout the first quarter of 2021. These improvements resulted primarily from the lifting or easing of restrictions by many governmental authorities, especially those in our U.S. Gulf Coast and U.S. Mid-Continent regions, in response to decreasing COVID-19 infection rates and increasing numbers of people receiving COVID-19 vaccines, which were approved by a number of regulators throughout the world in late 2020 and early 2021. While many governmental authorities in areas located in our U.S. West Coast and North Atlantic regions, such as California, Canada, and the United Kingdom (U.K.), continue to impose restrictions, some of these restrictions have been or are soon expected to be moderately lifted. The ongoing distribution of vaccines may result in the continued lifting of restrictions and may be seen as a key factor in helping to restore public confidence, and thus stimulate and increase economic activity, potentially to pre-pandemic levels; however, the risk remains that the vaccines may not be distributed widely on a timely basis, they may not be effective against new variants of the COVID-19 virus, the distribution of some or all of the vaccines may be paused or withdrawn due to concerns with potential side effects, and/or the level of individuals’ willingness to receive a vaccine may not be as strong or as timely as needed. Based on these and other circumstances that cannot be predicted, the broader implications of the pandemic on our results of operations and financial position remain uncertain.

The balance sheet as of December 31, 2020 has been derived from our audited financial statements as of that date. For further information, refer to our financial statements and notes thereto included in our annual report on Form 10-K for the year ended December 31, 2020.

Reclassifications

Reclassifications

Certain prior year amounts presented in Note 11 have been reclassified to conform to the 2021 presentation. The change was due to the reclassification of amounts for income taxes receivable from prepaid expenses and other to “receivables, net.”

Use of Estimates

Use of Estimates

The preparation of financial statements in conformity with U.S. GAAP requires us to make estimates and assumptions that affect the amounts reported in the 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.

Adoption of Accounting Pronouncement

Adoption of Accounting Pronouncement

The following Financial Accounting Standards Board (FASB) Accounting Standards Update (ASU) was issued and adopted by us on January 7, 2021. Our adoption of this ASU did not have a material impact on our financial statements or related disclosures.

ASU		Basis of Adoption
2021-01	Reference Rate Reform (Topic 848): Scope	Prospectively

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 non-consolidated 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 various government and regulatory programs. We enter into derivative instruments to manage some of these risks, including derivative instruments related to the various commodities we purchase or produce, and foreign currency exchange and purchase contracts, as described below under “Risk Management Activities by Type of Risk.” These derivative instruments are recorded as either assets or liabilities measured at their fair values (see Note 12), as summarized below under “Fair Values of Derivative Instruments.” The effect of these derivative instruments on our income and other comprehensive income (loss) is summarized below under “Effect of Derivative Instruments on Income and Other Comprehensive Income (Loss).”

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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Basis of Presentation and Significant Accounting Policies (Tables)

3 Months Ended

Mar. 31, 2021

Accounting Policies [Abstract]

Schedule of adopted accounting pronouncement

The following Financial Accounting Standards Board (FASB) Accounting Standards Update (ASU) was issued and adopted by us on January 7, 2021. Our adoption of this ASU did not have a material impact on our financial statements or related disclosures.

ASU		Basis of Adoption
2021-01	Reference Rate Reform (Topic 848): Scope	Prospectively

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Inventories (Tables)

3 Months Ended

Mar. 31, 2021

Inventory Disclosure [Abstract]

Schedule of inventories

Inventories consisted of the following (in millions):

	March 31, 2021		December 31, 2020
Refinery feedstocks	$	1,947	$	1,979
Refined petroleum products and blendstocks	3,284		3,425
Renewable diesel feedstocks and products	64		50
Ethanol feedstocks and products	297		297
Materials and supplies	289		287
Inventories	$	5,881	$	6,038

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Debt (Tables)

3 Months Ended

Mar. 31, 2021

Debt Disclosure [Abstract]

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, 2021
	Facility Amount		Maturity Date	Outstanding Borrowings		Letters of Credit Issued (a)		Availability
Committed facilities:
Valero Revolver	$	4,000	March 2024	$	—	$	118	$	3,882
364-day Revolving Credit Facility (b)	$	875	April 2021	$	—	n/a		$	875
Canadian Revolver	C$	150	November 2021	C$	—	C$	5	C$	145
Accounts receivable sales facility	$	1,000	July 2021	$	—	n/a		$	1,000
Letter of credit facility	$	50	November 2021	n/a		$	—	$	50
Committed facilities of VIEs (c):
DGD Revolver	$	400	March 2024	$	—	$	—	$	400
IEnova Revolver (d)	$	660	February 2028	$	606	n/a		$	54
Uncommitted facilities:
Letter of credit facilities	n/a		n/a	n/a		$	330	n/a

________________________

(a)Letters of credit issued as of March 31, 2021 expire at various times in 2021 through 2023.

(b)This facility matured on April 12, 2021 and was not renewed.

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

(d)As of March 31, 2021 and December 31, 2020, the variable interest rate on the IEnova Revolver was 3.888 percent and 3.870 percent, respectively.

