Edgar Filing: Marathon Petroleum Corp

Document

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, 2018



¨	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 and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted 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 and post such files.) Yes x No ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, 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	¨ (Do not check if a smaller reporting company)	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

There were 461,878,776 shares of Marathon Petroleum Corporation common stock outstanding as of April 26, 2018.

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MARATHON PETROLEUM CORPORATION

Form 10-Q

Quarter Ended March 31, 2018

INDEX



	Page
PART I – FINANCIAL INFORMATION
Item 1. Financial Statements:
Consolidated Statements of Income (Unaudited)	3
Consolidated Statements of Comprehensive Income (Unaudited)	4
Consolidated Balance Sheets (Unaudited)	5
Consolidated Statements of Cash Flows (Unaudited)	6
Consolidated Statements of Equity and Redeemable Noncontrolling Interest (Unaudited)	7
Notes to Consolidated Financial Statements (Unaudited)	8
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	32
Item 3. Quantitative and Qualitative Disclosures about Market Risk	53
Item 4. Controls and Procedures	54
Supplementary Statistics (Unaudited)	55

PART II – OTHER INFORMATION
Item 1. Legal Proceedings	58
Item 1A. Risk Factors	58
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	58
Item 5. Other Information	58
Item 6. Exhibits	59
Signatures	60

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.

GLOSSARY OF TERMS

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



ASC	Accounting Standards Codification
ASU	Accounting Standards Update
ATB	Articulated tug barges
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
EBITDA	Earnings Before Interest, Tax, Depreciation and Amortization, a non-GAAP financial measure
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
OTC	Over-the-Counter
ppm	Parts per million
RIN	Renewable Identification Number
SEC	United States Securities and Exchange Commission
TCJA	Tax Cuts and Jobs Act
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

Part I – Financial Information

Item 1. Financial Statements

Marathon Petroleum Corporation

Consolidated Statements of Income (Unaudited)



	Three Months Ended March 31,
(In millions, except per share data)	2018		2017
Revenues and other income:
Sales and other operating revenues^(a)	$	18,694	$	16,134
Sales to related parties	172		154
Income from equity method investments	86		57
Net gain on disposal of assets	2		5
Other income	30		43
Total revenues and other income	18,984		16,393
Costs and expenses:
Cost of revenues (excludes items below)^(a)	17,370		14,946
Purchases from related parties	141		122
Depreciation and amortization	528		536
Selling, general and administrative expenses	402		390
Other taxes	103		108
Total costs and expenses	18,544		16,102
Income from operations	440		291
Net interest and other financial costs	183		149
Income before income taxes	257		142
Provision for income taxes	22		41
Net income	235		101
Less net income attributable to:
Redeemable noncontrolling interest	16		16
Noncontrolling interests	182		55
Net income attributable to MPC	$	37	$	30
Per Share Data (See Note 8)
Basic:
Net income attributable to MPC per share	$	0.08	$	0.06
Weighted average shares outstanding	476		525
Diluted:
Net income attributable to MPC per share	$	0.08	$	0.06
Weighted average shares outstanding	480		530
Dividends paid	$	0.46	$	0.36


^(a)	The 2018 period reflects an election to present certain taxes on a net basis. See Notes 2 and 3 for further information.

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

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Marathon Petroleum Corporation

Consolidated Statements of Comprehensive Income (Unaudited)



	Three Months Ended March 31,
(In millions)	2018			2017
Net income	$	235		$	101
Other comprehensive income (loss):
Defined benefit postretirement and post-employment plans:
Actuarial changes, net of tax of $3 and $3	7			4
Prior service costs, net of tax of ($2) and ($4)	(7		)	(7		)
Other, net of tax of ($1) and $0	(2		)	—
Other comprehensive loss	(2		)	(3		)
Comprehensive income	233			98
Less comprehensive income attributable to:
Redeemable noncontrolling interest	16			16
Noncontrolling interests	182			55
Comprehensive income attributable to MPC	$	35		$	27

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

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Marathon Petroleum Corporation

Consolidated Balance Sheets (Unaudited)



(In millions, except share data)	March 31, 2018			December 31, 2017
Assets
Current assets:
Cash and cash equivalents (MPLX: $2 and $5, respectively)	$	4,653		$	3,011
Receivables, less allowance for doubtful accounts of $10 and $11 (MPLX: $322 and $299, respectively)	4,613			4,695
Inventories (MPLX: $64 and $65, respectively)	5,111			5,550
Other current assets (MPLX: $26 and $29, respectively)	148			145
Total current assets	14,525			13,401
Equity method investments (MPLX: $4,033 and $4,010, respectively)	4,817			4,787
Property, plant and equipment, net (MPLX: $13,291 and $12,187, respectively)	26,618			26,443
Goodwill (MPLX: $2,460 and $2,245, respectively)	3,586			3,586
Other noncurrent assets (MPLX: $472 and $479, respectively)	818			830
Total assets	$	50,364		$	49,047
Liabilities
Current liabilities:
Accounts payable (MPLX: $543 and $621, respectively)	$	7,066		$	8,297
Payroll and benefits payable (MPLX: $2 and $1, respectively)	337			591
Accrued taxes (MPLX: $34 and $38, respectively)	639			670
Debt due within one year (MPLX: $1 and $1, respectively)	26			624
Other current liabilities (MPLX: $138 and $130, respectively)	304			296
Total current liabilities	8,372			10,478
Long-term debt (MPLX: $11,861 and $6,945, respectively)	17,232			12,322
Deferred income taxes (MPLX: $10 and $5, respectively)	3,120			2,654
Defined benefit postretirement plan obligations	1,126			1,099
Deferred credits and other liabilities (MPLX: $232 and $230, respectively)	651			666
Total liabilities	30,501			27,219
Commitments and contingencies (see Note 22)
Redeemable noncontrolling interest	1,000			1,000
Equity
MPC stockholders’ equity:
Preferred stock, no shares issued and outstanding (par value 0.01 per share, 30 million shares authorized)	—			—
Common stock:
Issued – 734 million and 734 million shares (par value 0.01 per share, 1 billion shares authorized)	7			7
Held in treasury, at cost – 267 million and 248 million shares	(11,200		)	(9,869		)
Additional paid-in capital	13,669			11,262
Retained earnings	12,745			12,864
Accumulated other comprehensive loss	(233		)	(231		)
Total MPC stockholders’ equity	14,988			14,033
Noncontrolling interests	3,875			6,795
Total equity	18,863			20,828
Total liabilities, redeemable noncontrolling interest and equity	$	50,364		$	49,047

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

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Marathon Petroleum Corporation

Consolidated Statements of Cash Flows (Unaudited)



