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 September 30, 2017



¨	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 488,412,170 shares of Marathon Petroleum Corporation common stock outstanding as of October 27, 2017.

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MARATHON PETROLEUM CORPORATION

Form 10-Q

Quarter Ended September 30, 2017

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	37
Item 3. Quantitative and Qualitative Disclosures about Market Risk	60
Item 4. Controls and Procedures	61
Supplementary Statistics (Unaudited)	62

PART II – OTHER INFORMATION
Item 1. Legal Proceedings	65
Item 1A. Risk Factors	66
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	66
Item 5. Other Information	67
Item 6. Exhibits	68
Signatures	69

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:



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
NYSE	New York Stock Exchange
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

Part I – Financial Information

Item 1. Financial Statements

Marathon Petroleum Corporation

Consolidated Statements of Income (Unaudited)



	Three Months Ended September 30,						Nine Months Ended September 30,
(In millions, except per share data)	2017			2016			2017			2016
Revenues and other income:
Sales and other operating revenues (including consumer excise taxes)	$	19,053		$	16,616		$	53,220		$	46,179
Sales to related parties	157			2			458			5
Income (loss) from equity method investments	84			(208		)	224			(236		)
Net gain on disposal of assets	—			1			12			26
Other income	92			49			219			106
Total revenues and other income	19,386			16,460			54,133			46,080
Costs and expenses:
Cost of revenues (excludes items below)	14,605			12,944			41,913			35,475
Purchases from related parties	148			128			420			359
Inventory market valuation adjustment	—			—			—			(370		)
Consumer excise taxes	2,012			1,914			5,751			5,633
Impairment expense	—			—			—			130
Depreciation and amortization	517			507			1,574			1,497
Selling, general and administrative expenses	412			420			1,286			1,199
Other taxes	116			112			339			332
Total costs and expenses	17,810			16,025			51,283			44,255
Income from operations	1,576			435			2,850			1,825
Net interest and other financial income (costs)	(157		)	(141		)	(465		)	(420		)
Income before income taxes	1,419			294			2,385			1,405
Provision for income taxes	415			75			706			481
Net income	1,004			219			1,679			924
Less net income (loss) attributable to:
Redeemable noncontrolling interest	16			16			49			25
Noncontrolling interests	85			58			214			(48		)
Net income attributable to MPC	$	903		$	145		$	1,416		$	947
Per Share Data (See Note 7)
Basic:
Net income attributable to MPC per share	$	1.79		$	0.28		$	2.75		$	1.79
Weighted average shares outstanding	504			527			514			528
Diluted:
Net income attributable to MPC per share	$	1.77		$	0.27		$	2.73		$	1.78
Weighted average shares outstanding	508			530			518			531
Dividends paid	$	0.40		$	0.36		$	1.12		$	1.00

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 September 30,						Nine Months Ended September 30,
(In millions)	2017			2016			2017			2016
Net income	$	1,004		$	219		$	1,679		$	924
Other comprehensive income (loss):
Defined benefit postretirement and post-employment plans:
Actuarial changes, net of tax of $2, $0, $9 and $8	4			2			15			14
Prior service costs, net of tax of ($4), ($5), ($12) and ($14)	(7		)	(8		)	(20		)	(23		)
Other comprehensive loss	(3		)	(6		)	(5		)	(9		)
Comprehensive income	1,001			213			1,674			915
Less comprehensive income (loss) attributable to:
Redeemable noncontrolling interest	16			16			49			25
Noncontrolling interests	85			58			214			(48		)
Comprehensive income attributable to MPC	$	900		$	139		$	1,411		$	938