Activities under our credit facilities were as follows (in millions):

	Three Months Ended March 31,
	2021		2020
Borrowings:
Accounts receivable sales facility	$	—	$	300
IEnova Revolver	8		70

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,
	2021		2020
Interest and debt expense	$	164	$	145
Less: Capitalized interest	15		20
Interest and debt expense, net of capitalized interest	$	149	$	125

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Equity (Tables)

3 Months Ended

Mar. 31, 2021

Equity [Abstract]

Schedule of changes in 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,
	2021								2020
	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	$	(515)	$	(737)	$	(2)	$	(1,254)	$	(676)	$	(672)	$	(3)	$	(1,351)
Other comprehensive income (loss) before reclassifications	76		1		(5)		72		(606)		—		21		(585)
Amounts reclassified from accumulated other comprehensive loss	—		8		9		17		—		9		(10)		(1)
Other comprehensive income (loss)	76		9		4		89		(606)		9		11		(586)
Balance as of end of period	$	(439)	$	(728)	$	2	$	(1,165)	$	(1,282)	$	(663)	$	8	$	(1,937)

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Variable Interest Entities (Tables)

3 Months Ended

Mar. 31, 2021

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Summarized balance sheet information of consolidated VIEs

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

	March 31, 2021
	DGD		Central Mexico Terminals		Other		Total
Assets
Cash and cash equivalents	$	191	$	—	$	19	$	210
Other current assets	272		10		10		292
Property, plant, and equipment, net	1,431		614		94		2,139
Liabilities
Current liabilities, including current portion of debt and finance lease obligations	$	166	$	632	$	8	$	806
Debt and finance lease obligations, less current portion	1		—		24		25

	December 31, 2020
	DGD		Central Mexico Terminals		Other		Total
Assets
Cash and cash equivalents	$	144	$	1	$	16	$	161
Other current assets	219		24		8		251
Property, plant, and equipment, net	1,232		590		96		1,918
Liabilities
Current liabilities, including current portion of debt and finance lease obligations	$	90	$	620	$	8	$	718
Debt and finance lease obligations, less current portion	1		—		25		26

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Employee Benefit Plans (Tables)

3 Months Ended

Mar. 31, 2021

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
	2021		2020		2021		2020
Three months ended March 31
Service cost	$	40	$	35	$	2	$	1
Interest cost	18		21		2		2
Expected return on plan assets	(48)		(44)		—		—
Amortization of:
Net actuarial loss	20		18		—		—
Prior service credit	(4)		(5)		(2)		(1)
Net periodic benefit cost	$	26	$	25	$	2	$	2

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Earnings (Loss) Per Common Share (Tables)

3 Months Ended

Mar. 31, 2021

Earnings Per Share [Abstract]

Schedule of earnings (loss) per common share, basic and diluted

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

	Three Months Ended March 31,
	2021		2020
Loss per common share
Net loss attributable to Valero stockholders	$	(704)	$	(1,851)
Less: Income allocated to participating securities	1		1
Net loss available to common stockholders	$	(705)	$	(1,852)
Weighted-average common shares outstanding	407		408
Loss per common share	$	(1.73)	$	(4.54)
Loss per common share – assuming dilution
Net loss attributable to Valero stockholders	$	(704)	$	(1,851)
Less: Income allocated to participating securities	1		—
Net loss available to common stockholders	$	(705)	$	(1,851)
Weighted-average common shares outstanding – assuming dilution	407		408
Loss per common share – assuming dilution	$	(1.73)	$	(4.54)

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Revenues and Segment Information (Tables)

3 Months Ended

Mar. 31, 2021

Segment Reporting [Abstract]

Schedule of contract balances

Contract balances were as follows (in millions):

	March 31, 2021		December 31, 2020		Increase
Receivables from contracts with customers, included in receivables, net	$	4,701	$	3,642	$	1,059
Contract liabilities, included in accrued expenses	104		55		49

Segment information for our reportable segments

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

	Refining		Renewable Diesel		Ethanol		Corporate and Eliminations		Total
Three months ended March 31, 2021
Revenues:
Revenues from external customers	$	19,469	$	352	$	985	$	—	$	20,806
Intersegment revenues	3		79		60		(142)		—
Total revenues	19,472		431		1,045		(142)		20,806
Cost of sales:
Cost of materials and other	18,022		187		924		(141)		18,992
Operating expenses (excluding depreciation and amortization expense reflected below)	1,471		29		156		—		1,656
Depreciation and amortization expense	533		12		21		—		566
Total cost of sales	20,026		228		1,101		(141)		21,214
Other operating expenses	38		—		—		—		38
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		208		208
Depreciation and amortization expense	—		—		—		12		12
Operating income (loss) by segment	$	(592)	$	203	$	(56)	$	(221)	$	(666)

	Refining		Renewable Diesel		Ethanol		Corporate and Eliminations		Total
Three months ended March 31, 2020
Revenues:
Revenues from external customers	$	20,985	$	306	$	811	$	—	$	22,102
Intersegment revenues	2		53		64		(119)		—
Total revenues	20,987		359		875		(119)		22,102
Cost of sales:
Cost of materials and other	19,127		130		813		(118)		19,952
LCM inventory valuation adjustment	2,414		—		128		—		2,542
Operating expenses (excluding depreciation and amortization expense reflected below)	995		20		109		—		1,124
Depreciation and amortization expense	536		11		22		—		569
Total cost of sales	23,072		161		1,072		(118)		24,187
Other operating expenses	2		—		—		—		2
General and administrative expenses (excluding depreciation and amortization expense reflected below)	—		—		—		177		177
Depreciation and amortization expense	—		—		—		13		13
Operating income (loss) by segment	$	(2,087)	$	198	$	(197)	$	(191)	$	(2,277)

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,
	2021		2020
Refining:
Gasolines and blendstocks	$	8,729	$	8,244
Distillates	8,581		10,663
Other product revenues	2,159		2,078
Total refining revenues	19,469		20,985
Renewable diesel:
Renewable diesel	352		306
Ethanol:
Ethanol	752		629
Distillers grains	233		182
Total ethanol revenues	985		811
Revenues	$	20,806	$	22,102