	Three Months Ended March 31,
(In millions)	2018			2017
Operating activities:
Net income	$	235		$	101
Adjustments to reconcile net income to net cash provided by operating activities:
Amortization of deferred financing costs and debt discount	18			15
Depreciation and amortization	528			536
Pension and other postretirement benefits, net	32			27
Deferred income taxes	(19		)	(5		)
Net gain on disposal of assets	(2		)	(5		)
Income from equity method investments	(86		)	(57		)
Distributions from equity method investments	89			56
Changes in the fair value of derivative instruments	(14		)	28
Changes in:
Current receivables	96			333
Inventories	440			264
Current accounts payable and accrued liabilities	(1,455		)	(215		)
All other, net	1			30
Net cash provided by (used in) operating activities	(137		)	1,108
Investing activities:
Additions to property, plant and equipment	(755		)	(610		)
Acquisitions, net of cash acquired	—			(220		)
Disposal of assets	7			2
Investments – acquisitions, loans and contributions	(41		)	(566		)
– redemptions, repayments and return of capital	—			20
All other, net	11			21
Net cash used in investing activities	(778		)	(1,353		)
Financing activities:
Commercial paper – issued	—			300
– repayments	—			(300		)
Long-term debt – borrowings	9,610			2,241
– repayments	(5,264		)	(207		)
Debt issuance costs	(53		)	(21		)
Issuance of common stock	12			10
Common stock repurchased	(1,327		)	(420		)
Dividends paid	(219		)	(190		)
Issuance of MPLX LP common units	—			148
Distributions to noncontrolling interests	(195		)	(158		)
Contributions from noncontrolling interests	1			126
All other, net	(8		)	(6		)
Net cash provided by financing activities	2,557			1,523
Net increase in cash, cash equivalents and restricted cash	1,642			1,278
Cash, cash equivalents and restricted cash at beginning of period	3,015			892
Cash, cash equivalents and restricted cash at end of period	$	4,657		$	2,170

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

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Marathon Petroleum Corporation

Consolidated Statements of Equity and Redeemable Noncontrolling Interest (Unaudited)



	MPC Stockholders’ Equity
(In millions)	Common Stock		Treasury Stock			Additional Paid-in Capital		Retained Earnings			Accumulated Other Comprehensive Loss			Non-controlling Interests			Total Equity			Redeemable Non-controlling Interest
Balance as of December 31, 2016	$	7	$	(7,482	)	$	11,060	$	10,206		$	(234	)	$	6,646		$	20,203		$	1,000
Net income	—		—			—		30			—			55			85			16
Dividends declared	—		—			—		(190		)	—			—			(190		)	—
Distributions to noncontrolling interests	—		—			—		—			—			(142		)	(142		)	(16		)
Contributions from noncontrolling interests	—		—			—		—			—			126			126			—
Other comprehensive loss	—		—			—		—			(3		)	—			(3		)	—
Shares repurchased	—		(420		)	—		—			—			—			(420		)	—
Stock-based compensation	—		(3		)	27		—			—			—			24			—
Impact from equity transactions of MPLX LP	—		—			72		—			—			42			114			—
Balance as of March 31, 2017	$	7	$	(7,905	)	$	11,159	$	10,046		$	(237	)	$	6,727		$	19,797		$	1,000
Balance as of December 31, 2017	$	7	$	(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	—		—			—		(219		)	—			—			(219		)	—
Distributions to noncontrolling interests	—		—			—		—			—			(179		)	(179		)	(16		)
Contributions from noncontrolling interests	—		—			—		—			—			1			1			—
Other comprehensive loss	—		—			—		—			(2		)	—			(2		)	—
Shares repurchased	—		(1,327		)	—		—			—			—			(1,327		)	—
Stock-based compensation	—		(4		)	27		—			—			1			24			—
Impact from equity transactions of MPLX LP	—		—			2,380		—			—			(2,926		)	(546		)	—
Balance as of March 31, 2018	$	7	$	(11,200	)	$	13,669	$	12,745		$	(233	)	$	3,875		$	18,863		$	1,000

(Shares in millions)	Common Stock		Treasury Stock
Balance as of December 31, 2016	731		(203		)
Shares repurchased	—		(9		)
Balance as of March 31, 2017	731		(212		)
Balance as of December 31, 2017	734		(248		)
Shares repurchased	—		(19		)
Balance as of March 31, 2018	734		(267		)

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

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Notes to Consolidated Financial Statements (Unaudited)

1. Description of the Business and Basis of Presentation

Description of the Business—Our business consists of refining and marketing, retail and midstream services conducted primarily in the Midwest, Gulf Coast, East Coast, Northeast and Southeast regions of the United States, through subsidiaries, including Marathon Petroleum Company LP (“MPC LP”), Speedway LLC and its subsidiaries (“Speedway”) and MPLX LP and its subsidiaries (“MPLX”).

See Note 10 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, 2017. The results of operations for the three months ended March 31, 2018 are not necessarily indicative of the results to be expected for the full year.

Certain prior period financial statement amounts have been reclassified to conform to current period presentation.

2. Summary of Principal Accounting Policies

Revenue Recognition - As described in Note 3, we adopted ASU 2014-09, Revenue from Contracts with Customers (ASC 606) effective January 1, 2018. We recognize revenue based on consideration specified in contracts or agreements with customers when we satisfy our performance obligations by transferring control over products or services to a customer. Concurrent with our adoption of ASC 606, we made an accounting policy election that all taxes assessed by a governmental authority that are both imposed on and concurrent with a revenue-producing transaction and collected from our customers will be recognized on a net basis within “Sales and other operating revenues”.

The adoption of ASC 606 did not materially change our revenue recognition patterns, which are described below by reportable segment:

•

Refining & Marketing - The vast majority of our Refining & Marketing contracts contain pricing that is based on the market price for the product at the time of delivery. Our obligations to deliver product volumes are typically satisfied and revenue is recognized when control of the product transfers to our customers. Concurrent with the transfer of control, we typically receive the right to payment for the delivered product, the customer accepts the product and the customer has significant risks and rewards of ownership of the product. Payment terms require customers to pay shortly after delivery and do not contain significant financing components.

•

Speedway - Revenue is recognized when our customers receive control of the transportation fuels or merchandise. Payments from customers are received at the time sales occur in cash or by credit or debit card. Speedway offers a loyalty rewards program to its customers. We defer a minor portion of revenue on sales to the loyalty program participants until the participants redeem their rewards. The related contract liability, as defined in the standard, is not material to our financial statements.

•

Midstream - Midstream revenue transactions typically are defined by contracts under which we sell a product or provide a service. Revenues from sales of product are recognized when control of the product transfers to the customer. Revenues from sales of services are recognized over time when the performance obligation is satisfied as services are provided in a series. We have elected to use the output measure of progress to recognize revenue based on the units delivered, processed or transported. The transaction price in our Midstream contracts often has both fixed components, related to minimum volume commitments, and variable components which are primarily dependent on volumes. Variable consideration will generally not be estimated at contract inception as the transaction price is specifically allocable to the services provided each period end.

Refer to Note 10 for disclosure of our revenue disaggregated by segment and product line, as well as a description of our reportable segment operations.

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3. Accounting Standards

Recently Adopted

ASU 2014-09, Revenue - Revenue from Contracts with Customers (ASC 606). On January 1, 2018, we adopted the new revenue standard, applying the modified retrospective method, whereby a cumulative effect is recorded to opening retained earnings and ASC 606 is applied prospectively. We recorded a net increase of $1 million to our retained earnings balance as of January 1, 2018 due to the cumulative effect of applying the new revenue standard.

