10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

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

For the quarterly period ended March 31, 2019

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 001-35054

Marathon Petroleum Corporation

(Exact name of registrant as specified in its charter)

Delaware	27-1284632
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)
539 South Main Street, Findlay, Ohio	45840-3229
(Address of principal executive offices)	(Zip code)

(419) 422-2121

(Registrant’s telephone number, including area code)

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  x    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  x    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	x	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  x

Securities registered pursuant to Section 12(b) of the Act
Title of each class	Trading symbol(s)	Name of each exchange on which registered
Common Stock, par value $.01	MPC	New York Stock Exchange

There were 662,618,001 shares of Marathon Petroleum Corporation common stock outstanding as of May 3, 2019.

MARATHON PETROLEUM CORPORATION

FORM 10-Q

FOR THE QUARTERLY PERIOD ENDED MARCH 31, 2019

TABLE OF CONTENTS

	Page
PART I – FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS (UNAUDITED)
CONSOLIDATED STATEMENTS OF INCOME	3
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME	4
CONSOLIDATED BALANCE SHEETS	5
CONSOLIDATED STATEMENTS OF CASH FLOWS	6
CONSOLIDATED STATEMENTS OF EQUITY AND REDEEMABLE NONCONTROLLING INTEREST	7
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS	8
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	31
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	54
ITEM 4. CONTROLS AND PROCEDURES	55
PART II – OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS	56
ITEM 1A. RISK FACTORS	56
ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS	56
ITEM 5. OTHER INFORMATION	57
ITEM 6. EXHIBITS	58
SIGNATURES	59

Unless otherwise stated or the context otherwise indicates, all references in this Form 10-Q to “MPC,” “us,” “our,” “we” or “the Company” mean Marathon Petroleum Corporation and its consolidated subsidiaries.

1

GLOSSARY OF TERMS

Throughout this report, the following company or industry specific terms and abbreviations are used:

ANS	Alaskan North Slope crude oil, an oil index benchmark price
ASC	Accounting Standards Codification
ASU	Accounting Standards Update
barrel	One stock tank barrel, or 42 United States gallons liquid volume, used in reference to crude oil or other liquid hydrocarbons
bcf/d	One billion cubic feet per day
CARB	California Air Resources Board
CARBOB	California Reformulated Gasoline Blendstock for Oxygenate Blending
CBOB	Conventional Blending for Oxygenate Blending
EBITDA (a non-GAAP financial measure)	Earnings Before Interest, Tax, Depreciation and Amortization
EPA	United States Environmental Protection Agency
FASB	Financial Accounting Standards Board
GAAP	Accounting principles generally accepted in the United States
IDR	Incentive Distribution Right
LCM	Lower of cost or market
LIFO	Last in, first out, an inventory costing method
LLS	Louisiana Light Sweet crude oil, an oil index benchmark price
mbpd	Thousand barrels per day
MMBtu	One million British thermal units, an energy measurement
MMcf/d	One million cubic feet of natural gas per day
NGL	Natural gas liquids, such as ethane, propane, butanes and natural gasoline
NYMEX	New York Mercantile Exchange
OPEC	Organization of Petroleum Exporting Countries
OTC	Over-the-Counter
ppm	Parts per million
RIN	Renewable Identification Number
SEC	United States Securities and Exchange Commission
ULSD	Ultra-low sulfur diesel
USGC	U.S. Gulf Coast
VIE	Variable interest entity
WTI	West Texas Intermediate crude oil, an oil index benchmark price

2

PART I – FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

MARATHON PETROLEUM CORPORATION

CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)

	Three Months Ended  March 31,
(Millions of dollars, except per share data)	2019			2018
Revenues and other income:
Sales and other operating revenues	$	28,081		$	18,694
Sales to related parties	186			172
Income from equity method investments	99			86
Net gain on disposal of assets	214			2
Other income	35			30
Total revenues and other income	28,615			18,984
Costs and expenses:
Cost of revenues (excludes items below)	25,756			17,370
Purchases from related parties	204			141
Depreciation and amortization	919			528
Selling, general and administrative expenses	881			402
Other taxes	186			103
Total costs and expenses	27,946			18,544
Income from operations	669			440
Net interest and other financial costs	306			183
Income before income taxes	363			257
Provision for income taxes	104			22
Net income	259			235
Less net income attributable to:
Redeemable noncontrolling interest	20			16
Noncontrolling interests	246			182
Net income (loss) attributable to MPC	$	(7	)	$	37
Per Share Data (See Note 7)
Basic:
Net income (loss) attributable to MPC per share	$	(0.01	)	$	0.08
Weighted average shares outstanding	673			476
Diluted:
Net income (loss) attributable to MPC per share	$	(0.01	)	$	0.08
Weighted average shares outstanding	673			480

The accompanying notes are an integral part of these consolidated financial statements.

3

MARATHON PETROLEUM CORPORATION

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended  March 31,
(Millions of dollars)	2019			2018
Net income	$	259		$	235
Other comprehensive income (loss):
Defined benefit postretirement and post-employment plans:
Actuarial changes, net of tax of $6 and $3, respectively	(3		)	7
Prior service costs, net of tax of ($8) and ($2), respectively	(3		)	(7		)
Other, net of tax of $0 and ($1), respectively	(1		)	(2		)
Other comprehensive loss	(7		)	(2		)
Comprehensive income	252			233
Less comprehensive income attributable to:
Redeemable noncontrolling interest	20			16
Noncontrolling interests	246			182
Comprehensive income (loss) attributable to MPC	$	(14	)	$	35

The accompanying notes are an integral part of these consolidated financial statements.

4

MARATHON PETROLEUM CORPORATION

CONSOLIDATED BALANCE SHEETS

(Unaudited)

(Millions of dollars, except share data)	March 31, 2019			December 31, 2018
Assets
Current assets:
Cash and cash equivalents	$	877		$	1,687
Receivables, less allowance for doubtful accounts of $9 and $9, respectively	6,893			5,853
Inventories	9,833			9,837
Other current assets	548			646
Total current assets	18,151			18,023
Equity method investments	6,558			5,898
Property, plant and equipment, net	45,091			45,058
Goodwill	20,229			20,184
Right of use assets	2,680			—
Other noncurrent assets	3,727			3,777
Total assets	$	96,436		$	92,940
Liabilities
Current liabilities:
Accounts payable	$	10,568		$	9,366
Payroll and benefits payable	958			1,152
Accrued taxes	1,529			1,446
Debt due within one year	550			544
Operating lease liabilities	613			—
Other current liabilities	929			708
Total current liabilities	15,147			13,216
Long-term debt	27,565			26,980
Deferred income taxes	5,011			4,864
Defined benefit postretirement plan obligations	1,567			1,509
Long-term operating lease liabilities	2,153			—
Deferred credits and other liabilities	1,131			1,318
Total liabilities	52,574			47,887
Commitments and contingencies (see Note 24)
Redeemable noncontrolling interest	1,004			1,004
Equity
MPC stockholders’ equity:
Preferred stock, no shares issued and outstanding (par value $0.01 per share, 30 million shares authorized)	—			—
Common stock:
Issued – 976 million and 975 million shares (par value $0.01 per share, 2 billion shares authorized)	10			10
Held in treasury, at cost – 309 million and 295 million shares	(14,063		)	(13,175		)
Additional paid-in capital	33,764			33,729
Retained earnings	14,391			14,755
Accumulated other comprehensive loss	(151		)	(144		)
Total MPC stockholders’ equity	33,951			35,175
Noncontrolling interests	8,907			8,874
Total equity	42,858			44,049
Total liabilities, redeemable noncontrolling interest and equity	$	96,436		$	92,940

The accompanying notes are an integral part of these consolidated financial statements.

5

MARATHON PETROLEUM CORPORATION

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	Three Months Ended  March 31,
(Millions of dollars)	2019			2018
Operating activities:
Net income	$	259		$	235
Adjustments to reconcile net income to net cash provided by operating activities:
Amortization of deferred financing costs and debt discount	—			18
Depreciation and amortization	919			528
Pension and other postretirement benefits, net	52			32
Deferred income taxes	127			(19		)
Net gain on disposal of assets	(214		)	(2		)
Income from equity method investments	(99		)	(86		)
Distributions from equity method investments	148			89
Changes in the fair value of derivative instruments	29			(14		)
Changes in operating assets and liabilities, net of effects of businesses acquired:
Current receivables	(1,037		)	96
Inventories	(4		)	440
Current accounts payable and accrued liabilities	1,483			(1,455		)
Right of use assets/operating leases	(1		)	—
All other, net	(39		)	1
Net cash provided by (used in) operating activities	1,623			(137		)
Investing activities:
Additions to property, plant and equipment	(1,241		)	(755		)
Acquisitions, net of cash acquired	1			—
Disposal of assets	24			7
Investments – acquisitions, loans and contributions	(325		)	(41		)
– redemptions, repayments and return of capital	2			—
All other, net	19			11
Net cash used in investing activities	(1,520		)	(778		)
Financing activities:
Long-term debt – borrowings	2,604			9,610
– repayments	(2,031		)	(5,264		)
Debt issuance costs	—			(53		)
Issuance of common stock	2			12
Common stock repurchased	(885		)	(1,327		)
Dividends paid	(354		)	(219		)
Distributions to noncontrolling interests	(325		)	(195		)
Contributions from noncontrolling interests	95			1
All other, net	(26		)	(8		)
Net cash provided by (used in) financing activities	(920		)	2,557
Net increase (decrease) in cash, cash equivalents and restricted cash	(817		)	1,642
Cash, cash equivalents and restricted cash at beginning of period	1,725			3,015
Cash, cash equivalents and restricted cash at end of period	$	908		$	4,657

The accompanying notes are an integral part of these consolidated financial statements.

6

MARATHON PETROLEUM CORPORATION

CONSOLIDATED STATEMENTS OF EQUITY AND REDEEMBALE NONCONTROLLING INTEREST

(Unaudited)

	MPC Stockholders’ Equity
	Common Stock			Treasury Stock					Additional Paid-in Capital		Retained Earnings			Accumulated Other Comprehensive Income (Loss)			Non-controlling Interests			Total Equity			Redeemable Non-controlling Interest
(Shares in millions; amounts in millions of dollars)	Shares	Amount		Shares		Amount
Balance as of December 31, 2018	975	$	10	(295	)	$	(13,175	)	$	33,729	$	14,755		$	(144	)	$	8,874		$	44,049		$	1,004
Net income (loss)	—	—		—		—			—		(7		)	—			246			239			20
Dividends declared on common stock ($0.53 per share)	—	—		—		—			—		(357		)	—			—			(357		)	—
Distributions to noncontrolling interests	—	—		—		—			—		—			—			(305		)	(305		)	(20		)
Contributions from noncontrolling interests	—	—		—		—			—		—			—			95			95			—
Other comprehensive loss	—	—		—		—			—		—			(7		)	—			(7		)	—
Shares repurchased	—	—		(14	)	(885		)	—		—			—			—			(885		)	—
Stock based compensation	1	—		—		(3		)	32		—			—			(1		)	28			—
Impact from equity transactions of MPLX & ANDX	—	—		—		—			3		—			—			(1		)	2			—
Other	—	—		—		—			—		—			—			(1		)	(1		)	—
Balance as of March 31, 2019	976	$	10	(309	)	$	(14,063	)	$	33,764	$	14,391		$	(151	)	$	8,907		$	42,858		$	1,004
Balance as of December 31, 2017	734	$	7	(248	)	$	(9,869	)	$	11,262	$	12,864		$	(231	)	$	6,795		$	20,828		$	1,000
Cumulative effect of adopting new accounting standards	—	—		—		—			—		63			—			1			64			—
Net income	—	—		—		—			—		37			—			182			219			16
Dividends declared on common stock ($0.46 per share)	—	—		—		—			—		(219		)	—			—			(219		)	—
Distributions to noncontrolling interests	—	—		—		—			—		—			—			(179		)	(179		)	(16		)
Contributions from noncontrolling interests	—	—		—		—			—		—			—			1			1			—
Other comprehensive loss	—	—		—		—			—		—			(2		)	—			(2		)	—
Shares repurchased	—	—		(19	)	(1,327		)	—		—			—			—			(1,327		)	—
Stock based compensation	—	—		—		(4		)	27		—			—			1			24			—
Impact from equity transactions of MPLX & ANDX	—	—		—		—			2,380		—			—			(2,926		)	(546		)	—
Balance as of March 31, 2018	734	$	7	(267	)	$	(11,200	)	$	13,669	$	12,745		$	(233	)	$	3,875		$	18,863		$	1,000

The accompanying notes are an integral part of these consolidated financial statements.

7

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

1. DESCRIPTION OF THE BUSINESS AND BASIS OF PRESENTATION

Description of the Business

We are a leading, integrated, downstream energy company headquartered in Findlay, Ohio. We operate the nation's largest refining system with more than 3 million barrels per day of crude oil capacity across 16 refineries. We sell refined products to wholesale marketing customers domestically and internationally, to buyers on the spot market, to consumers through our Retail business segment and to independent entrepreneurs who operate approximately 6,900 branded outlets. Our retail operations own and operate approximately 3,920 retail transportation fuel and convenience stores across the United States and also sell transportation fuel to consumers through approximately 1,060 direct dealer locations under long-term supply contracts. MPC’s midstream operations are primarily conducted through MPLX LP (“MPLX”) and Andeavor Logistics LP (“ANDX”), which own and operate crude oil and light product transportation and logistics infrastructure as well as gathering, processing, and fractionation assets. We own the general partner and majority limited partner interest in these two midstream companies.

Refer to Note 4 for further information on the Andeavor acquisition, which closed on October 1, 2018, and to Notes 3 and 9 for additional information about our operations.

Basis of Presentation

All significant intercompany transactions and accounts have been eliminated.

These interim consolidated financial statements are unaudited; however, in the opinion of our management, these statements reflect all adjustments necessary for a fair statement of the results for the periods reported. All such adjustments are of a normal, recurring nature unless otherwise disclosed. These interim consolidated financial statements, including the notes, have been prepared in accordance with the rules of the SEC applicable to interim period financial statements and do not include all of the information and disclosures required by GAAP for complete financial statements.

These interim consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2018. The results of operations for the three months ended March 31, 2019 are not necessarily indicative of the results to be expected for the full year.

2. ACCOUNTING STANDARDS

Recently Adopted

ASU 2016-02, Leases

We adopted ASU No. 2016-02, Leases (“ASC 842”), as of January 1, 2019, electing the transition method which permits entities to adopt the provisions of the standard using the modified retrospective approach without adjusting comparative periods. We also elected the package of practical expedients permitted under the transition guidance within the new standard, which among other things, allowed us to grandfather the historical accounting conclusions until a reassessment event is present. We have also elected the practical expedient to not recognize short-term leases on the balance sheet, the practical expedient related to right of way permits and land easements which allows us to carry forward our accounting treatment for those existing agreements, and the practical expedient to combine lease and non-lease components for the majority of our underlying classes of assets except for our third-party contractor service and equipment agreements and boat and barge equipment agreements in which we are the lessee. We did not elect the practical expedient to combine lease and non-lease components for arrangements in which we are the lessor. In instances where the practical expedient was not elected, lease and non-lease consideration is allocated based on relative standalone selling price.

Right of use (“ROU”) assets represent our right to use an underlying asset in which we obtain substantially all of the economic benefits and the right to direct the use of the asset during the lease term. Lease liabilities represent our obligation to make lease payments arising from the lease. Operating lease ROU assets and lease liabilities are recognized at commencement date based on the present value of lease payments over the lease term. We recognize ROU assets and lease liabilities on the balance sheet for leases with a lease term of greater than one year. Payments that are not fixed at the commencement of the lease are considered variable and are excluded from the ROU asset and lease liability calculations. In the measurement of our ROU assets and lease liabilities, the fixed lease payments in the agreement are discounted using a secured incremental borrowing rate for a term similar to the duration of the lease, as our leases do not provide implicit rates. Operating lease expense is recognized on a straight-line basis over the lease term.

8

Adoption of the new standard resulted in the recording of ROU assets and lease liabilities of approximately $2.79 billion and $2.88 billion, respectively, as of January 1, 2019. The standard did not materially impact our consolidated statements of income, cash flows or equity as a result of adoption.

As a lessor under ASC 842, MPLX may be required to re-classify existing operating leases to sales-type leases upon modification and related reassessment of the leases. If such a modification were to occur, it may result in the de-recognition of existing assets, recognition of a receivable in the amount of the present value of fixed payments expected to be received by MPLX under the lease, and recognition of a corresponding gain or loss in the period of change. MPLX will evaluate the impact of a lease reassessment as modifications occur.

We also adopted the following ASUs during the first three months of 2019, none of which had a material impact to our financial statements or financial statement disclosures:

ASU		Effective Date
2018-02	Reporting Comprehensive Income - Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income	January 1, 2019
2017-12	Derivatives and Hedging - Targeted Improvements to Accounting for Hedging Activities	January 1, 2019

Not Yet Adopted

ASU 2017-04, Intangibles - Goodwill and Other - Simplifying the Test for Goodwill Impairment

In January 2017, the FASB issued an ASU which simplifies the subsequent measurement of goodwill by eliminating Step 2 from the goodwill impairment test. Under the new guidance, the recognition of an impairment charge is calculated based on the amount by which the carrying amount exceeds the reporting unit’s fair value, which could be different from the amount calculated under the current method using the implied fair value of the goodwill; however, the loss recognized should not exceed the total amount of goodwill allocated to that reporting unit. The guidance should be applied on a prospective basis, and is effective for annual or any interim goodwill impairment tests in fiscal years beginning after December 15, 2019.

ASU 2016-13, Credit Losses - Measurement of Credit Losses on Financial Instruments

In June 2016, the FASB issued an ASU related to the accounting for credit losses on certain financial instruments. The guidance requires that for most financial assets, losses be based on an expected loss approach which includes estimates of losses over the life of exposure that considers historical, current and forecasted information. Expanded disclosures related to the methods used to estimate the losses as well as a specific disaggregation of balances for financial assets are also required. The change is effective for fiscal years beginning after December 15, 2019, and interim periods within those fiscal years, with early adoption permitted for fiscal years beginning after December 15, 2018, and interim periods within those fiscal years. We do not expect application of this ASU to have a material impact on our consolidated financial statements.

3. MASTER LIMITED PARTNERSHIPS

MPLX

MPLX is a diversified, large-cap publicly traded limited partnership formed by us to own, operate, develop and acquire midstream energy infrastructure assets. MPLX is engaged in the transportation, storage and distribution of crude oil and refined petroleum products; gathering, processing and transportation of natural gas; and the gathering, transportation, fractionation, storage and marketing of NGLs. As of March 31, 2019, we owned 64 percent of the outstanding MPLX common units and we control MPLX through our ownership of the general partner of MPLX.

Dropdowns to MPLX and GP/IDR Exchange

On February 1, 2018, we contributed refining logistics assets and fuels distribution services to MPLX in exchange for $4.1 billion in cash and approximately 112 million common units and 2 million general partner units from MPLX. MPLX financed the cash portion of the transaction with its $4.1 billion364-day term loan facility, which was entered into on January 2, 2018. We agreed to waive approximately one-third of the first quarter 2018 distributions on the common units issued in connection with this transaction. The contributions of these assets were accounted for as transactions between entities under common control and we did not record a gain or loss.

Immediately following the February 1, 2018 dropdown to MPLX, our IDRs were cancelled and our economic general partner interest was converted into a non-economic general partner interest, all in exchange for 275 million newly issued MPLX common units (“GP/IDR Exchange”). As a result of this transaction, the general partner units and IDRs were eliminated, are no longer outstanding and no longer participate in distributions of cash from MPLX.

9

Agreements

We have various long-term, fee-based commercial agreements with MPLX. Under these agreements, MPLX provides transportation, storage, distribution and marketing services to us. Under certain agreements, we commit to provide MPLX with minimum throughput and distribution volumes of crude oil and refined products and minimum storage volumes of crude oil, refined products and butane. Under certain other agreements, we commit to pay for substantially all of the available capacity for certain marine transportation and refining logistics assets. These transactions are eliminated in consolidation, but are reflected as intersegment transactions between our Refining & Marketing and Midstream segments. We also have agreements with MPLX that establish fees for operational and management services provided between us and MPLX and for executive management services and certain general and administrative services provided by us to MPLX. These transactions are eliminated in consolidation, but are reflected as intersegment transactions between our Corporate and Midstream segments.

ANDX

Through the Andeavor acquisition, we acquired control of ANDX, which is a publicly traded limited partnership that was formed to own, operate, develop and acquire logistics assets. Its assets are integral to the success of our refining and marketing operations and are used to gather crude oil, natural gas, and water, process natural gas and distribute, transport and store crude oil and refined products. ANDX provides us with various pipeline transportation, trucking, terminal distribution, storage and petroleum-coke handling services under long-term, fee-based commercial agreements. With certain exceptions, these agreements generally contain minimum volume commitments. These transactions are eliminated in consolidation, but are reflected as intersegment transactions between our Refining & Marketing and Midstream segments. We also have agreements with ANDX that establish fees for operational and management services provided between us and ANDX and for executive management services and certain general and administrative services provided by us to ANDX. These transactions are eliminated in consolidation, but are reflected as intersegment transactions between our Corporate and Midstream segments.

As of March 31, 2019, we owned 64 percent of the outstanding ANDX common units. We also hold 80,000 ANDX TexNew Mex Units as of March 31, 2019 and control ANDX through our ownership of the general partner of ANDX.

Noncontrolling Interest

As a result of equity transactions of MPLX and ANDX, we are required to adjust non-controlling interest and additional paid-in capital. Changes in MPC’s additional paid-in capital resulting from changes in its ownership interests in MPLX and ANDX were as follows:

	Three Months Ended  March 31,
(In millions)	2019			2018
Increase due to the issuance of MPLX common units and general partner units to MPC	$	—		$	1,114
Increase due to GP/IDR Exchange	—			1,808
Increase due to the issuance of MPLX & ANDX common units	4			4
Increase in MPC's additional paid-in capital	4			2,926
Tax impact	(1		)	(546		)
Increase in MPC's additional paid-in capital, net of tax	$	3		$	2,380

4. ACQUISITIONS

Acquisition of Andeavor

On October 1, 2018, we acquired all the outstanding shares of Andeavor. The total value of consideration transferred was $23.46 billion, consisting of $19.97 billion in equity and $3.49 billion in cash. The cash portion of the purchase price was funded using cash on hand. Our financial results reflect the results of Andeavor from the date of the acquisition.

We accounted for the Andeavor acquisition using the acquisition method of accounting, which requires Andeavor assets and liabilities to be recorded to our balance sheet at fair value as of the acquisition date. We will complete a final determination of the fair value of certain assets and liabilities within the one year measurement period from the date of the acquisition as required by FASB ASC Topic 805, “Business Combinations”. Due to the level of effort required to develop fair value measurements, the valuation studies necessary to determine the fair value of assets acquired and liabilities assumed are preliminary, including the underlying cash flows used to determine the fair value of identified intangible assets and economic obsolescence adjustments to property, plant and equipment. The size and the breadth of the Andeavor acquisition necessitates the use of the one year measurement period to fully analyze all the factors used in establishing the asset and liability fair values as of the acquisition date, including, but not limited to, property, plant and equipment, intangible assets, real property, leases,

10

environmental and asset retirement obligations and the related tax impacts of any changes made. Any potential adjustments made could be material in relation to the preliminary values.

During the three months ended March 31, 2019, we recorded adjustments to the preliminary fair value estimates of assets acquired and liabilities assumed as of the acquisition date as noted in the table below.

(In millions)	As originally reported		Adjustments			As adjusted
Cash and cash equivalents	$	382	$	—		$	382
Receivables	2,744		(2		)	2,742
Inventories	5,204		(8		)	5,196
Other current assets	378		—			378
Equity method investments	865		—			865
Property, plant and equipment, net	16,545		(1		)	16,544
Other noncurrent assets(a)	3,086		—			3,086
Total assets acquired	29,204		(11		)	29,193
Accounts payable	4,003		—			4,003
Payroll and benefits payable	348		—			348
Accrued taxes	590		—			590
Debt due within one year	34		—			34
Other current liabilities	392		23			415
Long-term debt	8,875		1			8,876
Deferred income taxes	1,609		22			1,631
Defined benefit postretirement plan obligations	432		—			432
Deferred credit and other liabilities	714		6			720
Noncontrolling interests	5,059		3			5,062
Total liabilities and noncontrolling interest assumed	22,056		55			22,111
Net assets acquired excluding goodwill	7,148		(66		)	7,082
Goodwill	16,314		66			16,380
Net assets acquired	$	23,462	$	—		$	23,462

^(a)  Includes intangible assets.

The preliminary purchase consideration allocation resulted in the recognition of $16.38 billion in goodwill, of which $893 million is tax deductible due to a carryover basis from Andeavor. Our Refining & Marketing, Midstream and Retail segments recognized $4.78 billion, $7.72 billion and $3.88 billion of preliminary goodwill. The recognized goodwill represents the value expected to be created by further optimization of crude supply, a nationwide retail and marketing platform, diversification of our refining and midstream footprints and optimization of information systems and business processes.

Pro Forma Financial Information

The following unaudited pro forma financial information presents consolidated results assuming the Andeavor acquisition occurred on January 1, 2017. The unaudited pro forma information does not give effect to potential synergies that could result from the transaction and is not necessarily indicative of the results of future operations.

	Three Months Ended  March 31,
(In millions)	2018
Sales and other operating revenues	$	29,206
Net income attributable to MPC	26

The pro forma information includes adjustments to align accounting policies, including our policy to expense refinery turnarounds when they occur, an adjustment to depreciation expense to reflect the increased fair value of property, plant and equipment, increased amortization expense related to identifiable intangible assets and the related income tax effects.

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Acquisition of Express Mart

During the fourth quarter of 2018, Speedway acquired 78 transportation fuel and convenience store locations from Petr-All Petroleum Consulting Corporation for total consideration of $266 million. These stores are located primarily in the Syracuse, Rochester and Buffalo markets in New York and had been operated under the Express Mart brand.

Based on the final fair value estimates of assets acquired and liabilities assumed at the acquisition date, $97 million of the purchase price was allocated to property, plant and equipment, $9 million to inventory, $2 million to intangibles and $158 million to goodwill. Goodwill is tax deductible and represents the value expected to be created by geographically expanding our retail platform and the assembled workforce. These operations are accounted for within the Retail segment.

Acquisition of Mt. Airy Terminal

On September 26, 2018, MPLX acquired an eastern U.S. Gulf Coast export terminal (“Mt. Airy Terminal”) from Pin Oak Holdings, LLC for total consideration of $451 million. At the time of the acquisition, the terminal included tanks with 4 million barrels of third-party leased storage capacity and a dock with 120 mbpd of capacity. The Mt. Airy Terminal is located on the Mississippi River between New Orleans and Baton Rouge, near several Gulf Coast refineries, including our Garyville Refinery, and numerous rail lines and pipelines. The Mt. Airy Terminal is accounted for within the Midstream segment. In the first quarter of 2019, an adjustment to the initial purchase price was made for approximately $5 million related to the final settlement of the acquisition. This reduced the total purchase price to $446 million and resulted in $336 million of property, plant and equipment, $121 million of goodwill and the remainder being attributable to net liabilities assumed.

Goodwill represents the significant growth potential of the terminal due to the multiple pipelines and rail lines which cross the property, the terminal’s position as an aggregation point for liquids growth in the region for both ocean-going vessels and inland barges, the proximity of the terminal to MPC’s Garyville refinery and other refineries in the region as well as the opportunity to construct an additional dock at the site. All of the goodwill recognized related to this transaction is tax deductible.

Assuming the acquisitions of Express Mart and Mt. Airy Terminal had occurred on January 1, 2017, the consolidated pro forma results would not have been materially different from the reported results.

5. VARIABLE INTEREST ENTITIES

Consolidated VIEs

We control MPLX and ANDX through our ownership of the general partner of both entities. MPLX and ANDX are VIEs because the limited partners do not have substantive kick-out or substantive participating rights over the general partner. We are the primary beneficiary of both MPLX and ANDX because in addition to our significant economic interest, we also have the ability, through our ownership of the general partner, to control the decisions that most significantly impact MPLX and ANDX. We therefore consolidate MPLX and ANDX and record a noncontrolling interest for the interest owned by the public. We also record a redeemable noncontrolling interest related to MPLX’s preferred units.

The creditors of MPLX and ANDX do not have recourse to MPC’s general credit through guarantees or other financial arrangements, except as noted. MPC has effectively guaranteed certain indebtedness of LOOP LLC (“LOOP”) and LOCAP LLC (“LOCAP”), in which MPLX holds an interest. See Note 24 for more information. Western Refining Southwest, Inc., a wholly-owned subsidiary of MPC and unitholder of ANDX, has guaranteed certain outstanding borrowings under the ANDX dropdown credit facility that were made in connection with the August 2018 dropdown transaction.

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The assets of MPLX and ANDX can only be used to settle their own obligations and their creditors have no recourse to our assets, except as noted above. The following table present balance sheet information for the assets and liabilities of MPLX and ANDX, which are included in our balance sheets.

	March 31, 2019				December 31, 2018
(In millions)	MPLX		ANDX(a)		MPLX		ANDX(a)
Assets
Cash and cash equivalents	$	93	$	29	$	68	$	10
Receivables, less allowance for doubtful accounts	372		248		425		199
Inventories	74		21		77		22
Other current assets	34		37		45		57
Equity method investments	4,270		602		4,174		602
Property, plant and equipment, net	14,816		6,882		14,639		6,845
Goodwill	2,581		1,052		2,586		1,051
Right of use assets	262		122		—		—
Other noncurrent assets	448		1,235		458		1,242
Liabilities
Accounts payable	$	583	$	177	$	776	$	215
Payroll and benefits payable	4		1		2		10
Accrued taxes	40		20		48		23
Debt due within one year	1		503		1		504
Operating lease liabilities	46		12		—		—
Other current liabilities	189		117		177		77
Long-term debt	13,832		4,629		13,392		4,469
Deferred income taxes	12		1		13		1
Long-term operating lease liabilities	216		109		—		—
Deferred credits and other liabilities	289		66		276		68

^(a)  The balances reflected here are ANDX’s historical balances as the preliminary purchase accounting adjustments related to ANDX’s assets and liabilities in connection with the Andeavor acquisition and reflected on our consolidated balance sheets as of December 31, 2018 and March 31, 2019 have not yet been pushed down to this subsidiary.

6. RELATED PARTY TRANSACTIONS

Transactions with related parties were as follows:

	Three Months Ended  March 31,
(In millions)	2019		2018
Sales to related parties(a)	$	186	$	172
Purchases from related parties(b)	204		141

^(a)   Sales to related parties consists primarily of sales of refined products to PFJ Southeast, an equity affiliate which owns and operates travel plazas primarily in the Southeast region of the United States.

^(b)   We obtain utilities, transportation services and purchase ethanol from certain of our equity affiliates.

Summarized financial information, in the aggregate, for our significant equity method investments on a 100 percent basis were as follows:

	Three Months Ended  March 31,
(In millions)	2019		2018
Revenues and other income	$	1,628	$	1,503
Income from operations	336		254
Net income	314		274

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7. INCOME (LOSS) PER COMMON SHARE

We compute basic earnings per share by dividing net income attributable to MPC less income allocated to participating securities by the weighted average number of shares of common stock outstanding. Since MPC grants certain incentive compensation awards to employees and non-employee directors that are considered to be participating securities, we have calculated our earnings per share using the two-class method. Diluted income per share assumes exercise of certain stock-based compensation awards, provided the effect is not anti-dilutive.

	Three Months Ended  March 31,
(In millions, except per share data)	2019			2018
Basic earnings (loss) per share:
Allocation of earnings:
Net income (loss) attributable to MPC	$	(7	)	$	37
Income allocated to participating securities	—			—
Income (loss) available to common stockholders – basic	$	(7	)	$	37
Weighted average common shares outstanding	673			476
Basic earnings (loss) per share	$	(0.01	)	$	0.08
Diluted earnings (loss) per share:
Allocation of earnings:
Net income (loss) attributable to MPC	$	(7	)	$	37
Income allocated to participating securities	—			—
Income (loss) available to common stockholders – diluted	$	(7	)	$	37
Weighted average common shares outstanding	673			476
Effect of dilutive securities	—			4
Weighted average common shares, including dilutive effect	673			480
Diluted earnings (loss) per share	$	(0.01	)	$	0.08

The following table summarizes the shares that were anti-dilutive and, therefore, were excluded from the diluted share calculation.

	Three Months Ended  March 31,
(In millions)	2019	2018
Shares issuable under stock-based compensation plans	7	—

8. EQUITY

As of March 31, 2019, we had $4.02 billion of share repurchase authorization remaining under authorizations from our board of directors. We may utilize various methods to effect the repurchases, which could include open market repurchases, negotiated block transactions, accelerated share repurchases or open market solicitations for shares, some of which may be effected through Rule 10b5-1 plans. The timing and amount of future repurchases, if any, will depend upon several factors, including market and business conditions, and such repurchases may be discontinued at any time.

Total share repurchases were as follows:

	Three Months Ended  March 31,
(In millions, except per share data)	2019		2018
Number of shares repurchased	14		19
Cash paid for shares repurchased	$	885	$	1,327
Average cost per share	$	62.98	$	68.74

As of March 31, 2019, we had agreements to acquire 493,625 common shares for $30 million, which settled in early April 2019.

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9. SEGMENT INFORMATION

We have three reportable segments: Refining & Marketing; Retail; and Midstream. Each of these segments is organized and managed based upon the nature of the products and services it offers.

• Refining & Marketing – refines crude oil and other feedstocks at our 16 refineries in the West Coast, Mid-Continent and Gulf Coast regions of the United States, purchases refined products and ethanol for resale and distributes refined products through transportation, storage, distribution and marketing services provided largely by our Midstream segment. We sell refined products to wholesale marketing customers domestically and internationally, to buyers on the spot market, to our Retail business segment and to independent entrepreneurs who operate primarily Marathon^® branded outlets.

• Retail – sells transportation fuels and convenience products in the retail market across the United States through company-owned and operated convenience stores, primarily under the Speedway^® brand, and long-term fuel supply contracts with direct dealers who operate locations primarily under the ARCO^® brand.

• Midstream – transports, stores, distributes and markets crude oil and refined products principally for the Refining & Marketing segment via refining logistics assets, pipelines, terminals, towboats and barges; gathers, processes and transports natural gas; and gathers, transports, fractionates, stores and markets NGLs. The Midstream segment primarily reflects the results of MPLX and ANDX, our sponsored master limited partnerships.

Segment income represents income from operations attributable to the reportable segments. Corporate administrative expenses, except for those attributable to MPLX and ANDX, and costs related to certain non-operating assets are not allocated to the Refining & Marketing and Retail segments. In addition, certain items that affect comparability (as determined by the chief operating decision maker) are not allocated to the reportable segments.

(In millions)	Refining & Marketing			Retail		Midstream		Total
Three Months Ended March 31, 2019
Revenues:
Third party	$	19,751		$	7,373	$	957	$	28,081
Intersegment	4,429			2		1,232		5,663
Related party	183			3		—		186
Segment revenues	$	24,363		$	7,378	$	2,189	$	33,930
Segment income (loss) from operations	$	(334	)	$	170	$	908	$	744
Income from equity method investments	1			17		81		99
Depreciation and amortization(a)	427			126		307		860
Capital expenditures and investments(b)	394			73		823		1,290

(In millions)	Refining & Marketing			Retail		Midstream		Total
Three Months Ended March 31, 2018
Revenues:
Third party	$	13,412		$	4,569	$	713	$	18,694
Intersegment	2,379			1		631		3,011
Related party	170			2		—		172
Segment revenues	$	15,961		$	4,572	$	1,344	$	21,877
Segment income (loss) from operations	$	(133	)	$	95	$	567	$	529
Income from equity method investments	3			14		69		86
Depreciation and amortization(a)	252			79		181		512
Capital expenditures and investments(b)	191			39		482		712

^(a)  Differences between segment totals and MPC consolidated totals represent amounts related to corporate and other unallocated items and are included in items not allocated to segments in the reconciliation below.

^(b)  Capital expenditures include changes in capital accruals and investments in affiliates. See reconciliation from segment totals to MPC consolidated total capital expenditures below.

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The following reconciles segment income from operations to income before income taxes as reported in the consolidated statements of income:

	Three Months Ended  March 31,
(In millions)	2019			2018
Segment income from operations	$	744		$	529
Items not allocated to segments:
Corporate and other unallocated items(a)	(191		)	(89		)
Capline restructuring gain(b)	207			—
Transaction-related costs(c)	(91		)	—
Income from operations	669			440
Net interest and other financial costs	306			183
Income before income taxes	$	363		$	257

^(a)  Corporate and other unallocated items consists primarily of MPC’s corporate administrative expenses and costs related to certain non-operating assets, except for corporate overhead expenses attributable to MPLX and ANDX, which are included in the Midstream segment. Corporate overhead expenses are not allocated to the Refining & Marketing and Retail segments.

^(b)  See Note 13.

^(c)  The transaction-related costs recognized in the first quarter largely relate to the recognition of an obligation for vacation benefits provided to former Andeavor employees.

The following reconciles segment capital expenditures and investments to total capital expenditures:

	Three Months Ended  March 31,
(In millions)	2019		2018
Segment capital expenditures and investments	$	1,290	$	712
Less investments in equity method investees	325		41
Plus items not allocated to segments:
Corporate	10		18
Capitalized interest	31		18
Total capital expenditures(a)	$	1,006	$	707

^(a)  Capital expenditures include changes in capital accruals. See Note 19 for a reconciliation of total capital expenditures to additions to property, plant and equipment as reported in the consolidated statements of cash flows.

10. NET INTEREST AND OTHER FINANCIAL COSTS

Net interest and other financial costs were as follows:

	Three Months Ended  March 31,
(In millions)	2019			2018
Interest income	$	(9	)	$	(20	)
Interest expense	340			213
Interest capitalized	(32		)	(18		)
Pension and other postretirement non-service costs(a)	(3		)	—
Loss on extinguishment of debt	—			4
Other financial costs	10			4
Net interest and other financial costs	$	306		$	183

^(a)  See Note 21.

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11. INCOME TAXES

The combined federal, state and foreign income tax rate was 29 percent and 9 percent for the three months ended March 31, 2019 and 2018, respectively. The effective tax rate for the three months ended March 31, 2019 was greater than the U.S. statutory rate of 21 percent primarily due to $36 million of state deferred tax expense recorded as an out of period adjustment, partially offset by permanent tax differences related to net income attributable to noncontrolling interests. The effective tax rate for the three months ended March 31, 2018 was less than the U.S. statutory rate primarily due to certain permanent tax differences related to net income attributable to noncontrolling interests, state and local deferred tax benefits primarily resulting from the February 1 dropdown and GP/IDR Exchange and equity compensation.

During the first quarter of 2019, MPC’s deferred tax liabilities increased $68 million with an offsetting increase to goodwill and the provision for income taxes of $32 million and $36 million, respectively for an out of period adjustment to correct the tax effects recorded in 2018 related to the Andeavor acquisition. The impact of the adjustment was not material to any previous period.

We are continuously undergoing examination of our income tax returns, which have been completed through the 2005 tax year for state returns and the 2008 tax year for our U.S. federal return. As of March 31, 2019, we had $231 million of unrecognized tax benefits.

Prior to its spinoff on June 30, 2011, Marathon Petroleum Corporation was included in the Marathon Oil Corporation (“Marathon Oil”) U.S. federal income tax returns for all applicable years. During the third quarter of 2017, Marathon Oil received a notice of Final Partnership Administrative Adjustment (“FPAA”) from the U.S. Internal Revenue Service for taxable year 2010, relating to certain partnership transactions. Marathon Oil filed a U.S. Tax Court petition disputing these adjustments during the fourth quarter of 2017. We received an FPAA for taxable years 2011-2014 for items resulting from this matter and filed a U.S. Tax Court petition for tax years 2011-2014 to dispute these corollary adjustments in the fourth quarter of 2017. We continue to believe that the issue in dispute is more likely than not to be fully sustained and, therefore, no liability has been accrued for this matter.

Pursuant to our tax sharing agreement with Marathon Oil, the unrecognized tax benefits related to pre-spinoff operations for which Marathon Oil was the taxpayer remain the responsibility of Marathon Oil and we have indemnified Marathon Oil accordingly. See Note 24 for indemnification information.

12. INVENTORIES

(In millions)	March 31, 2019		December 31, 2018
Crude oil and refinery feedstocks	$	3,689	$	3,655
Refined products	5,186		5,234
Materials and supplies	744		720
Merchandise	214		228
Total	$	9,833	$	9,837

Inventories are carried at the lower of cost or market value. The cost of inventories of crude oil and refinery feedstocks, refined products and merchandise is determined primarily under the LIFO method. There were no LIFO inventory liquidations recognized for the three months ended March 31, 2019.

13. EQUITY METHOD INVESTMENTS

During the three months ended March 31, 2019, we executed agreements with Capline Pipeline LLC (“Capline LLC”) to contribute our 33 percent undivided interest in Capline pipeline system in exchange for a 33 percent ownership interest in Capline LLC. Concurrent with our execution of these agreements, Capline LLC initiated a binding open season for southbound service from Patoka, IL to St. James, LA or Liberty, MS, with an additional origination point at Cushing, OK. Service from Cushing, OK is part of a joint tariff with Diamond pipeline. Crude oil service is expected to begin in the third quarter of 2020.

In accordance with ASC 810 “Consolidation”, we derecognized our undivided interest amounting to $143 million of net assets and recognized the Capline LLC ownership interest we received at fair value. We used an income approach to determine the fair value of our ownership interest under a Monte Carlo simulation method. We determined the fair value of our ownership interest was estimated to be $350 million as of January 30, 2019. This is a nonrecurring fair value measurement and is categorized in level 3 of the fair value hierarchy. The Monte Carlo simulation inputs include ranges of tariff rates, operating

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volumes, operating cost and capital expenditure assumptions. The estimated cash flows were discounted using a Monte Carlo market participant weighted average cost of capital estimate. None of the inputs to the Monte Carlo simulation are individually significant. The excess of the estimated fair value of our ownership interest over the carrying value of the derecognized net assets resulted in a $207 million non cash net gain recorded as a net gain on disposal of assets in the accompanying consolidated statements of income.

As the Capline system is currently idled, Capline LLC is unable to fund its operations without financial support from its equity owners and is a VIE. MPC is not deemed to be the primary beneficiary, due to our inability to unilaterally control significant decision-making rights. Our maximum exposure to loss as a result of our involvement with Capline LLC includes our equity investment, any additional capital contribution commitments and any operating expenses incurred by Capline LLC in excess of compensation received for performance of the operating services.