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

	March 31, 2021		December 31, 2020
Refining	$	45,649	$	42,939
Renewable diesel	1,948		1,659
Ethanol	1,736		1,728
Corporate and eliminations	4,281		5,448
Total assets	$	53,614	$	51,774

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Supplemental Cash Flow Information (Tables)

3 Months Ended

Mar. 31, 2021

Supplemental Cash Flow Information [Abstract]

Schedule of cash flows, supplemental disclosures

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

	Three Months Ended March 31,
	2021		2020
Decrease (increase) in current assets:
Receivables, net	$	(2,946)	$	2,968
Inventories	175		627
Prepaid expenses and other	(24)		(8)
Increase (decrease) in current liabilities:
Accounts payable	2,992		(4,222)
Accrued expenses	105		(79)
Taxes other than income taxes payable	(144)		(241)
Income taxes payable	26		(152)
Changes in current assets and current liabilities	$	184	$	(1,107)

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

	Three Months Ended March 31,
	2021		2020
Interest paid in excess of amount capitalized, including interest on finance leases	$	103	$	88
Income taxes paid, net	36		121

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

	Three Months Ended March 31,
	2021				2020
	Operating Leases		Finance Leases		Operating Leases		Finance Leases
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows	$	100	$	18	$	106	$	22
Financing cash flows	—		31		—		15
Changes in lease balances resulting from new and modified leases (a)	72		7		92		1,441

________________________

(a)Noncash activity for the three months ended March 31, 2020 primarily included $1.4 billion for a finance lease right-of-use asset and related liability recognized in connection with the terminaling agreement with MVP.

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Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2021

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, 2021 and December 31, 2020.

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, 2021
							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	$	386	$	—	$	—	$	386	$	(386)	$	—	$	—	$	—
Physical purchase contracts	—		10		—		10		n/a		n/a		10		n/a
Foreign currency contracts	10		—		—		10		n/a		n/a		10		n/a
Investments of certain benefit plans	75		—		8		83		n/a		n/a		83		n/a
Total	$	471	$	10	$	8	$	489	$	(386)	$	—	$	103
Liabilities
Commodity derivative contracts	$	444	$	—	$	—	$	444	$	(386)	$	(58)	$	—	$	(120)
Environmental credit obligations	—		62		—		62		n/a		n/a		62		n/a
Total	$	444	$	62	$	—	$	506	$	(386)	$	(58)	$	62

	December 31, 2020
							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	$	403	$	—	$	—	$	403	$	(373)	$	(18)	$	12	$	—
Physical purchase contracts	—		13		—		13		n/a		n/a		13		n/a
Investments of certain benefit plans	74		—		8		82		n/a		n/a		82		n/a
Total	$	477	$	13	$	8	$	498	$	(373)	$	(18)	$	107
Liabilities
Commodity derivative contracts	$	405	$	—	$	—	$	405	$	(373)	$	(32)	$	—	$	(44)
Environmental credit obligations	—		96		—		96		n/a		n/a		96		n/a
Foreign currency contracts	4		—		—		4		n/a		n/a		4		n/a
Total	$	409	$	96	$	—	$	505	$	(373)	$	(32)	$	100

Carrying amount and estimated fair value of financial instruments

Financial instruments that we recognize in our balance sheets at their carrying amounts are shown in the following table along with their associated fair values (in millions):

		March 31, 2021				December 31, 2020
	Fair Value Hierarchy	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Financial assets
Cash and cash equivalents	Level 1	$	2,254	$	2,254	$	3,313	$	3,313
Financial liabilities
Debt (excluding finance leases)	Level 2	13,024		14,776		13,013		15,103

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Price Risk Management Activities (Tables)

3 Months Ended

Mar. 31, 2021

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Risk management activities by type of risk

As of March 31, 2021, 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
	2021	2022
Derivatives designated as cash flow hedges
Refined petroleum products:
Futures – long	427	—
Futures – short	1,605	—
Derivatives designated as economic hedges
Crude oil and refined petroleum products:
Futures – long	66,513	64
Futures – short	56,880	22
Corn:
Futures – long	63,630	10
Futures – short	90,395	365
Physical contracts – long	26,563	351

Fair values of derivative instruments

The following tables provide information about the fair values of our derivative instruments as of March 31, 2021 and December 31, 2020 (in millions) and the line items in the balance sheets in which the fair values are reflected. See Note 12 for additional information related to the fair values of our derivative instruments.

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

	Balance Sheet Location	March 31, 2021				December 31, 2020
		Asset Derivatives		Liability Derivatives		Asset Derivatives		Liability Derivatives
Derivatives designated as hedging instruments
Commodity contracts	Receivables, net	$	5	$	10	$	4	$	17
Derivatives not designated as hedging instruments
Commodity contracts	Receivables, net	$	381	$	434	$	399	$	388
Physical purchase contracts	Inventories	10		—		13		—
Foreign currency contracts	Receivables, net	10		—		—		—
Foreign currency contracts	Accrued expenses	—		—		—		4
Total		$	401	$	434	$	412	$	392

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,
		2021		2020
Commodity contracts
Gain (loss) recognized in other comprehensive income (loss) on derivatives	N/A	$	(13)	$	55
Gain (loss) reclassified from accumulated other comprehensive loss into income	Revenues	(23)		26

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,
		2021		2020
Commodity contracts	Revenues	$	7	$	(8)
Commodity contracts	Cost of materials and other	(78)		(152)
Commodity contracts	Operating expenses (excluding depreciation and amortization expense)	1		(2)
Foreign currency contracts	Cost of materials and other	(8)		49
Foreign currency contracts	Other income, net	30		(165)