Impact of Adoption

The adoption of ASC 606 did not materially change our revenue recognition patterns. The most significant impacts of adopting ASC 606 for the period ended March 31, 2018 are as follows:

•

a reduction of “Sales and other operating revenues” of $1.25 billion for the three months ended March 31, 2018 due to our accounting policy election to present taxes incurred concurrently with revenue producing transactions and collected on behalf of our customers on a net basis. For the three months ended March 31, 2017, taxes are reflected on a gross basis in “Sales and other operating revenues” and “Cost of revenues”, and include $1.20 billion of taxes that are now subject to our net basis accounting policy election.

•

an increase to both “Sales and other operating revenues” and “Cost of revenues” of $117 million for the three months ended March 31, 2018 related to certain Midstream contract provisions for third party reimbursements, noncash consideration and imbalances that require gross presentation under ASC 606. Comparative information continues to be reported under the accounting standards in effect for those periods.

Practical Expedients

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, 2018, 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, 2018 include matching buy/sell receivables of $1.33 billion and income taxes receivables of $323 million.

ASU 2016-16, Income Taxes - Intra-Entity Transfers of Assets Other Than Inventory. We adopted this accounting standards update in the first quarter of 2018 and recorded a $61 million cumulative-effect adjustment as an increase to retained earnings as of January 1, 2018 with the offset recorded as a reduction to “Deferred Income Taxes”.

We also adopted the following standards during the first quarter of 2018, none of which had a material impact to our financial statements or financial statement disclosures:



ASU		Effective Date
2017-09	Stock Compensation - Scope of Modification Accounting	January 1, 2018
2017-07	Retirement Benefits - Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Cost	January 1, 2018
2017-05	Gains and Losses from the Derecognition of Nonfinancial Assets - Clarifying the Scope of Asset Derecognition Guidance	January 1, 2018
2017-01	Business Combinations - Clarifying the Definition of a Business	January 1, 2018
2016-18	Statement of Cash Flows - Restricted Cash	January 1, 2018
2016-15	Statement of Cash Flows - Classification of Certain Cash Receipts and Cash Payments	January 1, 2018
2016-01	Financial Instruments - Recognition and Measurement of Financial Assets and Liabilities	January 1, 2018

Not Yet Adopted

ASU 2018-02, Reporting Comprehensive Income - Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income. In February 2018, the FASB issued an accounting standards update allowing an entity the choice to reclassify to retained earnings the tax effects related to the Tax Cuts and Jobs Act that are stranded in accumulated other comprehensive income. We do not expect adoption of this standard to have a material impact on our financial statements. The amendment is effective beginning in 2019 with early adoption permitted.

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ASU 2017-12, Derivatives and Hedging - Targeted Improvements to Accounting for Hedging Activities. In August 2017, the FASB issued an accounting standards update to amend the hedge accounting rules to simplify the application of hedge accounting guidance and better portray the economic results of risk management activities in the financial statements. The guidance expands the ability to hedge nonfinancial and financial risk components, reduces complexity in fair value hedges of interest rate risk, eliminates the requirement to separately measure and report hedge ineffectiveness, as well as eases certain hedge effectiveness assessment requirements. The guidance is effective beginning in 2019 with early adoption permitted. We are currently evaluating the impact of this guidance, including transition elections and required disclosures, on our financial statements and the timing of adoption. However, since we have not historically designated our commodity derivatives as hedges, we do not expect the adoption of this accounting standards update to have a material impact on our consolidated financial statements.

ASU 2017-04, Intangibles - Goodwill and Other - Simplifying the Test for Goodwill Impairment. In January 2017, the FASB issued an accounting standards update 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 accounting standards update 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 accounting standards update to have a material impact on our consolidated financial statements.

ASU 2016-02, Leases. In February 2016, the FASB issued an accounting standards update requiring lessees to record virtually all leases on their balance sheets. The accounting standards update also requires expanded disclosures to help financial statement users better understand the amount, timing and uncertainty of cash flows arising from leases. For lessors, this amended guidance modifies the classification criteria and the accounting for sales-type and direct financing leases. The change will be effective on a modified retrospective basis for fiscal years beginning after December 15, 2018, and interim periods within those years, with early adoption permitted. We continue to evaluate the impact of this standard on our financial statements and disclosures, internal controls and accounting policies. This evaluation process includes reviewing all forms of leases, performing a completeness assessment over the lease population and analyzing the practical expedients in order to determine the best path of implementing changes to existing processes and controls. We are implementing a third-party supported lease accounting information system to account for our lease population in accordance with this new standard and establishing internal controls over the new system. We believe the adoption of the standard will have a material impact on our consolidated financial statements as virtually all leases will be recognized as a right of use asset and lease obligation.

4. MPLX LP

MPLX is a diversified, growth-oriented publicly traded master limited partnership formed by us to own, operate, develop and acquire midstream energy infrastructure assets. MPLX is engaged in the gathering, processing and transportation of natural gas; the gathering, transportation, fractionation, storage and marketing of NGLs; and the transportation, storage, distribution and marketing of crude oil and refined petroleum products.

As of March 31, 2018, we owned 63.6 percent of the outstanding MPLX common units and control MPLX through our ownership of the general partner interest in MPLX. MPLX is a VIE because the limited partners of MPLX do not have substantive kick-out or substantive participating rights over the general partner. We are the primary beneficiary of MPLX because in addition to our significant economic interest, we also have the power, through our 100 percent ownership of the general partner, to control the decisions that most significantly impact MPLX. We therefore consolidate MPLX and record a noncontrolling interest for the 36.4 percent interest owned by the public. We also record a redeemable noncontrolling interest related to MPLX’s preferred units.

The creditors of MPLX do not have recourse to MPC’s general credit through guarantees or other financial arrangements. The assets of MPLX are the property of MPLX and cannot be used to satisfy the obligations of MPC. MPC has effectively guaranteed certain indebtedness of LOOP LLC (“LOOP”) and LOCAP LLC (“LOCAP”), in which MPLX holds an interest. See Note 22 for more information.

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Dropdowns to MPLX and GP/IDR Exchange

On February 1, 2018, we contributed our 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 billion 364-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.

On September 1, 2017, we contributed our joint-interest ownership in certain pipelines and storage facilities to MPLX in exchange for $420 million in cash and approximately 19 million common units and 378 thousand general partner units from MPLX. We also agreed to waive approximately two-thirds of the third quarter 2017 common unit distributions, IDRs and general partner distributions with respect to the common units issued in 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.

On March 1, 2017, we contributed certain terminal, pipeline and storage assets to MPLX in exchange for $1.5 billion in cash and approximately 13 million common units and 264 thousand general partner units from MPLX. We also agreed to waive two-thirds of the first quarter 2017 common unit distributions, IDRs and general partner distributions with respect to the common units issued in 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.