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)	September 30, 2017			December 31, 2016
Assets
Current assets:
Cash and cash equivalents (MPLX: $3 and $234, respectively)	$	2,088		$	887
Receivables, less allowance for doubtful accounts of $10 and $12 (MPLX: $328 and $304, respectively)	3,900			3,617
Inventories (MPLX: $64 and $55, respectively)	5,493			5,656
Other current assets (MPLX: $30 and $33, respectively)	150			241
Total current assets	11,631			10,401
Equity method investments (MPLX: $3,997 and $2,471, respectively)	4,769			3,827
Property, plant and equipment, net (MPLX: $11,922 and $11,408, respectively)	26,036			25,765
Goodwill (MPLX: $2,245 and $2,245, respectively)	3,586			3,587
Other noncurrent assets (MPLX: $485 and $506, respectively)	784			833
Total assets	$	46,806		$	44,413
Liabilities
Current liabilities:
Accounts payable (MPLX: $576 and $541, respectively)	$	6,159		$	5,593
Payroll and benefits payable (MPLX: $1 and $1, respectively)	459			530
Consumer excise taxes payable (MPLX: $2 and $3, respectively)	371			464
Accrued taxes (MPLX: $42 and $35, respectively)	361			153
Debt due within one year (MPLX: $1 and $1, respectively)	29			28
Other current liabilities (MPLX: $107 and $81, respectively)	268			378
Total current liabilities	7,647			7,146
Long-term debt (MPLX: $6,848 and $4,422, respectively)	12,753			10,544
Deferred income taxes (MPLX: $7 and $6, respectively)	3,935			3,861
Defined benefit postretirement plan obligations	1,029			1,055
Deferred credits and other liabilities (MPLX: $209 and $189, respectively)	640			604
Total liabilities	26,004			23,210
Commitments and contingencies (see Note 21)
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 – 733 million and 731 million shares (par value 0.01 per share, 1 billion shares authorized)	7			7
Held in treasury, at cost – 235 million and 203 million shares	(9,118		)	(7,482		)
Additional paid-in capital	11,236			11,060
Retained earnings	11,044			10,206
Accumulated other comprehensive loss	(239		)	(234		)
Total MPC stockholders’ equity	12,930			13,557
Noncontrolling interests	6,872			6,646
Total equity	19,802			20,203
Total liabilities, redeemable noncontrolling interest and equity	$	46,806		$	44,413

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)



	Nine Months Ended September 30,
(In millions)	2017			2016
Increase (decrease) in cash and cash equivalents
Operating activities:
Net income	$	1,679		$	924
Adjustments to reconcile net income to net cash provided by operating activities:
Amortization of deferred financing costs and debt discount	46			47
Impairment expense	—			130
Depreciation and amortization	1,574			1,497
Inventory market valuation adjustment	—			(370		)
Pension and other postretirement benefits, net	(32		)	(21		)
Deferred income taxes	57			335
Net gain on disposal of assets	(12		)	(26		)
(Income) loss from equity method investments	(224		)	236
Distributions from equity method investments	252			199
Changes in the fair value of derivative instruments	101			6
Changes in:
Current receivables	(296		)	(209		)
Inventories	163			71
Current accounts payable and accrued liabilities	654			237
All other, net	(99		)	(54		)
Net cash provided by operating activities	3,863			3,002
Investing activities:
Additions to property, plant and equipment	(1,928		)	(2,147		)
Acquisitions, net of cash acquired	(249		)	—
Disposal of assets	64			88
Investments – acquisitions, loans and contributions	(730		)	(240		)
– redemptions, repayments and return of capital	64			20
All other, net	164			62
Net cash used in investing activities	(2,615		)	(2,217		)
Financing activities:
Commercial paper – issued	300			1,063
– repayments	(300		)	(1,063		)
Long-term debt – borrowings	2,661			714
– repayments	(470		)	(2,112		)
Debt issuance costs	(28		)	(11		)
Issuance of common stock	27			8
Common stock repurchased	(1,622		)	(177		)
Dividends paid	(578		)	(529		)
Issuance of MPLX LP common units	473			499
Issuance of MPLX LP redeemable preferred units	—			984
Distributions to noncontrolling interests	(505		)	(389		)
Contributions from noncontrolling interests	128			4
Contingent consideration payment	(89		)	(164		)
All other, net	(44		)	(30		)
Net cash used in financing activities	(47		)	(1,203		)
Net increase (decrease) in cash and cash equivalents	1,201			(418		)
Cash and cash equivalents at beginning of period	887			1,127
Cash and cash equivalents at end of period	$	2,088		$	709

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, 2015	$	7	$	(7,275	)	$	11,071		$	9,752		$	(318	)	$	6,438		$	19,675		$	—
Net income (loss)	—		—			—			947			—			(48		)	899			25
Dividends declared	—		—			—			(530		)	—			—			(530		)	—
Distributions to noncontrolling interests	—		—			—			—			—			(380		)	(380		)	(9		)
Contributions from noncontrolling interests	—		—			—			—			—			4			4			—
Other comprehensive loss	—		—			—			—			(9		)	—			(9		)	—
Shares repurchased	—		(177		)	—			—			—			—			(177		)	—
Shares issued (returned) – stock-based compensation	—		(7		)	8			—			—			—			1			—
Stock-based compensation	—		—			39			—			—			6			45			—
Impact from equity transactions of MPLX LP	—		—			(113		)	—			—			542			429			—
Issuance of MPLX LP redeemable preferred units	—		—			—			—			—			—			—			984
Balance as of September 30, 2016	$	7	$	(7,459	)	$	11,005		$	10,169		$	(327	)	$	6,562		$	19,957		$	1,000
Balance as of December 31, 2016	$	7	$	(7,482	)	$	11,060		$	10,206		$	(234	)	$	6,646		$	20,203		$	1,000
Net income	—		—			—			1,416			—			214			1,630			49
Dividends declared	—		—			—			(578		)	—			—			(578		)	—
Distributions to noncontrolling interests	—		—			—			—			—			(456		)	(456		)	(49		)
Contributions from noncontrolling interests	—		—			—			—			—			128			128			—
Other comprehensive loss	—		—			—			—			(5		)	—			(5		)	—
Shares repurchased	—		(1,622		)	—			—			—			—			(1,622		)	—
Shares issued (returned) – stock-based compensation	—		(14		)	27			—			—			—			13			—
Stock-based compensation	—		—			37			—			—			5			42			—
Impact from equity transactions of MPLX LP	—		—			112			—			—			335			447			—
Balance as of September 30, 2017	$	7	$	(9,118	)	$	11,236		$	11,044		$	(239	)	$	6,872		$	19,802		$	1,000