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Inventories (Details) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020	Mar. 31, 2020
Schedule of Inventories
Refinery feedstocks	$ 1,947	$ 1,979
Refined petroleum products and blendstocks	3,284	3,425
Renewable diesel feedstocks and products	64	50
Ethanol feedstocks and products	297	297
Materials and supplies	289	287
Inventories	5,881	6,038
Inventories (Textual)
LCM inventory valuation reserve			$ 2,500
Excess of market value over carrying amount of LIFO inventories	2,700	1,300
Amount of non-LIFO inventory	$ 1,200	$ 918

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Debt, Credit Facilities (Details)		Mar. 31, 2021 USD ($)	Mar. 31, 2021 CAD ($)	Dec. 31, 2020
Valero Revolver [Member] | Credit Facilities [Member]
Line of Credit Facility
Facility amount		$ 4,000,000,000
Outstanding borrowings or letters of credit issued		0
Availability		3,882,000,000
Valero Revolver Letter of Credit [Member] | Credit Facilities [Member]
Line of Credit Facility
Outstanding borrowings or letters of credit issued	[1]	118,000,000
364-Day Revolving Credit Facility [Member] | Credit Facilities [Member]
Line of Credit Facility
Facility amount	[2]	875,000,000
Outstanding borrowings or letters of credit issued, short-term	[2]	0
Availability	[2]	875,000,000
Canadian Revolver [Member] | Credit Facilities [Member]
Line of Credit Facility
Facility amount			$ 150,000,000
Outstanding borrowings or letters of credit issued, short-term			0
Availability			145,000,000
Canadian Revolver Letter of Credit [Member] | Credit Facilities [Member]
Line of Credit Facility
Outstanding borrowings or letters of credit issued, short-term	[1]		$ 5,000,000
Accounts Receivable Sales Facility [Member] | Credit Facilities [Member]
Line of Credit Facility
Facility amount		1,000,000,000
Outstanding borrowings or letters of credit issued, short-term		0
Availability		1,000,000,000
Committed Letter of Credit Facility Expires November 2021 [Member] | Credit Facilities [Member]
Line of Credit Facility
Facility amount		50,000,000
Outstanding borrowings or letters of credit issued, short-term	[1]	0
Availability		50,000,000
DGD Revolver [Member] | Diamond Green Diesel Holdings LLC [Member] | Credit Facilities [Member] | Variable Interest Entities (VIEs) [Member]
Line of Credit Facility
Facility amount	[3]	400,000,000
Outstanding borrowings or letters of credit issued	[3]	0
Availability	[3]	400,000,000
DGD Revolver Letter Of Credit [Member] | Diamond Green Diesel Holdings LLC [Member] | Credit Facilities [Member] | Variable Interest Entities (VIEs) [Member]
Line of Credit Facility
Facility amount		10,000,000
Outstanding borrowings or letters of credit issued	[1],[3]	$ 0
IEnova Revolver [Member] | Central Mexico Terminals [Member] | Credit Facilities [Member]
Credit Facilities (Textual)
Interest rate at period end (percent)		3.888%	3.888%	3.87%
IEnova Revolver [Member] | Central Mexico Terminals [Member] | Credit Facilities [Member] | Variable Interest Entities (VIEs) [Member]
Line of Credit Facility
Facility amount	[3],[4]	$ 660,000,000
Outstanding borrowings or letters of credit issued, short-term	[3],[4]	606,000,000
Availability	[3],[4]	54,000,000
Uncommitted Letter of Credit Facility [Member] | Credit Facilities [Member]
Line of Credit Facility
Outstanding borrowings or letters of credit issued, short-term	[1]	$ 330,000,000

[1] Letters of credit issued as of March 31, 2021 expire at various times in 2021 through 2023.

[2] This facility matured on April 12, 2021 and was not renewed.

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

[4] As of March 31, 2021 and December 31, 2020, the variable interest rate on the IEnova Revolver was 3.888 percent and 3.870 percent, respectively.

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Debt, Activity Under Credit Facilities (Details) - Line of Credit [Member] - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Accounts Receivable Sales Facility [Member]
Line of Credit Facility [Line Items]
Borrowings	$ 0	$ 300
IEnova Revolver [Member] | Central Mexico Terminals [Member]
Line of Credit Facility [Line Items]
Borrowings	$ 8	$ 70

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Debt, Narrative (Details) - Credit Facilities [Member] - Variable Interest Entity, Primary Beneficiary [Member] - Diamond Green Diesel Holdings LLC [Member]	3 Months Ended
	Mar. 31, 2021 USD ($)
DGD Revolver [Member]
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity	$ 400,000,000	[1]
Option to increase aggregate commitments under line of credit facility, increase limit, subject to certain restrictions	550,000,000
Borrowings from long-term lines of credit	0
Repayments of long-term lines of credit	0
DGD Revolver Letter Of Credit [Member]
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity	$ 10,000,000

[1] Creditors of our VIEs do not have recourse against us.