Noncontrolling Interest in MPLX

As a result of equity transactions of MPLX, 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 were as follows:



	Three Months Ended March 31,
(In millions)	2018			2017
Increase due to the issuance of MPLX LP common units to the public	$	4		$	10
Increase due to the issuance of MPLX LP common units and general partner units to MPC	1,114			96
Increase due to GP/IDR Exchange	1,808			—
Increase in MPC's additional paid-in capital	2,926			106
Tax impact	(546		)	(34		)
Increase in MPC's additional paid-in capital, net of tax	$	2,380		$	72

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 quarterly 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 100 percent of available capacity for certain marine transportation and refining logistics assets. 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 Refining & Marketing and Midstream segments.

5. Acquisitions and Investments

Acquisition of Ozark Pipeline

On March 1, 2017, MPLX acquired the Ozark pipeline from Enbridge Pipelines (Ozark) LLC for approximately $219 million, including purchase price adjustments made in the second quarter of 2017. Based on the fair value of assets acquired and liabilities assumed at the acquisition date, the final purchase price was primarily allocated to property, plant and equipment. The Ozark pipeline is a 433-mile, 22-inch crude oil pipeline originating in Cushing, Oklahoma, and terminating in Wood River, Illinois, capable of transporting approximately 230 mbpd. We account for the Ozark pipeline within the Midstream segment.

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Assuming the acquisition of the Ozark pipeline had occurred on January 1, 2016, the consolidated pro forma results would not have been materially different from reported results.

Investment in Pipeline Company

On February 15, 2017, MPLX acquired a partial, indirect equity interest in the Dakota Access Pipeline (“DAPL”) and Energy Transfer Crude Oil Company Pipeline (“ETCOP”) projects, collectively referred to as the Bakken Pipeline system, through a joint venture with Enbridge Energy Partners L.P. (“Enbridge Energy Partners”). The Bakken Pipeline system is capable of transporting more than 520 mbpd of crude oil from the Bakken/Three Forks production area in North Dakota to the Midwest through Patoka, Illinois and ultimately to the Gulf Coast. MPLX contributed $500 million of the $2 billion purchase price paid by the joint venture, MarEn Bakken Company LLC (“MarEn Bakken”), to acquire a 36.75 percent indirect equity interest in the Bakken Pipeline system from Energy Transfer Partners, L.P. (“ETP”) and Sunoco Logistics Partners, L.P. (“SXL”). MPLX holds, through a subsidiary, a 25 percent interest in MarEn Bakken, which equates to an approximate 9.2 percent indirect equity interest in the Bakken Pipeline system. We account for the investment in MarEn Bakken as part of our Midstream segment using the equity method of accounting.

Formation of Gathering and Processing Joint Venture

Effective January 1, 2017, MPLX and Antero Midstream formed a joint venture, Sherwood Midstream LLC (“Sherwood Midstream”), to support the development of Antero Resources Corporation’s Marcellus Shale acreage in West Virginia. MPLX has a 50 percent ownership interest in Sherwood Midstream. In connection with this transaction, MPLX contributed certain gas processing plants currently under construction at the Sherwood Complex with a fair value of approximately $134 million and cash of approximately $20 million. Antero Midstream made an initial capital contribution of approximately $154 million.

Also effective January 1, 2017, MPLX converted all of its ownership interests in MarkWest Ohio Fractionation Company, L.L.C. (“Ohio Fractionation”), a previously wholly-owned subsidiary, to Class A Interests and amended its LLC Agreement to create Class B-3 Interests, which were sold to Sherwood Midstream for $126 million in cash. The Class B-3 Interests provide Sherwood Midstream with the right to fractionation revenue and the obligation to pay expenses related to 20 mbpd of capacity in the Hopedale 3 fractionator.

Effective January 1, 2017, MPLX and Sherwood Midstream formed a joint venture, Sherwood Midstream Holdings LLC (“Sherwood Midstream Holdings”), for the purpose of owning, operating and maintaining all of the shared assets for the benefit of and use in the operation of the gas plants and other assets owned by Sherwood Midstream and the gas plants and deethanization facilities owned by MPLX. MPLX contributed certain real property, equipment and facilities with a fair value of approximately $209 million to Sherwood Midstream Holdings in exchange for a 79 percent initial ownership interest. Sherwood Midstream contributed cash of approximately $44 million to Sherwood Midstream Holdings in exchange for a 21 percent ownership interest. MPLX has a 10.5 percent indirect interest in Sherwood Midstream Holdings through its ownership in Sherwood Midstream. The net book value of the contributed assets was approximately $203 million. The contribution was determined to be an in-substance sale of real estate. As such, MPLX only recognized a gain for the portion attributable to Antero Midstream’s indirect interest of approximately $2 million. During the three months ended March 31, 2018, MarkWest Liberty Midstream sold to Sherwood Midstream 6 percent of their equity ownership in Sherwood Midstream Holdings for $15 million.

We account for our direct interests in Sherwood Midstream and Sherwood Midstream Holdings as part of our Midstream segment using the equity method of accounting. We continue to consolidate Ohio Fractionation and have recognized a noncontrolling interest for Sherwood Midstream’s interest in that entity.

See Note 6 for additional information related to the investments in Sherwood Midstream, Ohio Fractionation and Sherwood Midstream Holdings.

6. Variable Interest Entities

In addition to MPLX, as described in Note 4, the following entities are also VIEs.

Crowley Coastal Partners

In May 2016, Crowley Coastal Partners was formed to own an interest in both Crowley Ocean Partners and Crowley Blue Water Partners. We have determined that Crowley Coastal Partners is a VIE based on the terms of the existing financing arrangements for Crowley Blue Water Partners and Crowley Ocean Partners and the associated debt guarantees by MPC and Crowley. Our maximum exposure to loss at March 31, 2018 was $487 million, which includes our equity method investment in Crowley Coastal Partners and the debt guarantees provided to each of the lenders to Crowley Blue Water Partners and Crowley Ocean Partners. We are not the primary beneficiary of this VIE because we do not have the power to control the activities that significantly influence the economic outcomes of the entity and, therefore, do not consolidate the entity.

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MarkWest Utica EMG

On January 1, 2012, MarkWest Utica Operating Company, LLC (“Utica Operating”), a wholly-owned and consolidated subsidiary of MarkWest, and EMG Utica, LLC ("EMG Utica") (together the "Members"), executed agreements to form a joint venture, MarkWest Utica EMG LLC (“MarkWest Utica EMG”), to develop significant natural gas gathering, processing and NGL fractionation, transportation and marketing infrastructure in eastern Ohio.

As of March 31, 2018, MarkWest had a 56 percent ownership interest in MarkWest Utica EMG. MarkWest Utica EMG's inability to fund its planned activities without subordinated financial support qualify it as a VIE. Utica Operating is not deemed to be the primary beneficiary due to EMG Utica’s voting rights on significant matters. We account for our ownership interest in MarkWest Utica EMG as an equity method investment. MPLX receives engineering and construction and administrative management fee revenue and reimbursement for other direct personnel costs for operating MarkWest Utica EMG. Our maximum exposure to loss as a result of our involvement with MarkWest Utica EMG includes our equity investment, any additional capital contribution commitments and any operating expenses incurred by the subsidiary operator in excess of compensation received for the performance of the operating services. Our equity investment in MarkWest Utica EMG at March 31, 2018 was $2.1 billion.