14. PROPERTY, PLANT AND EQUIPMENT

(In millions)	March 31, 2019		December 31, 2018
Refining & Marketing	$	27,968	$	27,590
Retail	6,681		6,637
Midstream	25,929		25,692
Corporate and Other	1,304		1,294
Total	61,882		61,213
Less accumulated depreciation	16,791		16,155
Property, plant and equipment, net	$	45,091	$	45,058

15. FAIR VALUE MEASUREMENTS

Fair Values—Recurring

The following tables present assets and liabilities accounted for at fair value on a recurring basis as of March 31, 2019 and December 31, 2018 by fair value hierarchy level. We have elected to offset the fair value amounts recognized for multiple derivative contracts executed with the same counterparty, including any related cash collateral as shown below; however, fair value amounts by hierarchy level are presented on a gross basis in the following tables.

	March 31, 2019
	Fair Value Hierarchy
(In millions)	Level 1		Level 2		Level 3		Netting and Collateral(a)			Net Carrying Value on Balance Sheet(b)		Collateral Pledged Not Offset
Assets:
Commodity contracts	$	122	$	18	$	—	$	(128	)	$	12	$	42
Liabilities:
Commodity contracts	$	142	$	24	$	—	$	(161	)	$	5	$	—
Embedded derivatives in commodity contracts	—		—		65		—			65		—

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	December 31, 2018
	Fair Value Hierarchy
(In millions)	Level 1		Level 2		Level 3		Netting and Collateral(a)			Net Carrying Value on Balance Sheet(b)		Collateral Pledged Not Offset
Assets:
Commodity contracts	$	370	$	31	$	—	$	(323	)	$	78	$	2
Liabilities:
Commodity contracts	$	255	$	37	$	—	$	(284	)	$	8	$	—
Embedded derivatives in commodity contracts	—		—		61		—			61		—

^(a)  Represents the impact of netting assets, liabilities and cash collateral when a legal right of offset exists. As of March 31, 2019, cash collateral of $33 million was netted with the mark-to-market derivative liabilities. As of December 31, 2018, cash collateral of $52 million was netted with mark-to-market derivative assets and $13 million was netted with mark-to-market derivative liabilities.

^(b)  We have no derivative contracts that are subject to master netting arrangements reflected gross on the balance sheet.

Commodity derivatives in Level 1 are exchange-traded contracts for crude oil and refined products measured at fair value with a market approach using the close-of-day settlement prices for the market. Commodity derivatives are covered under master netting agreements with an unconditional right to offset. Collateral deposits in futures commission merchant accounts covered by master netting agreements related to Level 1 commodity derivatives are classified as Level 1 in the fair value hierarchy.

Level 2 instruments are valued based on quoted prices for similar assets and liabilities in active markets, and inputs other than quoted prices, such as liquidity, that are observable for the asset or liability. Commodity derivatives in Level 2 are OTC contracts, which are valued using market quotations from independent price reporting agencies, third-party brokers and commodity exchange price curves that are corroborated with market data.

Level 3 instruments are OTC NGL contracts and embedded derivatives in commodity contracts. The embedded derivative liability relates to a natural gas purchase agreement embedded in a keep‑whole processing agreement. The fair value calculation for these Level 3 instruments at March 31, 2019 used significant unobservable inputs including: (1) NGL prices interpolated and extrapolated due to inactive markets ranging from $0.60 to $1.25 per gallon and (2) the probability of renewal of 91 percent for the first five-year term and 82 percent for the second five-year term of the natural gas purchase agreement and the related keep-whole processing agreement. For these contracts, increases in forward NGL prices result in a decrease in the fair value of the derivative assets and an increase in the fair value of the derivative liabilities. Increases or decreases in the fractionation spread result in an increase or decrease in the fair value of the embedded derivative liability. An increase in the probability of renewal would result in an increase in the fair value of the related embedded derivative liability.

The following is a reconciliation of the beginning and ending balances recorded for net liabilities classified as Level 3 in the fair value hierarchy.

	Three Months Ended  March 31,
(In millions)	2019			2018
Beginning balance	$	61		$	66
Unrealized and realized losses included in net income	6			(3		)
Settlements of derivative instruments	(2		)	(3		)
Ending balance	$	65		$	60
The amount of total losses for the period included in earnings attributable to the change in unrealized losses relating to assets still held at the end of period:	$	5		$	(3	)

Fair Values – Reported

We believe the carrying value of our other financial instruments, including cash and cash equivalents, receivables, accounts payable and certain accrued liabilities, approximate fair value. Our fair value assessment incorporates a variety of considerations, including the short-term duration of the instruments and the expected insignificance of bad debt expense, which includes an evaluation of counterparty credit risk. The borrowings under our revolving credit facilities, which include variable interest rates, approximate fair value. The fair value of our fixed rate long-term debt is based on prices from recent trade activity and is categorized in level 3 of the fair value hierarchy. The carrying and fair values of our debt were approximately $27.6 billion and $28.5 billion at March 31, 2019, respectively, and approximately $27.0 billion and $26.5 billion at

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December 31, 2018, respectively. These carrying and fair values of our debt exclude the unamortized issuance costs which are netted against our total debt.

16. DERIVATIVES

For further information regarding the fair value measurement of derivative instruments, including any effect of master netting agreements or collateral, see Note 15. We do not designate any of our commodity derivative instruments as hedges for accounting purposes.

Derivatives that are not designated as accounting hedges may include commodity derivatives used to hedge price risk on (1) inventories, (2) fixed price sales of refined products, (3) the acquisition of foreign-sourced crude oil, (4) the acquisition of ethanol for blending with refined products, (5) the sale of NGLs and (6) the purchase of natural gas.

The following table presents the fair value of derivative instruments as of March 31, 2019 and December 31, 2018 and the line items in the balance sheets in which the fair values are reflected. The fair value amounts below are presented on a gross basis and do not reflect the netting of asset and liability positions permitted under the terms of our master netting arrangements including cash collateral on deposit with, or received from, brokers. We offset the recognized fair value amounts for multiple derivative instruments executed with the same counterparty in our financial statements when a legal right of offset exists. As a result, the asset and liability amounts below will not agree with the amounts presented in our consolidated balance sheets.

(In millions)	March 31, 2019
Balance Sheet Location	Asset		Liability
Commodity derivatives
Other current assets	$	139	$	160
Other current liabilities(a)	1		14
Deferred credits and other liabilities(a)	—		57

(In millions)	December 31, 2018
Balance Sheet Location	Asset		Liability
Commodity derivatives
Other current assets	$	400	$	283
Other current liabilities(a)	1		16
Deferred credits and other liabilities(a)	—		54

^(a)   Includes embedded derivatives.

The table below summarizes open commodity derivative contracts for crude oil, refined products and blending products as of March 31, 2019.

	Percentage of contracts that expire next quarter	Position
(Units in thousands of barrels)		Long	Short
Exchange-traded(a)
Crude oil	82.6%	49,844	58,466
Refined products	89.4%	11,373	9,945
Blending products	77.3%	4,688	4,866
OTC
Crude oil	—%	640	—
Blending products	—%	1,676	1,444

^(a)  Included in exchange-traded are spread contracts in thousands of barrels: Crude oil - 11,999 long and 3,980 short; Refined products - 300 long and 300 short; Blending products - 2,603 long and 2,506 short

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The following table summarizes the effect of all commodity derivative instruments in our consolidated statements of income:

	Loss
(In millions)	Three Months Ended March 31,
Income Statement Location	2019			2018
Sales and other operating revenues	$	(20	)	$	(1	)
Cost of revenues	(80		)	(27		)
Total	$	(100	)	$	(28	)

17. DEBT

Our outstanding borrowings at March 31, 2019 and December 31, 2018 consisted of the following:

(In millions)	March 31, 2019			December 31, 2018
Marathon Petroleum Corporation	$	9,120		$	9,114
MPLX LP	14,283			13,856
ANDX LP	5,168			5,010
Total debt	$	28,571		$	27,980
Unamortized debt issuance costs	(126		)	(128		)
Unamortized discount	(330		)	(328		)
Amounts due within one year	(550		)	(544		)
Total long-term debt due after one year	$	27,565		$	26,980

Available Capacity under our Facilities

(Dollars in millions)	Total Capacity		Outstanding Borrowings		Outstanding Letters of Credit		Available Capacity		Weighted Average Interest Rate		Expiration
MPC 364-day bank revolving credit facility	$	1,000	$	—	$	—	$	1,000	—		September 2019
MPC bank revolving credit facility	5,000		—		32		4,968		—		October 2023
MPLX bank revolving credit facility	2,250		425		3		1,822		3.92	%	July 2022
ANDX revolving & dropdown credit facilities(a)	2,100		1,404		—		696		4.32	%	January 2021
Trade receivables securitization facility	750		—		—		750		—		July 2019
	$	11,100	$	1,829	$	35	$	9,236

^(a)  Western Refining Southwest, Inc., a wholly-owned subsidiary of MPC and unitholder of ANDX, has guaranteed certain outstanding borrowings under the ANDX dropdown credit facility that were made in connection with the August 2018 dropdown transaction.

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18. REVENUE

The following table presents our revenues disaggregated by product line.

	Three Months Ended  March 31,
(In millions)	2019		2018
Refined products	$	24,653	$	16,158
Merchandise	1,464		1,130
Crude oil and refinery feedstocks	1,367		883
Midstream services, transportation and other	597		523
Sales and other operating revenues	$	28,081	$	18,694

Practical Expedients

On January 1, 2018, we adopted ASU 2014-09, Revenue - Revenue from Contracts with Customers (“ASC 606”). We elected the completed contract practical expedient and only applied ASC 606 to contracts that were not completed as of January 1, 2018.

We do not disclose information on the future performance obligations for any contract with expected duration of one year or less at inception. As of March 31, 2019, we do not have future performance obligations that are material to future periods.

Receivables

On the accompanying consolidated balance sheets, receivables, less allowance for doubtful accounts primarily consists of customer receivables. Significant, non-customer balances included in our receivables at March 31, 2019 include matching buy/sell receivables of $1.98 billion and income tax receivables of $76 million.

19. SUPPLEMENTAL CASH FLOW INFORMATION

	Three Months Ended  March 31,
(In millions)	2019		2018
Net cash provided by operating activities included:
Interest paid (net of amounts capitalized)	$	269	$	212
Net income taxes paid to taxing authorities	42		6
Cash paid for amounts included in the measurement of lease liabilities
Payments on operating leases	189		—
Interest payments under finance lease obligations	8		—
Net cash provided by financing activities included:
Principal payments under finance lease obligations	10		—
Non-cash investing and financing activities:
Right of use assets obtained in exchange for new operating lease obligations	31		—
Right of use assets obtained in exchange for new finance lease obligations	15		—
Contribution of net assets to Capline LLC(a)	143		—
Recognition of Capline LLC equity method investment(a)	350		—

^(a)  See Note 13.

(In millions)	March 31, 2019		December 31, 2018
Cash and cash equivalents	$	877	$	1,687
Restricted cash(a)	31		38
Cash, cash equivalents and restricted cash	$	908	$	1,725

^(a)  The restricted cash balance is included within other current assets on the consolidated balance sheets.

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The consolidated statements of cash flows exclude changes to the consolidated balance sheets that did not affect cash. The following is a reconciliation of additions to property, plant and equipment to total capital expenditures:

	Three Months Ended  March 31,
(In millions)	2019			2018
Additions to property, plant and equipment per the consolidated statements of cash flows	$	1,241		$	755
Asset retirement expenditures	—			1
Decrease in capital accruals	(235		)	(49		)
Total capital expenditures	$	1,006		$	707

20. ACCUMULATED OTHER COMPREHENSIVE LOSS

The following table shows the changes in accumulated other comprehensive loss by component. Amounts in parentheses indicate debits.

(In millions)	Pension Benefits			Other Benefits			Gain on Cash Flow Hedge			Workers Compensation		Total
Balance as of December 31, 2017	$	(190	)	$	(48	)	$	4		$	3	$	(231	)
Other comprehensive loss before reclassifications	—			—			(2		)	—		(2		)
Amounts reclassified from accumulated other comprehensive loss:
Amortization – prior service credit(a)	(8		)	(1		)	—			—		(9		)
– actuarial loss(a)	9			—			—			—		9
– settlement loss(a)	1			—			—			—		1
Other	—			—			—			—		—
Tax effect	(1		)	—			—			—		(1		)
Other comprehensive income (loss)	1			(1		)	(2		)	—		(2		)
Balance as of March 31, 2018	$	(189	)	$	(49	)	$	2		$	3	$	(233	)

(In millions)	Pension Benefits			Other Benefits			Gain on Cash Flow Hedge		Workers Compensation			Total
Balance as of December 31, 2018	$	(132	)	$	(23	)	$	2	$	9		$	(144	)
Other comprehensive loss before reclassifications	(1		)	—			—		—			(1		)
Amounts reclassified from accumulated other comprehensive loss:
Amortization – prior service credit(a)	(11		)	—			—		—			(11		)
– actuarial loss(a)	4			—			—		—			4
– settlement loss(a)	—			—			—		—			—
Other	—			—			—		(1		)	(1		)
Tax effect	2			—			—		—			2
Other comprehensive loss	(6		)	—			—		(1		)	(7		)
Balance as of March 31, 2019	$	(138	)	$	(23	)	$	2	$	8		$	(151	)

^(a)  These accumulated other comprehensive loss components are included in the computation of net periodic benefit cost. See Note 21.

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21. DEFINED BENEFIT PENSION AND OTHER POSTRETIREMENT PLANS

The following summarizes the components of net periodic benefit costs:

	Three Months Ended March 31,
	Pension Benefits						Other Benefits
(In millions)	2019			2018			2019		2018
Components of net periodic benefit cost:
Service cost	$	58		$	36		$	8	$	7
Interest cost	28			18			9		7
Expected return on plan assets	(32		)	(26		)	—		—
Amortization – prior service credit	(11		)	(8		)	—		(1		)
– actuarial loss	4			9			—		—
– settlement loss	—			1			—		—
Net periodic benefit cost	$	47		$	30		$	17	$	13

The components of net periodic benefit cost other than the service cost component are included in net interest and other financial costs on the consolidated statements of income.

During the three months ended March 31, 2019, we made no contributions to our funded pension plans. Benefit payments related to unfunded pension and other postretirement benefit plans were $3 million and $11 million, respectively, during the three months ended March 31, 2019.

22. STOCK-BASED COMPENSATION PLANS

Stock Option Awards

The following table presents a summary of our stock option award activity for the three months ended March 31, 2019:

	Number of Shares		Weighted Average Exercise Price
Outstanding at December 31, 2018	8,724,595		$	37.07
Granted	1,037,671		62.68
Exercised	(229,169	)	10.62
Forfeited or expired	—		—
Outstanding at March 31, 2019	9,533,097		40.49

The grant date fair value of stock option awards granted during the three months ended March 31, 2019 was $14.34 per share. The fair value of stock options granted to our employees is estimated on the date of the grant using the Black Scholes option-pricing model, which employs various assumptions.

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Restricted Stock and Restricted Stock Unit Awards

The following table presents a summary of restricted stock and restricted stock unit award activity for the three months ended March 31, 2019:

	Restricted Stock				Restricted Stock Units
	Number of Shares		Weighted Average Grant Date Fair Value		Number of Units		Weighted Average Grant Date Fair Value
Outstanding at December 31, 2018	990,700		$	57.23	4,226,856		$	80.96
Granted	158,120		62.66		8,050		59.56
Vested	(114,136	)	49.58		(1,110,705	)	82.43
Forfeited	(12,622	)	56.84		(46,923	)	82.43
Outstanding at March 31, 2019	1,022,062		58.93		3,077,278		80.35

Performance Unit Awards

The following table presents a summary of the activity for performance unit awards to be settled in shares for the three months ended March 31, 2019:

	Number of Units		Weighted Average Grant Date Fair Value
Outstanding at December 31, 2018	8,618,583		$	0.79
Granted	6,200,000		0.72
Vested	(2,280,333	)	0.57
Forfeited	(120,000	)	0.84
Outstanding at March 31, 2019	12,418,250		0.79

The performance unit awards granted during the three months ended March 31, 2019 have a grant date fair value of $0.72 per unit, as calculated using a Monte Carlo valuation model.

MPLX and ANDX Awards

Compensation expense for MPLX and ANDX equity awards was not material to our consolidated financial statements for the three months ended March 31, 2019.

23. LEASES

For further information regarding the adoption of ASC 842, including the method of adoption and practical expedients elected, see Note 2.

Lessee

We lease a wide variety of facilities and equipment including land and building space, office and field equipment, storage facilities and transportation equipment. Our remaining lease terms range from less than one year to 60 years. Most long-term leases include renewal options ranging from less than one year to 49 years and, in certain leases, also include purchase options. The lease term included in the measurement of right of use assets and lease liabilities includes options to extend or terminate our leases that we are reasonably certain to exercise. Options were included in the lease term primarily for retail store sites where we constructed property, plant and equipment on leased land that is expected to exist beyond the initial lease term.

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Under ASC 842, the components of lease cost were as follows:

	Three Months Ended  March 31,
(In millions)	2019
Finance lease cost:
Amortization of right of use assets	$	14
Interest on lease liabilities	10
Operating lease cost	190
Variable lease cost	15
Short-term lease cost	152
Total lease cost	$	381

Supplemental balance sheet data related to leases were as follows:

(In millions)	March 31, 2019
Operating leases
Assets
Right of use assets	$	2,680
Liabilities
Operating lease liabilities	$	613
Long-term operating lease liabilities	2,153
Total operating lease liabilities	$	2,766
Weighted average remaining lease term	6.5 years
Weighted average discount rate	4.13		%
Finance leases
Assets
Property, plant and equipment, gross	$	760
Accumulated depreciation	206
Property, plant and equipment, net	$	554
Liabilities
Debt due within one year	$	45
Long-term debt	612
Total finance lease liabilities	$	657
Weighted average remaining lease term	13.2 years
Weighted average discount rate	6.02		%

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As of March 31, 2019, maturities of lease liabilities for operating lease obligations and finance lease obligations having initial or remaining non-cancellable lease terms in excess of one year are as follows:

(In millions)	Operating		Finance
2019	$	554	$	57
2020	629		76
2021	545		69
2022	370		76
2023	262		83
2024 and thereafter	832		596
Gross lease payments	3,192		957
Less: imputed interest	426		300
Total lease liabilities	$	2,766	$	657

Presented in accordance with ASC 840, future minimum commitments as of December 31, 2018 for operating lease obligations and capital lease obligations having initial or remaining non-cancellable lease terms in excess of one year were as follows:

(In millions)	Operating		Capital
2019	$	709	$	70
2020	619		71
2021	553		66
2022	389		75
2023	295		82
2024 and thereafter	858		586
Total minimum lease payments	$	3,423	950
Less: imputed interest costs			301
Present value of net minimum lease payments			$	649

Lessor

MPLX has certain natural gas gathering, transportation and processing agreements in which it is considered to be the lessor under several implicit operating lease arrangements in accordance with GAAP. MPLX’s primary implicit lease operations relate to a natural gas gathering agreement in the Marcellus region for which it earns a fixed-fee for providing gathering services to a single producer using a dedicated gathering system. As the gathering system is expanded, the fixed-fee charged to the producer is adjusted to include the additional gathering assets in the lease. The primary term of the natural gas gathering arrangement expires in 2038 and will continue thereafter on a year-to-year basis until terminated by either party. Other significant implicit leases relate to a natural gas processing agreement in the Marcellus region and a natural gas processing agreement in the Southern Appalachia region for which MPLX earns minimum monthly fees for providing processing services to a single producer using a dedicated processing plant. The primary term of these natural gas processing agreements expire during 2023 and 2033.

MPLX did not elect to use the practical expedient to combine lease and non-lease components for lessor arrangements. The tables below represent the portion of the contract allocated to the lease component based on relative standalone selling price. Lessor agreements are currently deemed operating, as we elected the practical expedient to grandfather in old conclusions. We are still determining the impact of the new standard on these arrangements if and when a modification occurs and they are required to be assessed under ASC 842. MPLX may be required to re-classify existing operating leases to sales-type leases upon modification and related reassessment of the leases.

Our revenue from implicit lease arrangements, excluding executory costs, totaled approximately $60 million in the three months ended March 31, 2019. The implicit lease arrangements related to the processing facilities contain contingent rental provisions whereby we receive additional fees if the producer customer exceeds the monthly minimum processed volumes. During the three months ended March 31, 2019, MPLX did not receive any material contingent lease payments. The following is a schedule of minimum future rentals on the non‑cancellable operating leases as of March 31, 2019:

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(In millions)
2019	$	144
2020	168
2021	162
2022	160
2023	154
2024 and thereafter	1,205
Total minimum future rentals	$	1,993

The following schedule summarizes our investment in assets held for operating lease by major classes as of March 31, 2019:

(In millions)	March 31, 2019
Natural gas gathering and NGL transportation pipelines and facilities	$	1,036
Natural gas processing facilities	642
Terminal and related assets	112
Land, building, office equipment and other	41
Property, plant and equipment	1,831
Less accumulated depreciation	261
Property, plant and equipment, net	$	1,570

24. COMMITMENTS AND CONTINGENCIES

We are the subject of, or a party to, a number of pending or threatened legal actions, contingencies and commitments involving a variety of matters, including laws and regulations relating to the environment. Some of these matters are discussed below. For matters for which we have not recorded a liability, we are unable to estimate a range of possible loss because the issues involved have not been fully developed through pleadings, discovery or court proceedings. However, the ultimate resolution of some of these contingencies could, individually or in the aggregate, be material.

Environmental Matters

We are subject to federal, state, local and foreign laws and regulations relating to the environment. These laws generally provide for control of pollutants released into the environment and require responsible parties to undertake remediation of hazardous waste disposal sites and certain other locations including presently or formerly owned or operated retail marketing sites. Penalties may be imposed for noncompliance.

At March 31, 2019 and December 31, 2018, accrued liabilities for remediation totaled $451 million and $455 million, respectively. It is not presently possible to estimate the ultimate amount of all remediation costs that might be incurred or the penalties if any that may be imposed. Receivables for recoverable costs from certain states, under programs to assist companies in clean-up efforts related to underground storage tanks at presently or formerly owned or operated retail marketing sites, were $33 million and $35 million at March 31, 2019 and December 31, 2018, respectively.

Governmental and other entities in California, New York, Maryland and Rhode Island have filed lawsuits against coal, gas, oil and petroleum companies, including the Company. The lawsuits allege damages as a result of climate change and the plaintiffs are seeking unspecified damages and abatement under various tort theories. Similar lawsuits may be filed in other jurisdictions. At this early stage, the ultimate outcome of these matters remain uncertain, and neither the likelihood of an unfavorable outcome nor the ultimate liability, if any, can be determined.

We are involved in a number of environmental enforcement matters arising in the ordinary course of business. While the outcome and impact on us cannot be predicted with certainty, management believes the resolution of these environmental matters will not, individually or collectively, have a material adverse effect on our consolidated results of operations, financial position or cash flows.

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Lawsuits

In May 2015, the Kentucky attorney general filed a lawsuit against our wholly-owned subsidiary, Marathon Petroleum Company LP (“MPC LP”), in the United States District Court for the Western District of Kentucky asserting claims under federal and state antitrust statutes, the Kentucky Consumer Protection Act, and state common law. The complaint, as amended in July 2015, alleges that MPC LP used deed restrictions, supply agreements with customers and exchange agreements with competitors to unreasonably restrain trade in areas within Kentucky and seeks declaratory relief, unspecified damages, civil penalties, restitution and disgorgement of profits. At this stage, the ultimate outcome of this litigation remains uncertain, and neither the likelihood of an unfavorable outcome nor the ultimate liability, if any, can be determined, and we are unable to estimate a reasonably possible loss (or range of loss) for this matter. We intend to vigorously defend ourselves in this matter.

In May 2007, the Kentucky attorney general filed a lawsuit against us and Marathon Oil in state court in Franklin County, Kentucky for alleged violations of Kentucky’s emergency pricing and consumer protection laws following Hurricanes Katrina and Rita in 2005. The lawsuit alleges that we overcharged customers by $89 millionduring September and October 2005. The complaint seeks disgorgement of these sums, as well as penalties, under Kentucky’s emergency pricing and consumer protection laws. We are vigorously defending this litigation. We believe that this is the first lawsuit for damages and injunctive relief under the Kentucky emergency pricing laws to progress this far and it contains many novel issues. In May 2011, the Kentucky attorney general amended his complaint to include a request for immediate injunctive relief as well as unspecified damages and penalties related to our wholesale gasoline pricing in April and May 2011 under statewide price controls that were activated by the Kentucky governor on April 26, 2011 and which have since expired. The court denied the attorney general’s request for immediate injunctive relief, and the remainder of the 2011 claims likely will be resolved along with those dating from 2005. If the lawsuit is resolved unfavorably in its entirety, it could materially impact our consolidated results of operations, financial position or cash flows. However, management does not believe the ultimate resolution of this litigation will have a material adverse effect on our consolidated financial position, results of operations, or cash flows.

We are also a party to a number of other lawsuits and other proceedings arising in the ordinary course of business. While the ultimate outcome and impact to us cannot be predicted with certainty, we believe that the resolution of these other lawsuits and proceedings will not have a material adverse effect on our consolidated financial position, results of operations or cash flows.

Guarantees

We have provided certain guarantees, direct and indirect, of the indebtedness of other companies. Under the terms of most of these guarantee arrangements, we would be required to perform should the guaranteed party fail to fulfill its obligations under the specified arrangements. In addition to these financial guarantees, we also have various performance guarantees related to specific agreements.

Guarantees related to indebtedness of equity method investees—MPC and MPLX hold interests in an offshore oil port, LOOP, and MPLX holds an interest in a crude oil pipeline system, LOCAP. Both LOOP and LOCAP have secured various project financings with throughput and deficiency agreements. Under the agreements, MPC, as a shipper, is required to advance funds if the investees are unable to service their debt. Any such advances are considered prepayments of future transportation charges. The duration of the agreements vary but tend to follow the terms of the underlying debt, which extend through 2037. Our maximum potential undiscounted payments under these agreements for the debt principal totaled $171 million as of March 31, 2019.

In connection with MPLX’s approximate nine percent indirect interest in a joint venture that owns and operates the Dakota Access Pipeline and Energy Transfer Crude Oil Pipeline projects, collectively referred to as the Bakken Pipeline system, MPLX has entered into a Contingent Equity Contribution Agreement. MPLX, along with the other joint venture owners in the Bakken Pipeline system, have agreed to make equity contributions to the joint venture upon certain events occurring to allow the entities that own and operate the Bakken Pipeline system to satisfy their senior note payment obligations. The senior notes were issued to repay amounts owed by the pipeline companies to fund the cost of construction of the Bakken Pipeline system. As of March 31, 2019, our maximum potential undiscounted payments under the Contingent Equity Contribution Agreement was approximately $230 million.

In connection with our 50 percent indirect interest in Crowley Ocean Partners, we have agreed to conditionally guarantee our portion of the obligations of the joint venture and its subsidiaries under a senior secured term loan agreement. The term loan agreement provides for loans of up to $325 million to finance the acquisition of four product tankers. MPC’s liability under the guarantee for each vessel is conditioned upon the occurrence of certain events, including if we cease to maintain an investment grade credit rating or the charter for the relevant product tanker ceases to be in effect and is not replaced by a charter with an investment grade company on certain defined commercial terms. As of March 31, 2019, our maximum potential undiscounted payments under this agreement for debt principal totaled $135 million.

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In connection with our 50 percent indirect interest in Crowley Blue Water Partners, we have agreed to provide a conditional guarantee of up to 50 percent of its outstanding debt balance in the event there is no charter agreement in place with an investment grade customer for the entity’s three vessels as well as other financial support in certain circumstances. As of March 31, 2019, our maximum potential undiscounted payments under this arrangement was $125 million .

Marathon Oil indemnifications—In conjunction with our spinoff from Marathon Oil, we have entered into arrangements with Marathon Oil providing indemnities and guarantees with recorded values of $1 million as of March 31, 2019, which consist of unrecognized tax benefits related to MPC, its consolidated subsidiaries and the refining, marketing and transportation business operations prior to our spinoff which are not already reflected in the unrecognized tax benefits described in Note 11, and other contingent liabilities Marathon Oil may incur related to taxes. Furthermore, the separation and distribution agreement and other agreements with Marathon Oil to effect our spinoff provide for cross-indemnities between Marathon Oil and us. In general, Marathon Oil is required to indemnify us for any liabilities relating to Marathon Oil’s historical oil and gas exploration and production operations, oil sands mining operations and integrated gas operations, and we are required to indemnify Marathon Oil for any liabilities relating to Marathon Oil’s historical refining, marketing and transportation operations. The terms of these indemnifications are indefinite and the amounts are not capped.

Other guarantees—We have entered into other guarantees with maximum potential undiscounted payments totaling $123 million as of March 31, 2019, which primarily consist of a commitment to contribute cash to an equity method investee for certain catastrophic events, in lieu of procuring insurance coverage, a commitment to fund a share of the bonds issued by a government entity for construction of public utilities in the event that other industrial users of the facility default on their utility payments and leases of assets containing general lease indemnities and guaranteed residual values. See Note 5 for information regarding our guarantee of certain borrowings under the ANDX dropdown credit facility.

General guarantees associated with dispositions—Over the years, we have sold various assets in the normal course of our business. Certain of the related agreements contain performance and general guarantees, including guarantees regarding inaccuracies in representations, warranties, covenants and agreements, and environmental and general indemnifications that require us to perform upon the occurrence of a triggering event or condition. These guarantees and indemnifications are part of the normal course of selling assets. We are typically not able to calculate the maximum potential amount of future payments that could be made under such contractual provisions because of the variability inherent in the guarantees and indemnities. Most often, the nature of the guarantees and indemnities is such that there is no appropriate method for quantifying the exposure because the underlying triggering event has little or no past experience upon which a reasonable prediction of the outcome can be based.

Contractual Commitments and Contingencies

At March 31, 2019, our contractual commitments to acquire property, plant and equipment and advance funds to equity method investees totaled $1.06 billion.

Certain natural gas processing and gathering arrangements require us to construct natural gas processing plants, natural gas gathering pipelines and NGL pipelines and contain certain fees and charges if specified construction milestones are not achieved for reasons other than force majeure. In certain cases, certain producer customers may have the right to cancel the processing arrangements with us if there are significant delays that are not due to force majeure.

25. SUBSEQUENT EVENT

On May 8, 2019, MPC, MPLX and ANDX announced that MPLX and ANDX have entered into a definitive merger agreement whereby MPLX will acquire ANDX in a unit-for-unit transaction. Under the terms of the merger agreement, ANDX public unitholders will receive 1.135 MPLX common units for each ANDX common unit held and MPC will receive 1.0328 MPLX common units for each ANDX common unit held. As described in Notes 4 and 5, we consolidate ANDX in accordance with ASC 810 and previously recorded ANDX’s assets and liabilities to our balance sheet at preliminary fair values as of the Andeavor acquisition date of October 1, 2018. Upon closing of this merger, we will account for the unit-for-unit transaction as a common control transaction, which will result in a change in our noncontrolling interest and additional paid-in capital.

The transaction has been approved by MPLX’s and ANDX’s respective Conflicts Committees and both Boards of Directors. Subject to the satisfaction of customary closing conditions and receipt of regulatory approvals, the transaction is expected to close in the second half of 2019.

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

This section should also be read in conjunction with the unaudited consolidated financial statements and accompanying footnotes included under Item 1. Financial Statements and in conjunction with our Annual Report on Form 10-K for the year ended December 31, 2018.

All statements in this section, other than statements of historical fact, are forward-looking statements that are inherently uncertain. You can identify our forward-looking statements by words such as “anticipate,” “believe,” “could,” “design,” “estimate,” “expect,” “forecast,” “goal,” “guidance,” “imply,” “intend,” “may,” “objective,” “opportunity,” “outlook,” “plan,” “position,” “potential,” “predict,” “project,” “prospective,” “pursue,” “seek,” “should,” “strategy,” “target,” “will,” “would” or other similar expressions that convey the uncertainty of future events or outcomes. In accordance with “safe harbor” provisions of the Private Securities Litigation Reform Act of 1995, these statements are accompanied by cautionary language identifying important factors, though not necessarily all such factors, that could cause future outcomes to differ materially from those set forth in the forward-looking statements.

Forward-looking statements include, but are not limited to, statements that relate to, or statements that are subject to risks, contingencies or uncertainties that relate to:

• the risk that the cost savings and any other synergies from the Andeavor acquisition may not be fully realized or may take longer to realize than expected;

• disruption from the Andeavor acquisition making it more difficult to maintain relationships with customers, employees or suppliers;

• risks relating to any unforeseen liabilities of Andeavor;

• the proposed transaction between MPLX LP and Andeavor Logistics LP;

• future levels of revenues, refining and marketing margins, operating costs, retail gasoline and distillate margins, merchandise margins, income from operations, net income or earnings per share;

• the regional, national and worldwide availability and pricing of refined products, crude oil, natural gas, NGLs and other feedstocks;

• consumer demand for refined products;

• our ability to manage disruptions in credit markets or changes to our credit rating;

• future levels of capital, environmental or maintenance expenditures, general and administrative and other expenses;

• the success or timing of completion of ongoing or anticipated capital or maintenance projects;

• the reliability of processing units and other equipment;

• business strategies, growth opportunities and expected investments;

• share repurchase authorizations, including the timing and amounts of any common stock repurchases;

• the adequacy of our capital resources and liquidity, including but not limited to, availability of sufficient cash flow to execute our business plan and to effect any share repurchases or dividend increases, including within the expected timeframe;

• the effect of restructuring or reorganization of business components;

• the potential effects of judicial or other proceedings on our business, financial condition, results of operations and cash flows;

• continued or further volatility in and/or degradation of general economic, market, industry or business conditions;

• compliance with federal and state environmental, economic, health and safety, energy and other policies and regulations, including the cost of compliance with the Renewable Fuel Standard, and/or enforcement actions initiated thereunder; and

• the anticipated effects of actions of third parties such as competitors, activist investors or federal, foreign, state or local regulatory authorities or plaintiffs in litigation.

Our forward-looking statements are not guarantees of future performance, and you should not rely unduly on them, as they involve risks, uncertainties and assumptions that we cannot predict. Material differences between actual results and any future performance suggested in our forward-looking statements could result from a variety of factors, including the following:

• volatility or degradation in general economic, market, industry or business conditions;

• availability and pricing of domestic and foreign supplies of natural gas, NGLs and crude oil and other feedstocks;

• the ability of the members of the OPEC to agree on and to influence crude oil price and production controls;

• availability and pricing of domestic and foreign supplies of refined products such as gasoline, diesel fuel, jet fuel, home heating oil and petrochemicals;

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• foreign imports and exports of crude oil, refined products, natural gas and NGLs;

• refining industry overcapacity or under capacity;

• changes in producer customers’ drilling plans or in volumes of throughput of crude oil, natural gas, NGLs, refined products or other hydrocarbon-based products;

• changes in the cost or availability of third-party vessels, pipelines, railcars and other means of transportation for crude oil, natural gas, NGLs, feedstocks and refined products;

• changes to our capital budget, expected construction costs and timing of projects;

• the price, availability and acceptance of alternative fuels and alternative-fuel vehicles and laws mandating such fuels or vehicles;

• fluctuations in consumer demand for refined products, natural gas and NGLs, including seasonal fluctuations;

• political and economic conditions in nations that consume refined products, natural gas and NGLs, including the United States, and in crude oil producing regions, including the Middle East, Africa, Canada and South America;

• actions taken by our competitors, including pricing adjustments, expansion of retail activities, the expansion and retirement of refining capacity and the expansion and retirement of pipeline capacity, processing, fractionation and treating facilities in response to market conditions;

• completion of pipeline projects within the United States;

• changes in fuel and utility costs for our facilities;

• failure to realize the benefits projected for capital projects, or cost overruns associated with such projects;

• modifications to MPLX and ANDX earnings and distribution growth objectives;

• the ability to successfully implement growth opportunities, including strategic initiatives and actions;

• risks and uncertainties associated with intangible assets, including any future goodwill or intangible assets impairment charges;

• the ability to realize the strategic benefits of joint venture opportunities;

• accidents or other unscheduled shutdowns affecting our refineries, machinery, pipelines, processing, fractionation and treating facilities or equipment, or those of our suppliers or customers;

• unusual weather conditions and natural disasters, which can unforeseeably affect the price or availability of crude oil and other feedstocks and refined products;

• acts of war, terrorism or civil unrest that could impair our ability to produce refined products, receive feedstocks or to gather, process, fractionate or transport crude oil, natural gas, NGLs or refined products;

• state and federal environmental, economic, health and safety, energy and other policies and regulations, including the cost of compliance with the renewable fuel standard program;

• adverse changes in laws including with respect to tax and regulatory matters;

• rulings, judgments or settlements and related expenses in litigation or other legal, tax or regulatory matters, including unexpected environmental remediation costs, in excess of any reserves or insurance coverage;

• political pressure and influence of environmental groups upon policies and decisions related to the production, gathering, refining, processing, fractionation, transportation and marketing of crude oil or other feedstocks, refined products, natural gas, NGLs or other hydrocarbon-based products;

• labor and material shortages;

• the maintenance of satisfactory relationships with labor unions and joint venture partners;

• the ability and willingness of parties with whom we have material relationships to perform their obligations to us;

• the market price of our common stock and its impact on our share repurchase authorizations;

• changes in the credit ratings assigned to our debt securities and trade credit, changes in the availability of unsecured credit, changes affecting the credit markets generally and our ability to manage such changes;

• capital market conditions and our ability to raise adequate capital to execute our business plan;

• the costs, disruption and diversion of management’s attention associated with campaigns commenced by activist investors; and

• the other factors described in Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended December 31, 2018.

We undertake no obligation to update any forward-looking statements except to the extent required by applicable law.

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CORPORATE OVERVIEW

We are a leading, integrated, downstream energy company. We own and operate the nation’s largest refining system with more than 3 million barrels per calendar day of crude oil capacity across 16 refineries, located in the West Coast, Mid-Continent and Gulf Coast regions of the United States. Our refineries supply refined products to wholesale marketing customers domestically and internationally, to buyers on the spot market, to consumers through our Retail business segment and to independent entrepreneurs who operate branded outlets. We believe we are one of the largest wholesale suppliers of gasoline and distillates to resellers in the United States.

We have three strong brands: Marathon^®, Speedway^® and ARCO^®. Approximately 6,900 branded outlets, primarily carrying the Marathon brand name, are operated by independent entrepreneurs in 35 states, the District of Columbia and Mexico. We believe our Retail segment operates the second largest chain of company-owned and operated retail transportation fuel and convenience stores in the United States, with approximately 3,920 convenience stores. Our Retail segment also sells transportation fuel to consumers through approximately 1,060 direct dealer locations. Our company-owned and operated locations primarily carry the Speedway^® brand name and the direct dealer locations carry the ARCO^® brand name.

We are one of the largest midstream operators in North America. We primarily conduct our midstream operations through our ownership interests in MPLX and ANDX, which own and operate crude oil and light product transportation and logistics infrastructure as well as gathering, processing, and fractionation assets. As of March 31, 2019, we owned, leased or had ownership interests in approximately 16,600 miles of crude oil and refined product pipelines to deliver crude oil to ourrefineries and other locations and refined products to wholesale and retail market areas. We distribute our refined products through one of the largest terminal operations in the United States and one of the largest private domestic fleets of inland petroleum product barges. Our integrated midstream gathering and processing network links producers of natural gas and NGLs from some of the largest supply basins in the United States to domestic and international markets. Our midstream gathering and processing operations include: natural gas gathering, processing and transportation; and NGL gathering, transportation, fractionation, storage and marketing. As of March 31, 2019, our assets include approximately 9.9 bcf/d of gathering capacity, 11.1bcf/d of natural gas processing capacity and 790 mbpd of fractionation capacity.

At March 31, 2019, our operations consisted of three reportable segments: Refining & Marketing; Retail; and Midstream. Each of these segments is organized and managed based upon the nature of the products and services it offers.

• Refining & Marketing – refines crude oil and other feedstocks at our 16 refineries in the West Coast, Mid-Continent and Gulf Coast regions of the United States, purchases refined products and ethanol for resale and distributes refined products through transportation, storage, distribution and marketing services provided largely by our Midstream segment. We sell refined products to wholesale marketing customers domestically and internationally, to buyers on the spot market, to our Retail business segment and to independent entrepreneurs who operate primarily Marathon^® branded outlets.

• Retail – sells transportation fuels and convenience products in the retail market across the United States through company-owned and operated convenience stores, primarily under the Speedway^® brand, and long-term fuel supply contracts with direct dealers who operate locations primarily under the ARCO^® brand.

• Midstream – transports, stores, distributes and markets crude oil and refined products principally for the Refining & Marketing segment via refining logistics assets, pipelines, terminals, towboats and barges; gathers, processes and transports natural gas; and gathers, transports, fractionates, stores and markets NGLs. The Midstream segment primarily reflects the results of MPLX and ANDX, our sponsored master limited partnerships.

Recent Developments

On May 8, 2019, MPC, MPLX and ANDX announced that MPLX and ANDX have entered into a definitive merger agreement whereby MPLX will acquire ANDX in a unit-for-unit transaction at a blended exchange ratio of 1.07x. Under the terms of the merger agreement, ANDX public unitholders will receive 1.135 MPLX common units for each ANDX common unit held, representing a premium of 7.3 percent, and MPC will receive 1.0328 MPLX common units for each ANDX common unit held, representing a 2.4 percent discount, based on May 2, 2019 closing prices. As described in Notes 4 and 5, we consolidate ANDX in accordance with ASC 810 and previously recorded ANDX’s assets and liabilities to our balance sheet at preliminary fair values as of the Andeavor acquisition date of October 1, 2018. Upon closing of this merger, we will account for the unit-for-unit transaction as a common control transaction, which will result in a change in our noncontrolling interest and additional paid-in capital.

The anticipated transaction simplifies MPLX and ANDX into a single listed entity to create a leading, large-scale, diversified midstream company anchored by fee-based cash flows. The combined entity will have an expanded geographic footprint that is expected to enhance its long-term growth opportunities and the sustainable cash flow profile of the business.

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The transaction has been approved by MPLX’s and ANDX’s respective Conflicts Committees and both Boards of Directors. Subject to the satisfaction of customary closing conditions and receipt of regulatory approvals, the transaction is expected to close in the second half of 2019.