(Shares in millions)	Common Stock		Treasury Stock
Balance as of December 31, 2015	729		(198		)
Shares repurchased	—		(4		)
Shares issued (returned) – stock-based compensation	2		(1		)
Balance as of September 30, 2016	731		(203		)
Balance as of December 31, 2016	731		(203		)
Shares repurchased	—		(31		)
Shares issued (returned) – stock-based compensation	2		(1		)
Balance as of September 30, 2017	733		(235		)

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 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, 2016. The results of operations for the three and nine months ended September 30, 2017 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.

In the first quarter of 2017, we revised our segment reporting in connection with the contribution of certain terminal, pipeline and storage assets to MPLX. See Note 3 for additional information. The operating results for these assets are now reported in our Midstream segment. Previously, they were reported as part of our Refining & Marketing segment. Comparable prior period information has been recast to reflect our revised presentation. The results for the pipeline and storage assets were recast effective January 1, 2015, and the results for the terminal assets were recast effective April 1, 2016. Prior to these dates, these assets were not considered businesses for accounting purposes and, therefore, there are no financial results from which to recast segment results. Additionally, the MPLX asset and liability balances as of December 31, 2016, reported in parentheses on our consolidated balance sheets, have also been recast to reflect this transaction. See Note 9 and Note 13 for additional information.

2. Accounting Standards

Recently Adopted

In October 2016, the FASB issued an accounting standards update to amend the consolidation guidance issued in February 2015 to require that a decision maker consider, in the determination of the primary beneficiary, its indirect interest in a VIE held by a related party that is under common control on a proportionate basis only. The change was effective for our financial statements for fiscal years beginning after December 15, 2016, and interim periods within those fiscal years. We were required to apply the standard retrospective to January 1, 2016, the date on which we adopted the consolidation guidance issued in February 2015. Adoption of this accounting standards update in the first quarter of 2017 did not have an impact on our consolidated financial statements.

In March 2016, the FASB issued an accounting standards update to simplify some provisions in stock compensation accounting. The areas for simplification involve the accounting for share-based payment transactions, including income tax consequences, classifications of awards as either equity or liabilities and classification within the statement of cash flows. The changes were effective for fiscal years beginning after December 15, 2016, and interim periods within those fiscal years. Adoption of this accounting standards update in the first quarter of 2017 did not have a material impact on our consolidated financial statements.

In March 2016, the FASB issued an accounting standards update eliminating the requirement that an investor retrospectively apply equity method accounting when an investment that it had accounted for by another method initially qualifies for the equity method. This change was effective for fiscal years beginning after December 15, 2016, and interim periods within those fiscal years. Adoption of this accounting standards update in the first quarter of 2017 did not have an impact on our consolidated financial statements.

Not Yet Adopted

In August 2017, the FASB issued 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.

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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.

In May 2017, the FASB issued an accounting standards update to provide guidance about when changes to the terms or conditions of a share-based payment award require an entity to apply modification accounting. An entity should account for the effects of a modification unless the fair value, vesting conditions and balance sheet classification of the modified award is the same as the original award immediately before the original award is modified. We will adopt this accounting standards update January 1, 2018. This update should be applied prospectively to an award modified on or after the adoption date. We do not expect the application of this accounting standards update to have a material impact on our consolidated financial statements.

In March 2017, the FASB issued an accounting standards update requiring that the service cost component of pension and postretirement benefit costs be presented in the same line item as other current employee compensation costs and other components of those benefit costs be presented separately from the service cost component and outside a subtotal of income from operations, if presented. The update also requires that only the service cost component of pension and postretirement benefit cost is eligible for capitalization. We will adopt this accounting standards update January 1, 2018. Application is retrospective for the presentation of the components of these benefit costs and prospective for the capitalization of only service costs. We do not expect the application of this accounting standards update to have a material impact on our consolidated financial statements.