Ohio Gathering

Ohio Gathering Company, L.L.C. (“Ohio Gathering”) is a subsidiary of MarkWest Utica EMG and is engaged in providing natural gas gathering services in the Utica Shale in eastern Ohio. Ohio Gathering is a joint venture between MarkWest Utica EMG and Summit Midstream Partners, LLC. As of March 31, 2018, we had a 34 percent indirect ownership interest in Ohio Gathering. As this entity is a subsidiary of MarkWest Utica EMG, which is accounted for as an equity method investment, MPLX reports its portion of Ohio Gathering’s net assets as a component of its investment in MarkWest Utica EMG. MPLX receives engineering and construction and administrative management fee revenue and reimbursement for other direct personnel costs for operating Ohio Gathering.

Sherwood Midstream

As described in Note 5, MPLX and Antero Midstream formed a joint venture, Sherwood Midstream, to support the development of Antero Resources Corporation’s Marcellus Shale acreage in West Virginia. As of March 31, 2018, MPLX had a 50 percent ownership interest in Sherwood Midstream. Sherwood Midstream’s inability to fund its planned activities without additional subordinated financial support qualify it as a VIE. MPLX is not deemed to be the primary beneficiary, due to Antero Midstream’s voting rights on significant matters. We account for our ownership interest in Sherwood Midstream using the equity method of accounting. Our maximum exposure to loss as a result of our involvement with Sherwood Midstream includes our equity investment, any additional capital contribution commitments and any operating expenses incurred by the subsidiary operator in excess of compensation received for the performance of the operating services. Our equity investment in Sherwood Midstream at March 31, 2018 was $260 million.

Ohio Fractionation

As described in Note 5, MPLX converted all of its ownership interests in Ohio Fractionation to Class A Interests and amended its LLC Agreement to create Class B-3 Interests, which were sold to Sherwood Midstream, providing it with the right to fractionation revenue and the obligation to pay expenses related to 20 mbpd of capacity in the Hopedale 3 fractionator. Ohio Fractionation’s inability to fund its operations without additional subordinated financial support qualify it as a VIE. MPLX has been deemed to be the primary beneficiary of Ohio Fractionation because it has control over decisions that could significantly impact its financial performance, and as a result, consolidates Ohio Fractionation.

Sherwood Midstream Holdings

As described in Note 5, MPLX and Sherwood Midstream entered into a joint venture, Sherwood Midstream Holdings, for the purpose of owning, operating and maintaining all of the shared assets for the benefit of and use in the operation of the gas plants and other assets owned by Sherwood Midstream and the gas plants and deethanization facilities owned by MPLX. MPLX had an initial 79 percent direct ownership in Sherwood Midstream Holdings, in addition to a 10.5 percent indirect interest through its ownership in Sherwood Midstream. Sherwood Midstream Holdings’ inability to fund its operations without additional subordinated financial support qualify it as a VIE. We account for our ownership interest in Sherwood Midstream Holdings using the equity method of accounting as Sherwood Midstream is considered to be the general partner and controls all decisions related to Sherwood Midstream Holdings. Our maximum exposure to loss as a result of our involvement with Sherwood Midstream Holdings includes our equity investment, any additional capital contribution commitments and any operating expenses incurred by the subsidiary operator in excess of compensation received for the performance of the operating services. Our equity investment in Sherwood Midstream Holdings at March 31, 2018 was $151 million.

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7. Related Party Transactions

Our related parties include:


•	Crowley Blue Water Partners, in which we have a 50 percent indirect noncontrolling interest. Crowley Blue Water Partners owns and operates three Jones Act ATB vessels.


•	Crowley Ocean Partners, in which we have a 50 percent indirect noncontrolling interest. Crowley Ocean Partners owns and operates Jones Act product tankers.


•	Illinois Extension Pipeline Company, L.L.C. (“Illinois Extension Pipeline”), in which we have a 35 percent noncontrolling interest. Illinois Extension Pipeline owns and operates the Southern Access Extension (“SAX”) crude oil pipeline.


•	LOCAP, in which we have a 59 percent noncontrolling interest. LOCAP owns and operates a crude oil pipeline.


•	LOOP, in which we have a 51 percent noncontrolling interest. LOOP owns and operates the only U.S. deepwater crude oil port.


•	MarkWest Utica EMG, in which we have a 56 percent noncontrolling interest. MarkWest Utica EMG is engaged in natural gas processing and NGL fractionation, transportation and marketing in Ohio.


•	Ohio Gathering, in which we have a 34 percent indirect noncontrolling interest. Ohio Gathering is a subsidiary of MarkWest Utica EMG providing natural gas gathering service in the Utica Shale region of eastern Ohio.


•	PFJ Southeast, in which we have a 29 percent noncontrolling interest. PFJ Southeast owns and operates travel plazas primarily in the Southeast region of the United States.


•	Sherwood Midstream, in which we have a 50 percent noncontrolling interest. Sherwood Midstream supports the development of Antero Resources Corporation’s Marcellus Shale acreage in West Virginia.


•	Sherwood Midstream Holdings, in which we have an 81 percent direct and indirect noncontrolling interest. Sherwood Midstream Holdings owns certain infrastructure at the Sherwood Complex that is shared by and supports the operation of both the Sherwood Midstream and MarkWest gas processing plants and deethanization facilities.


•	The Andersons Albion Ethanol LLC (“TAAE”), in which we have a 45 percent noncontrolling interest, The Andersons Clymers Ethanol LLC (“TACE”), in which we have a 61 percent noncontrolling interest and The Andersons Marathon Ethanol LLC (“TAME”), in which we have a 67 percent noncontrolling interest. These companies each own and operate an ethanol production facility.


•	Other equity method investees.

We believe that transactions with related parties were conducted on terms comparable to those with unaffiliated parties.

Sales to related parties were as follows:



	Three Months Ended March 31,
(In millions)	2018		2017
PFJ Southeast	$	169	$	151
Other equity method investees	3		3
Total	$	172	$	154

Sales to related parties consists primarily of sales of refined products.

Other income from related parties, which is included in “Other income” on the accompanying consolidated statements of income, were as follows:



	Three Months Ended March 31,
(In millions)	2018		2017
MarkWest Utica EMG	$	4	$	4
Ohio Gathering	4		4
Sherwood Midstream	3		1
Other equity method investees	2		2
Total	$	13	$	11

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Other income from related parties consists primarily of fees received for operating transportation assets for our related parties.