The above discussion contains forward-looking statements with respect to the proposed transaction between MPLX and ANDX. Factors that could affect the proposed transaction between MPLX and ANDX include, but are not limited to, the ability to complete the proposed transaction between MPLX and ANDX on the proposed terms and timetable; the ability to satisfy various conditions to the closing of the transaction contemplated by the merger agreement; the ability to obtain regulatory approvals for the proposed transaction on the proposed terms and schedule, and any conditions imposed on the combined entity in connection with the consummation of the proposed transaction; the risk that anticipated opportunities and any other synergies from or anticipated benefits of the proposed transaction may not be fully realized or may take longer to realize than expected, including whether the proposed transaction will be accretive within the expected timeframe or at all; disruption from the proposed transaction making it more difficult to maintain relationships with customers, employees or suppliers; other risk factors inherent to MPLX’s and ANDX’s industry; and risks related to MPC. For additional information on forward-looking statements and risks that can affect our business, see “Disclosures Regarding Forward-Looking Statements” and “Risk Factors” herein, together with Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended December 31, 2018.

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EXECUTIVE SUMMARY

Results

Select results are reflected in the following table. Our results include the results of Andeavor from the October 1, 2018 acquisition date forward.

	Three Months Ended  March 31,
(In millions, except per share data)	2019			2018
Income (loss) from operations by segment
Refining & Marketing	$	(334	)	$	(133	)
Retail	170			95
Midstream	908			567
Items not allocated to segments	(75		)	(89		)
Income from operations	$	669		$	440
Net income (loss) attributable to MPC	$	(7	)	$	37
Net income (loss) attributable to MPC per diluted share	$	(0.01	)	$	0.08

Net income (loss) attributable to MPC was $(7) million, or $(0.01) per diluted share, in the first quarter of 2019 compared to $37 million, or $0.08 per diluted share, for the first quarter of 2018. Increased income from operations was more than offset by increased net interest and other financial costs, provision for income taxes and net income attributable to noncontrolling interests. Refer to the Results of Operations section for a discussion of consolidated financial results and segment results for the first quarter of 2019 as compared to the first quarter of 2018.

Andeavor Acquisition

On October 1, 2018, we completed the Andeavor acquisition. Andeavor stockholders received in the aggregate approximately 239.8 million shares of MPC common stock valued at $19.8 billion and approximately $3.5 billion in cash in connection with the Andeavor acquisition.

Andeavor was a highly integrated marketing, logistics and refining company operating primarily in the Western and Mid-Continent United States. Andeavor’s operations included procuring crude oil from its source or from other third parties, transporting the crude oil to one of its 10 refineries, and producing, marketing and distributing refined products. Its marketing system included more than 3,300 stations marketed under multiple well-known fuel brands including ARCO^®. Also, we acquired the general partner and 156 million common units of ANDX, which is a publicly traded limited partnership that was formed to own, operate, develop and acquire logistics assets. Its assets are integral to the success of our refining and marketing operations and are used to gather crude oil, natural gas, and water, process natural gas and distribute, transport and store crude oil and refined products.

This transaction combined two strong, complementary companies to create a leading nationwide U.S. downstream energy company. The acquisition substantially increases our geographic diversification and scale and strengthens each of our operating segments by diversifying our refining portfolio into attractive markets and increasing access to advantaged feedstocks, enhancing our midstream footprint in the Permian Basin, and creating a nationwide retail and marketing portfolio all of which is expected to substantially improve efficiencies and our ability to serve customers. We expect the combination to generate up to approximately $1.4 billion in gross run-rate synergies within the first three years, significantly enhancing our long-term cash flow generation profile.

MPLX and ANDX

On February 1, 2018, we contributed refining logistics assets and fuels distribution services to MPLX in exchange for $4.1 billion in cash and approximately 114 million newly issued MPLX units. Immediately following the dropdown, our IDRs were cancelled and our economic general partner interest was converted into a non-economic general partner interest, all in exchange for 275 million newly issued MPLX common units. MPLX financed the cash portion of the February 1, 2018 dropdown with its $4.1 billion364-day term loan facility, which was entered into on January 2, 2018. On February 8, 2018, MPLX issued $5.5 billion in aggregate principal amount of senior notes in a public offering. MPLX used $4.1 billion of the net proceeds of the offering to repay the 364-day term-loan facility. The remaining proceeds were used to repay outstanding borrowings under MPLX’s revolving credit facility and intercompany loan agreement with us and for general partnership purposes.

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The following table summarizes the MPLX distributions we received in the three months endedMarch 31, 2019 and 2018 and ANDX distributions we received in the three months endedMarch 31, 2019.

	Three Months Ended  March 31,
(In millions)	2019		2018
Cash distributions received:
Limited partner distributions - MPLX	$	327	$	171
Limited partner distributions - ANDX	146		—
Total	$	473	$	171

We owned approximately 505 million MPLX common units at March 31, 2019 with a market value of $16.60 billion based on the March 29, 2019 closing price of $32.89 per common unit. On April 29, 2019, MPLX declared a quarterly cash distribution of $0.6575 per common unit payable on May 15, 2019. As a result, MPLX will make distributions totaling $523 million to its common unitholders. MPC’s portion of these distributions is approximately $332 million.

We owned approximately 156 million ANDX common units at March 31, 2019 with a market value of $5.51 billion based on the March 29, 2019 closing price of $35.26 per common unit. On April 29, 2019, ANDX declared a quarterly cash distribution of $1.03 per common unit payable on May 15, 2019. As a result, ANDX will make distributions totaling $240 million to its common unitholders. MPC’s portion of this distribution is approximately $148 million, which is net of a $12.5 million quarterly waiver. This quarterly distribution waiver is scheduled to remain in effect through the quarter ending December 31, 2019.

See Note 3 to the unaudited consolidated financial statements for additional information on MPLX and ANDX.

Share Repurchases

During the three months endedMarch 31, 2019, we returned $885 million to our shareholders through repurchases of approximately 14 million shares of common stock at an average price per share of $62.98.

Since January 1, 2012, our board of directors has approved $18.0 billion in total share repurchase authorizations and we have repurchased a total of $13.98 billion of our common stock, leaving $4.02 billion available for repurchases as of March 31, 2019. See Note 8 to the unaudited consolidated financial statements.

Liquidity

As of March 31, 2019, we had cash and cash equivalents of approximately $755 million, excluding MPLX and ANDX cash and cash equivalents of $93 million and $29 million, respectively, no borrowings and $32 million in letters of credit outstanding under our $6.0 billion bank revolving credit facilities and no borrowings outstanding under our $750 million trade receivables facility, resulting in cash and available liquidity of almost $7.5 billion. As of March 31, 2019, MPLX had approximately $1.82 billion available through its bank revolving credit agreement and $1 billion available through its intercompany credit facility with MPC. As of March 31, 2019, ANDX had approximately $696 million available through its bank revolving credit agreements and $500 million available through its intercompany credit facility with MPC.

OVERVIEW OF SEGMENTS

Refining & Marketing

Refining & Marketing segment income from operations depends largely on our Refining & Marketing margin and refinery throughputs.

Our Refining & Marketing margin is the difference between the prices of refined products sold and the costs of crude oil and other charge and blendstocks refined, including the costs to transport these inputs to our refineries and the costs of products purchased for resale. The crack spread is a measure of the difference between market prices for refined products and crude oil, commonly used by the industry as a proxy for the refining margin. Crack spreads can fluctuate significantly, particularly when prices of refined products do not move in the same relationship as the cost of crude oil. As a performance benchmark and a comparison with other industry participants, we calculate West Coast, Mid-Continent and Gulf Coast 3-2-1 crack spreads that we believe most closely track our operations and slate of products. The following are used for these crack-spread calculations:

• The West Coast crack spread uses three barrels of ANS crude producing two barrels of LA CARBOB and one barrel of LA CARB Diesel;

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• The Mid-Continent crack spread uses three barrels of WTI crude producing two barrels of Chicago CBOB gasoline and one barrel of Chicago ULSD; and

• The Gulf Coast crack spread uses three barrels of LLS crude producing two barrels of USGC CBOB gasoline and one barrel of USGC ULSD.

Our refineries can process significant amounts of sweet and sour crude oil, which typically can be purchased at a discount to crude oil referenced in these crack spreads. The amount of these discounts, the sweet and sour differentials, can vary significantly, causing our Refining & Marketing margin to differ from crack spreads. In general, larger sweet and sour differentials will enhance our Refining & Marketing margin.

Future crude oil differentials will be dependent on a variety of market and economic factors, as well as U.S. energy policy.

The following table provides sensitivities showing an estimated change in annual net income due to potential changes in market conditions.

(In millions, after-tax)
Blended crack spread sensitivity(a) (per $1.00/barrel change)	$	900
Sour differential sensitivity(b)(per $1.00/barrel change)	450
Sweet differential sensitivity(c)(per $1.00/barrel change)	370
Natural gas price sensitivity(d)(per $1.00/MMBtu)	300

^(a)  Crack spread based on 38 percent WTI, 38 percent LLS and 24 percent ANS with Mid-Continent, Gulf Coast and West Coast product pricing, respectively, and assumes all other differentials and pricing relationships remain unchanged.

^(b)  Sour crude oil basket consists of the following crudes: ANS, Argus Sour Crude Index, Maya and Western Canadian Select

^(c)  Sweet crude oil basket consists of the following crudes: Bakken, Brent, LLS, WTI-Cushing and WTI-Midland

^(d)  This is consumption based exposure for our Refining & Marketing segment and does not include the the effects to our Midstream segment.

In addition to the market changes indicated by the crack spreads, the sour differential and the sweet differential, our Refining & Marketing margin is impacted by factors such as:

• the selling prices realized for and the mix of refined products as compared to the assumptions used to calculate the market crack spreads;

• the types of crude oil and other charge and blendstocks processed as compared to the assumptions used to calculate the market crack spreads;

• our refinery yields;

• the cost of products purchased for resale;

• the impact of commodity derivative instruments used to hedge price risk; and

• the potential impact of LCM adjustments to inventories in periods of declining prices.

Inventories are stated at the lower of cost or market. Costs of crude oil, refinery feedstocks and refined products are stated under the LIFO inventory costing method and aggregated on a consolidated basis for purposes of assessing if the cost basis of these inventories may have to be written down to market values.

Refining & Marketing segment income from operations is also affected by changes in refinery direct operating costs, which include turnaround and major maintenance, depreciation and amortization and other manufacturing expenses. Changes in manufacturing costs are primarily driven by the cost of energy used by our refineries, including purchased natural gas, and the level of maintenance costs. Planned major maintenance activities, or turnarounds, requiring temporary shutdown of certain refinery operating units, are periodically performed at each refinery. Costs for planned turnaround, major maintenance and engineering projects are expensed in the period incurred.

We have various long-term, fee-based commercial agreements with MPLX and ANDX. Under these agreements, MPLX and ANDX, which are reported in our Midstream segment, provide transportation, storage, distribution and marketing services to our Refining & Marketing segment. Certain of these agreements include commitments for minimum quarterly throughput and distribution volumes of crude oil and refined products and minimum storage volumes of crude oil, refined products and other products. Certain other agreements include commitments to pay for 100 percent of available capacity for certain marine transportation and refining logistics assets.

Retail

Retail segment profitability is impacted by fuel and merchandise margin. Fuel margin for gasoline and distillate is the price paid by consumers or direct dealers less the cost of refined products, including transportation, consumer excise taxes and bankcard processing fees (where applicable). Gasoline and distillate prices are volatile and are impacted by changes in supply

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and demand in the regions where we operate. Numerous factors impact gasoline and distillate demand throughout the year, including local competition, seasonal demand fluctuations, the available wholesale supply, the level of economic activity in our marketing areas and weather conditions.

The margin on merchandise sold at our convenience stores historically has been less volatile and has contributed substantially to our Retail segment margin. Our Retail convenience stores offer a wide variety of merchandise, including prepared foods, beverages and non-food items.

Inventories are carried at the lower of cost or market value. Costs of refined products and merchandise are stated under the LIFO inventory costing method and aggregated on a consolidated basis for purposes of assessing if the cost basis of these inventories may have to be written down to market values.

Midstream

Our Midstream segment transports, stores, distributes and markets crude oil and refined products, principally for our Refining & Marketing segment. The profitability of our pipeline transportation operations primarily depends on tariff rates and the volumes shipped through the pipelines. The profitability of our marine operations primarily depends on the quantity and availability of our vessels and barges. The profitability of our light product terminal operations primarily depends on the throughput volumes at these terminals. The profitability of our fuels distribution services primarily depends on the sales volumes of certain refined products. The profitability of our refining logistics operations depends on the quantity and availability of our refining logistics assets. A majority of the crude oil and refined product shipments on our pipelines and marine vessels and the refined product throughput at our terminals serve our Refining & Marketing segment and our refining logistics assets and fuels distribution services are used solely by our Refining & Marketing segment. As discussed above in the Refining & Marketing section, MPLX and ANDX, which are reported in our Midstream segment, have various long-term, fee-based commercial agreements related to services provided to our Refining & Marketing segment. Under these agreements, MPLX and ANDX have received various commitments of minimum throughput, storage and distribution volumes as well as commitments to pay for all available capacity of certain assets. The volume of crude oil that we transport is directly affected by the supply of, and refiner demand for, crude oil in the markets served directly by our crude oil pipelines, terminals and marine operations. Key factors in this supply and demand balance are the production levels of crude oil by producers in various regions or fields, the availability and cost of alternative modes of transportation, the volumes of crude oil processed at refineries and refinery and transportation system maintenance levels. The volume of refined products that we transport, store, distribute and market is directly affected by the production levels of, and user demand for, refined products in the markets served by our refined product pipelines and marine operations. In most of our markets, demand for gasoline and distillate peaks during the summer driving season, which extends from May through September of each year, and declines during the fall and winter months. As with crude oil, other transportation alternatives and system maintenance levels influence refined product movements.

Our Midstream segment also gathers and processes natural gas and NGLs. NGL and natural gas prices are volatile and are impacted by changes in fundamental supply and demand, as well as market uncertainty, availability of NGL transportation and fractionation capacity and a variety of additional factors that are beyond our control. Our Midstream segment profitability is affected by prevailing commodity prices primarily as a result of processing at our own or third‑party processing plants, purchasing and selling or gathering and transporting volumes of natural gas at index‑related prices and the cost of third‑party transportation and fractionation services. To the extent that commodity prices influence the level of natural gas drilling by our producer customers, such prices also affect profitability.

RESULTS OF OPERATIONS

The following discussion includes comments and analysis relating to our results of operations. Our results include the results of Andeavor from the October 1, 2018 acquisition date forward. This discussion should be read in conjunction with Item 1. Financial Statements and is intended to provide investors with a reasonable basis for assessing our historical operations, but should not serve as the only criteria for predicting our future performance.

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Consolidated Results of Operations

	Three Months Ended  March 31,
(In millions)	2019			2018		Variance
Revenues and other income:
Sales and other operating revenues	$	28,081		$	18,694	$	9,387
Sales to related parties	186			172		14
Income from equity method investments	99			86		13
Net gain on disposal of assets	214			2		212
Other income	35			30		5
Total revenues and other income	28,615			18,984		9,631
Costs and expenses:
Cost of revenues (excludes items below)	25,756			17,370		8,386
Purchases from related parties	204			141		63
Depreciation and amortization	919			528		391
Selling, general and administrative expenses	881			402		479
Other taxes	186			103		83
Total costs and expenses	27,946			18,544		9,402
Income from operations	669			440		229
Net interest and other financial costs	306			183		123
Income before income taxes	363			257		106
Provision for income taxes	104			22		82
Net income	259			235		24
Less net income attributable to:
Redeemable noncontrolling interest	20			16		4
Noncontrolling interests	246			182		64
Net income (loss) attributable to MPC	$	(7	)	$	37	$	(44	)

Net income (loss) attributable to MPCdecreased$44 million in the first quarter of 2019 compared to the first quarter of 2018 primarily due to an increase in income from operations more than offset by increases in net interest and other financial costs, provision for income taxes and net income attributable to noncontrolling interests.

First Quarter 2019 Compared to First Quarter 2018

Revenues and other income increased$9.63 billion primarily due to:

• increased sales and other operating revenues of $9.39 billion primarily due to increased Refining & Marketing segment refined product sales volumes, which increased1,408 mbpd largely due to the Andeavor acquisition on October 1, 2018; and

• increased net gain on disposal of assets of $212 million primarily due to a $207 million gain recognized in connection with MPC’s exchange of its undivided interest in the Capline pipeline system for an equity ownership in Capline LLC.

Costs and expenses increased$9.40 billion primarily due to:

• increased cost of revenues of $8.39 billion primarily due to the inclusion of costs related to the Andeavor operations following the acquisition;

• increased depreciation and amortization of $391 million primarily due to the depreciation of the fair value of assets acquired in connection with the Andeavor acquisition;

• increased selling, general and administrative expenses of $479 million primarily due to increased costs of the combined company subsequent to the acquisition of Andeavor and reflects MPC’s classification of costs and expenses; and

• increased other taxes of $83 million primarily due to the inclusion of other taxes related to the acquired Andeavor operations.

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Net interest and other financial costs increased$123 million primarily due to debt assumed in the acquisition of Andeavor and increased MPLX borrowings.

Provision for income taxesincreased$82 million primarily due to increased income before income taxes of $106 million and $36 million of state deferred tax expense recorded as an out of period adjustment related to the Andeavor acquisition. The combined federal, state and foreign income tax rate was 29 percent and 9 percent for the three months ended March 31, 2019 and 2018, respectively. The effective tax rate for the three months ended March 31, 2019 was greater than the U.S. statutory rate of 21 percent primarily due to $36 million of state deferred tax expense recorded as an out of period adjustment partially offset by permanent tax differences related to net income attributable to noncontrolling interests. The effective tax rate for the three months ended March 31, 2018 was less than the U.S. statutory rate of 21 percent primarily due to certain permanent tax differences related to net income attributable to noncontrolling interests, state and local deferred tax benefits primarily resulting from the February 1, 2018 dropdown and GP/IDR Exchange and equity compensation.

Net income attributable to noncontrolling interests increased$64 million primarily due to net income attributable to noncontrolling interest in ANDX.

Segment Results

Refining & Marketing

The following includes key financial and operating data for the first quarter of 2019 compared to the first quarter of 2018. Our results include the results of Andeavor from the October 1, 2018 acquisition date forward.

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^(a)  Includes intersegment sales and sales destined for export.

^(b)  Sales revenue less cost of refinery inputs and purchased products, divided by total refinery throughputs.

^(c)  See “Non-GAAP Measures” section for reconciliation and further information regarding this non-GAAP measure.

^(d)  Per barrel of total refinery throughputs.

^(e)  Includes utilities, labor, routine maintenance and other operating costs.

^(f)  Primarily related to refined product distribution costs, including fees paid to our two sponsored master limited partnerships, MPLX and ANDX.

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The following table presents certain benchmark prices in our marketing areas and market indicators that we believe are helpful in understanding the results of our Refining & Marketing segment. Following the acquisition of Andeavor in October 2018, we expanded the benchmark prices included in these tables to include market information for the West Coast region of the United States, including LA CARBOB and LA CARB diesel spot prices, ANS crude prices and a West Coast ANS 3-2-1 crack spread. However, since the results of the Andeavor businesses are only included in our results from October 1, 2018 forward, these market indicators did not affect our results for the first quarter of 2018. The benchmark crack spreads below do not reflect the market cost of RINs necessary to meet EPA renewable volume obligations for attributable products under the Renewable Fuel Standard.

	Three Months Ended  March 31,
Benchmark Spot Prices (dollars per gallon)	2019			2018
Chicago CBOB unleaded regular gasoline	$	1.51		$	1.74
Chicago ULSD	1.84			1.94
USGC CBOB unleaded regular gasoline	1.52			1.77
USGC ULSD	1.88			1.93
LA CARBOB	1.82			1.98
LA CARB diesel	1.92			2.01
Market Indicators (dollars per barrel)
LLS	$	62.34		$	65.82
WTI	54.90			62.89
ANS	64.48			67.00
Crack Spreads:
Mid-Continent WTI 3-2-1	$	11.70		$	9.89
USGC LLS 3-2-1	5.23			7.88
West Coast ANS 3-2-1	11.91			13.77
Blended 3-2-1(a)	9.29			8.69
Crude Oil Differentials:
Sweet	$	(3.30	)	$	(0.59	)
Sour	(3.13		)	(6.35		)

^(a)  Blended 3-2-1 Mid-Continent/USGC/West Coast crack spread is 38/38/24 percent in 2019 and Blended 3-2-1 Mid-Continent/USGC crack spread is 40/60 percent in 2018, which reflects MPC’s capacity prior to the Andeavor acquisition. These blends are based on our refining capacity by region in each period.

First Quarter 2019 Compared to First Quarter 2018

Refining & Marketing segment revenues increased$8.40 billion primarily due to higher refined product sales volumes, which increased1,408 mbpd mainly due to the Andeavor acquisition on October 1, 2018, partially offset by decreased average refined product sales prices of $0.08 per gallon.

Refining & Marketing segment loss from operations increased $201 million primarily driven by narrower crude discounts across our medium and heavy crude slate. Additionally, high industry gasoline inventories following the fourth quarter’s strong production environment resulted in weaker gasoline margins particularly in January of 2019.

Based on the changes in the market indicators shown above, which use spot market values and an estimated mix of crude purchases and product sales, we estimate a positive impact of $1.41 billion on Refining & Marketing segment income from operations, largely driven by a $1.54 billion benefit from increases in sales volume. Differences in our results compared to these market indicators, including the effects of product price realizations, the mix of crudes purchased and their costs, market structure on our crude oil acquisition prices, RIN prices on the crack spread, and other items like refinery yields and other feedstock variances, had an estimated negative effect of $120 million on Refining & Marketing segment income in the first quarter of 2019 compared to the first quarter of 2018.

Refinery capacity utilization was 95 percent inclusive of turnaround activity during the first quarter of 2019 and crude oil throughputs increased1,124 mbpd primarily due to the refineries acquired from Andeavor.

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Refining & Marketing margin was $11.17 per barrel for the first quarter of 2019 compared to $10.58 per barrel for the first quarter of 2018. Refinery direct operating costs decreased$0.02 per barrel. In the first quarter of 2019, planned turnaround and major maintenance costs decreased$0.99 per barrel, largely attributable to lower turnaround costs at our Galveston Bay refinery partially offset by higher turnaround costs at our Los Angeles and Robinson refineries. In the first quarter of 2019, other manufacturing costs were $0.94 per barrel higher primarily due to the refineries acquired in the Andeavor acquisition. Higher crude throughputs during the first three months of 2019 also reduced refinery direct operating costs per barrel.

Other operating expenses totaled $1,308 million for the first quarter of 2019 as compared to $630 million for the first quarter of 2018. These costs are primarily related to refined product distribution costs, including fees paid to our two sponsored master limited partnerships, MPLX and ANDX. Included in these costs were fees paid to MPLX of $609 million and $478 million for the first quarters of 2019 and 2018, respectively. The higher fees charged by MPLX were primarily due to one additional month of services provided to the Refining & Marketing segment in the first quarter of 2019 following the February 1, 2018 dropdown of refining logistic assets and fuels distribution services to MPLX. The balance of the increase was mainly driven by the inclusion of other operating expenses for the refining and marketing operations acquired from Andeavor.

Supplemental Refining & Marketing Statistics

	Three Months Ended  March 31,
	2019	2018
Refining & Marketing Operating Statistics
Refined product export sales volumes (mbpd)(a)	430	265
Crude oil capacity utilization percent(b)	95	93
Refinery throughputs (mbpd):(c)
Crude oil refined	2,869	1,745
Other charge and blendstocks	215	160
Total	3,084	1,905
Sour crude oil throughput percent	52	52
Sweet crude oil throughput percent	48	48
Refined product yields (mbpd):(c)
Gasoline	1,533	917
Distillates	1,091	609
Propane	53	31
Feedstocks and petrochemicals	330	287
Heavy fuel oil	45	34
Asphalt	80	58
Total	3,132	1,936

^(a)  Represents fully loaded export cargoes for each time period. These sales volumes are included in the total sales volume amounts.

^(b)  Based on calendar-day capacity, which is an annual average that includes down time for planned maintenance and other normal operating activities.

^(c)  Excludes inter-refinery volumes which totaled 76 mbpd and 42 mbpd for the three months ended March 31, 2019 and 2018, respectively.

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Retail

The following includes key financial and operating data for the first quarter of 2019 compared to the first quarter of 2018. Our results include the results of Andeavor from the October 1, 2018 acquisition date forward.

^(a)  The price paid by consumers or direct dealers less the cost of refined products, including transportation, consumer excise taxes and bankcard processing fees (where applicable), divided by gasoline and distillate sales volume. Excludes LCM inventory valuation adjustments.

^(b)  See “Non-GAAP Measures” section for reconciliation and further information regarding this non-GAAP measure.

	Three Months Ended  March 31,
Key Financial and Operating Data	2019			2018
Average fuel sales prices (dollars per gallon)	$	2.58		$	2.52
Merchandise sales (in millions)	$	1,413		$	1,129
Merchandise margin (in millions)(a)(b)	$	407		$	319
Same store gasoline sales volume (period over period)(c)	(3.2		%)	(1.5		%)
Same store merchandise sales (period over period)(c)(d)	5.4		%	2.3		%
Convenience stores at period-end	3,918			2,742
Direct dealer locations at period-end	1,062			—

^(a)  The price paid by the consumers less the cost of merchandise.

^(b)  See “Non-GAAP Measures” section for reconciliation and further information regarding this non-GAAP measure.

^(c)  Same store comparison includes only locations owned at least 13 months.

^(d)  Excludes cigarettes.

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First Quarter 2019 Compared to First Quarter 2018

Retail segment revenues increased$2.81 billion primarily due increased fuel and merchandise sales resulting from the Andeavor acquisition on October 1, 2018. The Andeavor acquisition added approximately 1,100 company-owned and operated locations along with long-term supply contracts for approximately 1,060 direct dealers locations. Fuel sales volumes increased1.11 billion gallons, almost all of which was related to the acquisition, and average fuel sales prices increased$0.06 per gallon. Merchandise sales increased$284 million resulting from the contributions of the acquired businesses.

Retail segment income from operations increased$75 million primarily due to higher light product and merchandise margins largely related to the addition of the legacy Andeavor retail operations as well as a $24 million year-over-year increase in MPC's legacy Speedway segment earnings. These increases were partially offset by an increase in operating expenses resulting from the locations acquired from Andeavor. The Retail fuel margin increased to 17.15 cents per gallon in the first quarter of 2019 compared with 15.61 cents per gallon in the first quarter of 2018 and the merchandise margin increased$88 million.

Midstream

The following includes key financial and operating data for the first quarter of 2019 compared to the first quarter of 2018. Our results include the results of Andeavor from the October 1, 2018 acquisition date forward.

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^(a)  On owned common-carrier pipelines, excluding equity method investments.

^(b)  Includes amounts related to unconsolidated equity method investments on a 100 percent basis.

	Three Months Ended  March 31,
Benchmark Prices	2019		2018
Natural Gas NYMEX HH ($ per MMBtu)	$	2.87	$	2.85
C2 + NGL Pricing ($ per gallon)(a)	$	0.62	$	0.73

^(a)  C2 + NGL pricing based on Mont Belvieu prices assuming an NGL barrel of approximately 35 percent ethane, 35 percent propane, 6 percent Iso-Butane, 12 percent normal butane and 12 percent natural gasoline.

First Quarter 2019 Compared to First Quarter 2018

On February 1, 2018, we completed the dropdown of refining logistics assets and fuels distribution services to MPLX, which is reported in our Midstream segment. These new businesses were reported in the Midstream segment prospectively from February 1, 2018.

Midstream segment revenue increased$845 million primarily due to the inclusion of ANDX revenues subsequent to the Andeavor acquisition on October 1, 2018. In addition, the first quarter of 2019 reflects a full quarter of fees charged for fuels distribution and refining logistics services provided to Refining & Marketing as compared to only two months of fees in the first quarter of 2018 following the February 1, 2018 dropdown to MPLX.

Midstream segment income from operations increased$341 million largely due to contributions of $220 million from ANDX and a $121 million increase in Midstream segment results driven primarily by growth across MPLX’s businesses.

Items not Allocated to Segments

Key Financial Information (in millions)	Three Months Ended  March 31,
	2019			2018
Items not allocated to segments:
Corporate and other unallocated items(a)	$	(191	)	$	(89	)
Capline restructuring gain	207			—
Transaction-related costs	(91		)	—

^(a)  Corporate and other unallocated items consists primarily of MPC’s corporate administrative expenses and costs related to certain non-operating assets, except for corporate overhead expenses attributable to MPLX and ANDX, which are included in the Midstream segment. Corporate overhead expenses are not allocated to the Refining & Marketing and Retail segments.

First Quarter 2019 Compared to First Quarter 2018

Corporate and other unallocated items increased$102 million largely due to increased costs and expenses for the combined company after the Andeavor acquisition.

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Other unallocated items include a $207 million gain resulting from the agreements executed with Capline LLC to contribute our 33 percent undivided interest in the Capline pipeline system in exchange for a 33 percent ownership interest in Capline LLC. Other unallocated items also include transaction-related costs of $91 million associated with the Andeavor acquisition. The transaction-related costs recognized in the first quarter largely relate to the recognition of an obligation for vacation benefits provided to former Andeavor employees.

Non-GAAP Financial Measures

Management uses certain financial measures to evaluate our operating performance that are calculated and presented on the basis of methodologies other than in accordance with GAAP. We believe these non-GAAP financial measures are useful to investors and analysts to assess our ongoing financial performance because, when reconciled to its most comparable GAAP financial measure, 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. These measures should not be considered a substitute for, or superior to, measures of financial performance prepared in accordance with GAAP, and our calculations thereof may not be comparable to similarly titled measures reported by other companies. The non-GAAP financial measures we use are as follows:

Refining & Marketing Margin

Refining margin is defined as sales revenue less the cost of refinery inputs and purchased products and excludes any LCM inventory market adjustment.

	Three Months Ended  March 31,
Reconciliation of Refining & Marketing loss from operations to Refining & Marketing margin (in millions)	2019			2018
Refining & Marketing loss from operations	$	(334	)	$	(133	)
Plus:
Refinery direct operating costs(a)	1,739			1,081
Refinery depreciation and amortization	387			236
Other:
Operating expenses(a)(b)	1,268			614
Depreciation and amortization	40			16
Refining & Marketing margin	$	3,100		$	1,814

^(a)  Excludes depreciation and amortization.

^(b)  These costs are primarily related to refined product distribution costs, including fees paid to our two sponsored master limited partnerships, MPLX and ANDX.

Retail Fuel Margin

Retail fuel margin is defined as the price paid by consumers or direct dealers less the cost of refined products, including transportation, consumer excise taxes and bankcard processing fees (where applicable) and excluding any LCM inventory market adjustment.

Retail Merchandise Margin

Retail merchandise margin is defined as the price paid by consumers less the cost of merchandise.

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	Three Months Ended  March 31,
Reconciliation of Retail income from operations to Retail total margin (in millions)	2019			2018
Retail income from operations	$	170		$	95
Plus (Less):
Operating, selling, general and administrative expenses	583			384
Depreciation and amortization	126			79
Income from equity method investments	(17		)	(14		)
Net gain on disposal of assets	(2		)	—
Other income	(2		)	(1		)
Retail total margin	$	858		$	543
Retail total margin:
Fuel margin	$	429		$	217
Merchandise margin	407			319
Other margin	22			7
Retail total margin	$	858		$	543

LIQUIDITY AND CAPITAL RESOURCES

Cash Flows

Our consolidated cash and cash equivalents balance was approximately $877 million at March 31, 2019 compared to $1.69 billion at December 31, 2018. Net cash provided by (used in) operating activities, investing activities and financing activities are presented in the following table. Our cash flows reflect the results of the business acquired in connection with the Andeavor acquisition from October 1, 2018 forward.

	Three Months Ended  March 31,
(In millions)	2019			2018
Net cash provided by (used in):
Operating activities	$	1,623		$	(137	)
Investing activities	(1,520		)	(778		)
Financing activities	(920		)	2,557
Total increase (decrease) in cash	$	(817	)	$	1,642

Net cash provided by operating activities increased$1.76 billion in the first three months of 2019 compared to the first three months of 2018, primarily due to favorable changes in working capital of $1.40 billion and an increase in operating results. Changes in working capital exclude changes in short-term debt.

Changes in working capital, excluding changes in short-term debt, were a net $470 million source of cash in the first three- months of 2019 compared to a net $933 million use of cash in the first three months of 2018.

For the first three months of 2019, changes in working capital, excluding changes in short-term debt, were a net $470 million source of cash primarily due to the effects of increasing energy commodity prices at the end of the period on working capital. Accounts payable increased primarily due to an increase in crude prices. Current receivables increased primarily due to higher refined product and crude prices and higher crude sales volumes. Inventories decreased due to decreases in refined product and merchandise inventories partially offset by increases in crude and materials and supplies inventories.

For the first three months of 2018, changes in working capital, excluding changes in short-term debt, were a net $933 million use of cash primarily due to the effect of decreases in volumes partially offset by increases in energy commodity prices at the end of the period on working capital. Accounts payable decreased primarily due to lower crude oil volumes purchased slightly offset by higher crude oil prices. Inventories decreased due to decreases in crude, refined products and materials and supplies inventories. Current receivables decreased primarily due to lower refined product volumes slightly offset by higher prices.

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Net cash used in investing activities increased$742 million in the first three months of 2019 compared to the first three months of 2018, primarily due to the following:

• An increase in additions to property, plant and equipment of $486 million primarily due to increased capital expenditures in the first three months of 2019 in our Midstream and Refining & Marketing segments; and

• an increase in net investments of $282 million largely due to investments in connection with the construction of the Gray Oak Pipeline, which is scheduled to commence operations in the fourth quarter of 2019.

The consolidated statements of cash flows exclude changes to the consolidated balance sheets that did not affect cash. A reconciliation of additions to property, plant and equipment per the consolidated statements of cash flows to reported total capital expenditures and investments follows.

	Three Months Ended  March 31,
(In millions)	2019			2018
Additions to property, plant and equipment per the consolidated statements of cash flows	$	1,241		$	755
Asset retirement expenditures	—			1
Decrease in capital accruals	(235		)	(49		)
Total capital expenditures	1,006			707
Investments in equity method investees (excludes acquisitions)	325			41
Total capital expenditures and investments	$	1,331		$	748

Financing activities were a net $920 million use of cash in the first three months of 2019 compared to a net $2.56 billion source of cash in the first three months of 2018.

• Long-term debt borrowings and repayments, including debt issuance costs, were a net $573 millionsource of cash in the first three months of 2019 compared to a net $4.29 billionsource of cash in the first three months of 2018. During the first three months of 2019, MPLX had net borrowings of $425 million under its revolving credit facility and ANDX had net borrowings of $159 million under its revolving credit facility. During the first three months of 2018, MPLX issued $5.5 billion of senior notes, we redeemed $600 million of our senior notes and MPLX repaid $505 million in outstanding borrowings under its revolving credit facility.

• Cash used in common stock repurchases decreased$442 million in the first three months of 2019 compared to the first three months of 2018. Share repurchases totaled $885 million in the first three months of 2019 compared to $1.33 billion in the first three months of 2018. In 2018, share repurchases were funded primarily by after tax proceeds from the February 1, 2018 dropdown. See Note 8 to the unaudited consolidated financial statements for further discussion of share repurchases.

• Cash used in dividend payments increased$135 million in the first three months of 2019 compared to the first three months of 2018, primarily due to a net increase in the number of shares of our common stock outstanding related to the Andeavor acquisition and a $0.07 per share increase in our base dividend, partially offset by a reduction of shares resulting from share repurchases. Our dividend payments were $0.53 per common share in the first three months of 2019 compared to $0.46 per common share in the first three months of 2018.

• Cash used in distributions to noncontrolling interests increased$130 million in the first three months of 2019 compared to the first three months of 2018, primarily due to the addition of ANDX distributions subsequent to the acquisition of Andeavor and an increase in MPLX’s distribution per common unit.

• Contributions from noncontrolling interests increased $94 million in the first three months of 2019 compared to the first three months of 2018 primarily due to cash received in 2019 for an increased noncontrolling interest in an MPLX subsidiary.

Derivative Instruments

See Item 3. Quantitative and Qualitative Disclosures about Market Risk for a discussion of derivative instruments and associated market risk.

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Capital Resources

Our liquidity totaled $7.47 billion at March 31, 2019 consisting of:

	March 31, 2019
(In millions)	Total Capacity		Outstanding Borrowings		Available Capacity
Bank revolving credit facility(a)	$	5,000	$	32	$	4,968
364-day bank revolving credit facility	1,000		—		$	1,000
Trade receivables facility	750		—		750
Total	$	6,750	$	32	$	6,718
Cash and cash equivalents(b)					755
Total liquidity					$	7,473

^(a)  Outstanding borrowings include $32 million in letters of credit outstanding under this facility. Excludes MPLX’s $2.25 billion bank revolving credit facility, which had approximately $1.82 billion available as of March 31, 2019, and ANDX’s $2.10 billion bank revolving credit facilities, which had approximately $696 million available as of March 31, 2019.

^(b)  Excludes MPLX and ANDX cash and cash equivalents of $93 million and $29 million, respectively.

Because of the alternatives available to us, including internally generated cash flow and access to capital markets and a commercial paper program, we believe that our short-term and long-term liquidity is adequate to fund not only our current operations, but also our near-term and long-term funding requirements, including capital spending programs, the repurchase of shares of our common stock, dividend payments, defined benefit plan contributions, repayment of debt maturities and other amounts that may ultimately be paid in connection with contingencies.

We have a commercial paper program that allows us to have a maximum of $2.0 billion in commercial paper outstanding. We do not intend to have outstanding commercial paper borrowings in excess of available capacity under our bank revolving credit facility. As of March 31, 2019, we had no commercial paper borrowings outstanding.

See Note 17 to the unaudited consolidated financial statements for further discussion of our debt.

The MPC credit agreements contain representations and warranties, affirmative and negative covenants and events of default that we consider usual and customary for agreements of these types. The financial covenant included in the MPC credit agreements requires us to maintain, as of the last day of each fiscal quarter, a ratio of Consolidated Net Debt to Total Capitalization (as defined in the MPC credit agreements) of no greater than 0.65 to 1.00. As of March 31, 2019, we were in compliance with this financial covenant, with a ratio of Consolidated Net Debt to Total Capitalization of 0.22 to 1.00, as well as the other covenants contained in the MPC bank revolving credit facility.

The MPLX credit agreement contains representations and warranties, affirmative and negative covenants and events of default that we consider usual and customary for agreements of these types. The MPLX credit agreement includes a financial covenant that requires MPLX to maintain a ratio of Consolidated Total Debt (as defined in the MPLX credit agreement) as of the end of each fiscal quarter to Consolidated EBITDA (as defined in the MPLX credit agreement) for the prior four fiscal quarters of not greater than 5.0 to 1.0 (or 5.5 to 1.0 during the six-month period following certain acquisitions). Consolidated EBITDA is subject to adjustments for certain acquisitions completed and capital projects undertaken during the relevant period. Other covenants restrict MPLX and/or certain of its subsidiaries from incurring debt, creating liens on assets and entering into transactions with affiliates. As of March 31, 2019, MPLX was in compliance with this debt covenant, with a ratio of Consolidated Total Debt to Consolidated EBITDA of 3.85 to 1.0, as well as the other covenants contained in the MPLX credit agreement.

The ANDX credit agreements contain certain representations and warranties, affirmative and restrictive covenants and events of default that we consider to be usual and customary for an agreement of this type, including a financial covenant that requires ANDX to maintain a Consolidated Leverage Ratio (as defined in the ANDX credit agreements) for the prior four fiscal quarters of no greater than 5.0 to 1.0 (or 5.5 to 1.0 for up to two fiscal quarters following certain acquisitions). Consolidated EBITDA used to calculate the Consolidated Leverage Ratio is subject to adjustments for certain acquisitions completed and capital projects undertaken during the relevant period. The covenants also restrict, among other things, ANDX’s ability and/or the ability of certain of its subsidiaries to incur debt, create liens on assets and enter into transactions with affiliates. As of March 31, 2019, ANDX was in compliance with this debt covenant, with a Consolidated Leverage Ratio of 3.86 to 1.0, as well as the other covenants contained in the ANDX credit agreements.

.

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Our intention is to maintain an investment-grade credit profile. As of March 31, 2019, the credit ratings on our senior unsecured debt were as follows.

Company	Rating Agency	Rating
MPC	Moody’s	Baa2 (stable outlook)
	Standard & Poor’s	BBB (stable outlook)
	Fitch	BBB (stable outlook)
MPLX	Moody’s	Baa3 (stable outlook)
	Standard & Poor’s	BBB (stable outlook)
	Fitch	BBB- (positive outlook)
ANDX	Moody’s	Ba1 (review for upgrade)
	Standard & Poor’s	BBB- (positive watch)
	Fitch	BBB- (stable outlook)

The ratings reflect the respective views of the rating agencies. Although it is our intention to maintain a credit profile that supports an investment-grade rating, there is no assurance that these ratings will continue for any given period of time. The ratings may be revised or withdrawn entirely by the rating agencies if, in their respective judgments, circumstances so warrant.

None of the MPC credit agreements, the MPLX credit agreement, the ANDX credit agreements or our trade receivables facility contains credit rating triggers that would result in the acceleration of interest, principal or other payments in the event that our credit ratings are downgraded. However, any downgrades of our senior unsecured debt could increase the applicable interest rates, yields and other fees payable under such agreements. In addition, a downgrade of our senior unsecured debt rating to below investment-grade levels could, under certain circumstances, decrease the amount of trade receivables that are eligible to be sold under our trade receivables facility, impact our ability to purchase crude oil on an unsecured basis and could result in us having to post letters of credit under existing transportation services or other agreements.

Capital Requirements

Capital Spending

MPC's capital investment plan for 2019 totals approximately $2.8 billion for capital projects and investments, excluding MPLX, ANDX, capitalized interest and acquisitions. MPC’s capital investment plan includes approximately $1.8 billion of growth capital and $1.0 billion of maintenance capital. This plan includes all of the planned capital spending for Refining & Marketing, Retail and Corporate as well as a portion of the planned capital investments in Midstream. MPLX’s capital investment plan for 2019, excluding capitalized interest and acquisitions, includes $2.2 billion of organic growth capital and approximately $200 million of maintenance capital. ANDX’s capital investment plan for 2019, excluding capitalized interest and acquisitions, includes $600 million of organic growth capital and approximately $100 million of maintenance capital. We continuously evaluate our capital plan and make changes as conditions warrant.

Capital expenditures and investments are summarized by segment below. These amounts include capital spending and investments related to businesses acquired in connection with the Andeavor acquisition from October 1, 2018 forward.

	Three Months Ended  March 31,
(In millions)	2019		2018
Refining & Marketing	$	394	$	191
Retail	73		39
Midstream	823		482
Corporate and Other(a)	41		36
Total capital expenditures and investments	$	1,331	$	748

^(a)  Includes capitalized interest of $31 million and $18 million for the three months ended March 31, 2019 and 2018, respectively.