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Debt, Interest Incurred (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Interest and Debt Expense, Net of Capitalized Interest
Interest and debt expense	$ 164	$ 145
Less: Capitalized interest	15	20
Interest and debt expense, net of capitalized interest	$ 149	$ 125

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Equity, Narrative (Details)	Apr. 16, 2021 $ / shares
Dividend Declared [Member] | Subsequent Event [Member]
Equity (Textual)
Dividends declared, amount per share (in dollars per share)	$ 0.98

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Equity, Changes in Accumulated Other Comprehensive Loss (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Changes in Accumulated Other Comprehensive Loss, By Component, Net of Tax
Beginning balance, accumulated other comprehensive loss, net of tax	$ 18,801
Other comprehensive income (loss) before reclassifications	72	$ (585)
Amounts reclassified from accumulated other comprehensive loss	17	(1)
Other comprehensive income (loss)	89	(586)
Ending balance, accumulated other comprehensive loss, net of tax	17,801
Accumulated Other Comprehensive Loss [Member]
Changes in Accumulated Other Comprehensive Loss, By Component, Net of Tax
Beginning balance, accumulated other comprehensive loss, net of tax	(1,254)	(1,351)
Ending balance, accumulated other comprehensive loss, net of tax	(1,165)	(1,937)
Foreign Currency Translation Adjustment [Member]
Changes in Accumulated Other Comprehensive Loss, By Component, Net of Tax
Beginning balance, accumulated other comprehensive loss, net of tax	(515)	(676)
Other comprehensive income (loss) before reclassifications	76	(606)
Amounts reclassified from accumulated other comprehensive loss	0	0
Other comprehensive income (loss)	76	(606)
Ending balance, accumulated other comprehensive loss, net of tax	(439)	(1,282)
Defined Benefit Plans Items [Member]
Changes in Accumulated Other Comprehensive Loss, By Component, Net of Tax
Beginning balance, accumulated other comprehensive loss, net of tax	(737)	(672)
Other comprehensive income (loss) before reclassifications	1	0
Amounts reclassified from accumulated other comprehensive loss	8	9
Other comprehensive income (loss)	9	9
Ending balance, accumulated other comprehensive loss, net of tax	(728)	(663)
Gains (Losses) on Cash Flow Hedges [Member]
Changes in Accumulated Other Comprehensive Loss, By Component, Net of Tax
Beginning balance, accumulated other comprehensive loss, net of tax	(2)	(3)
Other comprehensive income (loss) before reclassifications	(5)	21
Amounts reclassified from accumulated other comprehensive loss	9	(10)
Other comprehensive income (loss)	4	11
Ending balance, accumulated other comprehensive loss, net of tax	$ 2	$ 8

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Variable Interest Entities (Details) - USD ($) $ in Millions	Apr. 19, 2021	Mar. 31, 2021	Dec. 31, 2020
Assets
Cash and cash equivalents		$ 2,254	$ 3,313
Property, plant, and equipment, net		30,379	30,389
Liabilities
Current liabilities, including current portion of debt and finance lease obligations		12,307	9,283
Debt and finance lease obligations, less current portion		13,930	13,954
MVP Terminalling, LLC (MVP) [Member] | Subsequent Event [Member]
Variable Interest Entity (Textual)
Percent membership interest in unconsolidated joint venture sold (percent)	24.99%
Proceeds from sale of membership interest in unconsolidated joint venture	$ 270
Membership percentage in VIE (percent)	25.01%
Variable Interest Entity, Primary Beneficiary [Member]
Assets
Cash and cash equivalents		210	161
Other current assets		292	251
Property, plant, and equipment, net		2,139	1,918
Liabilities
Current liabilities, including current portion of debt and finance lease obligations		806	718
Debt and finance lease obligations, less current portion		25	26
Diamond Green Diesel Holdings LLC (DGD) [Member]
Assets
Cash and cash equivalents		191	144
Other current assets		272	219
Property, plant, and equipment, net		1,431	1,232
Liabilities
Current liabilities, including current portion of debt and finance lease obligations		166	90
Debt and finance lease obligations, less current portion		1	1
Central Mexico Terminals [Member]
Assets
Cash and cash equivalents		0	1
Other current assets		10	24
Property, plant, and equipment, net		614	590
Liabilities
Current liabilities, including current portion of debt and finance lease obligations		632	620
Debt and finance lease obligations, less current portion		0	0
Other VIEs [Member]
Assets
Cash and cash equivalents		19	16
Other current assets		10	8
Property, plant, and equipment, net		94	96
Liabilities
Current liabilities, including current portion of debt and finance lease obligations		8	8
Debt and finance lease obligations, less current portion		$ 24	$ 25

XML

Employee Benefit Plans (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Dec. 31, 2020
Pension Plans [Member]
Components of net periodic benefit cost:
Service cost	$ 40	$ 35
Interest cost	18	21
Expected return on plan assets	(48)	(44)
Amortization of:
Net actuarial loss	20	18
Prior service credit	(4)	(5)
Net periodic benefit cost	26	25
Employee Benefit Plans (Textual)
Future employer contributions to pension and other postretirement plans, as disclosed in annual report on Form 10-K			$ 128
Contributions to benefit plans	21	12
Other Postretirement Benefit Plans [Member]
Components of net periodic benefit cost:
Service cost	2	1
Interest cost	2	2
Expected return on plan assets	0	0
Amortization of:
Net actuarial loss	0	0
Prior service credit	(2)	(1)
Net periodic benefit cost	2	2
Employee Benefit Plans (Textual)
Future employer contributions to pension and other postretirement plans, as disclosed in annual report on Form 10-K			$ 22
Contributions to benefit plans	$ 3	$ 4

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Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Income Taxes (Textual)
Income tax benefit	$ 148	$ 616
Income tax benefit, tax NOL carryback provided for under CARES Act		110
Income tax benefit due to LCM inventory valuation adjustment		$ 551