Purchases from related parties were as follows:



	Three Months Ended March 31,
(In millions)	2018		2017
Crowley Blue Water Partners	$	16	$	14
Crowley Ocean Partners	20		19
Illinois Extension Pipeline	24		25
LOCAP	4		5
LOOP	17		13
TAAE	19		8
TACE	8		16
TAME	20		17
Other equity method investees	13		5
Total	$	141	$	122

Related party purchases from Crowley Blue Water Partners and Crowley Ocean Partners consist of leasing marine equipment primarily used to transport refined products. Related party purchases from Illinois Extension Pipeline, LOCAP, LOOP and other equity method investees consist primarily of crude oil transportation costs. Related party purchases from TAAE, TACE and TAME consist of ethanol purchases.

Receivables from related parties, which are included in “Receivables, less allowance for doubtful accounts” on the accompanying consolidated balance sheets, were as follows:



(In millions)	March 31, 2018		December 31, 2017
PFJ Southeast	$	30	$	28
Sherwood Midstream Holdings	15		—
Other equity method investees	7		8
Total	$	52	$	36

The long-term receivable, which is included in “Other noncurrent assets” on the accompanying consolidated balance sheet, was $1 million at March 31, 2018 and $1 million at December 31, 2017.

Payables to related parties, which are included in “Accounts payable” on the accompanying consolidated balance sheets, were as follows:



(In millions)	March 31, 2018		December 31, 2017
Illinois Extension Pipeline	$	7	$	8
LOOP	2		3
MarkWest Utica EMG	20		29
Ohio Gathering	1		9
Sherwood Midstream	11		8
Other equity method investees	10		12
Total	$	51	$	69

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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)	2018		2017
Revenues and other income	$	1,132	$	1,027
Income from operations	73		82
Net income	71		81

8. Income per Common Share

We compute basic earnings per share by dividing net income attributable to MPC by the weighted average number of shares of common stock outstanding. Diluted income per share assumes exercise of certain stock-based compensation awards, provided the effect is not anti-dilutive.

MPC grants certain incentive compensation awards to employees and non-employee directors that are considered to be participating securities. Due to the presence of participating securities, we have calculated our earnings per share using the two-class method.



	Three Months Ended March 31,
(In millions, except per share data)	2018		2017
Basic earnings per share:
Allocation of earnings:
Net income attributable to MPC	$	37	$	30
Income allocated to participating securities	—		—
Income available to common stockholders – basic	$	37	$	30
Weighted average common shares outstanding	476		525
Basic earnings per share	$	0.08	$	0.06
Diluted earnings per share:
Allocation of earnings:
Net income attributable to MPC	$	37	$	30
Income allocated to participating securities	—		—
Income available to common stockholders – diluted	$	37	$	30
Weighted average common shares outstanding	476		525
Effect of dilutive securities	4		5
Weighted average common shares, including dilutive effect	480		530
Diluted earnings per share	$	0.08	$	0.06

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)	2018	2017
Shares issued under stock-based compensation plans	—	2

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9. Equity

As of March 31, 2018, we had $1.86 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)	2018		2017
Number of shares repurchased	19		9
Cash paid for shares repurchased	$	1,327	$	420
Average cost per share	$	68.74	$	50.15

As of March 31, 2018, we had agreements to acquire 619,415 common shares for $45 million, which were settled in early April 2018.

10. Segment Information

We have three reportable segments: Refining & Marketing; Speedway; 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 six refineries in the Gulf Coast and Midwest regions of the United States, purchases refined products and ethanol for resale and distributes refined products through transportation, storage, distribution and marketing services provided by our Midstream segment. We sell refined products to wholesale marketing customers domestically and internationally, to buyers on the spot market, to our Speedway business segment and to independent entrepreneurs who operate Marathon^® retail outlets.


•	Speedway – sells transportation fuels and convenience merchandise in retail markets in the Midwest, East Coast and Southeast regions of the United States.

•

Midstream – gathers, processes and transports natural gas; gathers, transports, fractionates, stores and markets NGLs; and 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. The Midstream segment primarily reflects the results of MPLX, our sponsored master limited partnership.

As discussed in Note 4, on February 1, 2018, we contributed certain refining logistics assets and fuels distribution services to MPLX. The results of these new businesses are reported in the Midstream segment prospectively from February 1, resulting in a net reduction of $181 million to Refining & Marketing segment results and a net increase to Midstream segment results of the same amount. No effect was given to prior periods as these entities were not considered businesses prior to February 1, 2018.

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

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(In millions)	Refining & Marketing			Speedway		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^(b)	252			79		181		512
Capital expenditures and investments^(c)	191			39		482		712



(In millions)	Refining & Marketing			Speedway		Midstream		Total
Three Months Ended March 31, 2017
Revenues:
Third party	$	11,221		$	4,381	$	532	$	16,134
Intersegment^(a)	2,590			1		344		2,935
Related party	152			2		—		154
Segment revenues	$	13,963		$	4,384	$	876	$	19,223
Segment income (loss) from operations	$	(70	)	$	135	$	309	$	374
Income from equity method investments	2			13		42		57
Depreciation and amortization^(b)	267			64		191		522
Capital expenditures and investments^(c)(d)	192			35		1,070		1,297


^(a)	Management believes intersegment transactions were conducted under terms comparable to those with unaffiliated parties.


^(b)	Differences between segment totals and MPC totals represent amounts related to unallocated items and are included in “Items not allocated to segments” in the reconciliation below.


^(c)	Capital expenditures include changes in capital accruals, acquisitions and investments in affiliates.


^(d)	The Midstream segment includes $220 million for the acquisition of the Ozark pipeline and an investment of $500 million in MarEn Bakken related to the Bakken Pipeline system for the three months ended March 31, 2017.

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)	2018			2017
Segment income from operations	$	529		$	374
Items not allocated to segments:
Corporate and other unallocated items^(a)	(88		)	(83		)
Pension settlement expenses	(1		)	—
Income from operations	440			291
Net interest and other financial costs	183			149
Income before income taxes	$	257		$	142


^(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, which are included in the Midstream segment. Corporate overhead expenses are not allocated to the Refining & Marketing and Speedway segments.

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



	Three Months Ended March 31,
(In millions)	2018		2017
Segment capital expenditures and investments	$	712	$	1,297
Less investments in equity method investees^(a)	41		566
Plus items not allocated to segments:
Corporate	18		16
Capitalized interest	18		12
Total capital expenditures^(b)	$	707	$	759


^(a)	The three months ended March 31, 2017 includes an investment of $500 million in MarEn Bakken related to the Bakken Pipeline system.


^(b)	Capital expenditures include changes in capital accruals. See Note 18 for a reconciliation of total capital expenditures to additions to property, plant and equipment as reported in the consolidated statements of cash flows.