In February 2017, the FASB issued an accounting standards update addressing the derecognition of nonfinancial assets. The guidance defines in substance nonfinancial assets, and states that the derecognition of business activities should be evaluated under the consolidation guidance, with limited exceptions related to conveyances of oil and gas mineral rights or contracts with customers. The standard eliminates the previous exclusion for businesses that are in-substance real estate, and eliminates some differences based on whether a transferred set is that of assets or a business and whether the transfer is to a joint venture. The standard must be implemented in conjunction with the implementation date of the revenue recognition accounting standards update, which we will implement January 1, 2018. We plan to adopt the new standard using the modified retrospective method and do not expect the application of this accounting standards update to have a material impact on our consolidated financial statements.

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. Early adoption is permitted for interim or annual goodwill impairment tests performed on testing dates after January 1, 2017.

In January 2017, the FASB issued an accounting standards update to clarify the definition of a business with the objective of adding guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. The standard is intended to narrow the definition of a business by specifying the minimum inputs and processes and by narrowing the definition of outputs. The change is effective for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years. The guidance will be applied prospectively and early adoption is permitted for certain transactions.

In November 2016, the FASB issued an accounting standards update requiring that the statement of cash flows explain the change during the period in the total of cash, cash equivalents and amounts generally described as restricted cash or restricted cash equivalents. The change is effective for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years, with early adoption permitted. Retrospective application is required. Application of this accounting standards update will not have a material impact on our statements of cash flows.

In October 2016, the FASB issued an accounting standards update that requires recognition of the income tax consequences of intra-entity transfers of assets other than inventory when the transfer occurs. The change is effective for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years, with early adoption permitted. The amendments in this accounting standards update should be applied on a modified retrospective basis through a cumulative-effect adjustment directly to retained earnings as of the beginning of the period of adoption. We do not expect application of this accounting standards update to have a material impact on our consolidated financial statements.

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In August 2016, the FASB issued an accounting standards update related to the classification of certain cash flows. The accounting standards update provides specific guidance on eight cash flow classification issues, including debt prepayment or debt extinguishment costs, contingent consideration payments made after a business combination and distributions received from equity method investees, to reduce diversity in practice. The change is effective for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years, with early adoption permitted. Retrospective application is required. We do not expect application of this accounting standards update to have a material impact on our statements of cash flows.

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.

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 are currently evaluating 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 along with necessary system implementations. We do not plan to early adopt the standard. We believe the impact will be material on the consolidated financial statements as all leases will be recognized as a right of use asset and lease obligation. Based on results of our evaluation process to date, we also believe the impact on our existing processes, controls and information systems may be material.

In January 2016, the FASB issued an accounting standards update requiring unconsolidated equity investments, not accounted for under the equity method, to be measured at fair value with changes in fair value recognized in net income. The accounting standards update also requires the use of the exit price notion when measuring the fair value of financial instruments for disclosure purposes and the separate presentation of financial assets and liabilities by measurement category and form on the balance sheet and accompanying notes. The accounting standards update eliminates the requirement to disclose the methods and assumptions used in estimating the fair value of financial instruments measured at amortized cost. Lastly, the accounting standards update requires separate presentation in other comprehensive income of the portion of the total change in the fair value of a liability resulting from a change in the instrument-specific credit risk when electing to measure the liability at fair value in accordance with the fair value option for financial instruments. The changes are effective for fiscal years and interim periods within those fiscal years beginning after December 15, 2017. Early adoption is permitted only for the guidance regarding presentation of a liability’s credit risk. We do not expect application of this accounting standards update to have a material impact on our consolidated financial statements.

In May 2014, the FASB issued an accounting standards update for revenue recognition for contracts with customers. The guidance in the accounting standards update states that revenue is recognized when a customer obtains control of a good or service. Recognition of the revenue will involve a multiple step approach including identifying the contract, identifying the separate performance obligations, determining the transaction price, allocating the price to the performance obligations and recognizing the revenue as the obligations are satisfied. Additional disclosures will be required to provide adequate information to understand the nature, amount, timing and uncertainty of reported revenues and revenues expected to be recognized. We will adopt the standard January 1, 2018, using the modified retrospective method, which will result in a cumulative effect adjustment as of the date of adoption. We are currently evaluating the impact of this standard on our financial statements and disclosures, internal controls and accounting policies. Based on the results to date, we have reached tentative conclusions for most contract types and do not believe revenue recognition patterns will change materially. We do expect certain contracts in our Midstream segment to be presented on a gross revenue recognition basis as a result of implementation. In addition, we expect to elect to change our presentation of consumer excise taxes incurred concurrently with revenue producing transactions from gross to net upon the adoption of this accounting standards update. Based on the results of our evaluation process to date, we do not expect our existing revenue recognition processes, controls and information systems to materially change.