Capital expenditures during the three months ended March 31, 2019 were primarily for Midstream and Refining & Marketing segment projects. The Midstream segment capital investment plan includes projects for MPLX and ANDX. MPLX’s capital investment plan includes the addition of approximately 825 MMcf/d of processing capacity at five gas processing plants, two in the Marcellus and three in the Southwest, which expands MPLX’s processing capacity in the Permian Basin and the STACK shale play of Oklahoma. The MPLX capital investment plan also includes the addition of approximately 100 mbpd of fractionation capacity in the Marcellus and Utica basins and the continued expansion of MPLX’s marine fleet, long-haul crude

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oil, natural gas and NGL pipelines as well as projects to increase its export capability. The ANDX capital investment plan includes the construction of additional crude storage capacity for unloading of marine vessels, the construction of crude gathering systems to provide connectivity to multiple long-haul pipelines and a pipeline interconnect project to provide direct connectivity between certain MPC refineries. The remaining Midstreamsegment’s capital expenditure projects relate to investments in equity affiliate pipelines, including our expected investments in the Gray Oak Pipeline, a new pipeline spanning from the West Texas Permian Basin to the Gulf Coast which is expected to be in service by the end of 2019.

The Refining & Marketing segment capital investment plan includes projects focused on high-return investments in refinery optimization, production of higher value products, increased capacity to upgrade residual fuel oil and expanded export capacity. We also plan to continue investing in domestic light products supply placement flexibility.

Other Capital Requirements

During the three months ended March 31, 2019, we made no contributions to our funded pension plans, however, we have required funding for the 2019 plan year of approximately $64 million and we may choose to make additional contributions to our pension plans.

On April 24, 2019, our board of directors approved a dividend of $0.53 per share on common stock. The dividend is payable June 10, 2019, to shareholders of record as of the close of business on May 16, 2019.

We may, from time to time, repurchase our senior notes in the open market, in privately-negotiated transactions or otherwise in such volumes, at such prices and upon such other terms as we deem appropriate.

Share Repurchases

Since January 1, 2012, our board of directors has approved $18.0 billion in total share repurchase authorizations and we have repurchased a total of $13.98 billion of our common stock, leaving $4.02 billion available for repurchases at March 31, 2019. The table below summarizes our total share repurchases for the three months endedMarch 31, 2019 and 2018. See Note 8 to the unaudited consolidated financial statements for further discussion of the share repurchase plans.

	Three Months Ended  March 31,
(In millions, except per share data)	2019		2018
Number of shares repurchased	14		19
Cash paid for shares repurchased	$	885	$	1,327
Average cost per share	$	62.98	$	68.74

We may utilize various methods to effect the repurchases, which could include open market repurchases, negotiated block transactions, accelerated share repurchases or open market solicitations for shares, some of which may be effected through Rule 10b5-1 plans. The timing and amount of future repurchases, if any, will depend upon several factors, including market and business conditions, and such repurchases may be discontinued at any time.

Contractual Cash Obligations

As of March 31, 2019, our contractual cash obligations included long-term debt, capital and operating lease obligations, purchase obligations and other long-term liabilities. During the first three months of 2019, our long-term debt commitments decreased approximately $230 million due to interest payments made during the quarter partially offset by increased borrowings on the MPLX bank revolving credit facility and ANDX bank revolving credit facilities.

There were no other material changes to our contractual cash obligations outside the ordinary course of business since December 31, 2018.

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Off-Balance Sheet Arrangements

Off-balance sheet arrangements comprise those arrangements that may potentially impact our liquidity, capital resources and results of operations, even though such arrangements are not recorded as liabilities under U.S. GAAP. Our off-balance sheet arrangements are limited to indemnities and guarantees that are described below. Although these arrangements serve a variety of our business purposes, we are not dependent on them to maintain our liquidity and capital resources, and we are not aware of any circumstances that are reasonably likely to cause the off-balance sheet arrangements to have a material adverse effect on liquidity and capital resources.

We have provided various guarantees related to equity method investees. In conjunction with our spinoff from Marathon Oil, we entered into various indemnities and guarantees to Marathon Oil. These arrangements are described in Note 24 to the unaudited consolidated financial statements.

ENVIRONMENTAL MATTERS AND COMPLIANCE COSTS

We have incurred and may continue to incur substantial capital, operating and maintenance, and remediation expenditures as a result of environmental laws and regulations. If these expenditures, as with all costs, are not ultimately reflected in the prices of our products and services, our operating results will be adversely affected. We believe that substantially all of our competitors must comply with similar environmental laws and regulations. However, the specific impact on each competitor may vary depending on a number of factors, including the age and location of its operating facilities, marketing areas, production processes and whether it is also engaged in the petrochemical business or the marine transportation of crude oil and refined products.

On March 3, 2014, the EPA signed the final Tier 3 fuel standards. The final Tier 3 fuel standards require, among other things, a lower annual average sulfur level in gasoline to no more than 10 ppm beginning in calendar year 2017. In addition, gasoline refiners and importers may not exceed a maximum per-gallon sulfur standard of 80 ppm while retailers may not exceed a maximum per-gallon sulfur standard of 95 ppm. From 2014 through 2018, we made approximately $490 million in capital expenditures to comply with these standards, and expect to make approximately $260 million in capital expenditures for these standards in 2019.

There have been no significant changes to our environmental matters and compliance costs during the three months ended March 31, 2019.

CRITICAL ACCOUNTING ESTIMATES

As of March 31, 2019, there have been no significant changes to our critical accounting estimates since our Annual Report on Form 10-K for the year ended December 31, 2018.

ACCOUNTING STANDARDS NOT YET ADOPTED

As discussed in Note 2 to the unaudited consolidated financial statements, certain new financial accounting pronouncements will be effective for our financial statements in the future.

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ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

For a detailed discussion of our risk management strategies and our derivative instruments, see Item 7A. Quantitative and Qualitative Disclosures about Market Risk in our Annual Report on Form 10-K for the year ended December 31, 2018.

See Notes 15 and 16 to the unaudited consolidated financial statements for more information about the fair value measurement of our derivatives, as well as the amounts recorded in our consolidated balance sheets and statements of income. We do not designate any of our commodity derivative instruments as hedges for accounting purposes.

The following table includes the composition of net losses on our commodity derivative positions as of March 31, 2019 and 2018, respectively.

	Three Months Ended  March 31,
(In millions)	2019			2018
Realized gain on settled derivative positions	$	39		$	5
Unrealized loss on open net derivative positions	(139		)	(33		)
Net loss	$	(100	)	$	(28	)

See Note 16 to the unaudited consolidated financial statements for additional information on our open derivative positions atMarch 31, 2019.

Sensitivity analysis of the effects on income from operations (“IFO”) of hypothetical 10 percent and 25 percent increases and decreases in commodity prices for open commodity derivative instruments as of March 31, 2019 is provided in the following table.

	Change in IFO from a Hypothetical Price Increase of						Change in IFO from a Hypothetical Price Decrease of
(In millions)	10%			25%			10%			25%
As of March 31, 2019
Crude	$	(61	)	$	(152	)	$	62		$	154
Refined products	5			12			(5		)	(12		)
Blending products	(4		)	(10		)	4			10
Embedded derivatives	(7		)	(16		)	7			16

We remain at risk for possible changes in the market value of commodity derivative instruments; however, such risk should be mitigated by price changes in the underlying physical commodity. Effects of these offsets are not reflected in the above sensitivity analysis.

We evaluate our portfolio of commodity derivative instruments on an ongoing basis and add or revise strategies in anticipation of changes in market conditions and in risk profiles. Changes to the portfolio after March 31, 2019 would cause future IFO effects to differ from those presented above.

Sensitivity analysis of the effect of a hypothetical 100-basis-point change in interest rates on long-term debt, including the portion classified as current and excluding finance leases, as of March 31, 2019 is provided in the following table. Fair value of cash and cash equivalents, receivables, accounts payable and accrued interest approximate carrying value and are relatively insensitive to changes in interest rates due to the short-term maturity of the instruments. Accordingly, these instruments are excluded from the table.

(In millions)	Fair Value as of March 31, 2019(a)		Change in Fair Value(b)		Change in Net Income for the Three Months Ended March 31, 2019(c)
Long-term debt
Fixed-rate	$	26,759	$	2,246	n/a
Variable-rate	1,832		n/a		4

^(a)  Fair value was based on market prices, where available, or current borrowing rates for financings with similar terms and maturities.

^(b)  Assumes a 100-basis-point decrease in the weighted average yield-to-maturity at March 31, 2019.

^(c)  Assumes a 100-basis-point change in interest rates. The change to net income was based on the weighted average balance of debt outstanding for the three months ended March 31, 2019.

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At March 31, 2019, our portfolio of long-term debt was comprised of fixed-rate instruments and variable-rate borrowings. The fair value of our fixed-rate debt is relatively sensitive to interest rate fluctuations. Our sensitivity to interest rate declines and corresponding increases in the fair value of our debt portfolio unfavorably affects our results of operations and cash flows only when we elect to repurchase or otherwise retire fixed-rate debt at prices above carrying value. Interest rate fluctuations generally do not impact the fair value of borrowings under our variable-rate debt, but may affect our results of operations and cash flows.

See Note 15 to the unaudited consolidated financial statements for additional information on the fair value of our debt.

ITEM 4. CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

An evaluation of the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13(a)-15(e) under the Securities Exchange Act of 1934, as amended) was carried out under the supervision and with the participation of our management, including our chief executive officer and chief financial officer. Based upon that evaluation, the chief executive officer and chief financial officer concluded that the design and operation of these disclosure controls and procedures were effective as of March 31, 2019, the end of the period covered by this report.

Internal Control over Financial Reporting and Changes in Internal Control over Financial Reporting

During the quarter ended March 31, 2019, there were no changes in our internal control over financial reporting that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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PART II – OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

We are the subject of, or a party to, a number of pending or threatened legal actions, contingencies and commitments involving

a variety of matters, including laws and regulations relating to the environment.

In the first quarter of 2019, MPLX entered into an agreement to settle notices of violation received from the West Virginia Department of Environmental Protection relating to earth disturbance activities in connection with construction of an NGL line. The $124,030 penalty payment is expected to be made in the second quarter of 2019.

ITEM 1A. RISK FACTORS

There have been no material changes from the risk factors previously disclosed in our Annual Report on Form 10-K for the year ended December 31, 2018 other than the risks described below related to the pending MLP Merger.

The pending merger between MPLX and ANDX (the “MLP Merger”) is subject to conditions, including certain conditions that may not be satisfied or completed on a timely basis, if at all. Failure to complete the MLP merger could have a material and adverse effect on us and, even if completed, the MLP merger may not achieve some or all of the anticipated benefits.

On May 8, 2019, we, together with MPLX and ANDX, announced the MLP Merger. Completion of the MLP Merger is subject to a number of customary conditions set forth in the MLP Merger Agreement, including approval by a majority of ANDX’s unitholders, MPLX’s registration statement on Form S-4 having become effective under the Securities Act of 1933, the approval to list MPLX units issuable in connection with the MLP Merger on the New York Stock Exchange, the absence of any governmental order or law prohibiting the consummation of the MLP Merger, the accuracy of each party’s representations and warranties under the MLP Merger Agreement (subject to the materiality standards set forth in the MLP Merger Agreement), MPLX’s and ANDX’s performance of their respective obligations under the MLP Merger Agreement in all material respects, and the receipt by both parties from their respective counsels of a written opinion regarding the U.S. federal income tax treatment of the transaction. These and other conditions to the closing of the MLP Merger may not be fulfilled in a timely manner or at all, and, accordingly, the MLP Merger may be delayed or may not be completed.

If the MLP Merger is not completed, our ongoing businesses may be adversely affected and, without realizing any of the benefits of having completed the MLP Merger, we will be subject to a number of risks, including the following:

• we will be required to pay our costs relating to the MLP Merger, such as legal, accounting and financial advisory expenses, whether or not MLP Merger is completed;

• time and resources committed by our management to matters relating to MLP Merger could otherwise have been devoted to pursuing other beneficial opportunities; and

• the market price of our common stock could decline to the extent that the current market price reflects a market assumption that the MLP Merger will be completed.

In addition, even if completed there can be no assurance that the MLP Merger will deliver the strategic, financial and operational benefits anticipated by us.

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

The following table sets forth a summary of our purchases during the quarter ended March 31, 2019, of equity securities that are registered by MPC pursuant to Section 12 of the Securities Exchange Act of 1934, as amended.

Period	Total Number of Shares Purchased(a)	Average Price Paid per Share(b)		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs	Maximum Dollar Value of Shares that May Yet Be Purchased Under the Plans or Programs(c)
01/01/19-01/31/19	4,490,477	$	63.48	4,489,490	$	4,619,604,825
02/01/19-02/28/19	4,398,691	64.84		4,395,511	4,334,605,410
03/01/19-03/31/19	5,204,982	60.97		5,167,580	4,019,606,059
Total	14,094,150	62.98		14,052,581

^(a)  The amounts in this column include 987, 3,180 and 37,402 shares of our common stock delivered by employees to MPC, upon vesting of restricted stock, to satisfy tax withholding requirements in January, February and March, respectively.

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^(b)  Amounts in this column reflect the weighted average price paid for shares purchased under our share repurchase authorizations and for shares tendered to us in satisfaction of employee tax withholding obligations upon the vesting of restricted stock granted under our stock plans. The weighted average price includes commissions paid to brokers on shares purchased under our share repurchase authorizations.

^(c)  On April 30, 2018, we announced that our board of directors had approved a $5.0 billion share repurchase authorization. This share repurchase authorization has no expiration date. The share repurchase authorization announced on April 30, 2018, together with prior authorizations, results in a total of $18.0 billion of share repurchase authorizations since January 1, 2012.

ITEM 5. OTHER INFORMATION

None

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ITEM 6. EXHIBITS

			Incorporated by Reference			Filed Herewith	Furnished Herewith
Exhibit Number	Exhibit Description	Form	Exhibit	Filing Date	SEC File No.
2.1*	Agreement and Plan of Merger, dated as of April 29, 2018, by and among MPC, Andeavor, Mahi Inc. and Mahi LLC	8-K	2.1	4/30/2018	001-35054
2.2	Amendment to Agreement and Plan of Merger, dated as of July 3, 2018, by and among Andeavor, MPC, Mahi Inc. and Mahi LLC	S-4/A	2.2	7/5/2018	333-225244
2.3	Second Amendment to Agreement and Plan of Merger, dated as of September 18, 2018, by and among Andeavor, MPC, Mahi Inc. and Mahi LLC	8-K	2.1	9/18/2018	001-35054
2.4 *	Agreement and Plan of Merger, dated as of May 7, 2019, by and among Andeavor Logistics LP, Tesoro Logistics GP, LLC, MPLX LP, MPLX GP LLC and MPLX MAX LLC.	8-K	2.1	5/8/2019	001-35054
3.1	Restated Certificate of Incorporation of MPC, dated October 1, 2018	8-K	3.2	10/1/2018	001-35054
3.2	Amended and Restated Bylaws of MPC dated February 27, 2019	10-K	3.2	2/28/2019	001-35054
10.1	Restricted Stock Award Agreement - Officer					X
10.2	Nonqualified Stock Option Award Agreement - Officer					X
10.3	Performance Unit Award Agreement 2019 - 2021 Performance Cycle					X
10.4	First Amendment to Fourth Amended and Restated Omnibus Agreement, dated as of January 30, 2019, among Andeavor LLC, Marathon Petroleum Company LP, Tesoro Refining & Marketing Company LLC, Tesoro Companies, Inc., Tesoro Alaska Company LLC, Andeavor Logistics LP and Tesoro Logistics GP, LLC	10-K	10.77	2/28/2019	001-35054
10.5	Support Agreement, dated as of May 7, 2019, by and among MPLX LP, Andeavor Logistics LP, Tesoro Logistics GP, LLC, Western Refining Southwest, Inc. and Marathon Petroleum Corporation.	8-K	10.1	5/8/2019	001-35054
31.1	Certification of Chief Executive Officer pursuant to Rule 13(a)-14 and 15(d)-14 under the Securities Exchange Act of 1934					X
31.2	Certification of Chief Financial Officer pursuant to Rule 13(a)-14 and 15(d)-14 under the Securities Exchange Act of 1934					X
32.1	Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350						X
32.2	Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350						X
101.INS	XBRL Instance Document					X
101.SCH	XBRL Taxonomy Extension Schema					X
101.PRE	XBRL Taxonomy Extension Presentation Linkbase					X
101.CAL	XBRL Taxonomy Extension Calculation Linkbase					X
101.DEF	XBRL Taxonomy Extension Definition Linkbase					X
101.LAB	XBRL Taxonomy Extension Label Linkbase					X

* Schedules have been omitted pursuant to Item 601(b)(2) of Regulation S-K. Marathon Petroleum Corporation hereby undertakes to furnish supplementally a copy of any omitted schedule upon request by the SEC.

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SIGNATURES

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.

May 9, 2019	MARATHON PETROLEUM CORPORATION
	By:	/s/ John J. Quaid
		John J. Quaid Vice President and Controller

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EX-10.1

EXHIBIT 10.1

MARATHON PETROLEUM CORPORATION RESTRICTED STOCK AWARD AGREEMENT

OFFICER

As evidenced by this Award Agreement and under the Amended and Restated Marathon Petroleum Corporation 2012 Incentive Compensation Plan (the “Plan”), Marathon Petroleum Corporation (the “Corporation”) has granted to [NAME] (the “Participant”), an employee of the Corporation or a Subsidiary, on [DATE] (the “Grant Date”), [NUMBER] shares of Restricted Stock (“Restricted Shares”). The number of Restricted Shares awarded is subject to adjustment as provided in the Plan, and the Restricted Shares are subject to the following terms and conditions:

1.Relationship to the Plan. This grant of Restricted Shares is subject to all of the terms, conditions and provisions of the Plan and administrative interpretations thereunder, if any, that have been adopted by the Committee. Except as otherwise defined in this Award Agreement, capitalized terms shall have the same meanings given to them under the Plan. To the extent that any provision of this Award Agreement conflicts with the express terms of the Plan, the terms of the Plan shall control and, if necessary, the applicable provisions of this Award Agreement shall be hereby deemed amended so as to carry out the purpose and intent of the Plan.

2. Vesting and Forfeiture of Restricted Shares.

(a)The Restricted Shares shall vest incrementally in three cumulative annual installments, as follows:

(i) one-third of the Restricted Shares shall vest upon the completion of the service period which commences on the Grant Date and ends on the first anniversary of the Grant Date;

(ii) an additional one-third of the Restricted Shares shall vest upon the completion of the service period which commences on the first anniversary of the Grant Date and ends on the second anniversary of the Grant Date; and

(iii) all remaining Restricted Shares shall vest upon the completion of the service period which commences on the second anniversary of the Grant Date and ends on the third anniversary of the Grant Date;

provided, however, that the Participant must be in continuous Employment from the Grant Date through the completion of the service period as listed above for each annual installment in order for the Restricted Shares for each annual installment to vest. If the Employment of the Participant is terminated for any reason (including non-Mandatory Retirement) other than death or Mandatory Retirement, any Restricted Shares that have not vested as of the date of such termination of Employment shall be forfeited to the Corporation.

(b)The Restricted Shares shall immediately vest in full, irrespective of the limitations set forth in subparagraph (a) of this Paragraph 2, upon the events set out below:

(i) termination of the Participant’s Employment due to death;

(ii) termination of the Participant’s Employment due to Mandatory Retirement; or

(iii) the Participant’s Qualified Termination provided that as of such Qualified Termination the Participant has been in continuous Employment since the Grant Date.

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3.Issuance of Shares. Effective as of the Grant Date, the Committee or its designated representative shall cause a number of shares of Common Stock equal to the number of Restricted Shares to be issued and registered in the Participant’s name, subject to the conditions and restrictions set forth in this Award Agreement and the Plan. Such issuance and registration shall be evidenced by an entry on the registry books of the Corporation. Any book entries evidencing the Restricted Shares shall carry or be endorsed with a legend referring to the conditions and restrictions set forth in this Award Agreement and the Plan. The Participant shall not be entitled to release of the restrictions on the book entry evidencing such Restricted Shares for any portion of the Restricted Shares unless and until the related Restricted Shares have vested pursuant to Paragraph 2. In the event the Restricted Shares are forfeited in full or in part, the Participant hereby consents to the relinquishment of the forfeited Restricted Shares theretofore issued and registered in the Participant’s name to the Corporation at that time.

4.Conditions Precedent. This Paragraph 4 shall apply to this Award notwithstanding any other provision of this Award Agreement to the contrary. The Participant’s services to the Corporation and its Subsidiaries are unique, extraordinary and essential to the business of the Corporation and its Subsidiaries, particularly in view of the Participant’s access to the Corporation’s or its Subsidiaries’ confidential information and trade secrets. Accordingly, in consideration of this Award Agreement and by accepting this Award, the Participant agrees that in order to otherwise vest in any right to payment of Restricted Shares under Paragraph 2, the Participant must satisfy the following conditions to and including the vesting date for each applicable annual installment or other applicable portion of the Award, and including any dividend right under the Award, under the vesting provisions in Paragraph 2:

(a)The Participant agrees that the Participant will not, without the prior written approval of the Board, at any time during the term of the Participant’s Employment and for a period of one year following the date on which the Participant’s Employment terminates (the “Restricted Period”), directly or indirectly, serve as an officer, director, owner, contractor, consultant, or employee of any the following organizations (or any of their respective subsidiaries or divisions): BP plc, Chevron Corporation; ExxonMobil Corporation, HollyFrontier Corporation; PBF Energy Inc.; Phillips 66; Valero Energy Corporation; Buckeye Partners, L.P.; DCP Midstream Partners, L.P; Enterprise Product Partners; Gas; Genesis Energy, L.P. ; Holly Energy Partners L.P.; Magellan Midstream Partners, L.P.; Phillips 66 Partners, L.P.; Plains All American Pipeline L.P.; Western Gas Equity Partners, or otherwise engage in any business activity directly or indirectly competitive with the business of the Corporation or any of its Subsidiaries as in effect from time to time.

(b)The Participant agrees that during the term of the Participant’s Employment and for a period of one year following the date on which the Participant’s Employment terminates, the Participant will not, alone or in conjunction with another party, hire, solicit for hire, aid in or facilitate the hire, or cause to be hired, either as an employee, contractor or consultant, any individual who is currently engaged, or was engaged at any time during the six month period prior such event, as an employee, contractor or consultant of the Corporation or any of its Subsidiaries.

(c)The Participant agrees that the Participant may not, either during the Participant’s Employment or thereafter, make or encourage others to make any public statement or release any information or otherwise engage in any conduct that is intended to, or reasonably could be foreseen to, embarrass, criticize or harm the reputation or goodwill of the Corporation or any of its Subsidiaries, or any of their employees, directors or shareholders; provided that this shall not preclude the Participant from reporting to the Corporation’s management or directors or to the

2

government or a regulator conduct the Participant believes to be in violation of the law or the Corporation’s Code of Business Conduct or responding truthfully to questions or requests for information to the government, a regulator or in a court of law in connection with a legal or regulatory investigation or proceeding.

(d)The Participant agrees and understands that the Corporation and its Subsidiaries own and/or control information and material which is not generally available to third parties and which the Corporation or its Subsidiaries consider confidential, including, without limitation, methods, products, processes, customer lists, trade secrets and other information applicable to its business and that it may from time to time acquire, improve or produce additional methods, products, processes, customers lists, trade secrets and other information (collectively, the “Confidential Information”). The Participant acknowledges that each element of the Confidential Information constitutes a unique and valuable asset of the Corporation and its Subsidiaries, and that certain items of the Confidential Information have been acquired from third parties upon the express condition that such items would not be disclosed to the Corporation or a Subsidiary and the officers and agents thereof other than in the ordinary course of business. The Participant acknowledges that disclosure of the Confidential Information to and/or use by anyone other than in the Corporation’s or its Subsidiaries’ ordinary course of business would result in irreparable and continuing damage to the Corporation and its Subsidiaries. Accordingly, the Participant agrees to hold the Confidential Information in the strictest secrecy, and covenants that, during the term of the Participant’s Employment or at any time thereafter, the Participant will not, without the prior written consent of the Board, directly or indirectly, allow any element of the Confidential Information to be disclosed, published or used, nor permit the Confidential Information to be discussed, published or used, either by the Participant or by any third parties, except in effecting the Participant’s duties for the Corporation and its Subsidiaries in the ordinary course of business.

(e)The Participant agrees that in addition to the forfeiture provisions otherwise provided for in this Award Agreement, upon the Participant’s failure to satisfy in any respect of any of the conditions described in Paragraphs 4(a), (b), (c) or (d), any unvested and unpaid portion of this Award at the time of such breach shall be forfeited, and the rights of the Participant and the obligations of the Corporation under this Award Agreement shall be satisfied in full, in each case to the extent permitted by applicable law.

5. Forfeiture or Repayment Resulting from Forfeiture Event.

(a)If there is a Forfeiture Event either during the Participant’s Employment or within two years after termination of the Participant’s Employment, then the Committee may, but is not obligated to, cause all of the Participant’s unvested Restricted Shares to be forfeited by the Participant and returned to the Corporation.

(b)If there is a Forfeiture Event either during the Participant’s Employment or within two years after termination of the Participant’s Employment, then with respect to Restricted Shares granted under this Award Agreement that have vested, the Committee may, but is not obligated to, require that the Participant pay to the Corporation an amount (the “Forfeiture Amount”) up to (but not in excess of) the lesser of (i) the value of such previously vested Restricted Shares as of the date such shares vested or (ii) the value of such previously vested Restricted Shares as of the date on which the Committee makes a demand for payment of the Forfeiture Amount. Any Forfeiture Amount shall be paid by the Participant within 60 days of receipt from the Corporation of written notice requiring payment of such Forfeiture Amount.

3

(c)This Paragraph 5 shall apply notwithstanding any provision of this Award Agreement to the contrary and is meant to provide the Corporation with rights in addition to any other remedy which may exist in law or in equity. This Paragraph 5 shall not apply to the Participant following the effective time of a Change in Control.

(d)Notwithstanding the foregoing or any other provision of this Award Agreement to the contrary, the Participant agrees that the Corporation may also require that the Participant repay to the Corporation any compensation paid to the Participant under this Award Agreement, as is required by the provisions of the Dodd-Frank Wall Street Reform and Consumer Protection Act and the regulations thereunder or any other “clawback” provisions as required by law or by the applicable listing standards of the exchange on which the Common Stock is listed for trading.

6.Taxes. Pursuant to the applicable provisions of the Plan, the Corporation or its designated representative shall have the right to withhold applicable taxes from the shares of Common Stock otherwise deliverable to the Participant due to the vesting of Restricted Shares pursuant to this Award Agreement (to the extent such withholding does not violate Section 409A of the Code), or from other compensation payable to the Participant, at the time of the vesting and delivery of such shares.

7.Shareholder Rights; Dividends. Unless and until the Restricted Shares are forfeited, the Participant shall have the rights of a shareholder with respect to the Restricted Shares as of the Grant Date, including the right to vote the Restricted Shares and the right to receive dividends. Dividends, if any, declared by the Corporation, will accrue and be payable on the Restricted Shares and will be subject to the same vesting and forfeiture provisions applicable to the underlying Restricted Shares. Any dividends that accrue on the Restricted Shares from the Grant Date to the date on which the Restricted Shares vest pursuant to Paragraph 2 shall be paid in cash in a lump sum to the Participant on the 15th day after such applicable vesting date. The Participant consents to receiving any such dividends through the Corporation’s payroll as the Corporation may in its discretion direct, and, accordingly, the Participant further consents to the Corporation’s transfer agent to paying such dividends to the Corporation on the Participant’s behalf and for further payment by the Corporation to the Participant.

8.Nonassignability. Upon the Participant’s death, the Restricted Shares shall be transferred to the Participant’s estate. Otherwise, the Participant may not sell, transfer, assign, pledge or otherwise encumber any portion of the Restricted Shares, and any attempt to sell, transfer, assign, pledge or encumber any portion of the Restricted Shares shall have no effect.

9.No Employment Guaranteed. Nothing in this Award Agreement shall give the Participant any rights to (or impose any obligations for) continued Employment by the Corporation or any Subsidiary or successor, nor shall it give such entities any rights (or impose any obligations) with respect to continued performance of duties by the Participant.

10.Modification of Agreement. Any modification of this Award Agreement shall be binding only if evidenced in writing and signed by an authorized representative of the Corporation, provided that no modification may, without the consent of the Participant, adversely affect the rights of the Participant hereunder.

11.Officer Holding Requirement. Participant agrees that any shares vested under this Award shall be subject an additional holding period of one year from the date on which the Award is settled, during which holding

4

period such shares (net of shares used to satisfy the applicable tax withholding requirements) may not be sold or transferred by the Participant. This holding requirement shall cease to apply upon the death, retirement or other separation from service of the Participant during the holding period.

12. Definitions. For purposes of this Award Agreement:

“Employment” means employment with the Corporation or any of its Subsidiaries. For purposes of this Award Agreement, Employment shall also include any period of time during which the Participant is on Disability status. The length of any period of Employment shall be determined by the Corporation or the Subsidiary that either (i) employs the Participant or (ii) employed the Participant immediately prior to the Participant’s termination of Employment.

“Forfeiture Event” means the occurrence of at least one of the following (a) the Corporation is required, pursuant to a determination made by the Securities and Exchange Commission or by the Audit Committee of the Board, to prepare a material accounting restatement due to the noncompliance of the Corporation with any financial reporting requirement under applicable securities laws as a result of misconduct, and the Committee determines that (1) the Participant knowingly engaged in the misconduct, (2) the Participant was grossly negligent with respect to such misconduct or (3) the Participant knowingly or grossly negligently failed to prevent the misconduct or (b) the Committee concludes that the Participant engaged in fraud, embezzlement or other similar misconduct materially detrimental to the Corporation.

“Mandatory Retirement” means termination of Employment as a result of the Corporation’s policy, if any, in effect at the time of the Grant Date, requiring the mandatory retirement of officers and/or other employees upon reaching a certain age or milestone.

“Qualified Termination” for purposes of this Award Agreement shall have the same definition as under the Marathon Petroleum Corporation Amended and Restated Executive Change in Control Severance Benefits Plan, as in effect on the Grant Date, and such definition and associated terms are hereby incorporated into this Award Agreement by reference.

Marathon Petroleum Corporation
By
	Authorized Officer

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EX-10.2

EXHIBIT 10.2

MARATHON PETROLEUM CORPORATION NONQUALIFIED STOCK OPTION AWARD AGREEMENT

OFFICER

As evidenced by this Award Agreement, Marathon Petroleum Corporation (the “Corporation”) has granted to [NAME] (the “Participant”), an employee of the Corporation or a Subsidiary, on [DATE] (the “Grant Date”), a right (the “Option”) to purchase from the Corporation [NUMBER] shares of Common Stock of the Corporation at a grant price of $[PRICE] per share (the “Grant Price”), pursuant to the Amended and Restated Marathon Petroleum Corporation 2012 Incentive Compensation Plan (the “Plan”), with such number of shares and such price per share being subject to adjustment as provided in the Plan, and further subject to the following terms and conditions:

1.Relationship to the Plan. This Option is subject to all of the terms, conditions and provisions of the Plan and administrative interpretations thereunder, if any, that have been adopted by the Committee. Except as otherwise defined in this Award Agreement, capitalized terms shall have the same meanings given to them under the Plan. To the extent that any provision of this Award Agreement conflicts with the express terms of the Plan, the terms of the Plan shall control and, if necessary, the applicable provisions of this Award Agreement shall be hereby deemed amended so as to carry out the purpose and intent of the Plan. References to the Participant also include the heirs or other legal representatives of the Participant.

2. Schedule for Exercisability of Options.

(a) This Option shall become exercisable in three cumulative annual installments, as follows:

(i) one-third of the Option Shares shall become exercisable on the first anniversary of the Grant Date;

(ii) an additional one-third of the Option Shares shall become exercisable on the second anniversary of the Grant Date; and

(iii) the remaining one-third of the Option Shares shall become exercisable on the third anniversary of the Grant Date;

provided, however, that the Participant must be in continuous Employment from the Grant Date through the applicable date of exercisability of each installment in order for the applicable portion of the Option to become exercisable with respect to additional shares of Common Stock on such date. If the Employment of the Participant is terminated for any reason other than death or Retirement, any Option Shares that are not exercisable as of the date of such termination of Employment shall be forfeited to the Corporation.

(b) This Option shall become fully exercisable, irrespective of the limitations set forth in subparagraph

(a) above, upon:

(i) termination of the Participant’s Employment due to death;

(ii) termination of the Participant’s Employment due to Retirement; or

(iii) the Participant’s Qualified Termination, provided that as of such Qualified Termination the Participant had been in continuous Employment since the Grant Date.

1

3. Expiration of Option.

(a)Expiration of Option Period. The Option Period shall expire on the tenth anniversary of the Grant

Date.

(b)Termination of Employment Due to Death or Retirement. If Employment of the Participant is terminated due to death or Retirement, the Option shall expire upon the earlier of (i) five years following the date of termination of Employment or (ii) expiration of the Option Period. The death of the Participant following Retirement but prior to the expiration of the Option shall have no effect on the expiration of the Option.

(c)Termination of Employment by the Corporation for Cause or Due to Resignation. If Employment of the Participant is terminated by the Corporation or any of its Subsidiaries for Cause or due to voluntary resignation by the Participant, the Option shall expire upon the termination of Employment.

(d)Termination of Employment by the Corporation Other Than For Cause. If Employment of the Participant is terminated by the Corporation or any of its affiliates for any reason other than Cause, the Option shall expire upon the earlier of (i) 90 days following the date of termination of Employment or (ii) expiration of the Option Period.

(e)Termination of Employment Following a Qualified Termination. If Employment of the Participant is terminated in a Qualified Termination, the Option shall remain exercisable throughout the Option Period.

4.Employment with a Competitor. Notwithstanding anything herein to the contrary, in the event the Committee, the Chief Executive Officer, or an authorized officer determines that the Participant has accepted or intends to accept employment with a competitor of any business unit of the Corporation, the Committee, the Chief Executive Officer, or the authorized officer may cancel the Option by written notice to the Participant.

5.Conditions Precedent. This Paragraph 5 shall apply to this Award notwithstanding any other provision of this Award Agreement to the contrary. The Participant’s services to the Corporation and its Subsidiaries are unique, extraordinary and essential to the business of the Corporation and its Subsidiaries, particularly in view of the Participant’s access to the Corporation’s or its Subsidiaries’ confidential information and trade secrets. Accordingly, in consideration of this Award Agreement and by accepting this Award, the Participant agrees that in order to otherwise vest in any right to any portion of the Option under Paragraph 2, the Participant must satisfy the following conditions to and including the vesting date for each applicable annual installment or other applicable portion of the Option under the vesting provisions in Paragraph 2:

(a)The Participant agrees that the Participant will not, without the prior written approval of the Board, at any time during the term of the Participant’s Employment and for a period of one year following the date on which the Participant’s Employment terminates (the “Restricted Period”), directly or indirectly, serve as an officer, director, owner, contractor, consultant, or employee of any the following organizations (or any of their respective subsidiaries or divisions): BP plc, Chevron Corporation; ExxonMobil Corporation, HollyFrontier Corporation; PBF Energy Inc.; Phillips 66; Valero Energy Corporation; Buckeye Partners, L.P.; DCP Midstream Partners, L.P; Enterprise Product Partners; Gas; Genesis Energy, L.P. ; Holly Energy Partners L.P.; Magellan Midstream Partners, L.P.; Phillips 66 Partners, L.P.; Plains All American Pipeline L.P.; Western Gas Equity Partners, or otherwise engage in any business activity directly or indirectly competitive with the business of the Corporation or any of its Subsidiaries as in effect

2

from time to time.

(b)The Participant agrees that during the term of the Participant’s Employment and for a period of one year following the date on which the Participant’s Employment terminates, the Participant will not, alone or in conjunction with another party, hire, solicit for hire, aid in or facilitate the hire, or cause to be hired, either as an employee, contractor or consultant, any individual who is currently engaged, or was engaged at any time during the six month period prior such event, as an employee, contractor or consultant of the Corporation or any of its Subsidiaries.

(c)The Participant agrees that the Participant may not, either during the Participant’s Employment or thereafter, make or encourage others to make any public statement or release any information or otherwise engage in any conduct that is intended to, or reasonably could be foreseen to, embarrass, criticize or harm the reputation or goodwill of the Corporation or any of its Subsidiaries, or any of their employees, directors or shareholders; provided that this shall not preclude the Participant from reporting to the Corporation’s management or directors or to the government or a regulator conduct the Participant believes to be in violation of the law or the Corporation’s Code of Business Conduct or responding truthfully to questions or requests for information to the government, a regulator or in a court of law in connection with a legal or regulatory investigation or proceeding.

(d)The Participant agrees and understands that the Corporation and its Subsidiaries own and/or control information and material which is not generally available to third parties and which the Corporation or its Subsidiaries consider confidential, including, without limitation, methods, products, processes, customer lists, trade secrets and other information applicable to its business and that it may from time to time acquire, improve or produce additional methods, products, processes, customers lists, trade secrets and other information (collectively, the “Confidential Information”). The Participant acknowledges that each element of the Confidential Information constitutes a unique and valuable asset of the Corporation and its Subsidiaries, and that certain items of the Confidential Information have been acquired from third parties upon the express condition that such items would not be disclosed to the Corporation or a Subsidiary and the officers and agents thereof other than in the ordinary course of business. The Participant acknowledges that disclosure of the Confidential Information to and/or use by anyone other than in the Corporation’s or its Subsidiaries’ ordinary course of business would result in irreparable and continuing damage to the Corporation and its Subsidiaries. Accordingly, the Participant agrees to hold the Confidential Information in the strictest secrecy, and covenants that, during the term of the Participant’s Employment or at any time thereafter, the Participant will not, without the prior written consent of the Board, directly or indirectly, allow any element of the Confidential Information to be disclosed, published or used, nor permit the Confidential Information to be discussed, published or used, either by Participant or by any third parties, except in effecting the Participant’s duties for the Corporation and its Subsidiaries in the ordinary course of business.

(e)The Participant agrees that in addition to the forfeiture provisions otherwise provided for in this Award Agreement, upon the Participant’s failure to satisfy in any respect of any of the conditions described in Paragraphs 5(a), (b), (c) or (d), any unvested and unexercised portion of the Option provided for under this Award at the time of such breach shall be forfeited, and the rights of the Participant and the obligations of the Corporation under this Award Agreement shall be satisfied in full, in each case to the extent permitted by applicable law.

6. Forfeiture or Repayment Resulting from Forfeiture Event.

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(a)Forfeiture of Unexercised Option. If a Forfeiture Event (as defined herein) occurs during the Participant’s Employment or within two years following Participant’s termination of Employment, the Committee may, but is not obligated to, cause the Option granted under this Award Agreement to be forfeited with respect to some or all shares of Common Stock subject to the Option.

(b)Repayment of Spread on Exercised Option. If a Forfeiture Event occurs during the Participant’s Employment or within two years following Participant’s termination of Employment, the Committee may, but is not obligated to, require the Participant to pay to the Corporation an amount up to (but not in excess of) the difference between the Grant Price and market price of the Option on the date of exercise with respect to any shares for which the Option has been exercised (the “Forfeited Spread Amount”). Any Forfeited Spread Amount shall be paid by the Participant within 60 days of receipt from the Corporation of written notice requiring payment of such Forfeited Spread Amount.

(c)Application of Forfeiture Provisions. This Paragraph 6 shall apply notwithstanding any provision of this Award Agreement to the contrary and is meant to provide the Corporation with rights in addition to any other remedy which may exist in law or in equity. This Paragraph 6 shall not apply to the Participant following the effective time of a Change in Control.

(d)Notwithstanding the foregoing or any other provision of this Award Agreement to the contrary, the Participant agrees that the Corporation may also require that the Participant repay to the Corporation any compensation paid to the Participant under this Award Agreement, as is required by the provisions of the Dodd-Frank Wall Street Reform and Consumer Protection Act and the regulations thereunder or any other “clawback” provisions as required by law or by the applicable listing standards of the exchange on which the Common Stock is listed for trading.

7.Exercise of Option. Subject to the limitations set forth herein and in the Plan, this Option may be exercised in whole or in part by providing notice to the Committee or its designated representative of the number of Option Shares to be exercised. Such notice shall be accompanied by payment of the Grant Price of such Option Shares in cash or, at the election of the Participant, in shares of Common Stock or any combination thereof. For purposes of determining the amount, if any, of the purchase price satisfied by payment in Common Stock, such Common Stock shall be valued at its Fair Market Value on the date of exercise. Upon receipt of the purchase price, the Corporation or its designated representative shall issue or cause to be issued to the Participant a number of shares of Common Stock equal to the number of Option Shares then exercised.

8.Taxes. The Corporation or its designated representative shall have the right to withhold applicable taxes from the shares of Common Stock otherwise payable to the Participant upon exercise of the Option or from compensation otherwise payable to the Participant at the time of exercise pursuant to the applicable provisions of the Plan.

9.Shareholder Rights. The Participant shall have no rights of a shareholder with respect to the Option Shares unless and until such time as the Option has been exercised and shares of Common Stock have been issued to the Participant in conjunction with the exercise of the Option.

10.Nonassignability. During the Participant’s lifetime, the Option may be exercised only by the Participant or by the Participant’s guardian or legal representative. Upon the Participant’s death, the Option shall be

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transferred to the Participant’s estate. Otherwise, the Participant may not sell, transfer, assign, pledge or otherwise encumber any portion of the Option, and any attempt to sell, transfer, assign, pledge or encumber any portion of the Option shall have no effect.

11.No Employment Guaranteed. Nothing in this Award Agreement shall give the Participant any rights to (or impose any obligations for) continued Employment by the Corporation or any affiliate thereof or successor thereto, nor shall it give such entities any rights (or impose any obligations) with respect to continued performance of duties by the Participant.

12.Modification of Agreement. Any modification of this Award Agreement shall be binding only if evidenced in writing and signed by an authorized representative of the Corporation, provided that no modification may, without the consent of the Participant, adversely affect the rights of the Participant hereunder.

13. Definitions. For purposes of this Award Agreement:

“Cause” means termination from Employment by the Corporation or its Subsidiaries due to unacceptable performance, gross misconduct, gross negligence, material dishonesty, material acts detrimental or destructive to the Corporation or its Subsidiaries, employees or property, or any material violation of the policies of the Corporation or its Subsidiaries.

“Employment” means employment with the Corporation or any of its affiliates. For purposes of this Option, Employment shall also include any period of time during which the Participant is on Disability status. The length of any period of Employment shall be determined by the Corporation or the Subsidiary that either (i) employs the Participant or (ii) employed the Participant immediately prior to the Participant’s termination of Employment.