Revenues by product line were as follows:



	Three Months Ended March 31,
(In millions)	2018		2017
Refined products	$	16,158	$	13,876
Merchandise	1,130		1,192
Crude oil and refinery feedstocks	883		687
Service, transportation and other	523		379
Sales and other operating revenues	$	18,694	$	16,134

11. Other Items

Net interest and other financial costs were as follows:



	Three Months Ended March 31,
(In millions)	2018			2017
Interest income	$	(20	)	$	(5	)
Interest expense	213			163
Interest capitalized	(18		)	(15		)
Loss on extinguishment of debt	4			—
Other financial costs	4			6
Net interest and other financial costs	$	183		$	149

12. Income Taxes

The combined federal, state and foreign income tax rate was 9 percent and 29 percent for the three months ended March 31, 2018 and 2017, respectively. 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 interest, state and local deferred tax benefits primarily resulting from the February 1 dropdown and GP/IDR Exchange and equity compensation. The effective tax rate for the three months ended March 31, 2017 was less than the U.S. statutory rate of 35 percent primarily due to certain permanent tax differences related to equity compensation, net income attributable to noncontrolling interest and the domestic manufacturing deduction offset by state and local tax expense.

We are continuously undergoing examination of our income tax returns, which have been completed through the 2007 tax year for state returns and the 2009 tax year for our U.S. federal return. As of March 31, 2018, we had $19 million of unrecognized tax benefits.

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Prior to its spin-off on June 30, 2011, Marathon Petroleum Corporation was included in the Marathon Oil Corporation (“Marathon Oil”) federal income tax returns for all applicable years. During the third quarter 2017, Marathon Oil received a notice of Final Partnership Administrative Adjustment (“FPAA”) from the IRS for taxable year 2010, relating to certain pre-spinoff 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 22 for indemnification information.

13. Inventories



(In millions)	March 31, 2018		December 31, 2017
Crude oil and refinery feedstocks	$	1,777	$	2,056
Refined products	2,746		2,839
Materials and supplies	435		494
Merchandise	153		161
Total	$	5,111	$	5,550

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 material liquidations of LIFO inventories for the three months ended March 31, 2018.

14. Property, Plant and Equipment



(In millions)	March 31, 2018		December 31, 2017
Refining & Marketing^(a)	$	18,117	$	19,490
Speedway	5,359		5,358
Midstream^(a)	16,889		14,898
Corporate and Other	811		792
Total	41,176		40,538
Less accumulated depreciation	14,558		14,095
Property, plant and equipment, net	$	26,618	$	26,443


^(a)	On February 1, 2018, we contributed certain refining logistics assets and fuels distribution services to MPLX. In connection with this transaction, approximately $830 million of net property, plant and equipment was recorded to the Midstream segment with an offsetting reduction to the Refining & Marketing segment.

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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, 2018 and December 31, 2017 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, 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
Commodity derivative instruments, assets	$	21	$	—	$	—	$	(21	)	$	—	$	22
Other assets	3		—		—		N/A			3		—
Total assets at fair value	$	24	$	—	$	—	$	(21	)	$	3	$	22

Commodity derivative instruments, liabilities^(c)	$	60	$	—	$	1	$	(60	)	$	1	$	—
Embedded derivatives in commodity contracts^(c)	—		—		59		—			59		—
Total liabilities at fair value	$	60	$	—	$	60	$	(60	)	$	60	$	—



	December 31, 2017
	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
Commodity derivative instruments, assets	$	127	$	—	$	—	$	(118	)	$	9	$	8
Other assets	3		—		—		N/A			3		—
Total assets at fair value	$	130	$	—	$	—	$	(118	)	$	12	$	8

Commodity derivative instruments, liabilities	$	126	$	—	$	2	$	(126	)	$	2	$	—
Embedded derivatives in commodity contracts^(c)	—		—		64		—			64		—
Total liabilities at fair value	$	126	$	—	$	66	$	(126	)	$	66	$	—


^(a)	Represents the impact of netting assets, liabilities and cash collateral when a legal right of offset exists. As of March 31, 2018, cash collateral of $39 million was netted with the mark-to-market derivative liabilities. As of December 31, 2017, $8 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.


^(c)	Level 3 includes $11 million and $12 million classified as current at March 31, 2018 and December 31, 2017, respectively.

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 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 used significant unobservable inputs including: (1) NGL prices interpolated and extrapolated due to inactive markets ranging from $0.26 to $1.47 per gallon and (2) the probability of renewal of 62.5 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. The forward prices for the individual NGL products generally increase or decrease in a positive correlation with one another. Increases or decreases in forward NGL prices result in an increase or decrease in the fair value of the embedded derivative. An increase in the probability of renewal would result in an increase in the fair value of the related embedded derivative liability.

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



	Three Months Ended March 31,
(In millions)	2018			2017
Beginning balance	$	66		$	190
Unrealized and realized losses included in net income	(3		)	(12		)
Settlements of derivative instruments	(3		)	(3		)
Ending balance	$	60		$	175

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:
Derivative instruments	$	(3	)	$	(13	)
Contingent consideration agreement	—			1
Total	$	(3	)	$	(12	)

Fair Values – Reported

The following table summarizes financial instruments on the basis of their nature, characteristics and risk at March 31, 2018 and December 31, 2017, excluding the derivative financial instruments and contingent consideration reported above.



	March 31, 2018				December 31, 2017
(In millions)	Fair Value		Carrying Value		Fair Value		Carrying Value
Financial assets:
Environmental receivables and misc. deposits	18		18		17		17
Total financial assets	$	18	$	18	$	17	$	17
Financial liabilities:
Long-term debt^(a)	$	17,893	$	17,010	$	13,893	$	12,642
Deferred credits and other liabilities	118		108		122		109
Total financial liabilities	$	18,011	$	17,118	$	14,015	$	12,751


^(a)	Excludes capital leases and debt issuance costs; includes amount classified as debt due within one year.

Our current assets and liabilities include financial instruments, the most significant of which are trade accounts receivable and payables.

Fair values of our financial assets and of our financial liabilities included in deferred credits and other liabilities are measured primarily using an income approach and most inputs are internally generated, which results in a Level 3 classification. Estimated future cash flows are discounted using a rate deemed appropriate to obtain the fair value. Deferred credits and other liabilities primarily consist of a liability resulting from a financing arrangement for the construction of MPLX’s steam methane reformer at the Javelina gas processing and fractionation complex in Corpus Christi, Texas, insurance liabilities and environmental remediation liabilities.

Fair value of fixed-rate long-term debt is measured using Level 3 inputs. Fair value of variable-rate long-term debt approximates the carrying value.

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.

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The following table presents the gross fair values of derivative instruments, excluding cash collateral, and where they appear on the consolidated balance sheets as of March 31, 2018 and December 31, 2017:



(In millions)	March 31, 2018
Balance Sheet Location	Asset		Liability
Commodity derivatives
Other current assets	$	21	$	60
Other current liabilities^(a)	—		12
Deferred credits and other liabilities^(a)	—		48



(In millions)	December 31, 2017
Balance Sheet Location	Asset		Liability
Commodity derivatives
Other current assets	$	127	$	126
Other current liabilities^(a)	—		14
Deferred credits and other liabilities^(a)	—		52


^(a)	Includes embedded derivatives.

The tables below summarize open commodity derivative contracts for crude oil and refined products as of March 31, 2018.



	Position	Total Barrels (In thousands)
Crude Oil^(a)
Exchange-traded	Long	16,664
Exchange-traded	Short	(22,145	)


^{(a )}	94.7 percent of the exchange-traded contracts expire in the second quarter of 2018.