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Earnings (Loss) Per Common Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Loss per common share
Net loss attributable to Valero stockholders	$ (704)	$ (1,851)
Less: Income allocated to participating securities	1	1
Net loss available to common stockholders	$ (705)	$ (1,852)
Weighted-average common shares outstanding (in shares)	407	408
Loss per common share (in dollars per share)	$ (1.73)	$ (4.54)
Loss per common share – assuming dilution
Net loss attributable to Valero stockholders	$ (704)	$ (1,851)
Less: Income allocated to participating securities	1	0
Net loss available to common stockholders	$ (705)	$ (1,851)
Weighted-average common shares outstanding – assuming dilution (in shares)	407	408
Loss per common share – assuming dilution (in dollars per share)	$ (1.73)	$ (4.54)

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Revenues and Segment Information, Contract Balances (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Receivables from contracts with customers, included in receivables, net
Increase		$ (3,400)
Contract liabilities, included in accrued expenses
Beginning balance	$ 55
Increase	49
Ending balance	104
Contract Balances (Textual)
Revenue recognized that was included in contract liabilities as of prior year end	37	$ 52
Receivables from Contracts with Customers [Member]
Receivables from contracts with customers, included in receivables, net
Beginning balance	3,642
Increase	1,059
Ending balance	$ 4,701

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Revenues and Segment Information, Components of Operating Income (Loss) (Details) $ in Millions		3 Months Ended
		Mar. 31, 2021 USD ($) segment	Mar. 31, 2020 USD ($)
Segment Information for our Reportable Segments
Revenues	[1]	$ 20,806	$ 22,102
Cost of sales:
Cost of materials and other		18,992	19,952
LCM inventory valuation adjustment		0	2,542
Operating expenses (excluding depreciation and amortization expense reflected below)		1,656	1,124
Depreciation and amortization expense		566	569
Total cost of sales		21,214	24,187
Other operating expenses		38	2
General and administrative expenses (excluding depreciation and amortization expense reflected below)		208	177
Depreciation and amortization expense		12	13
Operating loss		$ (666)	(2,277)
Disclosure of Entity's Reportable Segments (Textual)
Number of reportable segments | segment		3
Corporate, Reconciling Items And Eliminations [Member]
Segment Information for our Reportable Segments
Revenues		$ (142)	(119)
Cost of sales:
Operating loss		(221)	(191)
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)		208	177
Depreciation and amortization expense		12	13
Intersegment Eliminations [Member]
Segment Information for our Reportable Segments
Revenues		(142)	(119)
Cost of sales:
Cost of materials and other		(141)	(118)
LCM inventory valuation adjustment			0
Operating expenses (excluding depreciation and amortization expense reflected below)		0	0
Depreciation and amortization expense		0	0
Total cost of sales		(141)	(118)
Other operating expenses		0	0
Refining [Member]
Segment Information for our Reportable Segments
Revenues		19,469	20,985
Refining [Member] | Operating Segments [Member]
Segment Information for our Reportable Segments
Revenues		19,472	20,987
Cost of sales:
Cost of materials and other		18,022	19,127
LCM inventory valuation adjustment			2,414
Operating expenses (excluding depreciation and amortization expense reflected below)		1,471	995
Depreciation and amortization expense		533	536
Total cost of sales		20,026	23,072
Other operating expenses		38	2
General and administrative expenses (excluding depreciation and amortization expense reflected below)		0	0
Depreciation and amortization expense		0	0
Operating loss		(592)	(2,087)
Refining [Member] | Intersegment Eliminations [Member]
Segment Information for our Reportable Segments
Revenues		3	2
Renewable Diesel [Member]
Segment Information for our Reportable Segments
Revenues		352	306
Renewable Diesel [Member] | Operating Segments [Member]
Segment Information for our Reportable Segments
Revenues		431	359
Cost of sales:
Cost of materials and other		187	130
LCM inventory valuation adjustment			0
Operating expenses (excluding depreciation and amortization expense reflected below)		29	20
Depreciation and amortization expense		12	11
Total cost of sales		228	161
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 loss		203	198
Renewable Diesel [Member] | Intersegment Eliminations [Member]
Segment Information for our Reportable Segments
Revenues		79	53
Ethanol [Member]
Segment Information for our Reportable Segments
Revenues		985	811
Ethanol [Member] | Operating Segments [Member]
Segment Information for our Reportable Segments
Revenues		1,045	875
Cost of sales:
Cost of materials and other		924	813
LCM inventory valuation adjustment			128
Operating expenses (excluding depreciation and amortization expense reflected below)		156	109
Depreciation and amortization expense		21	22
Total cost of sales		1,101	1,072
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 loss		(56)	(197)
Ethanol [Member] | Intersegment Eliminations [Member]
Segment Information for our Reportable Segments
Revenues		$ 60	$ 64

[1] Includes excise taxes on sales by certain of our international operations of $1,120 million and $1,368 million for the three months ended March 31, 2021 and 2020, respectively.

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Revenues and Segment Information, Disaggregation of Revenue by Product (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2021	Mar. 31, 2020
Revenue by Segment
Revenues	[1]	$ 20,806	$ 22,102
Refining [Member]
Revenue by Segment
Revenues		19,469	20,985
Refining [Member] | Gasoline and Blendstocks [Member]
Revenue by Segment
Revenues		8,729	8,244
Refining [Member] | Distillates [Member]
Revenue by Segment
Revenues		8,581	10,663
Refining [Member] | Other Product Revenues [Member]
Revenue by Segment
Revenues		2,159	2,078
Renewable Diesel [Member]
Revenue by Segment
Revenues		352	306
Renewable Diesel [Member] | Renewable Diesel [Member]
Revenue by Segment
Revenues		352	306
Ethanol [Member]
Revenue by Segment
Revenues		985	811
Ethanol [Member] | Ethanol [Member]
Revenue by Segment
Revenues		752	629
Ethanol [Member] | Distillers Grains [Member]
Revenue by Segment
Revenues		$ 233	$ 182

[1] Includes excise taxes on sales by certain of our international operations of $1,120 million and $1,368 million for the three months ended March 31, 2021 and 2020, respectively.