“Forfeiture Event” means the occurrence of at least one of the following (a) the Corporation is required, pursuant to a determination made by the Securities and Exchange Commission or by the Audit Committee of the Board, to prepare a material accounting restatement due to the noncompliance of the Corporation with any financial reporting requirement under applicable securities laws as a result of misconduct, and the Committee determines that (1) the Participant knowingly engaged in the misconduct, (2) the Participant was grossly negligent with respect to such misconduct or (3) the Participant knowingly or grossly negligently failed to prevent the misconduct or (b) the Committee concludes that the Participant engaged in fraud, embezzlement or other similar misconduct materially detrimental to the Corporation.

“Option Period” means the period commencing upon the Participant’s receipt of this Award Agreement and ending on the date on which the Option expires pursuant to Paragraph 3(a).

“Option Shares” means the shares of Common Stock covered by this Option.

“Qualified Termination” for purposes of this Award Agreement shall have the same definition as under the Marathon Petroleum Corporation Amended and Restated Executive Change in Control Severance Benefits Plan, as in effect on the Grant Date (disregarding subsection II of

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such definition), and such definition and associated terms are hereby incorporated into this Award Agreement by reference.

“Retirement” means (a) for an Employee with ten or more years of Employment, termination on or after the Employee’s 50th birthday, or (b) termination on or after the Employee’s 65th birthday.

Marathon Petroleum Corporation
By
	Authorized Officer

6

EX-10.3

EXHIBIT 10.3

MARATHON PETROLEUM CORPORATION PERFORMANCE UNIT AWARD AGREEMENT 2019 – 2021 PERFORMANCE CYCLE

As evidenced by this Award Agreement and under the Amended and Restates Marathon Petroleum Corporation 2012 Incentive Compensation Plan (the “Plan”), Marathon Petroleum Corporation (the “Corporation”) has granted to [NAME] (the “Participant”), an employee of the Corporation or a Subsidiary, on [DATE] (the “Grant Date”), [NUMBER] performance units (“Performance Units”), conditioned upon the Corporation’s TSR ranking relative to the Peer Group for the Performance Cycle as established by the Compensation Committee of the Board of Directors of the Corporation (the “Committee”), and as set forth herein. The Performance Units are subject to the following terms and conditions:

1.Relationship to the Plan. This grant of Performance Units is subject to all of the terms, conditions and provisions of the Plan and administrative interpretations thereunder, if any, that have been adopted by the Committee. Except as otherwise defined in this Award Agreement, capitalized terms shall have the same meanings given to them under the Plan. To the extent that any provision of this Award Agreement conflicts with the express terms of the Plan, the terms of the Plan shall control and, if necessary, the applicable provisions of this Award Agreement shall be hereby deemed amended so as to carry out the purpose and intent of the Plan. References to the Participant also include the heirs or other legal representatives of the Participant.

2.Determination of Payout Percentage. As soon as administratively feasible following the close of the Performance Cycle, the Committee shall determine and certify the TSR Performance Percentile. The final Payout Percentage will be the simple average of the Payout Percentage of the four performance periods, which are as follows:

(i) January 1, 2019 through December 31, 2019;

(ii) January 1, 2020 through December 31, 2020;

(iii) January 1, 2021 through December 31, 2021; and

(iv) January 1, 2019 through December 31, 2021.

The Committee shall determine the TSR Performance Percentile and the Payout Percentage for each performance period as follows:

(a)First, the Committee shall determine the TSR Performance Percentile, and then the Payout Percentage as follows (using straight-line interpolation between the 30th percentile and the 50th percentile and between the 50th percentile and the 100th percentile:

TSR Performance Percentile	Payout Percentage
Ranked below 30th percentile	0%
Ranked at 30th percentile	50%
Ranked at 50th percentile	100%
Ranked at the 100th percentile	200%

(b) Notwithstanding anything herein to the contrary, if the Corporation’s TSR calculated for the

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performance period is negative, then the Payout Percentage for that performance period shall not exceed 100% regardless of the TSR Performance Percentile for the performance period.

(c)Notwithstanding anything herein to the contrary, the Committee has the sole and absolute authority and discretion to reduce the Payout Percentage as it may deem appropriate.

3.Vesting of Performance Units. Unless the Participant’s right to the Performance Units is previously forfeited or vested in accordance with Paragraphs 4, 5, 6, 7 or 8, following the Committee’s determinations pursuant to Paragraph 2, the Participant shall vest in and be entitled to receive a payment equal to the Payout Value. The Payout Value shall be distributed 75% in cash and 25% in Common Stock. The number of shares of Common Stock distributed shall be calculated by dividing 25% of the Payout Value by the Fair Market Value of the Common Stock on the date on which the Payout Percentage is certified by the Committee, rounding down to the nearest whole share. The remainder shall be paid in cash. Such payments shall be made as soon as administratively feasible following the Committee’s determination under Paragraph 2 and, in any event, between January 1 and March 15 immediately following the end of the Performance Cycle. If, in accordance with the Committee’s determination under Paragraph 2, the Payout Value is zero, the Participant shall immediately forfeit any and all rights to the Performance Units. Upon the vesting and/or forfeiture of the Performance Units pursuant to this Paragraph 3 and the making of the related cash payment, if any, the rights of the Participant and the obligations of the Corporation under this Award Agreement shall be satisfied in full.

4.Termination of Employment. Except as provided in Paragraphs 5, 6, 7, or 8, if the Participant’s Employment is terminated prior to the close of the Performance Cycle, the Participant’s right to the Performance Units shall be forfeited in its entirety as of the date of such termination, and the rights of the Participant and the obligations of the Corporation under this Award Agreement shall be terminated.

5.Termination of Employment due to Death. If Participant’s Employment is terminated by reason of death prior to the close of the Performance Cycle, the Participant’s right to receive the Performance Units shall vest in full as of the date of death and the Payout Percentage shall be 100%. The payment equal to the vested value of the Performance Units shall be made in accordance with Paragraph 3 as soon as administratively feasible but in all cases no later than the last day of the calendar year following the calendar year in which the Participant’s death occurs; provided, however, that the timing of the payment shall be determined in the sole discretion of the Board and no other individual or entity shall directly or indirectly designate the taxable year of payment. Such vesting shall satisfy the rights of the Participant and the obligations of the Corporation under this Award Agreement in full.

6.Termination of Employment due to Retirement. In the event of the Retirement of the Participant after nine months of the Performance Cycle have elapsed, the Participant’s Performance Units shall be settled based on the performance for the Performance Cycle and payable on a pro-rata basis as determined and certified by the Committee after the close of the Performance Cycle, as described below. Subject to the negative discretion of the Committee, the Participant will be entitled to receive a payment equal to the product of (i) the pro-rata vesting percentage equal to the days of Participant’s Employment during the Performance Cycle divided by the total days in the Performance Cycle and (ii) the Payout Value. Such payment shall be made as soon as administratively feasible following the Committee’s determination under Paragraph 2 and, in any event, between January 1 and March 15 immediately following the end of the Performance Cycle. If, in accordance with the Committee’s determination under Paragraph 2, the Payout Value is zero, the Participant shall immediately forfeit any and all rights to the Performance

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Units. Upon the vesting and/or forfeiture of the Performance Units pursuant to this Paragraph 6 and the making of the related cash payment, if any, the rights of the Participant and the obligations of the Corporation under this Award Agreement shall be satisfied in full. The death of the Participant following Retirement but prior to the close of the Performance Cycle shall have no effect on this Paragraph 6.

7.Vesting Upon a Qualified Termination. Notwithstanding anything in this Award to the contrary, upon a Participant’s Qualified Termination prior to the end of the Performance Cycle, the Participant’s right to receive the Performance Units, unless previously forfeited pursuant to Paragraph 4, shall vest in full and the Payout Percentage shall be determined as follows: (i) for the time period from the beginning of the Performance Cycle to the date of the Change in Control, the Payout Percentage shall be based upon actual TSR Performance Percentile; and (ii) for the time period from the date of the Change in Control to the Qualified Termination, the Payout Percentage shall be 100%. A payment equal to the vested value of the Performance Units shall be made in accordance with Paragraph 3, except that it shall be made 100% in cash and between January 1 and March 15 immediately following the end of the Performance Cycle. Such vesting shall satisfy the rights of the Participant and the obligations of the Corporation under this Award Agreement in full.

8.Termination of Employment due to Mandatory Retirement. In the event the Participant’s Employment is terminated as a result of Mandatory Retirement prior to the end of the Performance Cycle, the Participant’s Performance Units shall be settled based on the TSR Performance Percentile for the Performance Cycle. Following the Committee’s determinations pursuant to Paragraph 2, the Participant shall vest in and be entitled to receive a payment equal to the Payout Value. The payment shall be made as soon as administratively feasible following the Committee’s determination and, in any event, between January 1 and March 15 immediately following the end of the Performance Cycle. If, in accordance with the Committee’s determinations under Paragraph 2, the Payout Value is zero, the Participant shall immediately forfeit any and all rights to the Performance Units. Upon the vesting and/or forfeiture of the Performance Units pursuant to this Paragraph 8 and the making of the related cash payment, if any, the rights of the Participant and the obligations of the Corporation under this Award Agreement shall be satisfied in full. The death of the Participant following Mandatory Retirement but prior to the close of the Performance Cycle shall have no effect on this Paragraph 8.

9.Conditions Precedent. This Paragraph 9 shall apply to this Award notwithstanding any other provision of this Award Agreement to the contrary. The Participant’s services to the Corporation and its Subsidiaries are unique, extraordinary and essential to the business of the Corporation and its Subsidiaries, particularly in view of the Participant’s access to the Corporation’s or its Subsidiaries’ confidential information and trade secrets. Accordingly, in consideration of this Award Agreement and by accepting this Award, the Participant agrees that in order to otherwise vest in any right to payment of Performance Units under Paragraph 3, the Participant must satisfy the following conditions to and including the vesting date for each applicable annual installment or other applicable portion of the Award, under the vesting provisions in Paragraph 3:

(a)The Participant agrees that the Participant will not, without the prior written approval of the Board, at any time during the term of the Participant’s Employment and for a period of one year following the date on which the Participant’s Employment terminates (the “Restricted Period”), directly or indirectly, serve as an officer, director, owner, contractor, consultant, or employee of any the following organizations (or any of their respective subsidiaries or divisions): BP plc, Chevron Corporation; ExxonMobil Corporation, HollyFrontier Corporation; PBF Energy Inc.; Phillips 66; Valero Energy Corporation; Buckeye Partners, L.P.; DCP Midstream Partners, L.P; Enterprise Product

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Partners; Gas; Genesis Energy, L.P. ; Holly Energy Partners L.P.; Magellan Midstream Partners, L.P.; Phillips 66 Partners, L.P.; Plains All American Pipeline L.P.; Western Gas Equity Partners, or otherwise engage in any business activity directly or indirectly competitive with the business of the Corporation or any of its Subsidiaries as in effect from time to time.

(b)The Participant agrees that during the term of the Participant’s Employment and for a period of one year following the date on which the Participant’s Employment terminates, the Participant will not, alone or in conjunction with another party, hire, solicit for hire, aid in or facilitate the hire, or cause to be hired, either as an employee, contractor or consultant, any individual who is currently engaged, or was engaged at any time during the six month period prior such event, as an employee, contractor or consultant of the Corporation or any of its Subsidiaries.

(c)The Participant agrees that the Participant may not, either during the Participant’s Employment or thereafter, make or encourage others to make any public statement or release any information or otherwise engage in any conduct that is intended to, or reasonably could be foreseen to, embarrass, criticize or harm the reputation or goodwill of the Corporation or any of its Subsidiaries, or any of their employees, directors or shareholders; provided that this shall not preclude the Participant from reporting to the Corporation’s management or directors or to the government or a regulator conduct the Participant believes to be in violation of the law or the Corporation’s Code of Business Conduct or responding truthfully to questions or requests for information to the government, a regulator or in a court of law in connection with a legal or regulatory investigation or proceeding.

(d)The Participant agrees and understands that the Corporation and its Subsidiaries own and/or control information and material which is not generally available to third parties and which the Corporation or its Subsidiaries consider confidential, including, without limitation, methods, products, processes, customer lists, trade secrets and other information applicable to its business and that it may from time to time acquire, improve or produce additional methods, products, processes, customers lists, trade secrets and other information (collectively, the “Confidential Information”). The Participant acknowledges that each element of the Confidential Information constitutes a unique and valuable asset of the Corporation and its Subsidiaries, and that certain items of the Confidential Information have been acquired from third parties upon the express condition that such items would not be disclosed to the Corporation or a Subsidiary and the officers and agents thereof other than in the ordinary course of business. The Participant acknowledges that disclosure of the Confidential Information to and/or use by anyone other than in the Corporation’s or its Subsidiaries’ ordinary course of business would result in irreparable and continuing damage to the Corporation and its Subsidiaries. Accordingly, the Participant agrees to hold the Confidential Information in the strictest secrecy, and covenants that, during the term of the Participant’s Employment or at any time thereafter, the Participant will not, without the prior written consent of the Board, directly or indirectly, allow any element of the Confidential Information to be disclosed, published or used, nor permit the Confidential Information to be discussed, published or used, either by the Participant or by any third parties, except in effecting the Participant’s duties for the Corporation and its Subsidiaries in the ordinary course of business.

(e)The Participant agrees that in addition to the forfeiture provisions otherwise provided for in this Award Agreement, upon the Participant’s failure to satisfy in any respect of any of the conditions described in Paragraphs 9(a), (b), (c) or (d), any unvested and unpaid portion of this Award at the time of such breach shall be forfeited, and the rights of the Participant and the obligations of the Corporation under this Award Agreement shall be satisfied in full, in each case to the extent permitted by applicable law.

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10. Repayment or Forfeiture Resulting from Forfeiture Event.

(a)If there is a Forfeiture Event either during the Participant’s Employment or within three years after termination of the Participant’s Employment, then the Committee may, but is not obligated to, cause some or all of the Participant’s outstanding Performance Units to be forfeited by the Participant.

(b)If there is a Forfeiture Event either during the Participant’s Employment or within three years after termination of the Participant’s Employment and a payment has previously been made in settlement of Performance Units granted under this Award Agreement, the Committee may, but is not obligated to, require that the Participant pay to the Corporation an amount in cash (the “Forfeiture Amount”) up to (but not in excess of) the amount paid in settlement of the Performance Units.

(c)This Paragraph 10 shall apply notwithstanding any provision of this Award Agreement to the contrary and is meant to provide the Corporation with rights in addition to any other remedy which may exist in law or in equity. This Paragraph 10 shall not apply to the Participant following the effective time of a Change in Control.

(d)Notwithstanding the foregoing or any other provision of this Award Agreement to the contrary, the Participant agrees that the Corporation may also require that the Participant repay to the Corporation any compensation paid to the Participant under this Award Agreement, as is required by the provisions of the Dodd-Frank Wall Street Reform and Consumer Protection Act and the regulations thereunder or any other “clawback” provisions as required by law or by the applicable listing standards of the exchange on which the Common Stock is listed for trading.

11.Taxes. Pursuant to the applicable provisions of the Plan, the Corporation or its designated representative shall have the right to withhold applicable taxes from the shares of Common Stock and cash otherwise payable to the Participant, or from other compensation payable to the Participant (to the extent consistent with Section 409A of the Code), at the time of the vesting and delivery of such cash payment and shares.

12.No Shareholder Rights. The Participant shall in no way be entitled to any of the rights of a shareholder as a result of this Award Agreement unless and until such time as shares of Common Stock have been issued to the Participant in settlement of the Performance Units.

13.Nonassignability. Upon the Participant’s death, the Performance Units may be transferred by will or by the laws governing the descent and distribution of the Participant’s estate. Otherwise, the Participant may not sell, transfer, assign, pledge or otherwise encumber any portion of the Performance Units, and any attempt to sell, transfer, assign, pledge, or encumber any portion of the Performance Units shall have no effect.

14.No Employment Guaranteed. Nothing in this Award Agreement shall give the Participant any rights to (or impose any obligations for) continued Employment by the Corporation or any affiliate thereof or successor thereto, nor shall it give such entities any rights (or impose any obligations) with respect to continued performance of duties by the Participant.

15.Modification of Agreement. Any modification of this Award Agreement shall be binding only if evidenced in writing and signed by an authorized representative of the Corporation, provided that no modification

5

may, without the consent of the Participant, adversely affect the rights of the Participant hereunder.

16.Officer Holding Requirement. Participant agrees that any shares received by the Participant in settlement of this Award shall be subject an additional holding period of one year from the date on which the Award is settled, during which holding period such shares (net of shares used to satisfy the applicable tax withholding requirements) may not be sold or transferred by the Participant. This holding requirement shall cease to apply upon the death, retirement or other separation from service of the Participant during the holding period.

17. Definitions. For purposes of this Award Agreement:

“Beginning Stock Price” means the average of the daily closing price of common stock for the 20 trading days immediately prior to the commencement of the Performance Cycle, historically adjusted, if necessary, for any stock split, stock dividend, recapitalizations, or similar corporate events that occur during the measurement period.

“Change in Control” for purposes of this Award Agreement shall have the same definition as under the Marathon Petroleum Corporation Amended and Restated Executive Change in Control Severance Benefits Plan, as in effect on the Grant Date, and such definition and associated terms are hereby incorporated into this Award Agreement by reference.

“Employment” means employment with the Corporation or any of its Subsidiaries. For purposes of this Award Agreement, Employment shall also include any period of time during which the Participant is on Disability status. The length of any period of Employment shall be determined by the Corporation or the Subsidiary that either (i) employs the Participant or (ii) employed the Participant immediately prior to the Participant’s termination of Employment.

“Ending Stock Price” means the average of the daily closing price of common stock for the 20 trading days prior to the end of the Performance Cycle.

“Forfeiture Event” means the occurrence of at least one of the following (a) the Corporation is required, pursuant to a determination made by the Securities and Exchange Commission or by the Audit Committee of the Board, to prepare a material accounting restatement due to the noncompliance of the Corporation with any financial reporting requirement under applicable securities laws as a result of misconduct, and the Committee determines that (1) the Participant knowingly engaged in the misconduct, (2) the Participant was grossly negligent with respect to such misconduct or (3) the Participant knowingly or grossly negligently failed to prevent the misconduct or (b) the Committee concludes that the Participant engaged in fraud, embezzlement or other similar misconduct materially detrimental to the Corporation.

“Mandatory Retirement” means, as determined by the Board of Directors of the Corporation (or its delegate), a Participant’s mandatory retirement under the Marathon Petroleum Corporation Mandatory Retirement Policy, or equivalent thereto, provided such Mandatory Retirement constitutes a separation from service within the meaning of Section 409A of the Code.

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“Payout Percentage” means the percentage (from 0% to 200%) determined by the Committee in accordance with the procedures set forth in Paragraph 2, which shall be used to determine the Payout Value.

“Payout Value” means the product of the Payout Percentage, the number of Performance Units, and $1.00.

“Peer Group” means the group of companies that are pre-established by the Committee which principally represent a group of selected peers, or such other group of companies as selected and pre-established by the Committee. Such pre-established Peer Group is subject to the following adjustments:

(a)If a member of the Peer Group is substantially acquired by another company, the acquired Peer Group company will be removed from the Peer Group for the performance periods not yet completed and for the entire 36-month Performance Cycle.

(b)If a member of the Peer Group sells, spins-off, or disposes of a portion of its business, then such Peer Group company will remain in the Peer Group for the Performance Cycle unless such disposition(s) results in the disposition of more than 50% of such company’s total assets during the Performance Cycle.

(c)If a member of the Peer Group acquires another company, the acquiring Peer Group company will remain in the Peer Group for the Performance Cycle, unless the newly formed company’s primary business no longer satisfies the criteria for which such member was originally selected as a member of the Peer Group, then in such case the company shall be removed from the Peer Group.

(d)If a member of the Peer Group is delisted on all major U.S. stock exchanges, or is no longer publicly-traded, such company will be removed from the Peer Group for the Performance Cycle.

(e)If any member of the Peer Group splits its stock, such company’s TSR performance will be adjusted for the stock split so as not to give an advantage or disadvantage to such company by comparison to the other companies.

(f)Members of the Peer Group that file for bankruptcy, liquidation or reorganization during the Performance Cycle will remain in the Peer Group positioned below the lowest performing non-bankrupt member of the Peer Group for performance periods note yet completed and for the entire 36-month Performance Cycle.

In addition, the Compensation Committee shall have the discretionary authority to make other appropriate adjustments in response to a change in circumstances after the commencement of the Performance Cycle that results in a member of the Peer Group no longer satisfying the criteria for which such member was originally selected. In applying the described adjustments, the event that

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any adjustment is made to the Peer Group during any Performance Cycle, MPC’s relative TSR ranking within the peer group will be calculated for any incomplete or future performance periods (including the entire 36-month Performance Cycle) as if that company was not a peer at the start of each incomplete performance period. Relative TSR ranking for performance periods completed prior to the removal of the peer will not be recalculated.

“Performance Cycle” means the period beginning on January 1, 2019 and ending at the close of December 31, 2021.

“Qualified Termination” for purposes of this Award Agreement shall have the same definition as under the Marathon Petroleum Corporation Amended and Restated Executive Change in Control Severance Benefits Plan, as in effect on the Grant Date, and such definition and associated terms are hereby incorporated into this Award Agreement by reference.

“Retirement” means (a) for a Participant with ten or more years of Employment, termination on or after the Participant’s 50th birthday, or (b) termination on or after the Participant’s 65th birthday, provided that such termination constitutes a separation from service within the meaning of Section 409A of the Code.

“Total Shareholder Return” or “TSR” means for the Corporation and each entity in the Peer Group, the number derived using the following formula:

(End Stock Price – Beginning Stock Price) + Cumulative Dividends

Beginning Stock Price

“TSR Performance Percentile” means the percentile ranking of the Corporation’s Total Shareholder Return for a performance period among the Total Shareholder Returns of the Peer Group companies, ranked in descending order, for the performance period as determined at the end of the Performance Cycle.

Marathon Petroleum Corporation
By
	Authorized Officer

8

EX-31.1

Exhibit 31.1

MARATHON PETROLEUM CORPORATION

CERTIFICATION PURSUANT TO SECTION 302 OF

THE SARBANES-OXLEY ACT OF 2002

I, Gary R. Heminger, certify that:

1. I have reviewed this report on Form 10-Q of Marathon Petroleum 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:	May 9, 2019	/s/ Gary R. Heminger
		Gary R. Heminger
		Chairman of the Board and Chief Executive Officer

EX-31.2

Exhibit 31.2

MARATHON PETROLEUM CORPORATION

CERTIFICATION PURSUANT TO SECTION 302 OF

THE SARBANES-OXLEY ACT OF 2002

I, Timothy T. Griffith, certify that:

1. I have reviewed this report on Form 10-Q of Marathon Petroleum 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:	May 9, 2019	/s/ Timothy T. Griffith
		Timothy T. Griffith
		Senior Vice President and Chief Financial Officer

EX-32.1

Exhibit 32.1

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 Marathon Petroleum Corporation (the “Company”) on Form 10-Q for the period ended March 31, 2019 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Gary R. Heminger, Chairman of the Board and Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that to the best of my knowledge:

(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.

May 9, 2019

/s/ Gary R. Heminger

Gary R. Heminger

Chairman of the Board and Chief Executive Officer

EX-32.2

Exhibit 32.2

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 Marathon Petroleum Corporation (the “Company”) on Form 10-Q for the period ended March 31, 2019 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Timothy T. Griffith, Senior Vice President and Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that to the best of my knowledge:

(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.

May 9, 2019

/s/ Timothy T. Griffith

Timothy T. Griffith

Senior Vice President and Chief Financial Officer

XML

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2019	May 03, 2019
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2019
Document Fiscal Year Focus	2019
Document Fiscal Period Focus (Q1,Q2,Q3,FY)	Q1
Trading Symbol	MPC
Entity Registrant Name	Marathon Petroleum Corp
Entity Central Index Key	0001510295
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Common Stock, Shares Outstanding		662,618,001

XML

Consolidated Statements of Income - USD ($) shares in Millions, $ in Millions		3 Months Ended
		Mar. 31, 2019	Mar. 31, 2018
Revenues and other income:
Sales and other operating revenues		$ 28,081	$ 18,694
Sales to related parties	[1]	186	172
Income from equity method investments		99	86
Net gain on disposal of assets		214	2
Other income		35	30
Total revenues and other income		28,615	18,984
Costs and expenses:
Cost of revenues (excludes items below)		25,756	17,370
Purchases from related parties	[2]	204	141
Depreciation and amortization		919	528
Selling, general and administrative expenses		881	402
Other taxes		186	103
Total costs and expenses		27,946	18,544
Income from operations		669	440
Net interest and other financial costs		306	183
Income before income taxes		363	257
Provision for income taxes		104	22
Net income		259	235
Less net income attributable to:
Redeemable noncontrolling interest		20	16
Noncontrolling interests		246	182
Net income (loss) attributable to MPC		$ (7)	$ 37
Basic:
Net income (loss) attributable to MPC per share		$ (0.01)	$ 0.08
Weighted average shares outstanding (in shares)		673	476
Diluted:
Net income (loss) attributable to MPC per share		$ (0.01)	$ 0.08
Weighted average shares outstanding (in shares)		673	480

[1] Sales to related parties consists primarily of sales of refined products to PFJ Southeast, an equity affiliate which owns and operates travel plazas primarily in the Southeast region of the United States.

[2] We obtain utilities, transportation services and purchase ethanol from certain of our equity affiliates.

XML

Consolidated Statements of Comprehensive Income - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Statement of Comprehensive Income [Abstract]
Net income	$ 259	$ 235
Defined benefit postretirement and post-employment plans:
Actuarial changes, net of tax of $6 and $3, respectively	(3)	7
Prior service costs, net of tax of ($8) and ($2), respectively	(3)	(7)
Other, net of tax of $0 and ($1), respectively	(1)	(2)
Other comprehensive loss	(7)	(2)
Comprehensive income	252	233
Less comprehensive income attributable to:
Redeemable noncontrolling interest	20	16
Noncontrolling interests	246	182
Comprehensive income (loss) attributable to MPC	$ (14)	$ 35

XML

Consolidated Statements of Comprehensive Income (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Statement of Comprehensive Income [Abstract]
Actuarial changes, tax	$ 6	$ 3
Prior service costs, tax	(8)	(2)
Other, tax	$ 0	$ (1)

XML

Consolidated Balance Sheets - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Current assets:
Cash and cash equivalents	$ 877	$ 1,687
Receivables, less allowance for doubtful accounts of $9 and $9, respectively	6,893	5,853
Inventories	9,833	9,837
Other current assets	548	646
Total current assets	18,151	18,023
Equity method investments	6,558	5,898
Property, plant and equipment, net	45,091	45,058
Goodwill	20,229	20,184
Right of use assets	2,680	0
Other noncurrent assets	3,727	3,777
Total assets	96,436	92,940
Current liabilities:
Accounts payable	10,568	9,366
Payroll and benefits payable	958	1,152
Accrued taxes	1,529	1,446
Debt due within one year	550	544
Operating lease liabilities	613	0
Other current liabilities	929	708
Total current liabilities	15,147	13,216
Long-term debt	27,565	26,980
Deferred income taxes	5,011	4,864
Defined benefit postretirement plan obligations	1,567	1,509
Long-term operating lease liabilities	2,153	0
Deferred credits and other liabilities	1,131	1,318
Total liabilities	52,574	47,887
Commitments and contingencies (see Note 24)
Redeemable noncontrolling interest	1,004	1,004
MPC stockholders’ equity:
Preferred stock, no shares issued and outstanding (par value $0.01 per share, 30 million shares authorized)	0	0
Common stock:
Issued – 976 million and 975 million shares (par value $0.01 per share, 2 billion shares authorized)	10	10
Held in treasury, at cost – 309 million and 295 million shares	(14,063)	(13,175)
Additional paid-in capital	33,764	33,729
Retained earnings	14,391	14,755
Accumulated other comprehensive loss	(151)	(144)
Total MPC stockholders’ equity	33,951	35,175
Noncontrolling interests	8,907	8,874
Total equity	42,858	44,049
Total liabilities, redeemable noncontrolling interest and equity	$ 96,436	$ 92,940

XML

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Statement of Financial Position [Abstract]
Allowance for doubtful accounts	$ 9	$ 9
Preferred stock:
Shares issued	0	0
Shares outstanding	0	0
Par value	$ 0.01
Shares authorized	30,000,000
Common stock:
Shares issued	976,000,000	975,000,000
Par value	$ 0.01
Shares authorized	2,000,000,000
Treasury stock	(309,000,000)	(295,000,000)

XML

Consolidated Statements of Cash Flows - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Operating activities:
Net income	$ 259	$ 235
Adjustments to reconcile net income to net cash provided by operating activities:
Amortization of deferred financing costs and debt discount	0	18
Depreciation and amortization	919	528
Pension and other postretirement benefits, net	52	32
Deferred income taxes	127	(19)
Net gain on disposal of assets	(214)	(2)
Income from equity method investments	(99)	(86)
Distributions from equity method investments	148	89
Changes in the fair value of derivative instruments	29	(14)
Changes in operating assets and liabilities, net of effects of businesses acquired:
Current receivables	(1,037)	96
Inventories	(4)	440
Current accounts payable and accrued liabilities	1,483	(1,455)
Right of use assets/operating leases	(1)	0
All other, net	(39)	1
Net cash provided by (used in) operating activities	1,623	(137)
Investing activities:
Additions to property, plant and equipment	(1,241)	(755)
Acquisitions, net of cash acquired	1	0
Disposal of assets	24	7
Investments – acquisitions, loans and contributions	(325)	(41)
Investments - redemptions, repayments and return of capital	2	0
All other, net	19	11
Net cash used in investing activities	(1,520)	(778)
Financing activities:
Long-term debt – borrowings	2,604	9,610
Long-term debt – repayments	(2,031)	(5,264)
Debt issuance costs	0	(53)
Issuance of common stock	2	12
Common stock repurchased	(885)	(1,327)
Dividends paid	(354)	(219)
Distributions to noncontrolling interests	(325)	(195)
Contributions from noncontrolling interests	95	1
All other, net	(26)	(8)
Net cash provided by (used in) financing activities	(920)	2,557
Net increase (decrease) in cash, cash equivalents and restricted cash	(817)	1,642
Cash, cash equivalents and restricted cash at beginning of period	1,725	3,015
Cash, cash equivalents and restricted cash at end of period	$ 908	$ 4,657

XML

Consolidated Statements of Equity - USD ($) $ in Millions	Total	Common Stock	Treasury Stock	Additional Paid-in Capital	Retained Earnings	Accumulated Other Comprehensive Loss	Non-controlling Interests
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Cumulative effect of new accounting principle in period of adoption	$ 64				$ 63		$ 1
Beginning balance at Dec. 31, 2017	20,828	$ 7	$ (9,869)	$ 11,262	12,864	$ (231)	6,795
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	219				37		182
Dividends declared on common stock	(219)				(219)
Distributions to noncontrolling interests	(179)						(179)
Contributions from noncontrolling interests	1						1
Other comprehensive loss	(2)					(2)
Shares repurchased	(1,327)		(1,327)
Shares returned - stock based compensation			(4)
Shares issued - stock based compensation				27
Net shares issued - stock based compensation	24						1
Impact from equity transactions of MPLX & ANDX	(546)			2,380			(2,926)
Ending balance at Mar. 31, 2018	18,863	7	(11,200)	13,669	12,745	(233)	3,875
Beginning balance at Dec. 31, 2018	44,049	10	(13,175)	33,729	14,755	(144)	8,874
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	239				(7)		246
Dividends declared on common stock	(357)				(357)
Distributions to noncontrolling interests	(305)						(305)
Contributions from noncontrolling interests	95						95
Other comprehensive loss	(7)					(7)
Shares repurchased	(885)		(885)
Shares returned - stock based compensation			(3)
Shares issued - stock based compensation				32
Net shares issued - stock based compensation	28						(1)
Impact from equity transactions of MPLX & ANDX	2			3			(1)
Other	(1)						(1)
Ending balance at Mar. 31, 2019	$ 42,858	$ 10	$ (14,063)	$ 33,764	$ 14,391	$ (151)	$ 8,907

XML

Consolidated Statement of Equity - Shares of Common Stock - shares shares in Millions	Total	Common Stock
Beginning balance at Dec. 31, 2017		734
Number of common shares issued - stock compensation		0
Ending balance at Mar. 31, 2018		734
Beginning balance at Dec. 31, 2018	975	975
Number of common shares issued - stock compensation		1
Ending balance at Mar. 31, 2019	976	976

XML

Consolidated Statements of Equity - Shares of Treasury Stock - shares shares in Millions	Total	Treasury Stock
Beginning balance at Dec. 31, 2017		(248)
Number of shares repurchased	(19)	(19)
Number of shares returned - stock compensation		0
Ending balance at Mar. 31, 2018		(267)
Beginning balance at Dec. 31, 2018	(295)	(295)
Number of shares repurchased	(14)	(14)
Number of shares returned - stock compensation		0
Ending balance at Mar. 31, 2019	(309)	(309)

XML

Redeemable Noncontrolling Interest - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Temporary Equity [Abstract]
Beginning balance	$ 1,004	$ 1,000
Net income attributable to redeemable noncontrolling interest	20	16
Distributions to noncontrolling interests	(20)	(16)
Ending balance	$ 1,004	$ 1,000

XML

Consolidated Statements of Equity and Redeemable Noncontrolling Interest (Parenthetical) - $ / shares	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Statement of Stockholders' Equity [Abstract]
Dividends declared per share of common stock (in dollars per share)	$ 0.53	$ 0.46

XML

Description of the Business and Basis of Presentation

3 Months Ended

Mar. 31, 2019

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Description of the Business and Basis of Presentation

DESCRIPTION OF THE BUSINESS AND BASIS OF PRESENTATION

Description of the Business

We are a leading, integrated, downstream energy company headquartered in Findlay, Ohio. We operate the nation's largest refining system with more than 3 million barrels per day of crude oil capacity across 16 refineries. We sell refined products to wholesale marketing customers domestically and internationally, to buyers on the spot market, to consumers through our Retail business segment and to independent entrepreneurs who operate approximately 6,900 branded outlets. Our retail operations own and operate approximately 3,920 retail transportation fuel and convenience stores across the United States and also sell transportation fuel to consumers through approximately 1,060 direct dealer locations under long-term supply contracts. MPC’s midstream operations are primarily conducted through MPLX LP (“MPLX”) and Andeavor Logistics LP (“ANDX”), which own and operate crude oil and light product transportation and logistics infrastructure as well as gathering, processing, and fractionation assets. We own the general partner and majority limited partner interest in these two midstream companies.

Refer to Note 4 for further information on the Andeavor acquisition, which closed on October 1, 2018, and to Notes 3 and 9 for additional information about our operations.

Basis of Presentation

All significant intercompany transactions and accounts have been eliminated.

These interim consolidated financial statements are unaudited; however, in the opinion of our management, these statements reflect all adjustments necessary for a fair statement of the results for the periods reported. All such adjustments are of a normal, recurring nature unless otherwise disclosed. These interim consolidated financial statements, including the notes, have been prepared in accordance with the rules of the SEC applicable to interim period financial statements and do not include all of the information and disclosures required by GAAP for complete financial statements.

These interim consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2018. The results of operations for the three months ended March 31, 2019 are not necessarily indicative of the results to be expected for the full year.

XML

Accounting Standards

3 Months Ended

Mar. 31, 2019

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

Recently Adopted

ACCOUNTING STANDARDS

Recently Adopted

ASU 2016-02, Leases

We adopted ASU No. 2016-02, Leases (“ASC 842”), as of January 1, 2019, electing the transition method which permits entities to adopt the provisions of the standard using the modified retrospective approach without adjusting comparative periods. We also elected the package of practical expedients permitted under the transition guidance within the new standard, which among other things, allowed us to grandfather the historical accounting conclusions until a reassessment event is present. We have also elected the practical expedient to not recognize short-term leases on the balance sheet, the practical expedient related to right of way permits and land easements which allows us to carry forward our accounting treatment for those existing agreements, and the practical expedient to combine lease and non-lease components for the majority of our underlying classes of assets except for our third-party contractor service and equipment agreements and boat and barge equipment agreements in which we are the lessee. We did not elect the practical expedient to combine lease and non-lease components for arrangements in which we are the lessor. In instances where the practical expedient was not elected, lease and non-lease consideration is allocated based on relative standalone selling price.

Right of use (“ROU”) assets represent our right to use an underlying asset in which we obtain substantially all of the economic benefits and the right to direct the use of the asset during the lease term. Lease liabilities represent our obligation to make lease payments arising from the lease. Operating lease ROU assets and lease liabilities are recognized at commencement date based on the present value of lease payments over the lease term. We recognize ROU assets and lease liabilities on the balance sheet for leases with a lease term of greater than one year. Payments that are not fixed at the commencement of the lease are considered variable and are excluded from the ROU asset and lease liability calculations. In the measurement of our ROU assets and lease liabilities, the fixed lease payments in the agreement are discounted using a secured incremental borrowing rate for a term similar to the duration of the lease, as our leases do not provide implicit rates. Operating lease expense is recognized on a straight-line basis over the lease term.

Adoption of the new standard resulted in the recording of ROU assets and lease liabilities of approximately $2.79 billion and $2.88 billion, respectively, as of January 1, 2019. The standard did not materially impact our consolidated statements of income, cash flows or equity as a result of adoption.

As a lessor under ASC 842, MPLX may be required to re-classify existing operating leases to sales-type leases upon modification and related reassessment of the leases. If such a modification were to occur, it may result in the de-recognition of existing assets, recognition of a receivable in the amount of the present value of fixed payments expected to be received by MPLX under the lease, and recognition of a corresponding gain or loss in the period of change. MPLX will evaluate the impact of a lease reassessment as modifications occur.

We also adopted the following ASUs during the first three months of 2019, none of which had a material impact to our financial statements or financial statement disclosures:

ASU		Effective Date
2018-02	Reporting Comprehensive Income - Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income	January 1, 2019
2017-12	Derivatives and Hedging - Targeted Improvements to Accounting for Hedging Activities	January 1, 2019

Not Yet Adopted

Not Yet Adopted

ASU 2017-04, Intangibles - Goodwill and Other - Simplifying the Test for Goodwill Impairment

In January 2017, the FASB issued an ASU which simplifies the subsequent measurement of goodwill by eliminating Step 2 from the goodwill impairment test. Under the new guidance, the recognition of an impairment charge is calculated based on the amount by which the carrying amount exceeds the reporting unit’s fair value, which could be different from the amount calculated under the current method using the implied fair value of the goodwill; however, the loss recognized should not exceed the total amount of goodwill allocated to that reporting unit. The guidance should be applied on a prospective basis, and is effective for annual or any interim goodwill impairment tests in fiscal years beginning after December 15, 2019.

ASU 2016-13, Credit Losses - Measurement of Credit Losses on Financial Instruments

In June 2016, the FASB issued an ASU related to the accounting for credit losses on certain financial instruments. The guidance requires that for most financial assets, losses be based on an expected loss approach which includes estimates of losses over the life of exposure that considers historical, current and forecasted information. Expanded disclosures related to the methods used to estimate the losses as well as a specific disaggregation of balances for financial assets are also required. The change is effective for fiscal years beginning after December 15, 2019, and interim periods within those fiscal years, with early adoption permitted for fiscal years beginning after December 15, 2018, and interim periods within those fiscal years. We do not expect application of this ASU to have a material impact on our consolidated financial statements.

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Master Limited Partnerships

3 Months Ended

Mar. 31, 2019

Noncontrolling Interest [Abstract]

MPLX LP

MASTER LIMITED PARTNERSHIPS

MPLX

MPLX is a diversified, large-cap publicly traded limited partnership formed by us to own, operate, develop and acquire midstream energy infrastructure assets. MPLX is engaged in the transportation, storage and distribution of crude oil and refined petroleum products; gathering, processing and transportation of natural gas; and the gathering, transportation, fractionation, storage and marketing of NGLs. As of March 31, 2019, we owned 64 percent of the outstanding MPLX common units and we control MPLX through our ownership of the general partner of MPLX.

Dropdowns to MPLX and GP/IDR Exchange

On February 1, 2018, we contributed refining logistics assets and fuels distribution services to MPLX in exchange for $4.1 billion in cash and approximately 112 million common units and 2 million general partner units from MPLX. MPLX financed the cash portion of the transaction with its $4.1 billion364-day term loan facility, which was entered into on January 2, 2018. We agreed to waive approximately one-third of the first quarter 2018 distributions on the common units issued in connection with this transaction. The contributions of these assets were accounted for as transactions between entities under common control and we did not record a gain or loss.

Immediately following the February 1, 2018 dropdown to MPLX, our IDRs were cancelled and our economic general partner interest was converted into a non-economic general partner interest, all in exchange for 275 million newly issued MPLX common units (“GP/IDR Exchange”). As a result of this transaction, the general partner units and IDRs were eliminated, are no longer outstanding and no longer participate in distributions of cash from MPLX.

Agreements

We have various long-term, fee-based commercial agreements with MPLX. Under these agreements, MPLX provides transportation, storage, distribution and marketing services to us. Under certain agreements, we commit to provide MPLX with minimum throughput and distribution volumes of crude oil and refined products and minimum storage volumes of crude oil, refined products and butane. Under certain other agreements, we commit to pay for substantially all of the available capacity for certain marine transportation and refining logistics assets. These transactions are eliminated in consolidation, but are reflected as intersegment transactions between our Refining & Marketing and Midstream segments. We also have agreements with MPLX that establish fees for operational and management services provided between us and MPLX and for executive management services and certain general and administrative services provided by us to MPLX. These transactions are eliminated in consolidation, but are reflected as intersegment transactions between our Corporate and Midstream segments.

ANDX

Through the Andeavor acquisition, we acquired control of ANDX, which is a publicly traded limited partnership that was formed to own, operate, develop and acquire logistics assets. Its assets are integral to the success of our refining and marketing operations and are used to gather crude oil, natural gas, and water, process natural gas and distribute, transport and store crude oil and refined products. ANDX provides us with various pipeline transportation, trucking, terminal distribution, storage and petroleum-coke handling services under long-term, fee-based commercial agreements. With certain exceptions, these agreements generally contain minimum volume commitments. These transactions are eliminated in consolidation, but are reflected as intersegment transactions between our Refining & Marketing and Midstream segments. We also have agreements with ANDX that establish fees for operational and management services provided between us and ANDX and for executive management services and certain general and administrative services provided by us to ANDX. These transactions are eliminated in consolidation, but are reflected as intersegment transactions between our Corporate and Midstream segments.

As of March 31, 2019, we owned 64 percent of the outstanding ANDX common units. We also hold 80,000 ANDX TexNew Mex Units as of March 31, 2019 and control ANDX through our ownership of the general partner of ANDX.