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3. 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. On December 4, 2015, MPLX and MarkWest Energy Partners, L.P. (“MarkWest”) completed a merger, whereby MarkWest became a wholly-owned subsidiary of MPLX (the “MarkWest Merger”). MarkWest’s operations include: natural gas gathering, processing and transportation; and NGL gathering, transportation, fractionation, storage and marketing. MPLX owns or has an interest in a network of private and common carrier crude oil and product pipeline systems and associated storage assets in the Midwest and Gulf Coast regions of the United States, a butane cavern in Neal, West Virginia, and NGL storage caverns in Woodhaven, Michigan. MPLX owns an inland marine business, comprised of tow boats and barges, which transport crude oil and refined products principally for MPC in the Midwest and Gulf Coast regions of the United States. MPLX also owns a light-product terminal business, which provides terminalling services principally for MPC in the Midwest and Southeast regions of the United States.

See Note 4 for information on MPLX’s acquisition of the Ozark pipeline, its investment in the Bakken Pipeline system and the formation of a joint venture with Antero Midstream Partners LP (“Antero Midstream”) during the first quarter of 2017.

As of September 30, 2017, we owned a 30.4 percent interest in MPLX, including a two percent general partner interest. 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 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 69.6 percent interest owned by the public. The components of our noncontrolling interest consist of equity-based noncontrolling interest and redeemable noncontrolling interest. The redeemable noncontrolling interest relates to MPLX’s preferred units, discussed below.

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 21 for more information.

Reorganization Transactions

On September 1, 2016, MPC, MPLX and various affiliates initiated a series of reorganization transactions in order to simplify MPLX’s ownership structure and its financial and tax reporting. In connection with these transactions, MPC contributed $225 million to MPLX and all of the issued and outstanding MPLX Class A Units, all of which were held by MarkWest Hydrocarbon L.L.C. (“MarkWest Hydrocarbon”), a subsidiary of MPLX, were exchanged for newly issued common units representing limited partner interests in MPLX. The simple average of the NYSE closing price of MPLX common units for the 10 trading days preceding September 1, 2016 was used for purposes of these transactions. As a result of these transactions, MPC increased its ownership interest in MPLX by 7 million MPLX common units, or approximately 1 percent.

Private Placement of Preferred Units

On May 13, 2016, MPLX completed the private placement of approximately 30.8 million 6.5 percent Series A Convertible Preferred Units (the “MPLX Preferred Units”) for a cash price of $32.50 per unit. The aggregate net proceeds of approximately $984 million from the sale of the MPLX Preferred Units was used by MPLX for capital expenditures, repayment of debt and general partnership purposes.

The MPLX Preferred Units rank senior to all MPLX common units with respect to distributions and rights upon liquidation. The holders of the MPLX Preferred Units are entitled to receive quarterly distributions equal to $0.528125 per unit commencing for the quarter ended June 30, 2016, with a prorated amount from the date of issuance. Following the second anniversary of the issuance of the MPLX Preferred Units, the holders of the MPLX Preferred Units will receive as a distribution the greater of $0.528125 per unit or the amount of per unit distributions paid to holders of MPLX common units. The MPLX Preferred Units are convertible into MPLX common units on a one for one basis after three years, at the purchasers’ option, and after four years at MPLX’s option, subject to certain conditions.

The MPLX Preferred Units are considered redeemable securities due to the existence of redemption provisions upon a deemed liquidation event which is considered outside MPLX’s control. Therefore, they are presented as temporary equity in the mezzanine section of the consolidated balance sheets. We have recorded the MPLX Preferred Units at their issuance date fair value, net of issuance costs. Since the MPLX Preferred Units are not currently redeemable and not probable of becoming redeemable in the future, adjustment to the initial carrying amount is not necessary and would only be required if it becomes probable that the security would become redeemable.

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Dropdowns to MPLX

On September 1, 2017, we contributed our joint-interest ownership in certain pipelines and storage facilities to MPLX in exchange for total consideration of $1.05 billion. This consideration consisted of MPLX equity and $420 million in cash. We received approximately 19 million MPLX common units and 378 thousand general partner units from MPLX, which was determined by dividing $630 million by the simple average of the 10 day trading volume weighted average NYSE price of an MPLX common unit for the 10 trading days ending at market close on August 31, 2017, pursuant to a Membership Interests and Shares Contributions Agreement. We also agreed to waive 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 total consideration of $2.0 billion. This consideration consisted of MPLX equity and $1.5 billion in cash. We received approximately 13 million MPLX common units and 264 thousand general partner units from MPLX, which was determined by dividing $504 million by the simple average of the volume weighted average NYSE price of an MPLX common unit for the 10 trading days preceding February 28, 2017, pursuant to a Membership Interests Contributions Agreement. 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.