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Revenues and Segment Information, Assets (Details) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Total Assets by Reportable Segment
Reportable segment assets	$ 53,614	$ 51,774
Corporate and Eliminations [Member]
Total Assets by Reportable Segment
Reportable segment assets	4,281	5,448
Refining [Member] | Operating Segments [Member]
Total Assets by Reportable Segment
Reportable segment assets	45,649	42,939
Renewable Diesel [Member] | Operating Segments [Member]
Total Assets by Reportable Segment
Reportable segment assets	1,948	1,659
Ethanol [Member] | Operating Segments [Member]
Total Assets by Reportable Segment
Reportable segment assets	$ 1,736	$ 1,728

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Supplemental Cash Flow Information (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2021	Mar. 31, 2020
Decrease (increase) in current assets:
Receivables, net		$ (2,946)	$ 2,968
Inventories		175	627
Prepaid expenses and other		(24)	(8)
Increase (decrease) in current liabilities:
Accounts payable		2,992	(4,222)
Accrued expenses		105	(79)
Taxes other than income taxes payable		(144)	(241)
Income taxes payable		26	(152)
Changes in current assets and current liabilities		184	(1,107)
Cash Flows Related to Interest and Income Taxes
Interest paid in excess of amount capitalized, including interest on finance leases		103	88
Income taxes paid, net		36	121
Operating cash flows
Operating Leases		100	106
Finance Leases		18	22
Financing cash flows
Finance Leases		31	15
Changes in lease balances resulting from new and modified leases, Operating Leases	[1]	72	92
Changes in lease balances resulting from new and modified leases, Finance Leases	[1]	$ 7	1,441
Supplemental Cash Flow Information (Textual)
Decrease in receivables as a result of decrease in commodity prices and sales volumes			3,400
Increase in income taxes receivable			430
MVP Terminal [Member]
Financing cash flows
Changes in lease balances resulting from new and modified leases, Finance Leases			$ 1,400

[1] Noncash activity for the three months ended March 31, 2020 primarily included $1.4 billion for a finance lease right-of-use asset and related liability recognized in connection with the terminaling agreement with MVP.

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Fair Value Measurements, Recurring (Details) - Fair Value, Recurring [Member] - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Assets
Total gross fair value, assets	$ 489	$ 498
Effect of counterparty netting	(386)	(373)
Effect of cash collateral netting	0	(18)
Net carrying value on Balance Sheet, assets	103	107
Liabilities
Environmental credit obligations	62	96
Total gross fair value, liabilities	506	505
Effect of counterparty netting	(386)	(373)
Effect of cash collateral netting	(58)	(32)
Net carrying value on Balance Sheet, liabilities	62	100
Assets Held in Trust [Member]
Assets
Investments of certain benefit plans	83	82
Commodity Contracts [Member]
Assets
Derivative contracts	386	403
Effect of counterparty netting	(386)	(373)
Effect of cash collateral netting	0	(18)
Derivative contracts, net assets	0	12
Cash collateral received not offset	0	0
Liabilities
Derivative contracts	444	405
Effect of counterparty netting	(386)	(373)
Effect of cash collateral netting	(58)	(32)
Derivative contracts, net liabilities	0	0
Cash collateral paid not offset	(120)	(44)
Physical Purchase Contracts [Member]
Assets
Derivative contracts	10	13
Derivative contracts, net assets	10	13
Foreign Currency Contracts [Member]
Assets
Derivative contracts	10
Derivative contracts, net assets	10
Liabilities
Derivative contracts		4
Derivative contracts, net liabilities		4
Fair Value, Inputs, Level 1 [Member]
Assets
Total gross fair value, assets	471	477
Liabilities
Environmental credit obligations	0	0
Total gross fair value, liabilities	444	409
Fair Value, Inputs, Level 1 [Member] | Assets Held in Trust [Member]
Assets
Investments of certain benefit plans	75	74
Fair Value, Inputs, Level 1 [Member] | Commodity Contracts [Member]
Assets
Derivative contracts	386	403
Liabilities
Derivative contracts	444	405
Fair Value, Inputs, Level 1 [Member] | Physical Purchase Contracts [Member]
Assets
Derivative contracts	0	0
Fair Value, Inputs, Level 1 [Member] | Foreign Currency Contracts [Member]
Assets
Derivative contracts	10
Liabilities
Derivative contracts		4
Fair Value, Inputs, Level 2 [Member]
Assets
Total gross fair value, assets	10	13
Liabilities
Environmental credit obligations	62	96
Total gross fair value, liabilities	62	96
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	10	13
Fair Value, Inputs, Level 2 [Member] | Foreign Currency Contracts [Member]
Assets
Derivative contracts	0
Liabilities
Derivative contracts		0
Fair Value, Inputs, Level 3 [Member]
Assets
Total gross fair value, assets	8	8
Liabilities
Environmental credit 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	8	8
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	0	0
Fair Value, Inputs, Level 3 [Member] | Foreign Currency Contracts [Member]
Assets
Derivative contracts	$ 0
Liabilities
Derivative contracts		$ 0

XML

Fair Value Measurements, Nonrecurring (Details) - Fair Value, Nonrecurring [Member] - USD ($)	Mar. 31, 2021	Dec. 31, 2020
Fair Value Measurements (Textual)
Assets measured at fair value, nonrecurring	$ 0	$ 0
Liabilities measured at fair value, nonrecurring	$ 0	$ 0