Noncontrolling Interest

As a result of equity transactions of MPLX and ANDX, we are required to adjust non-controlling interest and additional paid-in capital. Changes in MPC’s additional paid-in capital resulting from changes in its ownership interests in MPLX and ANDX were as follows:

	Three Months Ended  March 31,
(In millions)	2019			2018
Increase due to the issuance of MPLX common units and general partner units to MPC	$	—		$	1,114
Increase due to GP/IDR Exchange	—			1,808
Increase due to the issuance of MPLX & ANDX common units	4			4
Increase in MPC's additional paid-in capital	4			2,926
Tax impact	(1		)	(546		)
Increase in MPC's additional paid-in capital, net of tax	$	3		$	2,380

XML

Acquisitions

3 Months Ended

Mar. 31, 2019

Business Combinations [Abstract]

Acquisitions and Investments

ACQUISITIONS

Acquisition of Andeavor

On October 1, 2018, we acquired all the outstanding shares of Andeavor. The total value of consideration transferred was $23.46 billion, consisting of $19.97 billion in equity and $3.49 billion in cash. The cash portion of the purchase price was funded using cash on hand. Our financial results reflect the results of Andeavor from the date of the acquisition.

We accounted for the Andeavor acquisition using the acquisition method of accounting, which requires Andeavor assets and liabilities to be recorded to our balance sheet at fair value as of the acquisition date. We will complete a final determination of the fair value of certain assets and liabilities within the one year measurement period from the date of the acquisition as required by FASB ASC Topic 805, “Business Combinations”. Due to the level of effort required to develop fair value measurements, the valuation studies necessary to determine the fair value of assets acquired and liabilities assumed are preliminary, including the underlying cash flows used to determine the fair value of identified intangible assets and economic obsolescence adjustments to property, plant and equipment. The size and the breadth of the Andeavor acquisition necessitates the use of the one year measurement period to fully analyze all the factors used in establishing the asset and liability fair values as of the acquisition date, including, but not limited to, property, plant and equipment, intangible assets, real property, leases, environmental and asset retirement obligations and the related tax impacts of any changes made. Any potential adjustments made could be material in relation to the preliminary values.

During the three months ended March 31, 2019, we recorded adjustments to the preliminary fair value estimates of assets acquired and liabilities assumed as of the acquisition date as noted in the table below.

(In millions)	As originally reported		Adjustments			As adjusted
Cash and cash equivalents	$	382	$	—		$	382
Receivables	2,744		(2		)	2,742
Inventories	5,204		(8		)	5,196
Other current assets	378		—			378
Equity method investments	865		—			865
Property, plant and equipment, net	16,545		(1		)	16,544
Other noncurrent assets(a)	3,086		—			3,086
Total assets acquired	29,204		(11		)	29,193
Accounts payable	4,003		—			4,003
Payroll and benefits payable	348		—			348
Accrued taxes	590		—			590
Debt due within one year	34		—			34
Other current liabilities	392		23			415
Long-term debt	8,875		1			8,876
Deferred income taxes	1,609		22			1,631
Defined benefit postretirement plan obligations	432		—			432
Deferred credit and other liabilities	714		6			720
Noncontrolling interests	5,059		3			5,062
Total liabilities and noncontrolling interest assumed	22,056		55			22,111
Net assets acquired excluding goodwill	7,148		(66		)	7,082
Goodwill	16,314		66			16,380
Net assets acquired	$	23,462	$	—		$	23,462

^(a)  Includes intangible assets.

The preliminary purchase consideration allocation resulted in the recognition of $16.38 billion in goodwill, of which $893 million is tax deductible due to a carryover basis from Andeavor. Our Refining & Marketing, Midstream and Retail segments recognized $4.78 billion, $7.72 billion and $3.88 billion of preliminary goodwill. The recognized goodwill represents the value expected to be created by further optimization of crude supply, a nationwide retail and marketing platform, diversification of our refining and midstream footprints and optimization of information systems and business processes.

Pro Forma Financial Information

The following unaudited pro forma financial information presents consolidated results assuming the Andeavor acquisition occurred on January 1, 2017. The unaudited pro forma information does not give effect to potential synergies that could result from the transaction and is not necessarily indicative of the results of future operations.

	Three Months Ended  March 31,
(In millions)	2018
Sales and other operating revenues	$	29,206
Net income attributable to MPC	26

The pro forma information includes adjustments to align accounting policies, including our policy to expense refinery turnarounds when they occur, an adjustment to depreciation expense to reflect the increased fair value of property, plant and equipment, increased amortization expense related to identifiable intangible assets and the related income tax effects.

Acquisition of Express Mart

During the fourth quarter of 2018, Speedway acquired 78 transportation fuel and convenience store locations from Petr-All Petroleum Consulting Corporation for total consideration of $266 million. These stores are located primarily in the Syracuse, Rochester and Buffalo markets in New York and had been operated under the Express Mart brand.

Based on the final fair value estimates of assets acquired and liabilities assumed at the acquisition date, $97 million of the purchase price was allocated to property, plant and equipment, $9 million to inventory, $2 million to intangibles and $158 million to goodwill. Goodwill is tax deductible and represents the value expected to be created by geographically expanding our retail platform and the assembled workforce. These operations are accounted for within the Retail segment.

Acquisition of Mt. Airy Terminal

On September 26, 2018, MPLX acquired an eastern U.S. Gulf Coast export terminal (“Mt. Airy Terminal”) from Pin Oak Holdings, LLC for total consideration of $451 million. At the time of the acquisition, the terminal included tanks with 4 million barrels of third-party leased storage capacity and a dock with 120 mbpd of capacity. The Mt. Airy Terminal is located on the Mississippi River between New Orleans and Baton Rouge, near several Gulf Coast refineries, including our Garyville Refinery, and numerous rail lines and pipelines. The Mt. Airy Terminal is accounted for within the Midstream segment. In the first quarter of 2019, an adjustment to the initial purchase price was made for approximately $5 million related to the final settlement of the acquisition. This reduced the total purchase price to $446 million and resulted in $336 million of property, plant and equipment, $121 million of goodwill and the remainder being attributable to net liabilities assumed.

Goodwill represents the significant growth potential of the terminal due to the multiple pipelines and rail lines which cross the property, the terminal’s position as an aggregation point for liquids growth in the region for both ocean-going vessels and inland barges, the proximity of the terminal to MPC’s Garyville refinery and other refineries in the region as well as the opportunity to construct an additional dock at the site. All of the goodwill recognized related to this transaction is tax deductible.

Assuming the acquisitions of Express Mart and Mt. Airy Terminal had occurred on January 1, 2017, the consolidated pro forma results would not have been materially different from the reported results.

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Variable Interest Entities

3 Months Ended

Mar. 31, 2019

Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]

Variable Interest Entities

VARIABLE INTEREST ENTITIES

Consolidated VIEs

We control MPLX and ANDX through our ownership of the general partner of both entities. MPLX and ANDX are VIEs because the limited partners do not have substantive kick-out or substantive participating rights over the general partner. We are the primary beneficiary of both MPLX and ANDX because in addition to our significant economic interest, we also have the ability, through our ownership of the general partner, to control the decisions that most significantly impact MPLX and ANDX. We therefore consolidate MPLX and ANDX and record a noncontrolling interest for the interest owned by the public. We also record a redeemable noncontrolling interest related to MPLX’s preferred units.

The creditors of MPLX and ANDX do not have recourse to MPC’s general credit through guarantees or other financial arrangements, except as noted. MPC has effectively guaranteed certain indebtedness of LOOP LLC (“LOOP”) and LOCAP LLC (“LOCAP”), in which MPLX holds an interest. See Note 24 for more information. Western Refining Southwest, Inc., a wholly-owned subsidiary of MPC and unitholder of ANDX, has guaranteed certain outstanding borrowings under the ANDX dropdown credit facility that were made in connection with the August 2018 dropdown transaction.

The assets of MPLX and ANDX can only be used to settle their own obligations and their creditors have no recourse to our assets, except as noted above. The following table present balance sheet information for the assets and liabilities of MPLX and ANDX, which are included in our balance sheets.

	March 31, 2019				December 31, 2018
(In millions)	MPLX		ANDX(a)		MPLX		ANDX(a)
Assets
Cash and cash equivalents	$	93	$	29	$	68	$	10
Receivables, less allowance for doubtful accounts	372		248		425		199
Inventories	74		21		77		22
Other current assets	34		37		45		57
Equity method investments	4,270		602		4,174		602
Property, plant and equipment, net	14,816		6,882		14,639		6,845
Goodwill	2,581		1,052		2,586		1,051
Right of use assets	262		122		—		—
Other noncurrent assets	448		1,235		458		1,242
Liabilities
Accounts payable	$	583	$	177	$	776	$	215
Payroll and benefits payable	4		1		2		10
Accrued taxes	40		20		48		23
Debt due within one year	1		503		1		504
Operating lease liabilities	46		12		—		—
Other current liabilities	189		117		177		77
Long-term debt	13,832		4,629		13,392		4,469
Deferred income taxes	12		1		13		1
Long-term operating lease liabilities	216		109		—		—
Deferred credits and other liabilities	289		66		276		68

^(a)  The balances reflected here are ANDX’s historical balances as the preliminary purchase accounting adjustments related to ANDX’s assets and liabilities in connection with the Andeavor acquisition and reflected on our consolidated balance sheets as of December 31, 2018 and March 31, 2019 have not yet been pushed down to this subsidiary.

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Related Party Transactions

3 Months Ended

Mar. 31, 2019

Related Party Transactions [Abstract]

Related Party Transactions

RELATED PARTY TRANSACTIONS

Transactions with related parties were as follows:

	Three Months Ended  March 31,
(In millions)	2019		2018
Sales to related parties(a)	$	186	$	172
Purchases from related parties(b)	204		141

^(a)   Sales to related parties consists primarily of sales of refined products to PFJ Southeast, an equity affiliate which owns and operates travel plazas primarily in the Southeast region of the United States.

^(b)   We obtain utilities, transportation services and purchase ethanol from certain of our equity affiliates.

Summarized financial information, in the aggregate, for our significant equity method investments on a 100 percent basis were as follows:

	Three Months Ended  March 31,
(In millions)	2019		2018
Revenues and other income	$	1,628	$	1,503
Income from operations	336		254
Net income	314		274

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Income (Loss) per Common Share

3 Months Ended

Mar. 31, 2019

Earnings Per Share [Abstract]

Income per Common Share

INCOME (LOSS) PER COMMON SHARE

We compute basic earnings per share by dividing net income attributable to MPC less income allocated to participating securities by the weighted average number of shares of common stock outstanding. Since MPC grants certain incentive compensation awards to employees and non-employee directors that are considered to be participating securities, we have calculated our earnings per share using the two-class method. Diluted income per share assumes exercise of certain stock-based compensation awards, provided the effect is not anti-dilutive.

	Three Months Ended  March 31,
(In millions, except per share data)	2019			2018
Basic earnings (loss) per share:
Allocation of earnings:
Net income (loss) attributable to MPC	$	(7	)	$	37
Income allocated to participating securities	—			—
Income (loss) available to common stockholders – basic	$	(7	)	$	37
Weighted average common shares outstanding	673			476
Basic earnings (loss) per share	$	(0.01	)	$	0.08
Diluted earnings (loss) per share:
Allocation of earnings:
Net income (loss) attributable to MPC	$	(7	)	$	37
Income allocated to participating securities	—			—
Income (loss) available to common stockholders – diluted	$	(7	)	$	37
Weighted average common shares outstanding	673			476
Effect of dilutive securities	—			4
Weighted average common shares, including dilutive effect	673			480
Diluted earnings (loss) per share	$	(0.01	)	$	0.08

The following table summarizes the shares that were anti-dilutive and, therefore, were excluded from the diluted share calculation.

	Three Months Ended  March 31,
(In millions)	2019	2018
Shares issuable under stock-based compensation plans	7	—

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Equity

3 Months Ended

Mar. 31, 2019

Equity [Abstract]

Equity

EQUITY

As of March 31, 2019, we had $4.02 billion of share repurchase authorization remaining under authorizations from our board of directors. We may utilize various methods to effect the repurchases, which could include open market repurchases, negotiated block transactions, accelerated share repurchases or open market solicitations for shares, some of which may be effected through Rule 10b5-1 plans. The timing and amount of future repurchases, if any, will depend upon several factors, including market and business conditions, and such repurchases may be discontinued at any time.

Total share repurchases were as follows:

	Three Months Ended  March 31,
(In millions, except per share data)	2019		2018
Number of shares repurchased	14		19
Cash paid for shares repurchased	$	885	$	1,327
Average cost per share	$	62.98	$	68.74

As of March 31, 2019, we had agreements to acquire 493,625 common shares for $30 million, which settled in early April 2019.

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Segment Information

3 Months Ended

Mar. 31, 2019

Segment Reporting [Abstract]

Segment Information

SEGMENT INFORMATION

We have three reportable segments: Refining & Marketing; Retail; and Midstream. Each of these segments is organized and managed based upon the nature of the products and services it offers.

• Refining & Marketing – refines crude oil and other feedstocks at our 16 refineries in the West Coast, Mid-Continent and Gulf Coast regions of the United States, purchases refined products and ethanol for resale and distributes refined products through transportation, storage, distribution and marketing services provided largely by our Midstream segment. We sell refined products to wholesale marketing customers domestically and internationally, to buyers on the spot market, to our Retail business segment and to independent entrepreneurs who operate primarily Marathon^® branded outlets.

• Retail – sells transportation fuels and convenience products in the retail market across the United States through company-owned and operated convenience stores, primarily under the Speedway^® brand, and long-term fuel supply contracts with direct dealers who operate locations primarily under the ARCO^® brand.

• Midstream – transports, stores, distributes and markets crude oil and refined products principally for the Refining & Marketing segment via refining logistics assets, pipelines, terminals, towboats and barges; gathers, processes and transports natural gas; and gathers, transports, fractionates, stores and markets NGLs. The Midstream segment primarily reflects the results of MPLX and ANDX, our sponsored master limited partnerships.

Segment income represents income from operations attributable to the reportable segments. Corporate administrative expenses, except for those attributable to MPLX and ANDX, and costs related to certain non-operating assets are not allocated to the Refining & Marketing and Retail segments. In addition, certain items that affect comparability (as determined by the chief operating decision maker) are not allocated to the reportable segments.

(In millions)	Refining & Marketing			Retail		Midstream		Total
Three Months Ended March 31, 2019
Revenues:
Third party	$	19,751		$	7,373	$	957	$	28,081
Intersegment	4,429			2		1,232		5,663
Related party	183			3		—		186
Segment revenues	$	24,363		$	7,378	$	2,189	$	33,930
Segment income (loss) from operations	$	(334	)	$	170	$	908	$	744
Income from equity method investments	1			17		81		99
Depreciation and amortization(a)	427			126		307		860
Capital expenditures and investments(b)	394			73		823		1,290

(In millions)	Refining & Marketing			Retail		Midstream		Total
Three Months Ended March 31, 2018
Revenues:
Third party	$	13,412		$	4,569	$	713	$	18,694
Intersegment	2,379			1		631		3,011
Related party	170			2		—		172
Segment revenues	$	15,961		$	4,572	$	1,344	$	21,877
Segment income (loss) from operations	$	(133	)	$	95	$	567	$	529
Income from equity method investments	3			14		69		86
Depreciation and amortization(a)	252			79		181		512
Capital expenditures and investments(b)	191			39		482		712

^(a)  Differences between segment totals and MPC consolidated totals represent amounts related to corporate and other unallocated items and are included in items not allocated to segments in the reconciliation below.

^(b)  Capital expenditures include changes in capital accruals and investments in affiliates. See reconciliation from segment totals to MPC consolidated total capital expenditures below.

The following reconciles segment income from operations to income before income taxes as reported in the consolidated statements of income:

	Three Months Ended  March 31,
(In millions)	2019			2018
Segment income from operations	$	744		$	529
Items not allocated to segments:
Corporate and other unallocated items(a)	(191		)	(89		)
Capline restructuring gain(b)	207			—
Transaction-related costs(c)	(91		)	—
Income from operations	669			440
Net interest and other financial costs	306			183
Income before income taxes	$	363		$	257

^(a)  Corporate and other unallocated items consists primarily of MPC’s corporate administrative expenses and costs related to certain non-operating assets, except for corporate overhead expenses attributable to MPLX and ANDX, which are included in the Midstream segment. Corporate overhead expenses are not allocated to the Refining & Marketing and Retail segments.

^(b)  See Note 13.

^(c)  The transaction-related costs recognized in the first quarter largely relate to the recognition of an obligation for vacation benefits provided to former Andeavor employees.

The following reconciles segment capital expenditures and investments to total capital expenditures:

	Three Months Ended  March 31,
(In millions)	2019		2018
Segment capital expenditures and investments	$	1,290	$	712
Less investments in equity method investees	325		41
Plus items not allocated to segments:
Corporate	10		18
Capitalized interest	31		18
Total capital expenditures(a)	$	1,006	$	707

^(a)  Capital expenditures include changes in capital accruals. See Note 19 for a reconciliation of total capital expenditures to additions to property, plant and equipment as reported in the consolidated statements of cash flows.

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Net Interest and Other Financial Costs

3 Months Ended

Mar. 31, 2019

Other Income and Expenses [Abstract]

Net Interest and Other Financial Costs

NET INTEREST AND OTHER FINANCIAL COSTS

Net interest and other financial costs were as follows:

	Three Months Ended  March 31,
(In millions)	2019			2018
Interest income	$	(9	)	$	(20	)
Interest expense	340			213
Interest capitalized	(32		)	(18		)
Pension and other postretirement non-service costs(a)	(3		)	—
Loss on extinguishment of debt	—			4
Other financial costs	10			4
Net interest and other financial costs	$	306		$	183

^(a)  See Note 21.

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Income Taxes

3 Months Ended

Mar. 31, 2019

Income Tax Disclosure [Abstract]

Income Taxes

INCOME TAXES

The combined federal, state and foreign income tax rate was 29 percent and 9 percent for the three months ended March 31, 2019 and 2018, respectively. The effective tax rate for the three months ended March 31, 2019 was greater than the U.S. statutory rate of 21 percent primarily due to $36 million of state deferred tax expense recorded as an out of period adjustment, partially offset by permanent tax differences related to net income attributable to noncontrolling interests. The effective tax rate for the three months ended March 31, 2018 was less than the U.S. statutory rate primarily due to certain permanent tax differences related to net income attributable to noncontrolling interests, state and local deferred tax benefits primarily resulting from the February 1 dropdown and GP/IDR Exchange and equity compensation.

During the first quarter of 2019, MPC’s deferred tax liabilities increased $68 million with an offsetting increase to goodwill and the provision for income taxes of $32 million and $36 million, respectively for an out of period adjustment to correct the tax effects recorded in 2018 related to the Andeavor acquisition. The impact of the adjustment was not material to any previous period.

We are continuously undergoing examination of our income tax returns, which have been completed through the 2005 tax year for state returns and the 2008 tax year for our U.S. federal return. As of March 31, 2019, we had $231 million of unrecognized tax benefits.

Prior to its spinoff on June 30, 2011, Marathon Petroleum Corporation was included in the Marathon Oil Corporation (“Marathon Oil”) U.S. federal income tax returns for all applicable years. During the third quarter of 2017, Marathon Oil received a notice of Final Partnership Administrative Adjustment (“FPAA”) from the U.S. Internal Revenue Service for taxable year 2010, relating to certain partnership transactions. Marathon Oil filed a U.S. Tax Court petition disputing these adjustments during the fourth quarter of 2017. We received an FPAA for taxable years 2011-2014 for items resulting from this matter and filed a U.S. Tax Court petition for tax years 2011-2014 to dispute these corollary adjustments in the fourth quarter of 2017. We continue to believe that the issue in dispute is more likely than not to be fully sustained and, therefore, no liability has been accrued for this matter.

Pursuant to our tax sharing agreement with Marathon Oil, the unrecognized tax benefits related to pre-spinoff operations for which Marathon Oil was the taxpayer remain the responsibility of Marathon Oil and we have indemnified Marathon Oil accordingly. See Note 24 for indemnification information.

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Inventories

3 Months Ended

Mar. 31, 2019

Inventory Disclosure [Abstract]

Inventories

INVENTORIES

(In millions)	March 31, 2019		December 31, 2018
Crude oil and refinery feedstocks	$	3,689	$	3,655
Refined products	5,186		5,234
Materials and supplies	744		720
Merchandise	214		228
Total	$	9,833	$	9,837

Inventories are carried at the lower of cost or market value. The cost of inventories of crude oil and refinery feedstocks, refined products and merchandise is determined primarily under the LIFO method. There were no LIFO inventory liquidations recognized for the three months ended March 31, 2019.

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Equity Method Investments

3 Months Ended

Mar. 31, 2019

Equity Method Investments and Joint Ventures [Abstract]

Equity Method Investments and Joint Ventures Disclosure [Text Block]

EQUITY METHOD INVESTMENTS

During the three months ended March 31, 2019, we executed agreements with Capline Pipeline LLC (“Capline LLC”) to contribute our 33 percent undivided interest in Capline pipeline system in exchange for a 33 percent ownership interest in Capline LLC. Concurrent with our execution of these agreements, Capline LLC initiated a binding open season for southbound service from Patoka, IL to St. James, LA or Liberty, MS, with an additional origination point at Cushing, OK. Service from Cushing, OK is part of a joint tariff with Diamond pipeline. Crude oil service is expected to begin in the third quarter of 2020.

In accordance with ASC 810 “Consolidation”, we derecognized our undivided interest amounting to $143 million of net assets and recognized the Capline LLC ownership interest we received at fair value. We used an income approach to determine the fair value of our ownership interest under a Monte Carlo simulation method. We determined the fair value of our ownership interest was estimated to be $350 million as of January 30, 2019. This is a nonrecurring fair value measurement and is categorized in level 3 of the fair value hierarchy. The Monte Carlo simulation inputs include ranges of tariff rates, operating volumes, operating cost and capital expenditure assumptions. The estimated cash flows were discounted using a Monte Carlo market participant weighted average cost of capital estimate. None of the inputs to the Monte Carlo simulation are individually significant. The excess of the estimated fair value of our ownership interest over the carrying value of the derecognized net assets resulted in a $207 million non cash net gain recorded as a net gain on disposal of assets in the accompanying consolidated statements of income.

As the Capline system is currently idled, Capline LLC is unable to fund its operations without financial support from its equity owners and is a VIE. MPC is not deemed to be the primary beneficiary, due to our inability to unilaterally control significant decision-making rights. Our maximum exposure to loss as a result of our involvement with Capline LLC includes our equity investment, any additional capital contribution commitments and any operating expenses incurred by Capline LLC in excess of compensation received for performance of the operating services.

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Property, Plant and Equipment

3 Months Ended

Mar. 31, 2019

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment

PROPERTY, PLANT AND EQUIPMENT

(In millions)	March 31, 2019		December 31, 2018
Refining & Marketing	$	27,968	$	27,590
Retail	6,681		6,637
Midstream	25,929		25,692
Corporate and Other	1,304		1,294
Total	61,882		61,213
Less accumulated depreciation	16,791		16,155
Property, plant and equipment, net	$	45,091	$	45,058

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Fair Value Measurements

3 Months Ended

Mar. 31, 2019

Fair Value Disclosures [Abstract]

Fair Value Measurements

FAIR VALUE MEASUREMENTS

Fair Values—Recurring

The following tables present assets and liabilities accounted for at fair value on a recurring basis as of March 31, 2019 and December 31, 2018 by fair value hierarchy level. We have elected to offset the fair value amounts recognized for multiple derivative contracts executed with the same counterparty, including any related cash collateral as shown below; however, fair value amounts by hierarchy level are presented on a gross basis in the following tables.

	March 31, 2019
	Fair Value Hierarchy
(In millions)	Level 1		Level 2		Level 3		Netting and Collateral(a)			Net Carrying Value on Balance Sheet(b)		Collateral Pledged Not Offset
Assets:
Commodity contracts	$	122	$	18	$	—	$	(128	)	$	12	$	42
Liabilities:
Commodity contracts	$	142	$	24	$	—	$	(161	)	$	5	$	—
Embedded derivatives in commodity contracts	—		—		65		—			65		—

	December 31, 2018
	Fair Value Hierarchy
(In millions)	Level 1		Level 2		Level 3		Netting and Collateral(a)			Net Carrying Value on Balance Sheet(b)		Collateral Pledged Not Offset
Assets:
Commodity contracts	$	370	$	31	$	—	$	(323	)	$	78	$	2
Liabilities:
Commodity contracts	$	255	$	37	$	—	$	(284	)	$	8	$	—
Embedded derivatives in commodity contracts	—		—		61		—			61		—

^(a)  Represents the impact of netting assets, liabilities and cash collateral when a legal right of offset exists. As of March 31, 2019, cash collateral of $33 million was netted with the mark-to-market derivative liabilities. As of December 31, 2018, cash collateral of $52 million was netted with mark-to-market derivative assets and $13 million was netted with mark-to-market derivative liabilities.

^(b)  We have no derivative contracts that are subject to master netting arrangements reflected gross on the balance sheet.

Commodity derivatives in Level 1 are exchange-traded contracts for crude oil and refined products measured at fair value with a market approach using the close-of-day settlement prices for the market. Commodity derivatives are covered under master netting agreements with an unconditional right to offset. Collateral deposits in futures commission merchant accounts covered by master netting agreements related to Level 1 commodity derivatives are classified as Level 1 in the fair value hierarchy.

Level 2 instruments are valued based on quoted prices for similar assets and liabilities in active markets, and inputs other than quoted prices, such as liquidity, that are observable for the asset or liability. Commodity derivatives in Level 2 are OTC contracts, which are valued using market quotations from independent price reporting agencies, third-party brokers and commodity exchange price curves that are corroborated with market data.

Level 3 instruments are OTC NGL contracts and embedded derivatives in commodity contracts. The embedded derivative liability relates to a natural gas purchase agreement embedded in a keep‑whole processing agreement. The fair value calculation for these Level 3 instruments at March 31, 2019 used significant unobservable inputs including: (1) NGL prices interpolated and extrapolated due to inactive markets ranging from $0.60 to $1.25 per gallon and (2) the probability of renewal of 91 percent for the first five-year term and 82 percent for the second five-year term of the natural gas purchase agreement and the related keep-whole processing agreement. For these contracts, increases in forward NGL prices result in a decrease in the fair value of the derivative assets and an increase in the fair value of the derivative liabilities. Increases or decreases in the fractionation spread result in an increase or decrease in the fair value of the embedded derivative liability. An increase in the probability of renewal would result in an increase in the fair value of the related embedded derivative liability.

The following is a reconciliation of the beginning and ending balances recorded for net liabilities classified as Level 3 in the fair value hierarchy.

	Three Months Ended  March 31,
(In millions)	2019			2018
Beginning balance	$	61		$	66
Unrealized and realized losses included in net income	6			(3		)
Settlements of derivative instruments	(2		)	(3		)
Ending balance	$	65		$	60
The amount of total losses for the period included in earnings attributable to the change in unrealized losses relating to assets still held at the end of period:	$	5		$	(3	)

Fair Values – Reported

We believe the carrying value of our other financial instruments, including cash and cash equivalents, receivables, accounts payable and certain accrued liabilities, approximate fair value. Our fair value assessment incorporates a variety of considerations, including the short-term duration of the instruments and the expected insignificance of bad debt expense, which includes an evaluation of counterparty credit risk. The borrowings under our revolving credit facilities, which include variable interest rates, approximate fair value. The fair value of our fixed rate long-term debt is based on prices from recent trade activity and is categorized in level 3 of the fair value hierarchy. The carrying and fair values of our debt were approximately $27.6 billion and $28.5 billion at March 31, 2019, respectively, and approximately $27.0 billion and $26.5 billion at December 31, 2018, respectively. These carrying and fair values of our debt exclude the unamortized issuance costs which are netted against our total debt.

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Derivatives

3 Months Ended

Mar. 31, 2019

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivatives

DERIVATIVES

For further information regarding the fair value measurement of derivative instruments, including any effect of master netting agreements or collateral, see Note 15. We do not designate any of our commodity derivative instruments as hedges for accounting purposes.

Derivatives that are not designated as accounting hedges may include commodity derivatives used to hedge price risk on (1) inventories, (2) fixed price sales of refined products, (3) the acquisition of foreign-sourced crude oil, (4) the acquisition of ethanol for blending with refined products, (5) the sale of NGLs and (6) the purchase of natural gas.

The following table presents the fair value of derivative instruments as of March 31, 2019 and December 31, 2018 and the line items in the balance sheets in which the fair values are reflected. The fair value amounts below are presented on a gross basis and do not reflect the netting of asset and liability positions permitted under the terms of our master netting arrangements including cash collateral on deposit with, or received from, brokers. We offset the recognized fair value amounts for multiple derivative instruments executed with the same counterparty in our financial statements when a legal right of offset exists. As a result, the asset and liability amounts below will not agree with the amounts presented in our consolidated balance sheets.

(In millions)	March 31, 2019
Balance Sheet Location	Asset		Liability
Commodity derivatives
Other current assets	$	139	$	160
Other current liabilities(a)	1		14
Deferred credits and other liabilities(a)	—		57

(In millions)	December 31, 2018
Balance Sheet Location	Asset		Liability
Commodity derivatives
Other current assets	$	400	$	283
Other current liabilities(a)	1		16
Deferred credits and other liabilities(a)	—		54

^(a)   Includes embedded derivatives.

The table below summarizes open commodity derivative contracts for crude oil, refined products and blending products as of March 31, 2019.

	Percentage of contracts that expire next quarter	Position
(Units in thousands of barrels)		Long	Short
Exchange-traded(a)
Crude oil	82.6%	49,844	58,466
Refined products	89.4%	11,373	9,945
Blending products	77.3%	4,688	4,866
OTC
Crude oil	—%	640	—
Blending products	—%	1,676	1,444

^(a)  Included in exchange-traded are spread contracts in thousands of barrels: Crude oil - 11,999 long and 3,980 short; Refined products - 300 long and 300 short; Blending products - 2,603 long and 2,506 short

The following table summarizes the effect of all commodity derivative instruments in our consolidated statements of income:

	Loss
(In millions)	Three Months Ended March 31,
Income Statement Location	2019			2018
Sales and other operating revenues	$	(20	)	$	(1	)
Cost of revenues	(80		)	(27		)
Total	$	(100	)	$	(28	)

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Debt

3 Months Ended

Mar. 31, 2019

Debt Disclosure [Abstract]

Debt

DEBT

Our outstanding borrowings at March 31, 2019 and December 31, 2018 consisted of the following:

(In millions)	March 31, 2019			December 31, 2018
Marathon Petroleum Corporation	$	9,120		$	9,114
MPLX LP	14,283			13,856
ANDX LP	5,168			5,010
Total debt	$	28,571		$	27,980
Unamortized debt issuance costs	(126		)	(128		)
Unamortized discount	(330		)	(328		)
Amounts due within one year	(550		)	(544		)
Total long-term debt due after one year	$	27,565		$	26,980

Available Capacity under our Facilities

(Dollars in millions)	Total Capacity		Outstanding Borrowings		Outstanding Letters of Credit		Available Capacity		Weighted Average Interest Rate		Expiration
MPC 364-day bank revolving credit facility	$	1,000	$	—	$	—	$	1,000	—		September 2019
MPC bank revolving credit facility	5,000		—		32		4,968		—		October 2023
MPLX bank revolving credit facility	2,250		425		3		1,822		3.92	%	July 2022
ANDX revolving & dropdown credit facilities(a)	2,100		1,404		—		696		4.32	%	January 2021
Trade receivables securitization facility	750		—		—		750		—		July 2019
	$	11,100	$	1,829	$	35	$	9,236

^(a)  Western Refining Southwest, Inc., a wholly-owned subsidiary of MPC and unitholder of ANDX, has guaranteed certain outstanding borrowings under the ANDX dropdown credit facility that were made in connection with the August 2018 dropdown transaction.

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Revenue

3 Months Ended

Mar. 31, 2019

Revenue from Contract with Customer [Abstract]

Revenue from Contract with Customer [Text Block]

REVENUE

The following table presents our revenues disaggregated by product line.

	Three Months Ended  March 31,
(In millions)	2019		2018
Refined products	$	24,653	$	16,158
Merchandise	1,464		1,130
Crude oil and refinery feedstocks	1,367		883
Midstream services, transportation and other	597		523
Sales and other operating revenues	$	28,081	$	18,694

Practical Expedients

On January 1, 2018, we adopted ASU 2014-09, Revenue - Revenue from Contracts with Customers (“ASC 606”). We elected the completed contract practical expedient and only applied ASC 606 to contracts that were not completed as of January 1, 2018.

We do not disclose information on the future performance obligations for any contract with expected duration of one year or less at inception. As of March 31, 2019, we do not have future performance obligations that are material to future periods.

Receivables

On the accompanying consolidated balance sheets, receivables, less allowance for doubtful accounts primarily consists of customer receivables. Significant, non-customer balances included in our receivables at March 31, 2019 include matching buy/sell receivables of $1.98 billion and income tax receivables of $76 million.

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Supplemental Cash Flow Information

3 Months Ended

Mar. 31, 2019

Supplemental Cash Flow Elements [Abstract]

Supplemental Cash Flow Information

SUPPLEMENTAL CASH FLOW INFORMATION

	Three Months Ended  March 31,
(In millions)	2019		2018
Net cash provided by operating activities included:
Interest paid (net of amounts capitalized)	$	269	$	212
Net income taxes paid to taxing authorities	42		6
Cash paid for amounts included in the measurement of lease liabilities
Payments on operating leases	189		—
Interest payments under finance lease obligations	8		—
Net cash provided by financing activities included:
Principal payments under finance lease obligations	10		—
Non-cash investing and financing activities:
Right of use assets obtained in exchange for new operating lease obligations	31		—
Right of use assets obtained in exchange for new finance lease obligations	15		—
Contribution of net assets to Capline LLC(a)	143		—
Recognition of Capline LLC equity method investment(a)	350		—

^(a)  See Note 13.

(In millions)	March 31, 2019		December 31, 2018
Cash and cash equivalents	$	877	$	1,687
Restricted cash(a)	31		38
Cash, cash equivalents and restricted cash	$	908	$	1,725

^(a)  The restricted cash balance is included within other current assets on the consolidated balance sheets.

The consolidated statements of cash flows exclude changes to the consolidated balance sheets that did not affect cash. The following is a reconciliation of additions to property, plant and equipment to total capital expenditures:

	Three Months Ended  March 31,
(In millions)	2019			2018
Additions to property, plant and equipment per the consolidated statements of cash flows	$	1,241		$	755
Asset retirement expenditures	—			1
Decrease in capital accruals	(235		)	(49		)
Total capital expenditures	$	1,006		$	707

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Accumulated Other Comprehensive Loss

3 Months Ended

Mar. 31, 2019

Equity [Abstract]

Accumulated Other Comprehensive Loss

ACCUMULATED OTHER COMPREHENSIVE LOSS

The following table shows the changes in accumulated other comprehensive loss by component. Amounts in parentheses indicate debits.

(In millions)	Pension Benefits			Other Benefits			Gain on Cash Flow Hedge			Workers Compensation		Total
Balance as of December 31, 2017	$	(190	)	$	(48	)	$	4		$	3	$	(231	)
Other comprehensive loss before reclassifications	—			—			(2		)	—		(2		)
Amounts reclassified from accumulated other comprehensive loss:
Amortization – prior service credit(a)	(8		)	(1		)	—			—		(9		)
– actuarial loss(a)	9			—			—			—		9
– settlement loss(a)	1			—			—			—		1
Other	—			—			—			—		—
Tax effect	(1		)	—			—			—		(1		)
Other comprehensive income (loss)	1			(1		)	(2		)	—		(2		)
Balance as of March 31, 2018	$	(189	)	$	(49	)	$	2		$	3	$	(233	)

(In millions)	Pension Benefits			Other Benefits			Gain on Cash Flow Hedge		Workers Compensation			Total
Balance as of December 31, 2018	$	(132	)	$	(23	)	$	2	$	9		$	(144	)
Other comprehensive loss before reclassifications	(1		)	—			—		—			(1		)
Amounts reclassified from accumulated other comprehensive loss:
Amortization – prior service credit(a)	(11		)	—			—		—			(11		)
– actuarial loss(a)	4			—			—		—			4
– settlement loss(a)	—			—			—		—			—
Other	—			—			—		(1		)	(1		)
Tax effect	2			—			—		—			2
Other comprehensive loss	(6		)	—			—		(1		)	(7		)
Balance as of March 31, 2019	$	(138	)	$	(23	)	$	2	$	8		$	(151	)

^(a)  These accumulated other comprehensive loss components are included in the computation of net periodic benefit cost. See Note 21.

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Defined Benefit Pension and Other Postretirement Plans

3 Months Ended

Mar. 31, 2019

Retirement Benefits [Abstract]

Defined Benefit Pension and Other Postretirement Plans

DEFINED BENEFIT PENSION AND OTHER POSTRETIREMENT PLANS

The following summarizes the components of net periodic benefit costs:

	Three Months Ended March 31,
	Pension Benefits						Other Benefits
(In millions)	2019			2018			2019		2018
Components of net periodic benefit cost:
Service cost	$	58		$	36		$	8	$	7
Interest cost	28			18			9		7
Expected return on plan assets	(32		)	(26		)	—		—
Amortization – prior service credit	(11		)	(8		)	—		(1		)
– actuarial loss	4			9			—		—
– settlement loss	—			1			—		—
Net periodic benefit cost	$	47		$	30		$	17	$	13

The components of net periodic benefit cost other than the service cost component are included in net interest and other financial costs on the consolidated statements of income.

During the three months ended March 31, 2019, we made no contributions to our funded pension plans. Benefit payments related to unfunded pension and other postretirement benefit plans were $3 million and $11 million, respectively, during the three months ended March 31, 2019.

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Stock-Based Compensation Plans

3 Months Ended

Mar. 31, 2019

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Stock-Based Compensation Plans

STOCK-BASED COMPENSATION PLANS

Stock Option Awards

The following table presents a summary of our stock option award activity for the three months ended March 31, 2019:

	Number of Shares		Weighted Average Exercise Price
Outstanding at December 31, 2018	8,724,595		$	37.07
Granted	1,037,671		62.68
Exercised	(229,169	)	10.62
Forfeited or expired	—		—
Outstanding at March 31, 2019	9,533,097		40.49

The grant date fair value of stock option awards granted during the three months ended March 31, 2019 was $14.34 per share. The fair value of stock options granted to our employees is estimated on the date of the grant using the Black Scholes option-pricing model, which employs various assumptions.

Restricted Stock and Restricted Stock Unit Awards

The following table presents a summary of restricted stock and restricted stock unit award activity for the three months ended March 31, 2019:

	Restricted Stock				Restricted Stock Units
	Number of Shares		Weighted Average Grant Date Fair Value		Number of Units		Weighted Average Grant Date Fair Value
Outstanding at December 31, 2018	990,700		$	57.23	4,226,856		$	80.96
Granted	158,120		62.66		8,050		59.56
Vested	(114,136	)	49.58		(1,110,705	)	82.43
Forfeited	(12,622	)	56.84		(46,923	)	82.43
Outstanding at March 31, 2019	1,022,062		58.93		3,077,278		80.35

Performance Unit Awards

The following table presents a summary of the activity for performance unit awards to be settled in shares for the three months ended March 31, 2019:

	Number of Units		Weighted Average Grant Date Fair Value
Outstanding at December 31, 2018	8,618,583		$	0.79
Granted	6,200,000		0.72
Vested	(2,280,333	)	0.57
Forfeited	(120,000	)	0.84
Outstanding at March 31, 2019	12,418,250		0.79

The performance unit awards granted during the three months ended March 31, 2019 have a grant date fair value of $0.72 per unit, as calculated using a Monte Carlo valuation model.

MPLX and ANDX Awards

Compensation expense for MPLX and ANDX equity awards was not material to our consolidated financial statements for the three months ended March 31, 2019.

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Leases

3 Months Ended

Mar. 31, 2019

Leases [Abstract]

Leases of Lessee Disclosure

LEASES

For further information regarding the adoption of ASC 842, including the method of adoption and practical expedients elected, see Note 2.

Lessee

We lease a wide variety of facilities and equipment including land and building space, office and field equipment, storage facilities and transportation equipment. Our remaining lease terms range from less than one year to 60 years. Most long-term leases include renewal options ranging from less than one year to 49 years and, in certain leases, also include purchase options. The lease term included in the measurement of right of use assets and lease liabilities includes options to extend or terminate our leases that we are reasonably certain to exercise. Options were included in the lease term primarily for retail store sites where we constructed property, plant and equipment on leased land that is expected to exist beyond the initial lease term.

Under ASC 842, the components of lease cost were as follows:

	Three Months Ended  March 31,
(In millions)	2019
Finance lease cost:
Amortization of right of use assets	$	14
Interest on lease liabilities	10
Operating lease cost	190
Variable lease cost	15
Short-term lease cost	152
Total lease cost	$	381

Supplemental balance sheet data related to leases were as follows:

(In millions)	March 31, 2019
Operating leases
Assets
Right of use assets	$	2,680
Liabilities
Operating lease liabilities	$	613
Long-term operating lease liabilities	2,153
Total operating lease liabilities	$	2,766
Weighted average remaining lease term	6.5 years
Weighted average discount rate	4.13		%
Finance leases
Assets
Property, plant and equipment, gross	$	760
Accumulated depreciation	206
Property, plant and equipment, net	$	554
Liabilities
Debt due within one year	$	45
Long-term debt	612
Total finance lease liabilities	$	657
Weighted average remaining lease term	13.2 years
Weighted average discount rate	6.02		%

As of March 31, 2019, maturities of lease liabilities for operating lease obligations and finance lease obligations having initial or remaining non-cancellable lease terms in excess of one year are as follows:

(In millions)	Operating		Finance
2019	$	554	$	57
2020	629		76
2021	545		69
2022	370		76
2023	262		83
2024 and thereafter	832		596
Gross lease payments	3,192		957
Less: imputed interest	426		300
Total lease liabilities	$	2,766	$	657

Leases of Lessor Disclosure

Lessor

MPLX has certain natural gas gathering, transportation and processing agreements in which it is considered to be the lessor under several implicit operating lease arrangements in accordance with GAAP. MPLX’s primary implicit lease operations relate to a natural gas gathering agreement in the Marcellus region for which it earns a fixed-fee for providing gathering services to a single producer using a dedicated gathering system. As the gathering system is expanded, the fixed-fee charged to the producer is adjusted to include the additional gathering assets in the lease. The primary term of the natural gas gathering arrangement expires in 2038 and will continue thereafter on a year-to-year basis until terminated by either party. Other significant implicit leases relate to a natural gas processing agreement in the Marcellus region and a natural gas processing agreement in the Southern Appalachia region for which MPLX earns minimum monthly fees for providing processing services to a single producer using a dedicated processing plant. The primary term of these natural gas processing agreements expire during 2023 and 2033.