	Position	Total Gallons (In thousands)
Refined Products^(a)
Exchange-traded	Long	159,390
Exchange-traded	Short	(147,252	)


^{(a )}	100 percent of the exchange-traded contracts expire in the second quarter of 2018.

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



	Gain (Loss)
(In millions)	Three Months Ended March 31,
Income Statement Location	2018			2017
Sales and other operating revenues	$	(1	)	$	16
Cost of revenues	(27		)	(24		)
Total	$	(28	)	$	(8	)

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17. Debt

Our outstanding borrowings at March 31, 2018 and December 31, 2017 consisted of the following:



(In millions)	March 31, 2018			December 31, 2017
Marathon Petroleum Corporation:
Commercial paper	$	—		$	—
364-day bank revolving credit facility due July 2018	—			—
Trade receivables securitization facility due July 2019	—			—
Bank revolving credit facility due 2022	—			—
Senior notes, 2.700% due December 2018	—			600
Senior notes, 3.400% due December 2020	650			650
Senior notes, 5.125% due March 2021	1,000			1,000
Senior notes, 3.625%, due September 2024	750			750
Senior notes, 6.500%, due March 2041	1,250			1,250
Senior notes, 4.750%, due September 2044	800			800
Senior notes, 5.850% due December 2045	250			250
Senior notes, 5.000%, due September 2054	400			400
Capital lease obligations due 2018-2033	350			356
MPLX LP:
MPLX 364-day term loan facility due 2018	—			—
MPLX term loan facility due 2019	—			—
MPLX bank revolving credit facility due 2022	—			505
MPLX senior notes, 5.500%, due February 2023	710			710
MPLX senior notes, 3.375%, due March 2023	500			—
MPLX senior notes, 4.500%, due July 2023	989			989
MPLX senior notes, 4.875%, due December 2024	1,149			1,149
MPLX senior notes, 4.000%, due February 2025	500			500
MPLX senior notes, 4.875%, due June 2025	1,189			1,189
MarkWest senior notes, 4.500% - 5.500%, due 2023 - 2025	63			63
MPLX senior notes, 4.125%, due March 2027	1,250			1,250
MPLX senior notes, 4.000%, due March 2028	1,250			—
MPLX senior notes, 4.500%, due April 2038	1,750			—
MPLX senior notes, 5.200%, due March 2047	1,000			1,000
MPLX senior notes, 4.700%, due April 2048	1,500			—
MPLX senior notes, 4.900%, due April 2058	500			—
MPLX capital lease obligations due 2020	7			7
Total	17,807			13,418
Unamortized debt issuance costs	(109		)	(59		)
Unamortized discount^(a)	(440		)	(413		)
Amounts due within one year	(26		)	(624		)
Total long-term debt due after one year	$	17,232		$	12,322


^(a)	Includes $362 million and $374 million of unamortized discount as of March 31, 2018 and December 31, 2017, respectively, related to the difference between the fair value and the principal amount of assumed MarkWest debt.

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Commercial Paper

During the three months ended March 31, 2018, we had no borrowings or repayments under the commercial paper program. At March 31, 2018, we had no amounts outstanding under the commercial paper program.

Trade Receivables Securitization Facility

At March 31, 2018, we had no amounts outstanding under our trade receivables securitization facility.

MPC Bank Revolving Credit Facilities

There were no borrowings or letters of credit outstanding under the MPC bank revolving credit facility at March 31, 2018.

MPC Senior Notes

On March 15, 2018, we redeemed all of the $600 million outstanding aggregate principal amount of our 2.700 percent senior notes due December 2018. The 2018 senior notes were redeemed at a price equal to par plus a make whole premium, plus accrued and unpaid interest. The make whole premium of $2.5 million was calculated based on the market yield of the applicable treasury issue as of the redemption date as determined in accordance with the indenture governing the 2018 senior notes.

MPLX Credit Agreement

During the three months ended March 31, 2018, MPLX borrowed $50 million under the MPLX bank revolving credit facility, at an average interest rate of 3.0 percent, and repaid $555 million. At March 31, 2018, MPLX had no outstanding borrowings and $3 million letters of credit outstanding under the MPLX bank revolving credit facility, resulting in total availability of $2.25 billion.

MPLX 364-Day Term Loan

On January 2, 2018, MPLX entered into a term loan agreement with a syndicate of lenders providing for a $4.1 billion, 364-day term loan facility. MPLX drew the entire amount of the term loan facility in a single borrowing to fund the cash portion of the consideration for the February 1, 2018 dropdown. On February 8, 2018, MPLX used $4.1 billion of the net proceeds from the issuance of MPLX senior notes to repay the 364-day term-loan facility.

MPLX Senior Notes

On February 8, 2018, MPLX issued $5.5 billion in aggregate principal amount of senior notes in a public offering, consisting of $500 million aggregate principal amount of 3.375 percent unsecured senior notes due March 2023, $1.25 billion aggregate principal amount of 4.000 percent unsecured senior notes due March 2028, $1.75 billion aggregate principal amount of 4.500 percent unsecured senior notes due April 2038, $1.5 billion aggregate principal amount of 4.700 percent unsecured senior notes due April 2048, and $500 million aggregate principal amount of 4.900 percent unsecured senior notes due April 2058. 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.

18. Supplemental Cash Flow Information



	Three Months Ended March 31,
(In millions)	2018		2017
Net cash provided by operating activities included:
Interest paid (net of amounts capitalized)	$	212	$	157
Net income taxes paid to taxing authorities	6		4
Non-cash investing and financing activities:
Contribution of assets to joint venture^(a)	—		328


^(a)	MarkWest’s contribution of assets to Sherwood Midstream and Sherwood Midstream Holdings. See Note 5.

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(In millions)	March 31, 2018		December 31, 2017
Cash and cash equivalents	$	4,653	$	3,011
Restricted cash^(a)	4		4
Cash, cash equivalents and restricted cash^(b)	$	4,657	$	3,015


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


^(b)	As a result of the adoption of ASU 2016-18, the consolidated statements of cash flows now explain the change during the period of both “Cash and cash equivalents” and “Restricted cash.”

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)	2018			2017
Additions to property, plant and equipment per consolidated statements of cash flows	$	755		$	610
Asset retirement expenditures	1			1
Decrease in capital accruals	(49		)	(72		)
Total capital expenditures before acquisitions	707			539
Acquisitions^(a)	—			220
Total capital expenditures	$	707		$	759


^(a)	The three months ended March 31, 2017 reflects the acquisition of the Ozark pipeline.

19. 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, 2016	$	(233	)	$	(7	)	$	4	$	2	$	(234	)
Other comprehensive loss before reclassifications	(1		)	—			—		—		(1		)
Amounts reclassified from accumulated other comprehensive loss:
Amortization – prior service credit^(a)	(10		)	(1		)	—		—		(11		)
– actuarial loss^(a)	9			—			—		—		9
– settlement loss^(a)	—			—			—		—		—
Tax effect	—			—			—