On March 31, 2016, we contributed our inland marine business to MPLX in exchange for 23 million MPLX common units and 460 thousand general partner units. The number of units we received from MPLX was determined by dividing $600 million by the simple average of the volume weighted average NYSE price of an MPLX common unit for the 10 trading days preceding March 14, 2016, pursuant to a Membership Interests Contribution Agreement. We also agreed to waive first-quarter 2016 common unit distributions, IDRs and general partner distributions with respect to the common units issued in this transaction. The contribution of our inland marine business was accounted for as a transaction between entities under common control and we did not record a gain or loss.

Public Offerings

On February 10, 2017, MPLX completed a public offering of $1.25 billion aggregate principal amount of 4.125% unsecured senior notes due March 2027 and $1.0 billion aggregate principal amount of 5.200% unsecured senior notes due March 2047. MPLX used the net proceeds from this offering to fund the $1.5 billion cash portion of the consideration MPLX paid MPC for the dropdown of assets on March 1, 2017, as well as for general partnership purposes. See Note 16 for more information.

ATM Program

On August 4, 2016, MPLX entered into a Second Amended and Restated Distribution Agreement (the “Distribution Agreement”) providing for the continuous issuance of common units, in amounts, at prices and on terms to be determined by market conditions and other factors at the time of any offerings (such continuous offering program, or at-the-market program, referred to as the “ATM Program”). MPLX expects to use the net proceeds from sales under the ATM Program for general partnership purposes including repayment of debt and funding for acquisitions, working capital requirements and capital expenditures.

During the nine months ended September 30, 2017, MPLX issued an aggregate of 14 million MPLX common units under the ATM Program, generating net proceeds of approximately $473 million. As of September 30, 2017, $1.74 billion of MPLX common units remain available for issuance through the ATM Program under the Distribution Agreement.

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Noncontrolling Interest

Changes in MPC’s equity and the offsetting changes to noncontrolling interest resulting from changes in MPC’s and the noncontrolling interest’s ownership interests in MPLX were as follows:



	Nine Months Ended September 30,
(In millions)	2017			2016
Transfers (to) from noncontrolling interest
Increase (decrease) in MPC's additional paid in capital for the issuance of MPLX LP common units to the public	$	25		$	(43	)
Increase in MPC's additional paid in capital for the issuance of MPLX LP common units and general partner units to MPC	113			—
Net transfers (to) from noncontrolling interests	138			(43		)
Tax impact	(26		)	(70		)
Change in MPC's additional paid-in capital, net of tax	$	112		$	(113	)

Agreements

We have various long-term, fee-based transportation, terminal and storage services agreements with MPLX. Under these agreements, MPLX provides transportation, terminal and storage services to us, and we commit to provide MPLX with minimum quarterly throughput volumes on crude oil and refined products systems and minimum storage volumes of crude oil, refined products and butane. 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.

4. 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.

The amounts of revenue and income from operations associated with the acquisition included in our consolidated statements of income, since the March 1, 2017 acquisition date, are as follows:



	Three Months Ended September 30,		Seven Months Ended September 30,
(In millions)	2017		2017
Sales and other operating revenues (including consumer excise taxes)	$	19	$	45
Income from operations	6		17

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.

Formation of Travel Plaza Joint Venture

In the fourth quarter of 2016, Speedway and Pilot Flying J finalized the formation of a joint venture consisting of travel plazas, primarily in the Southeast United States. The new entity, PFJ Southeast LLC (“PFJ Southeast”), originally consisted of 41 existing locations contributed by Speedway and 82 locations contributed by Pilot Flying J, all of which carry either the Pilot or Flying J brand and are operated by Pilot Flying J. We did not recognize a gain on the $273 million non-cash contribution of our travel plazas to the joint venture since the contribution was that of in-substance real estate. Our non-cash contribution consisted of $203 million of property, plant and equipment, $62 million of goodwill and $8 million of inventory.

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Marine Investments

We currently have indirect ownership interests in two ocean vessel joint ventures with Crowley Maritime Corporation (“Crowley”), which were established to own and operate Jones Act vessels in petroleum product service. We have invested a total of $189 million in these two ventures as described further below.