MPLX did not elect to use the practical expedient to combine lease and non-lease components for lessor arrangements. The tables below represent the portion of the contract allocated to the lease component based on relative standalone selling price. Lessor agreements are currently deemed operating, as we elected the practical expedient to grandfather in old conclusions. We are still determining the impact of the new standard on these arrangements if and when a modification occurs and they are required to be assessed under ASC 842. MPLX may be required to re-classify existing operating leases to sales-type leases upon modification and related reassessment of the leases.

Our revenue from implicit lease arrangements, excluding executory costs, totaled approximately $60 million in the three months ended March 31, 2019. The implicit lease arrangements related to the processing facilities contain contingent rental provisions whereby we receive additional fees if the producer customer exceeds the monthly minimum processed volumes. During the three months ended March 31, 2019, MPLX did not receive any material contingent lease payments. The following is a schedule of minimum future rentals on the non‑cancellable operating leases as of March 31, 2019:

(In millions)
2019	$	144
2020	168
2021	162
2022	160
2023	154
2024 and thereafter	1,205
Total minimum future rentals	$	1,993

The following schedule summarizes our investment in assets held for operating lease by major classes as of March 31, 2019:

(In millions)	March 31, 2019
Natural gas gathering and NGL transportation pipelines and facilities	$	1,036
Natural gas processing facilities	642
Terminal and related assets	112
Land, building, office equipment and other	41
Property, plant and equipment	1,831
Less accumulated depreciation	261
Property, plant and equipment, net	$	1,570

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Commitments and Contingencies

3 Months Ended

Mar. 31, 2019

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

COMMITMENTS AND CONTINGENCIES

We are the subject of, or a party to, a number of pending or threatened legal actions, contingencies and commitments involving a variety of matters, including laws and regulations relating to the environment. Some of these matters are discussed below. For matters for which we have not recorded a liability, we are unable to estimate a range of possible loss because the issues involved have not been fully developed through pleadings, discovery or court proceedings. However, the ultimate resolution of some of these contingencies could, individually or in the aggregate, be material.

Environmental Matters

We are subject to federal, state, local and foreign laws and regulations relating to the environment. These laws generally provide for control of pollutants released into the environment and require responsible parties to undertake remediation of hazardous waste disposal sites and certain other locations including presently or formerly owned or operated retail marketing sites. Penalties may be imposed for noncompliance.

At March 31, 2019 and December 31, 2018, accrued liabilities for remediation totaled $451 million and $455 million, respectively. It is not presently possible to estimate the ultimate amount of all remediation costs that might be incurred or the penalties if any that may be imposed. Receivables for recoverable costs from certain states, under programs to assist companies in clean-up efforts related to underground storage tanks at presently or formerly owned or operated retail marketing sites, were $33 million and $35 million at March 31, 2019 and December 31, 2018, respectively.

Governmental and other entities in California, New York, Maryland and Rhode Island have filed lawsuits against coal, gas, oil and petroleum companies, including the Company. The lawsuits allege damages as a result of climate change and the plaintiffs are seeking unspecified damages and abatement under various tort theories. Similar lawsuits may be filed in other jurisdictions. At this early stage, the ultimate outcome of these matters remain uncertain, and neither the likelihood of an unfavorable outcome nor the ultimate liability, if any, can be determined.

We are involved in a number of environmental enforcement matters arising in the ordinary course of business. While the outcome and impact on us cannot be predicted with certainty, management believes the resolution of these environmental matters will not, individually or collectively, have a material adverse effect on our consolidated results of operations, financial position or cash flows.

Lawsuits

In May 2015, the Kentucky attorney general filed a lawsuit against our wholly-owned subsidiary, Marathon Petroleum Company LP (“MPC LP”), in the United States District Court for the Western District of Kentucky asserting claims under federal and state antitrust statutes, the Kentucky Consumer Protection Act, and state common law. The complaint, as amended in July 2015, alleges that MPC LP used deed restrictions, supply agreements with customers and exchange agreements with competitors to unreasonably restrain trade in areas within Kentucky and seeks declaratory relief, unspecified damages, civil penalties, restitution and disgorgement of profits. At this stage, the ultimate outcome of this litigation remains uncertain, and neither the likelihood of an unfavorable outcome nor the ultimate liability, if any, can be determined, and we are unable to estimate a reasonably possible loss (or range of loss) for this matter. We intend to vigorously defend ourselves in this matter.

In May 2007, the Kentucky attorney general filed a lawsuit against us and Marathon Oil in state court in Franklin County, Kentucky for alleged violations of Kentucky’s emergency pricing and consumer protection laws following Hurricanes Katrina and Rita in 2005. The lawsuit alleges that we overcharged customers by $89 millionduring September and October 2005. The complaint seeks disgorgement of these sums, as well as penalties, under Kentucky’s emergency pricing and consumer protection laws. We are vigorously defending this litigation. We believe that this is the first lawsuit for damages and injunctive relief under the Kentucky emergency pricing laws to progress this far and it contains many novel issues. In May 2011, the Kentucky attorney general amended his complaint to include a request for immediate injunctive relief as well as unspecified damages and penalties related to our wholesale gasoline pricing in April and May 2011 under statewide price controls that were activated by the Kentucky governor on April 26, 2011 and which have since expired. The court denied the attorney general’s request for immediate injunctive relief, and the remainder of the 2011 claims likely will be resolved along with those dating from 2005. If the lawsuit is resolved unfavorably in its entirety, it could materially impact our consolidated results of operations, financial position or cash flows. However, management does not believe the ultimate resolution of this litigation will have a material adverse effect on our consolidated financial position, results of operations, or cash flows.

We are also a party to a number of other lawsuits and other proceedings arising in the ordinary course of business. While the ultimate outcome and impact to us cannot be predicted with certainty, we believe that the resolution of these other lawsuits and proceedings will not have a material adverse effect on our consolidated financial position, results of operations or cash flows.

Guarantees

We have provided certain guarantees, direct and indirect, of the indebtedness of other companies. Under the terms of most of these guarantee arrangements, we would be required to perform should the guaranteed party fail to fulfill its obligations under the specified arrangements. In addition to these financial guarantees, we also have various performance guarantees related to specific agreements.

Guarantees related to indebtedness of equity method investees—MPC and MPLX hold interests in an offshore oil port, LOOP, and MPLX holds an interest in a crude oil pipeline system, LOCAP. Both LOOP and LOCAP have secured various project financings with throughput and deficiency agreements. Under the agreements, MPC, as a shipper, is required to advance funds if the investees are unable to service their debt. Any such advances are considered prepayments of future transportation charges. The duration of the agreements vary but tend to follow the terms of the underlying debt, which extend through 2037. Our maximum potential undiscounted payments under these agreements for the debt principal totaled $171 million as of March 31, 2019.

In connection with MPLX’s approximate nine percent indirect interest in a joint venture that owns and operates the Dakota Access Pipeline and Energy Transfer Crude Oil Pipeline projects, collectively referred to as the Bakken Pipeline system, MPLX has entered into a Contingent Equity Contribution Agreement. MPLX, along with the other joint venture owners in the Bakken Pipeline system, have agreed to make equity contributions to the joint venture upon certain events occurring to allow the entities that own and operate the Bakken Pipeline system to satisfy their senior note payment obligations. The senior notes were issued to repay amounts owed by the pipeline companies to fund the cost of construction of the Bakken Pipeline system. As of March 31, 2019, our maximum potential undiscounted payments under the Contingent Equity Contribution Agreement was approximately $230 million.

In connection with our 50 percent indirect interest in Crowley Ocean Partners, we have agreed to conditionally guarantee our portion of the obligations of the joint venture and its subsidiaries under a senior secured term loan agreement. The term loan agreement provides for loans of up to $325 million to finance the acquisition of four product tankers. MPC’s liability under the guarantee for each vessel is conditioned upon the occurrence of certain events, including if we cease to maintain an investment grade credit rating or the charter for the relevant product tanker ceases to be in effect and is not replaced by a charter with an investment grade company on certain defined commercial terms. As of March 31, 2019, our maximum potential undiscounted payments under this agreement for debt principal totaled $135 million.

In connection with our 50 percent indirect interest in Crowley Blue Water Partners, we have agreed to provide a conditional guarantee of up to 50 percent of its outstanding debt balance in the event there is no charter agreement in place with an investment grade customer for the entity’s three vessels as well as other financial support in certain circumstances. As of March 31, 2019, our maximum potential undiscounted payments under this arrangement was $125 million .

Marathon Oil indemnifications—In conjunction with our spinoff from Marathon Oil, we have entered into arrangements with Marathon Oil providing indemnities and guarantees with recorded values of $1 million as of March 31, 2019, which consist of unrecognized tax benefits related to MPC, its consolidated subsidiaries and the refining, marketing and transportation business operations prior to our spinoff which are not already reflected in the unrecognized tax benefits described in Note 11, and other contingent liabilities Marathon Oil may incur related to taxes. Furthermore, the separation and distribution agreement and other agreements with Marathon Oil to effect our spinoff provide for cross-indemnities between Marathon Oil and us. In general, Marathon Oil is required to indemnify us for any liabilities relating to Marathon Oil’s historical oil and gas exploration and production operations, oil sands mining operations and integrated gas operations, and we are required to indemnify Marathon Oil for any liabilities relating to Marathon Oil’s historical refining, marketing and transportation operations. The terms of these indemnifications are indefinite and the amounts are not capped.

Other guarantees—We have entered into other guarantees with maximum potential undiscounted payments totaling $123 million as of March 31, 2019, which primarily consist of a commitment to contribute cash to an equity method investee for certain catastrophic events, in lieu of procuring insurance coverage, a commitment to fund a share of the bonds issued by a government entity for construction of public utilities in the event that other industrial users of the facility default on their utility payments and leases of assets containing general lease indemnities and guaranteed residual values. See Note 5 for information regarding our guarantee of certain borrowings under the ANDX dropdown credit facility.

General guarantees associated with dispositions—Over the years, we have sold various assets in the normal course of our business. Certain of the related agreements contain performance and general guarantees, including guarantees regarding inaccuracies in representations, warranties, covenants and agreements, and environmental and general indemnifications that require us to perform upon the occurrence of a triggering event or condition. These guarantees and indemnifications are part of the normal course of selling assets. We are typically not able to calculate the maximum potential amount of future payments that could be made under such contractual provisions because of the variability inherent in the guarantees and indemnities. Most often, the nature of the guarantees and indemnities is such that there is no appropriate method for quantifying the exposure because the underlying triggering event has little or no past experience upon which a reasonable prediction of the outcome can be based.

Contractual Commitments and Contingencies

At March 31, 2019, our contractual commitments to acquire property, plant and equipment and advance funds to equity method investees totaled $1.06 billion.

Certain natural gas processing and gathering arrangements require us to construct natural gas processing plants, natural gas gathering pipelines and NGL pipelines and contain certain fees and charges if specified construction milestones are not achieved for reasons other than force majeure. In certain cases, certain producer customers may have the right to cancel the processing arrangements with us if there are significant delays that are not due to force majeure.

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Subsequent Events

3 Months Ended

Mar. 31, 2019

Subsequent Events [Abstract]

Subsequent Events

SUBSEQUENT EVENT

On May 8, 2019, MPC, MPLX and ANDX announced that MPLX and ANDX have entered into a definitive merger agreement whereby MPLX will acquire ANDX in a unit-for-unit transaction. Under the terms of the merger agreement, ANDX public unitholders will receive 1.135 MPLX common units for each ANDX common unit held and MPC will receive 1.0328 MPLX common units for each ANDX common unit held. As described in Notes 4 and 5, we consolidate ANDX in accordance with ASC 810 and previously recorded ANDX’s assets and liabilities to our balance sheet at preliminary fair values as of the Andeavor acquisition date of October 1, 2018. Upon closing of this merger, we will account for the unit-for-unit transaction as a common control transaction, which will result in a change in our noncontrolling interest and additional paid-in capital.

The transaction has been approved by MPLX’s and ANDX’s respective Conflicts Committees and both Boards of Directors. Subject to the satisfaction of customary closing conditions and receipt of regulatory approvals, the transaction is expected to close in the second half of 2019.

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Description of the Business and Basis of Presentation (Policies)

3 Months Ended

Mar. 31, 2019

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Use of estimates

These interim consolidated financial statements are unaudited; however, in the opinion of our management, these statements reflect all adjustments necessary for a fair statement of the results for the periods reported. All such adjustments are of a normal, recurring nature unless otherwise disclosed. These interim consolidated financial statements, including the notes, have been prepared in accordance with the rules of the SEC applicable to interim period financial statements and do not include all of the information and disclosures required by GAAP for complete financial statements.

Inventories

Inventories are carried at the lower of cost or market value. The cost of inventories of crude oil and refinery feedstocks, refined products and merchandise is determined primarily under the LIFO method.

Derivative instruments

Derivatives that are not designated as accounting hedges may include commodity derivatives used to hedge price risk on (1) inventories, (2) fixed price sales of refined products, (3) the acquisition of foreign-sourced crude oil, (4) the acquisition of ethanol for blending with refined products, (5) the sale of NGLs and (6) the purchase of natural gas.

Stock-based compensation arrangements

The fair value of stock options granted to our employees is estimated on the date of the grant using the Black Scholes option-pricing model, which employs various assumptions.

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Master Limited Partnerships (Tables)

3 Months Ended

Mar. 31, 2019

Noncontrolling Interest [Abstract]

Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net

As a result of equity transactions of MPLX and ANDX, we are required to adjust non-controlling interest and additional paid-in capital. Changes in MPC’s additional paid-in capital resulting from changes in its ownership interests in MPLX and ANDX were as follows:

	Three Months Ended  March 31,
(In millions)	2019			2018
Increase due to the issuance of MPLX common units and general partner units to MPC	$	—		$	1,114
Increase due to GP/IDR Exchange	—			1,808
Increase due to the issuance of MPLX & ANDX common units	4			4
Increase in MPC's additional paid-in capital	4			2,926
Tax impact	(1		)	(546		)
Increase in MPC's additional paid-in capital, net of tax	$	3		$	2,380

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Acquisitions (Tables)

3 Months Ended

Mar. 31, 2019

Business Combinations [Abstract]

Schedule of Recognized Identified Assets Acquired and Liabilities Assumed [Table Text Block]

During the three months ended March 31, 2019, we recorded adjustments to the preliminary fair value estimates of assets acquired and liabilities assumed as of the acquisition date as noted in the table below.

(In millions)	As originally reported		Adjustments			As adjusted
Cash and cash equivalents	$	382	$	—		$	382
Receivables	2,744		(2		)	2,742
Inventories	5,204		(8		)	5,196
Other current assets	378		—			378
Equity method investments	865		—			865
Property, plant and equipment, net	16,545		(1		)	16,544
Other noncurrent assets(a)	3,086		—			3,086
Total assets acquired	29,204		(11		)	29,193
Accounts payable	4,003		—			4,003
Payroll and benefits payable	348		—			348
Accrued taxes	590		—			590
Debt due within one year	34		—			34
Other current liabilities	392		23			415
Long-term debt	8,875		1			8,876
Deferred income taxes	1,609		22			1,631
Defined benefit postretirement plan obligations	432		—			432
Deferred credit and other liabilities	714		6			720
Noncontrolling interests	5,059		3			5,062
Total liabilities and noncontrolling interest assumed	22,056		55			22,111
Net assets acquired excluding goodwill	7,148		(66		)	7,082
Goodwill	16,314		66			16,380
Net assets acquired	$	23,462	$	—		$	23,462

^(a)  Includes intangible assets.

Business Acquisition, Pro Forma Information [Table Text Block]

The following unaudited pro forma financial information presents consolidated results assuming the Andeavor acquisition occurred on January 1, 2017. The unaudited pro forma information does not give effect to potential synergies that could result from the transaction and is not necessarily indicative of the results of future operations.

	Three Months Ended  March 31,
(In millions)	2018
Sales and other operating revenues	$	29,206
Net income attributable to MPC	26

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Variable Interest Entities (Tables)

3 Months Ended

Mar. 31, 2019

Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]

Schedule of Variable Interest Entities [Table Text Block]

The assets of MPLX and ANDX can only be used to settle their own obligations and their creditors have no recourse to our assets, except as noted above. The following table present balance sheet information for the assets and liabilities of MPLX and ANDX, which are included in our balance sheets.

	March 31, 2019				December 31, 2018
(In millions)	MPLX		ANDX(a)		MPLX		ANDX(a)
Assets
Cash and cash equivalents	$	93	$	29	$	68	$	10
Receivables, less allowance for doubtful accounts	372		248		425		199
Inventories	74		21		77		22
Other current assets	34		37		45		57
Equity method investments	4,270		602		4,174		602
Property, plant and equipment, net	14,816		6,882		14,639		6,845
Goodwill	2,581		1,052		2,586		1,051
Right of use assets	262		122		—		—
Other noncurrent assets	448		1,235		458		1,242
Liabilities
Accounts payable	$	583	$	177	$	776	$	215
Payroll and benefits payable	4		1		2		10
Accrued taxes	40		20		48		23
Debt due within one year	1		503		1		504
Operating lease liabilities	46		12		—		—
Other current liabilities	189		117		177		77
Long-term debt	13,832		4,629		13,392		4,469
Deferred income taxes	12		1		13		1
Long-term operating lease liabilities	216		109		—		—
Deferred credits and other liabilities	289		66		276		68

^(a)  The balances reflected here are ANDX’s historical balances as the preliminary purchase accounting adjustments related to ANDX’s assets and liabilities in connection with the Andeavor acquisition and reflected on our consolidated balance sheets as of December 31, 2018 and March 31, 2019 have not yet been pushed down to this subsidiary.

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Related Party Transactions (Tables)

3 Months Ended

Mar. 31, 2019

Related Party Transactions [Abstract]

Sales to Related Parties

Transactions with related parties were as follows:

	Three Months Ended  March 31,
(In millions)	2019		2018
Sales to related parties(a)	$	186	$	172
Purchases from related parties(b)	204		141

^(a)   Sales to related parties consists primarily of sales of refined products to PFJ Southeast, an equity affiliate which owns and operates travel plazas primarily in the Southeast region of the United States.

^(b)   We obtain utilities, transportation services and purchase ethanol from certain of our equity affiliates.

Summarized Financial Information For Equity Method Investees Table [Table Text Block]

Summarized financial information, in the aggregate, for our significant equity method investments on a 100 percent basis were as follows:

	Three Months Ended  March 31,
(In millions)	2019		2018
Revenues and other income	$	1,628	$	1,503
Income from operations	336		254
Net income	314		274

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Income (Loss) per Common Share (Tables)

3 Months Ended

Mar. 31, 2019

Earnings Per Share [Abstract]

Summary of Earnings Per Common Share

We compute basic earnings per share by dividing net income attributable to MPC less income allocated to participating securities by the weighted average number of shares of common stock outstanding. Since MPC grants certain incentive compensation awards to employees and non-employee directors that are considered to be participating securities, we have calculated our earnings per share using the two-class method. Diluted income per share assumes exercise of certain stock-based compensation awards, provided the effect is not anti-dilutive.

	Three Months Ended  March 31,
(In millions, except per share data)	2019			2018
Basic earnings (loss) per share:
Allocation of earnings:
Net income (loss) attributable to MPC	$	(7	)	$	37
Income allocated to participating securities	—			—
Income (loss) available to common stockholders – basic	$	(7	)	$	37
Weighted average common shares outstanding	673			476
Basic earnings (loss) per share	$	(0.01	)	$	0.08
Diluted earnings (loss) per share:
Allocation of earnings:
Net income (loss) attributable to MPC	$	(7	)	$	37
Income allocated to participating securities	—			—
Income (loss) available to common stockholders – diluted	$	(7	)	$	37
Weighted average common shares outstanding	673			476
Effect of dilutive securities	—			4
Weighted average common shares, including dilutive effect	673			480
Diluted earnings (loss) per share	$	(0.01	)	$	0.08

Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share

The following table summarizes the shares that were anti-dilutive and, therefore, were excluded from the diluted share calculation.

	Three Months Ended  March 31,
(In millions)	2019	2018
Shares issuable under stock-based compensation plans	7	—

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Equity (Tables)

3 Months Ended

Mar. 31, 2019

Equity [Abstract]

Share Repurchases

Total share repurchases were as follows:

	Three Months Ended  March 31,
(In millions, except per share data)	2019		2018
Number of shares repurchased	14		19
Cash paid for shares repurchased	$	885	$	1,327
Average cost per share	$	62.98	$	68.74

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Segment Information (Tables)

3 Months Ended

Mar. 31, 2019

Segment Reporting [Abstract]

Income From Operations Attributable To Operating Segments

Segment income represents income from operations attributable to the reportable segments. Corporate administrative expenses, except for those attributable to MPLX and ANDX, and costs related to certain non-operating assets are not allocated to the Refining & Marketing and Retail segments. In addition, certain items that affect comparability (as determined by the chief operating decision maker) are not allocated to the reportable segments.

(In millions)	Refining & Marketing			Retail		Midstream		Total
Three Months Ended March 31, 2019
Revenues:
Third party	$	19,751		$	7,373	$	957	$	28,081
Intersegment	4,429			2		1,232		5,663
Related party	183			3		—		186
Segment revenues	$	24,363		$	7,378	$	2,189	$	33,930
Segment income (loss) from operations	$	(334	)	$	170	$	908	$	744
Income from equity method investments	1			17		81		99
Depreciation and amortization(a)	427			126		307		860
Capital expenditures and investments(b)	394			73		823		1,290

(In millions)	Refining & Marketing			Retail		Midstream		Total
Three Months Ended March 31, 2018
Revenues:
Third party	$	13,412		$	4,569	$	713	$	18,694
Intersegment	2,379			1		631		3,011
Related party	170			2		—		172
Segment revenues	$	15,961		$	4,572	$	1,344	$	21,877
Segment income (loss) from operations	$	(133	)	$	95	$	567	$	529
Income from equity method investments	3			14		69		86
Depreciation and amortization(a)	252			79		181		512
Capital expenditures and investments(b)	191			39		482		712

^(a)  Differences between segment totals and MPC consolidated totals represent amounts related to corporate and other unallocated items and are included in items not allocated to segments in the reconciliation below.

^(b)  Capital expenditures include changes in capital accruals and investments in affiliates. See reconciliation from segment totals to MPC consolidated total capital expenditures below.

Reconciliation Of Segment Income From Operations To Income Before Income Taxes

The following reconciles segment income from operations to income before income taxes as reported in the consolidated statements of income:

	Three Months Ended  March 31,
(In millions)	2019			2018
Segment income from operations	$	744		$	529
Items not allocated to segments:
Corporate and other unallocated items(a)	(191		)	(89		)
Capline restructuring gain(b)	207			—
Transaction-related costs(c)	(91		)	—
Income from operations	669			440
Net interest and other financial costs	306			183
Income before income taxes	$	363		$	257

^(a)  Corporate and other unallocated items consists primarily of MPC’s corporate administrative expenses and costs related to certain non-operating assets, except for corporate overhead expenses attributable to MPLX and ANDX, which are included in the Midstream segment. Corporate overhead expenses are not allocated to the Refining & Marketing and Retail segments.

^(b)  See Note 13.

^(c)  The transaction-related costs recognized in the first quarter largely relate to the recognition of an obligation for vacation benefits provided to former Andeavor employees.

Reconciliation Of Segment Capital Expenditures And Investments To Total Capital Expenditures

The following reconciles segment capital expenditures and investments to total capital expenditures:

	Three Months Ended  March 31,
(In millions)	2019		2018
Segment capital expenditures and investments	$	1,290	$	712
Less investments in equity method investees	325		41
Plus items not allocated to segments:
Corporate	10		18
Capitalized interest	31		18
Total capital expenditures(a)	$	1,006	$	707

^(a)  Capital expenditures include changes in capital accruals. See Note 19 for a reconciliation of total capital expenditures to additions to property, plant and equipment as reported in the consolidated statements of cash flows.

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Net Interest and Other Financial Costs (Tables)

3 Months Ended

Mar. 31, 2019

Other Income and Expenses [Abstract]

Net Interest And Other Financial Income (Costs)

Net interest and other financial costs were as follows:

	Three Months Ended  March 31,
(In millions)	2019			2018
Interest income	$	(9	)	$	(20	)
Interest expense	340			213
Interest capitalized	(32		)	(18		)
Pension and other postretirement non-service costs(a)	(3		)	—
Loss on extinguishment of debt	—			4
Other financial costs	10			4
Net interest and other financial costs	$	306		$	183

^(a)  See Note 21.

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Inventories (Tables)

3 Months Ended

Mar. 31, 2019

Inventory Disclosure [Abstract]

Summary Of Inventories

(In millions)	March 31, 2019		December 31, 2018
Crude oil and refinery feedstocks	$	3,689	$	3,655
Refined products	5,186		5,234
Materials and supplies	744		720
Merchandise	214		228
Total	$	9,833	$	9,837

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Property, Plant and Equipment (Tables)

3 Months Ended

Mar. 31, 2019

Property, Plant and Equipment [Abstract]

Summary Of Property, Plant And Equipment

(In millions)	March 31, 2019		December 31, 2018
Refining & Marketing	$	27,968	$	27,590
Retail	6,681		6,637
Midstream	25,929		25,692
Corporate and Other	1,304		1,294
Total	61,882		61,213
Less accumulated depreciation	16,791		16,155
Property, plant and equipment, net	$	45,091	$	45,058

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Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2019

Fair Value Disclosures [Abstract]

Assets and Liabilities Accounted for at Fair Value on Recurring Basis

The following tables present assets and liabilities accounted for at fair value on a recurring basis as of March 31, 2019 and December 31, 2018 by fair value hierarchy level. We have elected to offset the fair value amounts recognized for multiple derivative contracts executed with the same counterparty, including any related cash collateral as shown below; however, fair value amounts by hierarchy level are presented on a gross basis in the following tables.

	March 31, 2019
	Fair Value Hierarchy
(In millions)	Level 1		Level 2		Level 3		Netting and Collateral(a)			Net Carrying Value on Balance Sheet(b)		Collateral Pledged Not Offset
Assets:
Commodity contracts	$	122	$	18	$	—	$	(128	)	$	12	$	42
Liabilities:
Commodity contracts	$	142	$	24	$	—	$	(161	)	$	5	$	—
Embedded derivatives in commodity contracts	—		—		65		—			65		—

	December 31, 2018
	Fair Value Hierarchy
(In millions)	Level 1		Level 2		Level 3		Netting and Collateral(a)			Net Carrying Value on Balance Sheet(b)		Collateral Pledged Not Offset
Assets:
Commodity contracts	$	370	$	31	$	—	$	(323	)	$	78	$	2
Liabilities:
Commodity contracts	$	255	$	37	$	—	$	(284	)	$	8	$	—
Embedded derivatives in commodity contracts	—		—		61		—			61		—

^(a)  Represents the impact of netting assets, liabilities and cash collateral when a legal right of offset exists. As of March 31, 2019, cash collateral of $33 million was netted with the mark-to-market derivative liabilities. As of December 31, 2018, cash collateral of $52 million was netted with mark-to-market derivative assets and $13 million was netted with mark-to-market derivative liabilities.

^(b)  We have no derivative contracts that are subject to master netting arrangements reflected gross on the balance sheet.

Reconciliation of Net Beginning and Ending Balances Recorded for Net Assets and Liabilities Classified as Level 3

The following is a reconciliation of the beginning and ending balances recorded for net liabilities classified as Level 3 in the fair value hierarchy.

	Three Months Ended  March 31,
(In millions)	2019			2018
Beginning balance	$	61		$	66
Unrealized and realized losses included in net income	6			(3		)
Settlements of derivative instruments	(2		)	(3		)
Ending balance	$	65		$	60
The amount of total losses for the period included in earnings attributable to the change in unrealized losses relating to assets still held at the end of period:	$	5		$	(3	)

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Derivatives (Tables)

3 Months Ended

Mar. 31, 2019

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Classification of Fair Values of Derivative Instruments, Excluding Cash Collateral

The following table presents the fair value of derivative instruments as of March 31, 2019 and December 31, 2018 and the line items in the balance sheets in which the fair values are reflected. The fair value amounts below are presented on a gross basis and do not reflect the netting of asset and liability positions permitted under the terms of our master netting arrangements including cash collateral on deposit with, or received from, brokers. We offset the recognized fair value amounts for multiple derivative instruments executed with the same counterparty in our financial statements when a legal right of offset exists. As a result, the asset and liability amounts below will not agree with the amounts presented in our consolidated balance sheets.

(In millions)	March 31, 2019
Balance Sheet Location	Asset		Liability
Commodity derivatives
Other current assets	$	139	$	160
Other current liabilities(a)	1		14
Deferred credits and other liabilities(a)	—		57

(In millions)	December 31, 2018
Balance Sheet Location	Asset		Liability
Commodity derivatives
Other current assets	$	400	$	283
Other current liabilities(a)	1		16
Deferred credits and other liabilities(a)	—		54

^(a)   Includes embedded derivatives.

Open Commodity Derivative Contracts

The table below summarizes open commodity derivative contracts for crude oil, refined products and blending products as of March 31, 2019.

	Percentage of contracts that expire next quarter	Position
(Units in thousands of barrels)		Long	Short
Exchange-traded(a)
Crude oil	82.6%	49,844	58,466
Refined products	89.4%	11,373	9,945
Blending products	77.3%	4,688	4,866
OTC
Crude oil	—%	640	—
Blending products	—%	1,676	1,444

^(a)  Included in exchange-traded are spread contracts in thousands of barrels: Crude oil - 11,999 long and 3,980 short; Refined products - 300 long and 300 short; Blending products - 2,603 long and 2,506 short

Effect of Commodity Derivative Instruments in Statements of Income

The following table summarizes the effect of all commodity derivative instruments in our consolidated statements of income:

	Loss
(In millions)	Three Months Ended March 31,
Income Statement Location	2019			2018
Sales and other operating revenues	$	(20	)	$	(1	)
Cost of revenues	(80		)	(27		)
Total	$	(100	)	$	(28	)

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Debt (Tables)

3 Months Ended

Mar. 31, 2019

Debt Disclosure [Abstract]

Outstanding Borrowings

Our outstanding borrowings at March 31, 2019 and December 31, 2018 consisted of the following:

(In millions)	March 31, 2019			December 31, 2018
Marathon Petroleum Corporation	$	9,120		$	9,114
MPLX LP	14,283			13,856
ANDX LP	5,168			5,010
Total debt	$	28,571		$	27,980
Unamortized debt issuance costs	(126		)	(128		)
Unamortized discount	(330		)	(328		)
Amounts due within one year	(550		)	(544		)
Total long-term debt due after one year	$	27,565		$	26,980

Schedule of Line of Credit Facilities [Table Text Block]

Available Capacity under our Facilities

(Dollars in millions)	Total Capacity		Outstanding Borrowings		Outstanding Letters of Credit		Available Capacity		Weighted Average Interest Rate		Expiration
MPC 364-day bank revolving credit facility	$	1,000	$	—	$	—	$	1,000	—		September 2019
MPC bank revolving credit facility	5,000		—		32		4,968		—		October 2023
MPLX bank revolving credit facility	2,250		425		3		1,822		3.92	%	July 2022
ANDX revolving & dropdown credit facilities(a)	2,100		1,404		—		696		4.32	%	January 2021
Trade receivables securitization facility	750		—		—		750		—		July 2019
	$	11,100	$	1,829	$	35	$	9,236

^(a)  Western Refining Southwest, Inc., a wholly-owned subsidiary of MPC and unitholder of ANDX, has guaranteed certain outstanding borrowings under the ANDX dropdown credit facility that were made in connection with the August 2018 dropdown transaction.

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Revenue (Tables)

3 Months Ended

Mar. 31, 2019

Revenue from Contract with Customer [Abstract]

Revenue from External Customers by Products and Services [Table Text Block]

The following table presents our revenues disaggregated by product line.

	Three Months Ended  March 31,
(In millions)	2019		2018
Refined products	$	24,653	$	16,158
Merchandise	1,464		1,130
Crude oil and refinery feedstocks	1,367		883
Midstream services, transportation and other	597		523
Sales and other operating revenues	$	28,081	$	18,694

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Supplemental Cash Flow Information (Tables)

3 Months Ended

Mar. 31, 2019

Supplemental Cash Flow Elements [Abstract]

Summary of Supplemental Cash Flow Information

	Three Months Ended  March 31,
(In millions)	2019		2018
Net cash provided by operating activities included:
Interest paid (net of amounts capitalized)	$	269	$	212
Net income taxes paid to taxing authorities	42		6
Cash paid for amounts included in the measurement of lease liabilities
Payments on operating leases	189		—
Interest payments under finance lease obligations	8		—
Net cash provided by financing activities included:
Principal payments under finance lease obligations	10		—
Non-cash investing and financing activities:
Right of use assets obtained in exchange for new operating lease obligations	31		—
Right of use assets obtained in exchange for new finance lease obligations	15		—
Contribution of net assets to Capline LLC(a)	143		—
Recognition of Capline LLC equity method investment(a)	350		—

^(a)  See Note 13.

Schedule of Cash and Cash Equivalents

(In millions)	March 31, 2019		December 31, 2018
Cash and cash equivalents	$	877	$	1,687
Restricted cash(a)	31		38
Cash, cash equivalents and restricted cash	$	908	$	1,725

^(a)  The restricted cash balance is included within other current assets on the consolidated balance sheets.

Reconciliation of Additions to Property, Plant and Equipment to Total Capital Expenditures

The consolidated statements of cash flows exclude changes to the consolidated balance sheets that did not affect cash. The following is a reconciliation of additions to property, plant and equipment to total capital expenditures:

	Three Months Ended  March 31,
(In millions)	2019			2018
Additions to property, plant and equipment per the consolidated statements of cash flows	$	1,241		$	755
Asset retirement expenditures	—			1
Decrease in capital accruals	(235		)	(49		)
Total capital expenditures	$	1,006		$	707

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Accumulated Other Comprehensive Loss (Tables)

3 Months Ended

Mar. 31, 2019

Equity [Abstract]

Changes in Accumulated Other Comprehensive Loss by Component

The following table shows the changes in accumulated other comprehensive loss by component. Amounts in parentheses indicate debits.

(In millions)	Pension Benefits			Other Benefits			Gain on Cash Flow Hedge			Workers Compensation		Total
Balance as of December 31, 2017	$	(190	)	$	(48	)	$	4		$	3	$	(231	)
Other comprehensive loss before reclassifications	—			—			(2		)	—		(2		)
Amounts reclassified from accumulated other comprehensive loss:
Amortization – prior service credit(a)	(8		)	(1		)	—			—		(9		)
– actuarial loss(a)	9			—			—			—		9
– settlement loss(a)	1			—			—			—		1
Other	—			—			—			—		—
Tax effect	(1		)	—			—			—		(1		)
Other comprehensive income (loss)	1			(1		)	(2		)	—		(2		)
Balance as of March 31, 2018	$	(189	)	$	(49	)	$	2		$	3	$	(233	)

(In millions)	Pension Benefits			Other Benefits			Gain on Cash Flow Hedge		Workers Compensation			Total
Balance as of December 31, 2018	$	(132	)	$	(23	)	$	2	$	9		$	(144	)
Other comprehensive loss before reclassifications	(1		)	—			—		—			(1		)
Amounts reclassified from accumulated other comprehensive loss:
Amortization – prior service credit(a)	(11		)	—			—		—			(11		)
– actuarial loss(a)	4			—			—		—			4
– settlement loss(a)	—			—			—		—			—
Other	—			—			—		(1		)	(1		)
Tax effect	2			—			—		—			2
Other comprehensive loss	(6		)	—			—		(1		)	(7		)
Balance as of March 31, 2019	$	(138	)	$	(23	)	$	2	$	8		$	(151	)

^(a)  These accumulated other comprehensive loss components are included in the computation of net periodic benefit cost. See Note 21.

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Defined Benefit Pension and Other Postretirement Plans (Tables)

3 Months Ended

Mar. 31, 2019

Retirement Benefits [Abstract]

Components of Net Periodic Benefit Costs

The following summarizes the components of net periodic benefit costs:

	Three Months Ended March 31,
	Pension Benefits						Other Benefits
(In millions)	2019			2018			2019		2018
Components of net periodic benefit cost:
Service cost	$	58		$	36		$	8	$	7
Interest cost	28			18			9		7
Expected return on plan assets	(32		)	(26		)	—		—
Amortization – prior service credit	(11		)	(8		)	—		(1		)
– actuarial loss	4			9			—		—
– settlement loss	—			1			—		—
Net periodic benefit cost	$	47		$	30		$	17	$	13

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Stock-Based Compensation Plans (Tables)

3 Months Ended

Mar. 31, 2019

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Summary of Stock Option Award Activity

The following table presents a summary of our stock option award activity for the three months ended March 31, 2019:

	Number of Shares		Weighted Average Exercise Price
Outstanding at December 31, 2018	8,724,595		$	37.07
Granted	1,037,671		62.68
Exercised	(229,169	)	10.62
Forfeited or expired	—		—
Outstanding at March 31, 2019	9,533,097		40.49

Summary of Restricted Stock Award Activity

The following table presents a summary of restricted stock and restricted stock unit award activity for the three months ended March 31, 2019:

	Restricted Stock				Restricted Stock Units
	Number of Shares		Weighted Average Grant Date Fair Value		Number of Units		Weighted Average Grant Date Fair Value
Outstanding at December 31, 2018	990,700		$	57.23	4,226,856		$	80.96
Granted	158,120		62.66		8,050		59.56
Vested	(114,136	)	49.58		(1,110,705	)	82.43
Forfeited	(12,622	)	56.84		(46,923	)	82.43
Outstanding at March 31, 2019	1,022,062		58.93		3,077,278		80.35

Schedule of Performance Unit Awards

The following table presents a summary of the activity for performance unit awards to be settled in shares for the three months ended March 31, 2019:

	Number of Units		Weighted Average Grant Date Fair Value
Outstanding at December 31, 2018	8,618,583		$	0.79
Granted	6,200,000		0.72
Vested	(2,280,333	)	0.57
Forfeited	(120,000	)	0.84
Outstanding at March 31, 2019	12,418,250		0.79

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Leases (Tables)

3 Months Ended

Mar. 31, 2019

Leases [Abstract]

Lease, Cost

Under ASC 842, the components of lease cost were as follows:

	Three Months Ended  March 31,
(In millions)	2019
Finance lease cost:
Amortization of right of use assets	$	14
Interest on lease liabilities	10
Operating lease cost	190
Variable lease cost	15
Short-term lease cost	152
Total lease cost	$	381

Supplemental Balance Sheet Disclosures [Text Block]

Supplemental balance sheet data related to leases were as follows:

(In millions)	March 31, 2019
Operating leases
Assets
Right of use assets	$	2,680
Liabilities
Operating lease liabilities	$	613
Long-term operating lease liabilities	2,153
Total operating lease liabilities	$	2,766
Weighted average remaining lease term	6.5 years
Weighted average discount rate	4.13		%
Finance leases
Assets
Property, plant and equipment, gross	$	760
Accumulated depreciation	206
Property, plant and equipment, net	$	554
Liabilities
Debt due within one year	$	45
Long-term debt	612
Total finance lease liabilities	$	657
Weighted average remaining lease term	13.2 years
Weighted average discount rate	6.02		%

Schedule Of Future Minimum Lease Payments For Operating And Capital Leases Table [Text Block]

As of March 31, 2019, maturities of lease liabilities for operating lease obligations and finance lease obligations having initial or remaining non-cancellable lease terms in excess of one year are as follows:

(In millions)	Operating		Finance
2019	$	554	$	57
2020	629		76
2021	545		69
2022	370		76
2023	262		83
2024 and thereafter	832		596
Gross lease payments	3,192		957
Less: imputed interest	426		300
Total lease liabilities	$	2,766	$	657

Presented in accordance with ASC 840, future minimum commitments as of December 31, 2018 for operating lease obligations and capital lease obligations having initial or remaining non-cancellable lease terms in excess of one year were as follows:

(In millions)	Operating		Capital
2019	$	709	$	70
2020	619		71
2021	553		66
2022	389		75
2023	295		82
2024 and thereafter	858		586
Total minimum lease payments	$	3,423	950
Less: imputed interest costs			301
Present value of net minimum lease payments			$	649

Schedule of Future Minimum Rental Payments Receivable for Operating Leases [Table Text Block]

The following is a schedule of minimum future rentals on the non‑cancellable operating leases as of March 31, 2019:

(In millions)
2019	$	144
2020	168
2021	162
2022	160
2023	154
2024 and thereafter	1,205
Total minimum future rentals	$	1,993

Schedule of Property Subject to or Available for Operating Lease [Table Text Block]

The following schedule summarizes our investment in assets held for operating lease by major classes as of March 31, 2019:

(In millions)	March 31, 2019
Natural gas gathering and NGL transportation pipelines and facilities	$	1,036
Natural gas processing facilities	642
Terminal and related assets	112
Land, building, office equipment and other	41
Property, plant and equipment	1,831
Less accumulated depreciation	261
Property, plant and equipment, net	$	1,570

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Description of the Business and Basis of Presentation (Details) bbl / d in Millions	3 Months Ended
	Mar. 31, 2019 Store bbl / d refinery
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Capacity | bbl / d	3
Number of refineries | refinery	16
Number of branded outlets	6,900
Number of retail transportation fuel and convenience stores	3,920
Number of direct dealer locations	1,060

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Accounting Standards (Details) - Accounting Standards Update 2016-02 $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($)
Minimum
New accounting pronouncement or change in accounting principle, effect of adoption, quantification	$ 2,790
Maximum
New accounting pronouncement or change in accounting principle, effect of adoption, quantification	$ 2,880

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Master Limited Partnerships - MPLX (Detail)	Mar. 31, 2019
MPLX
Noncontrolling Interest [Line Items]
MPC's partnership interest in MLP (in percentage)	64.00%

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Master Limited Partnerships - Dropdowns to MPLX and GP/IDR Exchange (Details) - MPLX shares in Millions, $ in Billions	Feb. 01, 2018 USD ($) shares
MPLX 364-day term loan
Noncontrolling Interest [Line Items]
Maximum borrowing capacity | $	$ 4.1
Debt instrument, term	364 days
Cash and Cash Equivalents
Noncontrolling Interest [Line Items]
Cash consideration | $	$ 4.1
Limited Partner
Noncontrolling Interest [Line Items]
Units issued, number of units	112
Conversion of stock, units issued	275
General Partner
Noncontrolling Interest [Line Items]
Units issued, number of units	2