XML

Fair Value Measurements, Other Financial Instruments (Details) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Financial assets
Cash and cash equivalents, at carrying amount	$ 2,254	$ 3,313
Financial liabilities
Debt (excluding finance leases), at carrying amount	13,024	13,013
Fair Value, Inputs, Level 1 [Member]
Financial assets
Cash and cash equivalents, at fair value	2,254	3,313
Fair Value, Inputs, Level 2 [Member]
Financial liabilities
Debt (excluding finance leases), at fair value	$ 14,776	$ 15,103

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Price Risk Management Activities (Details) bu in Thousands, $ in Millions	3 Months Ended
	Mar. 31, 2021 USD ($) MBbls bu	Mar. 31, 2020 USD ($)
Price Risk Management Activities (Textual)
Compliance program costs | $	$ 18,992	$ 19,952
Environmental Compliance Program Price Risk [Member]
Price Risk Management Activities (Textual)
Compliance program costs | $	$ 360	$ 112
Derivatives Designated as Hedges [Member] | Cash Flow Hedges [Member] | Future, 2021 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	427
Derivatives Designated as Hedges [Member] | Cash Flow Hedges [Member] | Future, 2021 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	1,605
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	0
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	0
Derivatives Designated as Economic Hedges [Member] | Future, 2021 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	66,513
Derivatives Designated as Economic Hedges [Member] | Future, 2021 Maturity [Member] | Long (Purchases) [Member] | Corn (in thousands of bushels) [Member]
Volume of Outstanding Contracts
Nonmonetary notional amount of price risk derivatives, volume | bu	63,630
Derivatives Designated as Economic Hedges [Member] | Future, 2021 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	56,880
Derivatives Designated as Economic Hedges [Member] | Future, 2021 Maturity [Member] | Short (Sales) [Member] | Corn (in thousands of bushels) [Member]
Volume of Outstanding Contracts
Nonmonetary notional amount of price risk derivatives, volume | bu	90,395
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	64
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	10
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	22
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	365
Derivatives Designated as Economic Hedges [Member] | Physical Contracts, 2021 Maturity [Member] | Long (Purchases) [Member] | Corn (in thousands of bushels) [Member]
Volume of Outstanding Contracts
Nonmonetary notional amount of price risk derivatives, volume | bu	26,563
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	351
Derivatives Designated as Economic Hedges [Member] | Foreign Exchange Contract, US Dollars [Member]
Price Risk Management Activities (Textual)
Monetary notional amount of derivative liabilities | $	$ 245
Derivatives Designated as Economic Hedges [Member] | Foreign Exchange Contract, US Dollar Equivalent Canadian Dollars [Member]
Price Risk Management Activities (Textual)
Monetary notional amount of derivative liabilities | $	2,800
Derivatives Designated as Economic Hedges [Member] | Foreign Exchange Contract, Maturity on or Before April 27, 2021 [Member]
Price Risk Management Activities (Textual)
Monetary notional amount of derivative liabilities | $	1,000
Derivatives Designated as Economic Hedges [Member] | Foreign Exchange Contract, Maturity by July 15, 2021 [Member]
Price Risk Management Activities (Textual)
Monetary notional amount of derivative liabilities | $	$ 2,000

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Price Risk Management Activities, Hedging Instruments by Consolidated Balance Sheet Location (Details) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Derivatives Designated as Hedging Instruments [Member] | Commodity Contracts [Member] | Receivable, Net [Member]
Fair Values of Derivative Instruments
Derivative asset, fair value, gross asset	$ 5	$ 4
Derivative asset, fair value, gross liability	10	17
Derivatives Not Designated as Hedging Instruments [Member]
Fair Values of Derivative Instruments
Derivative asset, fair value, gross asset	401	412
Derivative liability, fair value, gross liability	434	392
Derivatives Not Designated as Hedging Instruments [Member] | Commodity Contracts [Member] | Receivable, Net [Member]
Fair Values of Derivative Instruments
Derivative asset, fair value, gross asset	381	399
Derivative asset, fair value, gross liability	434	388
Derivatives Not Designated as Hedging Instruments [Member] | Physical Purchase Contracts [Member] | Inventories [Member]
Fair Values of Derivative Instruments
Derivative asset, fair value, gross asset	10	13
Derivative asset, fair value, gross liability	0	0
Derivatives Not Designated as Hedging Instruments [Member] | Foreign Currency Contracts [Member] | Receivable, Net [Member]
Fair Values of Derivative Instruments
Derivative asset, fair value, gross asset	10	0
Derivative asset, fair value, gross liability	0	0
Derivatives Not Designated as Hedging Instruments [Member] | Foreign Currency Contracts [Member] | Accrued Expenses [Member]
Fair Values of Derivative Instruments
Derivative liability, fair value, gross asset	0	0
Derivative liability, fair value, gross liability	$ 0	$ 4

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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, 2021	Mar. 31, 2020
Commodity Contracts [Member]
Effect of Derivative Instruments on Income
Gain (loss) recognized in other comprehensive income (loss) on derivatives	$ (13)	$ 55
Commodity Contracts [Member] | Revenues [Member]
Effect of Derivative Instruments on Income
Gain (loss) reclassified from accumulated other comprehensive loss into income	(23)	26
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	(8)
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	(78)	(152)
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	(2)
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	(8)	49
Foreign Currency Contracts [Member] | Other Income, Net [Member] | Derivatives Not Designated as Hedging Instruments [Member]
Effect of Derivative Instruments on Income
Gain (loss) recognized in income on derivatives	$ 30	$ (165)