In September 2015, we acquired a 50 percent ownership interest in a joint venture, Crowley Ocean Partners LLC (“Crowley Ocean Partners”), with Crowley. The joint venture owns and operates four new Jones Act product tankers, three of which are leased to MPC. Two of the vessels were delivered in 2015 and the remaining two were delivered in 2016. We have contributed a total of $141 million for the four vessels.

In May 2016, MPC and Crowley formed a new ocean vessel joint venture, Crowley Coastal Partners LLC (“Crowley Coastal Partners”), in which MPC has a 50 percent ownership interest. MPC and Crowley each contributed their 50 percent ownership in Crowley Ocean Partners, discussed above, into Crowley Coastal Partners. In addition, we contributed $48 million in cash and Crowley contributed its 100 percent ownership interest in Crowley Blue Water Partners LLC (“Crowley Blue Water Partners”) to Crowley Coastal Partners. Crowley Blue Water Partners is an entity that owns and operates three 750 Series ATB vessels that are leased to MPC. We account for our 50 percent interest in Crowley Coastal Partners as part of our Midstream segment using the equity method of accounting.

See Note 5 for information on Crowley Coastal Partners as a VIE and Note 21 for information on our conditional guarantee of the indebtedness of Crowley Ocean Partners and Crowley Blue Water Partners.

Investment in Pipeline Company

On February 15, 2017, MPLX closed on the previously announced transaction to acquire 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 currently expected to deliver in excess of 470 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. In connection with this investment by MPLX, we have agreed to waive our right to receive IDRs of approximately $1.6 million per quarter for twelve consecutive quarters beginning with distributions declared by MPLX in the first quarter of 2017 and paid to us in the second quarter, which has been prorated to $0.8 million from the acquisition date. We account for the investment in MarEn Bakken as part of our Midstream segment using the equity method of accounting.

In connection with closing the transaction with ETP and SXL and the previous decision to indefinitely suspend the Sandpiper project, Enbridge Energy Partners canceled MPC’s transportation services agreement with respect to the Sandpiper pipeline and released MPC from paying any termination fee per that agreement.

Formation of Gathering and Processing Joint Venture

Effective January 1, 2017, MarkWest 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. MarkWest has a 50 percent ownership interest in Sherwood Midstream. In connection with this transaction, MarkWest 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, MarkWest 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, MarkWest 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 MarkWest. MarkWest 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

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percent ownership interest. MarkWest 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, MarkWest only recognized a gain for the portion attributable to Antero Midstream’s indirect interest of approximately $2 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 5 for additional information related to the investments in Sherwood Midstream, Ohio Fractionation and Sherwood Midstream Holdings.

5. Variable Interest Entities

In addition to MPLX, as described in Note 3, 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 September 30, 2017 was $493 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.

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 September 30, 2017, 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 September 30, 2017 was $2.2 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 September 30, 2017, 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 4, MarkWest 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 September 30, 2017, MarkWest 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. MarkWest 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 September 30, 2017 was $220 million.

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Ohio Fractionation

As described in Note 4, MarkWest 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. MarkWest 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 4, MarkWest 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 MarkWest. MarkWest 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 September 30, 2017 was $163 million.

6. 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.


•	Explorer Pipeline Company (“Explorer”), in which we have a 25 percent interest. Explorer owns and operates a refined products pipeline.


•	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 86 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.

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Sales to related parties were as follows:



	Three Months Ended September 30,				Nine Months Ended September 30,
(In millions)	2017		2016		2017		2016
PFJ Southeast	$	155	$	—	$	451	$	—
Other equity method investees	2		2		7		5
Total	$	157	$	2	$	458	$	5

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 September 30,				Nine Months Ended September 30,
(In millions)	2017		2016		2017		2016
MarkWest Utica EMG	$	5	$	5	$	13	$	12
Ohio Gathering	4		5		12		12
Other equity method investees	4		2		14		7
Total	$	13	$	12	$	39	$	31

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 September 30,				Nine Months Ended September 30,
(In millions)	2017		2016		2017		2016
Crowley Blue Water Partners	$	16	$	16	$	44	$	22
Crowley Ocean Partners	20		15		59		32
Explorer	7		4		7		12
Illinois Extension Pipeline	26		27		75		82
LOCAP	6		6		17		18
LOOP	14		14		53		42
TAAE	22		9		53		29
TACE	9		10		34		39
TAME	20		23		58		67
Other equity method investees	8		4		20		16
Total	$	148	$	128	$	420	$	359

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 Explorer consist primarily of refined product transportation costs. 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.

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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)	September 30, 2017		December 31, 2016
MarkWest Utica EMG	$	2	$	2
Ohio Gathering	2		2
PFJ Southeast	32		40
Other equity method investees	4		1
Total	$	40	$	45

The long-term receivable, which is included in “Other noncurrent assets” on the accompanying consolidated balance sheet, was $1 million at September 30, 2017 and $1 million at December 31, 2016.