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Master Limited Partnerships - ANDX (Details)	Mar. 31, 2019 shares
TexNew Mex units
Units outstanding	80,000
ANDX
MPC's partnership interest in MLP (in percentage)	64.00%

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Master Limited Partnerships - Noncontrolling Interest in MLPs (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Sep. 30, 2017
Increase in MPC's additional paid-in capital, net of tax	$ 2	$ (546)
Additional Paid-in Capital
Increase due to the issuance of MPLX common units and general partner units to MPC	0		$ 1,114
Increase due to GP/IDR Exchange	0		1,808
Increase due to the issuance of MPLX & ANDX common units	4		4
Increase in MPC's additional paid-in capital	4		2,926
Tax impact	(1)		(546)
Increase in MPC's additional paid-in capital, net of tax	$ 3	$ 2,380	$ 2,380

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Acquisitions - Acquisition of Andeavor (Details) - USD ($) $ in Millions	Oct. 01, 2018	Mar. 31, 2019	Dec. 31, 2018
Business Acquisition [Line Items]
Goodwill		$ 20,229	$ 20,184
Andeavor
Business Acquisition [Line Items]
Total fair value of consideration transferred	$ 23,460
Fair value of MPC shares issued	19,970
Cash payment to Andeavor stockholders	3,490
Goodwill	16,380
Goodwill, expected tax deductible amount	893
Andeavor | Refining & Marketing
Business Acquisition [Line Items]
Goodwill	4,780
Andeavor | Midstream
Business Acquisition [Line Items]
Goodwill	7,720
Andeavor | Retail
Business Acquisition [Line Items]
Goodwill	$ 3,880

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Acquisitions - Schedule of Assets Acquired and Liabilities Assumed - Andeavor (Details) - USD ($) $ in Millions		Mar. 31, 2019	Dec. 31, 2018	Oct. 01, 2018
Business Acquisition [Line Items]
Goodwill		$ 20,229	$ 20,184
Andeavor
Business Acquisition [Line Items]
Cash and cash equivalents				$ 382
Receivables				2,742
Inventories				5,196
Other current assets				378
Equity method investments				865
Property, plant and equipment, net				16,544
Other noncurrent assets	[1]			3,086
Total assets acquired				29,193
Accounts payable				4,003
Payroll and benefits payable				348
Accrued taxes				590
Debt due within one year				34
Other current liabilities				415
Long-term debt				8,876
Deferred income taxes				1,631
Defined benefit postretirement plan obligations				432
Deferred credit and other liabilities				720
Noncontrolling interests				5,062
Total liabilities and noncontrolling interest assumed				22,111
Net assets acquired excluding goodwill				7,082
Goodwill				16,380
Net assets acquired				23,462
Andeavor | As originally reported
Business Acquisition [Line Items]
Cash and cash equivalents				382
Receivables				2,744
Inventories				5,204
Other current assets				378
Equity method investments				865
Property, plant and equipment, net				16,545
Other noncurrent assets	[1]			3,086
Total assets acquired				29,204
Accounts payable				4,003
Payroll and benefits payable				348
Accrued taxes				590
Debt due within one year				34
Other current liabilities				392
Long-term debt				8,875
Deferred income taxes				1,609
Defined benefit postretirement plan obligations				432
Deferred credit and other liabilities				714
Noncontrolling interests				5,059
Total liabilities and noncontrolling interest assumed				22,056
Net assets acquired excluding goodwill				7,148
Goodwill				16,314
Net assets acquired				23,462
Andeavor | Adjustments
Business Acquisition [Line Items]
Cash and cash equivalents				0
Receivables				(2)
Inventories				(8)
Other current assets				0
Equity method investments				0
Property, plant and equipment, net				(1)
Other noncurrent assets	[1]			0
Total assets acquired				(11)
Accounts payable				0
Payroll and benefits payable				0
Accrued taxes				0
Debt due within one year				0
Other current liabilities				23
Long-term debt				1
Deferred income taxes				22
Defined benefit postretirement plan obligations				0
Deferred credit and other liabilities				6
Noncontrolling interests				3
Total liabilities and noncontrolling interest assumed				55
Net assets acquired excluding goodwill				(66)
Goodwill		$ 32		66
Net assets acquired				$ 0

[1] Includes intangible assets

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Acquisition - Pro Forma Information - Andeavor (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Business Acquisition [Line Items]
Sales and other operating revenues	$ 28,081	$ 18,694
Net income (loss) attributable to MPC	$ (7)	37
Andeavor
Business Acquisition [Line Items]
Sales and other operating revenues		29,206
Net income (loss) attributable to MPC		$ 26

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Acquisition - Acquisition of Express Mart (Details) $ in Millions	Nov. 16, 2018 USD ($) Store	Mar. 31, 2019 USD ($)	Dec. 31, 2018 USD ($)
Business Acquisition [Line Items]
Goodwill		$ 20,229	$ 20,184
Express Mart
Business Acquisition [Line Items]
Number of stores | Store	78
Cash consideration	$ 266
Property, plant and equipment, net	97
Inventories	9
Finite-lived intangibles	2
Goodwill	$ 158

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Acquisitions - Acquisition of Mt. Airy Terminal (Details) bbl / d in Thousands, bbl in Millions, $ in Millions	Sep. 26, 2018 USD ($) bbl / d bbl	Mar. 31, 2019 USD ($)	Dec. 31, 2018 USD ($)
Goodwill		$ 20,229	$ 20,184
Mt. Airy Terminal
Storage capacity | bbl	4
Barrels handled | bbl / d	120
Mt. Airy Terminal | MPLX
Cash consideration	$ 446
Property, plant and equipment, net	336
Goodwill	121
Mt. Airy Terminal | As originally reported | MPLX
Cash consideration	451
Mt. Airy Terminal | Adjustments | MPLX
Cash consideration	$ 5

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Variable Interest Entities - Consolidated VIEs (Details) - USD ($) $ in Millions		Mar. 31, 2019	Dec. 31, 2018
Assets
Cash and cash equivalents		$ 877	$ 1,687
Receivables, less allowance for doubtful accounts		6,893	5,853
Inventories		9,833	9,837
Other current assets		548	646
Equity method investments		6,558	5,898
Property, plant and equipment, net		45,091	45,058
Goodwill		20,229	20,184
Right of use assets		2,680	0
Other noncurrent assets		3,727	3,777
Liabilities
Accounts payable		10,568	9,366
Payroll and benefits payable		958	1,152
Accrued taxes		1,529	1,446
Debt due within one year		550	544
Operating lease liabilities		613	0
Other current liabilities		929	708
Long-term debt		27,565	26,980
Defined benefit postretirement plan obligations		1,567	1,509
Long-term operating lease liabilities		2,153	0
Deferred credits and other liabilities		1,131	1,318
Variable Interest Entity, Primary Beneficiary [Member] | MPLX
Assets
Cash and cash equivalents		93	68
Receivables, less allowance for doubtful accounts		372	425
Inventories		74	77
Other current assets		34	45
Equity method investments		4,270	4,174
Property, plant and equipment, net		14,816	14,639
Goodwill		2,581	2,586
Right of use assets		262	0
Other noncurrent assets		448	458
Liabilities
Accounts payable		583	776
Payroll and benefits payable		4	2
Accrued taxes		40	48
Debt due within one year		1	1
Operating lease liabilities		46	0
Other current liabilities		189	177
Long-term debt		13,832	13,392
Deferred income taxes		12	13
Long-term operating lease liabilities		216	0
Deferred credits and other liabilities		289	276
Variable Interest Entity, Primary Beneficiary [Member] | ANDX
Assets
Cash and cash equivalents	[1]	29	10
Receivables, less allowance for doubtful accounts	[1]	248	199
Inventories	[1]	21	22
Other current assets	[1]	37	57
Equity method investments	[1]	602	602
Property, plant and equipment, net	[1]	6,882	6,845
Goodwill	[1]	1,052	1,051
Right of use assets	[1]	122	0
Other noncurrent assets	[1]	1,235	1,242
Liabilities
Accounts payable	[1]	177	215
Payroll and benefits payable	[1]	1	10
Accrued taxes	[1]	20	23
Debt due within one year	[1]	503	504
Operating lease liabilities	[1]	12	0
Other current liabilities	[1]	117	77
Long-term debt	[1]	4,629	4,469
Deferred income taxes	[1]	1	1
Long-term operating lease liabilities	[1]	109	0
Deferred credits and other liabilities	[1]	$ 66	$ 68

[1] The balances reflected here are ANDX’s historical balances as the preliminary purchase accounting adjustments related to ANDX’s assets and liabilities in connection with the Andeavor acquisition and reflected on our consolidated balance sheets as of December 31, 2018 and March 31, 2019 have not yet been pushed down to this subsidiary.

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Related Party Transactions (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2019	Mar. 31, 2018
Related Party Transactions [Abstract]
Sales to related parties	[1]	$ 186	$ 172
Purchases from related parties	[2]	$ 204	$ 141

[1] Sales to related parties consists primarily of sales of refined products to PFJ Southeast, an equity affiliate which owns and operates travel plazas primarily in the Southeast region of the United States.

[2] We obtain utilities, transportation services and purchase ethanol from certain of our equity affiliates.

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Related Party Transactions - Summarized Financial Information for Significant Equity Affiliates (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Related Party Transactions [Abstract]
Revenues and other income	$ 1,628	$ 1,503
Income from operations	336	254
Net income	$ 314	$ 274

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Income (Loss) Per Common Share - Summary of Earnings Per Common Share (Detail) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Basic earnings (loss) per share:
Net income (loss) attributable to MPC	$ (7)	$ 37
Income allocated to participating securities	0	0
Income (loss) available to common stockholders – basic	$ (7)	$ 37
Weighted average common shares outstanding (in shares)	673	476
Basic earnings (loss) per share	$ (0.01)	$ 0.08
Diluted earnings (loss) per share:
Net income (loss) attributable to MPC	$ (7)	$ 37
Income allocated to participating securities	0	0
Income (loss) available to common stockholders – diluted	$ (7)	$ 37
Weighted average common shares outstanding (in shares)	673	476
Effect of dilutive securities (in shares)	0	4
Weighted average common shares, including dilutive effect (in shares)	673	480
Diluted earnings (loss) per share	$ (0.01)	$ 0.08

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Income (Loss) Per Common Share - Anti-dilutive Shares (Details) - shares shares in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Stock Based Compensation Expense [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares issuable under stock-based compensation plans	7	0

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Equity - Additional Information (Detail) - USD ($) $ in Millions	1 Months Ended	3 Months Ended
	Apr. 30, 2019	Mar. 31, 2019	Mar. 31, 2018
Number of shares repurchased		14,000,000	19,000,000
Cash paid for shares repurchased		$ 885	$ 1,327
Stock repurchase program, remaining authorized repurchase amount		$ 4,020
Forecast
Number of shares repurchased	493,625
Cash paid for shares repurchased	$ 30

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Equity - Share Repurchases (Detail) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Equity [Abstract]
Number of shares repurchased	14	19
Cash paid for shares repurchased	$ 885	$ 1,327
Average cost per share	$ 62.98	$ 68.74

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Segment Information - Additional Information (Detail)	3 Months Ended
	Mar. 31, 2019 Segment refinery
Segment Reporting [Abstract]
Number of reportable segments | Segment	3
Number of refineries | refinery	16

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Segment Information - Income From Operations Attributable To Operating Segments (Detail) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2019	Mar. 31, 2018
Segment Reporting Information [Line Items]
Sales and other operating revenues		$ 28,081	$ 18,694
Sales to related parties	[1]	186	172
Income (loss) from operations		669	440
Income from equity method investments		99	86
Depreciation and amortization		919	528
Intersegment Eliminations
Segment Reporting Information [Line Items]
Sales and other operating revenues		5,663	3,011
Operating Segments
Segment Reporting Information [Line Items]
Sales and other operating revenues		33,930	21,877
Income (loss) from operations		744	529
Income from equity method investments		99	86
Depreciation and amortization	[2]	860	512
Capital expenditures and investments	[3]	1,290	712
Refining & Marketing
Segment Reporting Information [Line Items]
Sales and other operating revenues		19,751	13,412
Sales to related parties		183	170
Refining & Marketing | Intersegment Eliminations
Segment Reporting Information [Line Items]
Sales and other operating revenues		4,429	2,379
Refining & Marketing | Operating Segments
Segment Reporting Information [Line Items]
Sales and other operating revenues		24,363	15,961
Income (loss) from operations		(334)	(133)
Income from equity method investments		1	3
Depreciation and amortization		427	252
Capital expenditures and investments		394	191
Retail
Segment Reporting Information [Line Items]
Sales and other operating revenues		7,373	4,569
Sales to related parties		3	2
Retail | Intersegment Eliminations
Segment Reporting Information [Line Items]
Sales and other operating revenues		2	1
Retail | Operating Segments
Segment Reporting Information [Line Items]
Sales and other operating revenues		7,378	4,572
Income (loss) from operations		170	95
Income from equity method investments		17	14
Depreciation and amortization		126	79
Capital expenditures and investments		73	39
Midstream
Segment Reporting Information [Line Items]
Sales and other operating revenues		957	713
Sales to related parties		0	0
Midstream | Intersegment Eliminations
Segment Reporting Information [Line Items]
Sales and other operating revenues		1,232	631
Midstream | Operating Segments
Segment Reporting Information [Line Items]
Sales and other operating revenues		2,189	1,344
Income (loss) from operations		908	567
Income from equity method investments		81	69
Depreciation and amortization		307	181
Capital expenditures and investments		823	482
Reportable Segment
Segment Reporting Information [Line Items]
Sales and other operating revenues		$ 28,081	$ 18,694

[1] Sales to related parties consists primarily of sales of refined products to PFJ Southeast, an equity affiliate which owns and operates travel plazas primarily in the Southeast region of the United States.

[2] Differences between segment totals and MPC consolidated totals represent amounts related to corporate and other unallocated items and are included in items not allocated to segments in the reconciliation below.

[3] Capital expenditures include changes in capital accruals and investments in affiliates. See reconciliation from segment totals to MPC consolidated total capital expenditures below.

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Segment Information - Reconciliation Of Segment Income From Operations To Income Before Income Taxes (Detail) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2019		Mar. 31, 2018
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Income (loss) from operations		$ 669		$ 440
Net interest and other financial costs		306		183
Income before income taxes		363		257
Operating Segments
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Income (loss) from operations		744		529
Corporate and Other
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Income (loss) from operations	[1]	(191)		(89)
Segment Reconciling Items
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Capline restructuring gain		207	[2]	0
Transaction-related costs(c)		$ (91)		$ 0

[1] Corporate and other unallocated items consists primarily of MPC’s corporate administrative expenses and costs related to certain non-operating assets, except for corporate overhead expenses attributable to MPLX and ANDX, which are included in the Midstream segment. Corporate overhead expenses are not allocated to the Refining & Marketing and Retail segments.

[2] See Note 13.

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Segment Information - Reconciliation Of Segment Capital Expenditures And Investments To Total Capital Expenditures (Detail) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2019	Mar. 31, 2018
Plus items not allocated to segments:
Capital expenditures	[1]	$ 1,006	$ 707
Operating Segments
Reconciliation Of Segment Capital Expenditures And Investments To Total Capital Expenditures [Line Items]
Capital expenditures and investments	[2]	1,290	712
Less investments in equity method investees		325	41
Corporate and Other
Plus items not allocated to segments:
Corporate		10	18
Capitalized interest		$ 31	$ 18

[1] Capital expenditures include changes in capital accruals. See Note 19 for a reconciliation of total capital expenditures to additions to property, plant and equipment as reported in the consolidated statements of cash flows.

[2] Capital expenditures include changes in capital accruals and investments in affiliates. See reconciliation from segment totals to MPC consolidated total capital expenditures below.

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Net Interest And Other Financial Costs (Detail) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2019	Mar. 31, 2018
Other Income and Expenses [Abstract]
Interest income		$ (9)	$ (20)
Interest expense		340	213
Interest capitalized		(32)	(18)
Non-Service Pension and Postretirement Expense	[1]	(3)
Pension and other postretirement non-service costs	[1]		0
Loss on extinguishment of debt		0	4
Other financial costs		10	4
Net interest and other financial costs		$ 306	$ 183

[1] See Note 21.

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Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Income Tax Disclosure [Abstract]
Combined federal, state and foreign income tax rate	29.00%	9.00%
Federal statutory income tax rate, percent	21.00%
Unrecognized benefits	$ 231

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Income Taxes - Out of Period Adjustment (Detail) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018	Oct. 01, 2018
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Provision for income taxes	$ 104	$ 22
Goodwill	20,229		$ 20,184
Andeavor
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Goodwill				$ 16,380
Andeavor | Adjustments
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Provision for income taxes	36
Deferred tax liabilities	68
Goodwill	$ 32			$ 66

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Inventories - Summary Of Inventories (Detail) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Inventory Disclosure [Abstract]
Crude oil and refinery feedstocks	$ 3,689	$ 3,655
Refined products	5,186	5,234
Materials and supplies	744	720
Merchandise	214	228
Total	$ 9,833	$ 9,837

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Inventories - Additional Information (Detail) $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($)
Inventory Disclosure [Abstract]
Impact on income as a result of LIFO liquidations	$ 0

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Equity Method Investments (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2019		Mar. 31, 2018
Contribution of net assets to Capline LLC		$ 143	[1]	$ 0
Recognition of Capline LLC equity method investment		$ 350	[1]	$ 0
Capline
Undivided joint interest, ownership percentage		33.00%
Equity method investments, ownership percentage		33.00%
Contribution of net assets to Capline LLC	[1]	$ 143
Recognition of Capline LLC equity method investment	[1]	350
Capline restructuring gain	[1]	$ 207

[1] See Note 13.

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Property, Plant And Equipment - Summary Of Property, Plant And Equipment (Detail) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 61,882	$ 61,213
Less accumulated depreciation	16,791	16,155
Property, plant and equipment, net	45,091	45,058
Operating Segments | Refining & Marketing
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	27,968	27,590
Operating Segments | Retail
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	6,681	6,637
Operating Segments | Midstream
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	25,929	25,692
Corporate and Other
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 1,304	$ 1,294

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Fair Value Measurements - Assets and Liabilities Accounted for at Fair Value on Recurring Basis (Detail) - USD ($) $ in Millions		Mar. 31, 2019		Dec. 31, 2018
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash collateral netted with derivative liabilities		$ 33		$ 13
Cash collateral netted with derivatives assets				52
Fair Value, Measurements, Recurring | Commodity derivatives
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Commodity derivative instruments, assets - netting and collateral		(128)	[1]	(323)
Commodity derivative instruments, assets - net carrying value on balance sheet	[2]	12		78
Commodity derivative instruments, assets - collateral pledged not offset		42		2
Commodity derivative instruments, liabilities - netting and collateral		(161)	[1]	(284)
Commodity derivative instruments, liabilities - net carrying value on balance sheet	[2]	5		8
Commodity derivative instruments, liabilities - collateral pledged not offset		0		0
Fair Value, Measurements, Recurring | Embedded derivatives in commodity contracts
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Commodity derivative instruments, liabilities - netting and collateral		0		0
Commodity derivative instruments, liabilities - net carrying value on balance sheet	[2]	65		61
Commodity derivative instruments, liabilities - collateral pledged not offset		0		0
Fair Value, Measurements, Recurring | Level 1 | Commodity derivatives
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Commodity derivative instruments, assets - gross		122		370
Commodity derivative instruments, liabilities - gross		142		255
Fair Value, Measurements, Recurring | Level 1 | Embedded derivatives in commodity contracts
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Commodity derivative instruments, liabilities - gross		0		0
Fair Value, Measurements, Recurring | Level 2 | Commodity derivatives
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Commodity derivative instruments, assets - gross		18		31
Commodity derivative instruments, liabilities - gross		24		37
Fair Value, Measurements, Recurring | Level 2 | Embedded derivatives in commodity contracts
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Commodity derivative instruments, liabilities - gross		0		0
Fair Value, Measurements, Recurring | Level 3 | Commodity derivatives
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Commodity derivative instruments, assets - gross		0		0
Commodity derivative instruments, liabilities - gross		0		0
Fair Value, Measurements, Recurring | Level 3 | Embedded derivatives in commodity contracts
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Commodity derivative instruments, liabilities - gross		$ 65		$ 61

[1] Represents the impact of netting assets, liabilities and cash collateral when a legal right of offset exists. As of March 31, 2019, cash collateral of $33 million was netted with the mark-to-market derivative liabilities. As of December 31, 2018, cash collateral of $52 million was netted with mark-to-market derivative assets and $13 million was netted with mark-to-market derivative liabilities.

[2] We have no derivative contracts that are subject to master netting arrangements reflected gross on the balance sheet.

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Fair Value Measurements - Recurring Narrative (Detail)	3 Months Ended
	Mar. 31, 2019 USD ($)
Embedded derivatives in commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Embedded derivative renewal term	5 years
Level 3 | Commodity derivatives | Minimum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Forward commodity price	$ 0.60
Level 3 | Commodity derivatives | Maximum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Forward commodity price	$ 1.25
Level 3 | Embedded derivatives in commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Probability of renewal first term	91.00%
Probability of renewal second term	82.00%

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Fair Value Measurements - Reconciliation of Net Beginning and Ending Balances Recorded for Net Assets and Liabilities Classified as Level 3 (Detail) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	$ 61	$ 66
Unrealized and realized losses included in net income	6	(3)
Settlements of derivative instruments	(2)	(3)
Ending balance	$ 65	$ 60

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Fair Value Measurements - Losses Included in Earnings Relating to Assets Still Held at End of Period (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Fair Value Disclosures [Abstract]
The amount of total losses for the period included in earnings attributable to the change in unrealized losses relating to assets still held at the end of period:	$ 5	$ (3)

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Fair Value Measurements - Fair Values - Reported (Detail) - USD ($) $ in Billions	Mar. 31, 2019	Dec. 31, 2018
Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 28.5	$ 26.5
Carrying Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 27.6	$ 27.0

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Derivatives - Classification of Gross Fair Values of Derivative Instruments, Excluding Cash Collateral (Detail) - Commodity derivatives - USD ($) $ in Millions		Mar. 31, 2019	Dec. 31, 2018
Other current assets
Derivatives, Fair Value [Line Items]
Asset		$ 139	$ 400
Liability		160	283
Other current liabilities(a)
Derivatives, Fair Value [Line Items]
Asset		1	1
Liability	[1]	14	16
Deferred credits and other liabilities
Derivatives, Fair Value [Line Items]
Asset		0	0
Liability	[1]	$ 57	$ 54

[1] Includes embedded derivatives.

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Derivatives - Open Commodity Derivative Contracts (Details) gal in Thousands, bbl in Thousands	3 Months Ended
	Mar. 31, 2019 bbl gal
Exchange Traded | Crude oil
Derivative [Line Items]
Percentage of derivative contracts expiring in the period	82.60%
Exchange Traded | Crude oil | Long
Derivative [Line Items]
Notional contracts (in thousands of Total Barrels)	49,844	[1]
Exchange Traded | Crude oil | Long | Spread Contracts
Derivative [Line Items]
Notional contracts (in thousands of Total Barrels)	11,999
Exchange Traded | Crude oil | Short
Derivative [Line Items]
Notional contracts (in thousands of Total Barrels) | gal	58,466	[1]
Exchange Traded | Crude oil | Short | Spread Contracts
Derivative [Line Items]
Notional contracts (in thousands of Total Barrels)	3,980
Exchange Traded | Refined products
Derivative [Line Items]
Percentage of derivative contracts expiring in the period	89.40%
Exchange Traded | Refined products | Long
Derivative [Line Items]
Notional contracts (in thousands of Total Barrels)	11,373	[1]
Exchange Traded | Refined products | Long | Spread Contracts
Derivative [Line Items]
Notional contracts (in thousands of Total Barrels)	300
Exchange Traded | Refined products | Short
Derivative [Line Items]
Notional contracts (in thousands of Total Barrels) | gal	9,945	[1]
Exchange Traded | Refined products | Short | Spread Contracts
Derivative [Line Items]
Notional contracts (in thousands of Total Barrels)	300
Exchange Traded | Blending products
Derivative [Line Items]
Percentage of derivative contracts expiring in the period	77.30%
Exchange Traded | Blending products | Long
Derivative [Line Items]
Notional contracts (in thousands of Total Barrels)	4,688	[1]
Exchange Traded | Blending products | Long | Spread Contracts
Derivative [Line Items]
Notional contracts (in thousands of Total Barrels)	2,603
Exchange Traded | Blending products | Short
Derivative [Line Items]
Notional contracts (in thousands of Total Barrels) | gal	4,866	[1]
Exchange Traded | Blending products | Short | Spread Contracts
Derivative [Line Items]
Notional contracts (in thousands of Total Barrels)	2,506
Over the Counter | Crude oil
Derivative [Line Items]
Percentage of derivative contracts expiring in the period	0.00%
Over the Counter | Crude oil | Long
Derivative [Line Items]
Notional contracts (in thousands of Total Barrels)	640
Over the Counter | Crude oil | Short
Derivative [Line Items]
Notional contracts (in thousands of Total Barrels)	0
Over the Counter | Blending products
Derivative [Line Items]
Percentage of derivative contracts expiring in the period	0.00%
Over the Counter | Blending products | Long
Derivative [Line Items]
Notional contracts (in thousands of Total Barrels)	1,676
Over the Counter | Blending products | Short
Derivative [Line Items]
Notional contracts (in thousands of Total Barrels) | gal	1,444

[1] Included in exchange-traded are spread contracts in thousands of barrels: Crude oil - 11,999 long and 3,980 short; Refined products - 300 long and 300 short; Blending products - 2,603 long and 2,506 short

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Derivatives - Effect of Commodity Derivative Instruments in Statements of Income (Detail) - Commodity derivatives - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Derivative Instruments, Gain (Loss) [Line Items]
Loss	$ (100)	$ (28)
Sales and other operating revenues
Derivative Instruments, Gain (Loss) [Line Items]
Loss	(20)	(1)
Cost of revenues
Derivative Instruments, Gain (Loss) [Line Items]
Loss	$ (80)	$ (27)

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Debt - Outstanding Borrowings (Detail) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Total debt	$ 28,571	$ 27,980
Unamortized debt issuance costs	(126)	(128)
Unamortized discount	(330)	(328)
Amounts due within one year	(550)	(544)
Total long-term debt due after one year	27,565	26,980
Marathon Petroleum Corporation
Total debt	9,120	9,114
MPLX LP
Total debt	14,283	13,856
ANDX LP
Total debt	$ 5,168	$ 5,010

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Debt - Available Capacity under our Facilities (Details) $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($)
Debt Instrument [Line Items]
Total Capacity	$ 11,100
Outstanding Borrowings	1,829
Outstanding Letters of Credit	35
Available Capacity	9,236
MPC 364-day bank revolving credit facility
Debt Instrument [Line Items]
Total Capacity	1,000
Outstanding Borrowings	0
Outstanding Letters of Credit	0
Available Capacity	$ 1,000
Weighted Average Interest Rate	0.00%
Expiration	Sep. 30, 2019
MPC bank revolving credit facility
Debt Instrument [Line Items]
Total Capacity	$ 5,000
Outstanding Borrowings	0
Outstanding Letters of Credit	32
Available Capacity	$ 4,968
Weighted Average Interest Rate	0.00%
Expiration	Oct. 01, 2023
MPLX bank revolving credit facility
Debt Instrument [Line Items]
Total Capacity	$ 2,250
Outstanding Borrowings	425
Outstanding Letters of Credit	3
Available Capacity	$ 1,822
Weighted Average Interest Rate	3.92%
Expiration	Jul. 21, 2022
ANDX revolving & dropdown credit facilities(a)
Debt Instrument [Line Items]
Total Capacity	$ 2,100
Outstanding Borrowings	1,404	[1]
Outstanding Letters of Credit	0
Available Capacity	$ 696
Weighted Average Interest Rate	4.32%
Expiration	Jan. 29, 2021
Trade receivables securitization facility
Debt Instrument [Line Items]
Total Capacity	$ 750
Outstanding Borrowings	0
Outstanding Letters of Credit	0
Available Capacity	$ 750
Weighted Average Interest Rate	0.00%
Expiration	Jul. 19, 2019

[1] Western Refining Southwest, Inc., a wholly-owned subsidiary of MPC and unitholder of ANDX, has guaranteed certain outstanding borrowings under the ANDX dropdown credit facility that were made in connection with the August 2018 dropdown transaction.

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Revenue - Disaggregated by Product Line (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Sales and other operating revenues	$ 28,081	$ 18,694
Refined products
Sales and other operating revenues	24,653	16,158
Merchandise
Sales and other operating revenues	1,464	1,130
Crude oil and refinery feedstocks
Sales and other operating revenues	1,367	883
Midstream services, transportation and other
Sales and other operating revenues	$ 597	$ 523

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Revenue (Details) $ in Millions	Mar. 31, 2019 USD ($)
Revenue from Contract with Customer [Abstract]
Matching buy/sell receivables	$ 1,980
Income taxes receivable	$ 76

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Supplemental Cash Flow Information - Summary of Supplemental Cash Flow Information (Detail) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019		Mar. 31, 2018
Net cash provided by operating activities included:
Interest paid (net of amounts capitalized)	$ 269		$ 212
Net income taxes paid to taxing authorities	42		6
Payments on operating leases	189		0
Interest payments under finance lease obligations	8		0
Net cash provided by financing activities included:
Principal payments under finance lease obligations	10		0
Non-cash investing and financing activities:
Right of use assets obtained in exchange for new operating lease obligations	31		0
Right of use assets obtained in exchange for new finance lease obligations	15		0
Contribution of net assets to Capline LLC	143	[1]	0
Recognition of Capline LLC equity method investment	$ 350	[1]	$ 0

[1] See Note 13.

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Supplemental Cash Flow Information - Cash, Cash Equalivalents and Restricted Cash (Details) - USD ($) $ in Millions		Mar. 31, 2019	Dec. 31, 2018	Mar. 31, 2018	Dec. 31, 2017
Supplemental Cash Flow Elements [Abstract]
Cash and cash equivalents		$ 877	$ 1,687
Restricted cash	[1]	31	38
Cash, cash equivalents and restricted cash		$ 908	$ 1,725	$ 4,657	$ 3,015

[1] The restricted cash balance is included within other current assets on the consolidated balance sheets

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Supplemental Cash Flow Information - Reconciliation of Additions to Property, Plant and Equipment to Total Capital Expenditures (Detail) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2019	Mar. 31, 2018
Supplemental Cash Flow Elements [Abstract]
Additions to property, plant and equipment per the consolidated statements of cash flows		$ 1,241	$ 755
Asset retirement expenditures		0	1
Decrease in capital accruals		(235)	(49)
Capital expenditures	[1]	$ 1,006	$ 707

[1] Capital expenditures include changes in capital accruals. See Note 19 for a reconciliation of total capital expenditures to additions to property, plant and equipment as reported in the consolidated statements of cash flows.

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Accumulated Other Comprehensive Loss - Changes in Accumulated Other Comprehensive Loss by Component (Detail) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2019	Mar. 31, 2018
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		$ (144)	$ (231)
Other comprehensive loss before reclassifications		(1)	(2)
Amounts reclassified from accumulated other comprehensive loss:
Amortization - prior service credit		(11)	(9)
Amortization - actuarial loss		4	9
Amortization - settlement loss		0	1
Other		(1)	0
Tax effect		2	(1)
Other comprehensive loss		(7)	(2)
Ending balance		(151)	(233)
Accumulated Defined Benefit Plans Adjustment | Pension Benefits
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		(132)	(190)
Other comprehensive loss before reclassifications		(1)	0
Amounts reclassified from accumulated other comprehensive loss:
Amortization - prior service credit	[1]	(11)	(8)
Amortization - actuarial loss	[1]	4	9
Amortization - settlement loss	[1]	0	1
Tax effect		2	(1)
Other comprehensive loss		(6)	1
Ending balance		(138)	(189)
Accumulated Defined Benefit Plans Adjustment | Other Benefits
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		(23)	(48)
Other comprehensive loss before reclassifications		0	0
Amounts reclassified from accumulated other comprehensive loss:
Amortization - prior service credit	[1]	0	(1)
Amortization - actuarial loss	[1]	0	0
Amortization - settlement loss		0	0
Tax effect		0	0
Other comprehensive loss		0	(1)
Ending balance		(23)	(49)
Gain on Cash Flow Hedge
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		2	4
Other comprehensive loss before reclassifications		0	(2)
Amounts reclassified from accumulated other comprehensive loss:
Tax effect		0	0
Other comprehensive loss		0	(2)
Ending balance		2	2
Workers Compensation
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		9	3
Other comprehensive loss before reclassifications		0	0
Amounts reclassified from accumulated other comprehensive loss:
Other		(1)	0
Tax effect		0	0
Other comprehensive loss		(1)	0
Ending balance		$ 8	$ 3

[1] These accumulated other comprehensive loss components are included in the computation of net periodic benefit cost. See Note 21.

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Defined Benefit Pension and Other Postretirement Plans - Components of Net Periodic Benefit Costs (Detail) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Pension Benefits
Components of net periodic benefit cost:
Service cost	$ 58	$ 36
Interest cost	28	18
Expected return on plan assets	(32)	(26)
Amortization – prior service credit	(11)	(8)
Amortization – actuarial loss	4	9
Amortization - settlement loss	0	1
Net periodic benefit cost	47	30
Other Benefits
Components of net periodic benefit cost:
Service cost	8	7
Interest cost	9	7
Expected return on plan assets	0	0
Amortization – prior service credit	0	(1)
Amortization – actuarial loss	0	0
Amortization - settlement loss	0	0
Net periodic benefit cost	$ 17	$ 13

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Defined Benefit Pension and Other Postretirement Plans - Additional Information (Detail) $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($)
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Employer contributions	$ 0
Other Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Benefits paid	3
Other Benefits
Defined Benefit Plan Disclosure [Line Items]
Benefits paid	$ 11

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Stock-Based Compensation Plans - Summary of Stock Option Award Activity (Detail) - Stock Options	3 Months Ended
	Mar. 31, 2019 $ / shares shares
Number of Shares
Outstanding, beginning balance | shares	8,724,595
Granted | shares	1,037,671
Exercised | shares	(229,169)
Forfeited or expired | shares	0
Outstanding, ending balance | shares	9,533,097
Weighted Average Exercise Price
Outstanding, beginning balance (in USD per share) | $ / shares	$ 37.07
Granted (in USD per share) | $ / shares	62.68
Exercised (in USD per share) | $ / shares	10.62
Forfeited or expired (in USD per share) | $ / shares	0.00
Outstanding, ending balance (in USD per share) | $ / shares	$ 40.49

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Stock-Based Compensation Plans - Narrative (Detail)	3 Months Ended
	Mar. 31, 2019 $ / shares
Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant date fair value (in USD per share)	$ 14.34
Performance Unit Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted (in USD per share)	$ 0.72

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Stock-Based Compensation Plans - Summary of Restricted Stock Award Activity (Detail)	3 Months Ended
	Mar. 31, 2019 $ / shares shares
Restricted Stock
Number of Shares
Outstanding, beginning balance | shares	990,700
Granted | shares	158,120
RS Vested/RSUs Issued | shares	(114,136)
Forfeited | shares	(12,622)
Outstanding, ending balance | shares	1,022,062
Weighted Average Grant Date Fair Value
Outstanding, beginning balance (in USD per share) | $ / shares	$ 57.23
Granted (in USD per share) | $ / shares	62.66
RS's Vested/RSU's Issued (in USD per share) | $ / shares	49.58
Forfeited (in USD per share) | $ / shares	56.84
Outstanding, ending balance (in USD per share) | $ / shares	$ 58.93
Restricted Stock Units
Number of Shares
Outstanding, beginning balance | shares	4,226,856
Granted | shares	8,050
RS Vested/RSUs Issued | shares	(1,110,705)
Forfeited | shares	(46,923)
Outstanding, ending balance | shares	3,077,278
Weighted Average Grant Date Fair Value
Outstanding, beginning balance (in USD per share) | $ / shares	$ 80.96
Granted (in USD per share) | $ / shares	59.56
RS's Vested/RSU's Issued (in USD per share) | $ / shares	82.43
Forfeited (in USD per share) | $ / shares	82.43
Outstanding, ending balance (in USD per share) | $ / shares	$ 80.35

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Stock-Based Compensation Plans - Summary of Performance Unit Awards (Detail) - Performance Unit Awards	3 Months Ended
	Mar. 31, 2019 $ / shares shares
Number of Units
Outstanding, beginning balance | shares	8,618,583
Granted | shares	6,200,000
Vested | shares	(2,280,333)
Forfeited | shares	(120,000)
Outstanding, ending balance | shares	12,418,250
Weighted Average Grant Date Fair Value
Outstanding, beginning balance (in USD per share) | $ / shares	$ 0.79
Granted (in USD per share) | $ / shares	0.72
Vested (in USD per share) | $ / shares	0.57
Forfeited (in USD per share) | $ / shares	0.84
Outstanding, ending balance (in USD per share) | $ / shares	$ 0.79

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Lessee Narrative (Details)	3 Months Ended
	Mar. 31, 2019
Minimum
Term of agreements	1 year
Renewal term options	1 year
Maximum
Term of agreements	60 years
Renewal term options	49 years

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Components of Lease Cost (Details) $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($)
Finance lease cost:
Amortization of right of use assets	$ 14
Interest on lease liabilities	10
Operating lease cost	190
Variable lease cost	15
Short-term lease cost	152
Total lease cost	$ 381

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Leases Supplemental Balance Sheet Disclosure (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Operating leases
Right of use assets	$ 2,680	$ 0
Operating lease liabilities	613	0
Long-term operating lease liabilities	2,153	0
Total operating lease liabilities	$ 2,766
Weighted average remaining lease term	6 years 6 months 11 days
Weighted average discount rate	4.13%
Finance leases
Property, plant and equipment, gross	$ 61,882	61,213
Less accumulated depreciation	16,791	16,155
Property, plant and equipment, net	45,091	45,058
Debt due within one year	550	544
Long-term debt	27,565	26,980
Total finance lease liabilities	$ 657	$ 649
Weighted average remaining lease term	13 years 1 month 25 days
Weighted average discount rate	6.02%
Finance Lease
Finance leases
Property, plant and equipment, gross	$ 760
Less accumulated depreciation	206
Property, plant and equipment, net	554
Debt due within one year	45
Long-term debt	612
Total finance lease liabilities	$ 657

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Schedule of Minimum Lease Payments (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Operating leases
2019	$ 554	$ 709
2020	629	619
2021	545	553
2022	370	389
2023	262	295
2024 and thereafter	832	858
Gross lease payments	3,192	3,423
Less: imputed interest	426
Total operating lease liabilities	2,766
Finance Lease Liabilities, Payments, Due [Abstract]
2019	57	70
2020	76	71
2021	69	66
2022	76	75
2023	83	82
2024 and thereafter	596	586
Gross lease payments	957	950
Less: imputed interest	300	301
Total finance lease liabilities	$ 657	$ 649

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Lessor Narrative (Details) $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($)
Leases [Abstract]
Lease revenue	$ 60

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Schedule of Future Future Rental Payments Receivable for Operating Leases (Details) $ in Millions	Mar. 31, 2019 USD ($)
Leases [Abstract]
2019	$ 144
2020	168
2021	162
2022	160
2023	154
2024 and thereafter	1,205
Total minimum future rentals	$ 1,993

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Schedule of Property Subject to or Available for Operating Lease (Details) $ in Millions	Mar. 31, 2019 USD ($)
Property, plant and equipment	$ 1,831
Less accumulated depreciation	261
Property, plant and equipment, net	1,570
Natural gas gathering and NGL transportation pipelines and facilities
Property, plant and equipment	1,036
Natural gas processing facilities
Property, plant and equipment	642
Terminal and related assets
Property, plant and equipment	112
Land, building, office equipment and other
Property, plant and equipment	$ 41

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Commitments and Contingencies (Detail)	3 Months Ended
	Mar. 31, 2019
Pending Litigation
Loss Contingencies [Line Items]
Loss contingency, inestimable loss	<div style="font-family:Times New Roman;font-size:10pt;"><div style="line-height:120%;padding-top:6px;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">For matters for which we have not recorded a liability, we are unable to estimate a range of possible loss because the issues involved have not been fully developed through pleadings, discovery or court proceedings.</font></div></div>

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Commitments and Contingencies - Environmental Matters (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Commitments and Contingencies Disclosure [Abstract]
Accrued liabilities for remediation	$ 451	$ 455
Receivables for recoverable costs	$ 33	$ 35

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Commitments and Contingencies - Other Lawsuits (Details) - Pending Litigation - Emergency Pricing And Consumer Protection Laws $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($)
Loss Contingencies [Line Items]
Plaintiff	Commonwealth of Kentucky
Damages sought	$ 89
Loss contingency, period of occurrence	during September and October 2005

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Commitments and Contingencies - Guarantees (Details) $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($)
Other Guarantees
Loss Contingencies [Line Items]
Maximum potential undiscounted payments	$ 123
LOOP and LOCAP LLC | Guarantee of Indebtedness of Others | Financial Guarantee
Loss Contingencies [Line Items]
Expiration	Dec. 31, 2037
Maximum potential undiscounted payments	$ 171
Bakken Pipeline System | Other Guarantees
Loss Contingencies [Line Items]
Maximum potential undiscounted payments	$ 230
Crowley Ocean Partners
Loss Contingencies [Line Items]
Equity method investments, ownership percentage	50.00%
Crowley Ocean Partners | Guarantee of Indebtedness of Others | Financial Guarantee
Loss Contingencies [Line Items]
Maximum potential undiscounted payments	$ 135
Crowley Ocean Partners | Guarantee of Indebtedness of Others | Financial Guarantee | Crowley Term Loan
Loss Contingencies [Line Items]
Maximum borrowing capacity	$ 325
Crowley Blue Water Partners
Loss Contingencies [Line Items]
Equity method investments, ownership percentage	50.00%
Crowley Blue Water Partners | Guarantee of Indebtedness of Others | Financial Guarantee
Loss Contingencies [Line Items]
Maximum potential undiscounted payments	$ 125
Indirect Ownership Interest | Bakken Pipeline System
Loss Contingencies [Line Items]
Equity method investments, ownership percentage	9.00%
Marathon Oil Companies | Indemnification Agreement
Loss Contingencies [Line Items]
Guarantee obligation current carrying value	$ 1

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Commitments and Contingencies - Contractual Commitments and Contingencies (Details) $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($)
Commitments and Contingencies Disclosure [Abstract]
Contractual commitments to acquire property, plant and equipment and advance funds to equity method investees	$ 1,060

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Subsequent Event Subsequent Event (Details) - Subsequent Event [Member]	May 08, 2019 shares
Public
Subsequent Event [Line Items]
Common Units Conversion Ratio	1.135
Nonpublic
Subsequent Event [Line Items]
Common Units Conversion Ratio	1.0328