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



(In millions)	September 30, 2017		December 31, 2016
Illinois Extension Pipeline	$	9	$	9
LOCAP	2		2
LOOP	5		6
MarkWest Utica EMG	30		24
TAAE	2		2
TACE	1		4
TAME	2		4
Other equity method investees	13		2
Total	$	64	$	53

7. 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.

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	Three Months Ended September 30,				Nine Months Ended September 30,
(In millions, except per share data)	2017		2016		2017		2016
Basic earnings per share:
Allocation of earnings:
Net income attributable to MPC	$	903	$	145	$	1,416	$	947
Income allocated to participating securities	—		—		1		1
Income available to common stockholders – basic	$	903	$	145	$	1,415	$	946
Weighted average common shares outstanding	504		527		514		528
Basic earnings per share	$	1.79	$	0.28	$	2.75	$	1.79
Diluted earnings per share:
Allocation of earnings:
Net income attributable to MPC	$	903	$	145	$	1,416	$	947
Income allocated to participating securities	—		—		1		1
Income available to common stockholders – diluted	$	903	$	145	$	1,415	$	946
Weighted average common shares outstanding	504		527		514		528
Effect of dilutive securities	4		3		4		3
Weighted average common shares, including dilutive effect	508		530		518		531
Diluted earnings per share	$	1.77	$	0.27	$	2.73	$	1.78

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



	Three Months Ended September 30,		Nine Months Ended September 30,
(In millions)	2017	2016	2017	2016
Shares issued under stock-based compensation plans	1	3	1	3

8. Equity

On May 31, 2017, our board of directors approved an additional $3.0 billion share repurchase authorization. This authorization is in addition to its previous authorization, both of which have no expiration date.

As of September 30, 2017, we had $3.94 billion of remaining share repurchase authorization 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 affected 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 for the three and nine months ended September 30, 2017 and 2016:



	Three Months Ended September 30,				Nine Months Ended September 30,
(In millions, except per share data)	2017		2016		2017		2016
Number of shares repurchased	8		1		31		4
Cash paid for shares repurchased	$	452	$	51	$	1,622	$	177
Effective average cost per delivered share	$	53.85	$	42.76	$	52.16	$	41.14

As of September 30, 2017, we had agreements to acquire 985,400 common shares for $55 million, which were settled in early October 2017.

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9. Segment Information

In the first quarter of 2017, we revised our segment reporting in connection with the contribution of certain terminal, pipeline and storage assets to MPLX. The operating results for these assets are now reported in our Midstream segment. Previously, they were reported as part of our Refining & Marketing segment. Comparable prior period information has been recast to reflect our revised presentation. The results for the pipeline and storage assets were recast effective January 1, 2015, and the results for the terminal assets were recast effective April 1, 2016. Prior to these dates, these assets were not considered businesses and, therefore, there are no financial results from which to recast segment results.

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 seven refineries in the Gulf Coast and Midwest regions of the United States, purchases refined products and ethanol for resale and distributes refined products through various means, including pipeline and marine transportation, terminal and storage 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 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 – includes the operations of MPLX and certain other related operations. The Midstream segment gathers, processes and transports natural gas; gathers, transports, fractionates, stores and markets NGLs; and transports and stores crude oil and refined products principally for the Refining & Marketing segment.

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.



(In millions)	Refining & Marketing		Speedway		Midstream		Total
Three Months Ended September 30, 2017
Revenues:
Third party	$	13,573	$	4,895	$	585	$	19,053
Intersegment^(a)	2,904		1		369		3,274
Related party	155		2		—		157
Segment revenues	$	16,632	$	4,898	$	954	$	22,484
Segment income from operations^(b)	$	1,097	$	209	$	355	$	1,661
Income from equity method investments	6		20		57		83
Depreciation and amortization^(c)	266		68		169		503
Capital expenditures and investments^(d)	198		108		453		759



(In millions)	Refining & Marketing		Speedway		Midstream		Total
Three Months Ended September 30, 2016
Revenues:
Third party	$	11,284	$	4,848	$	484	$	16,616
Intersegment^(a)	2,798		1		346		3,145
Related party	2		—		—		2
Segment revenues	$	14,084	$	4,849	$	830	$	19,763
Segment income from operations^(b)	$	252	$	209	$	310	$	771
Income from equity method investments^(c)	8		—		51		59
Depreciation and amortization^(c)	267		71		155		493
Capital expenditures and investments^(d)	251		71		410		732

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(In millions)	Refining & Marketing		Speedway		Midstream		Total
Nine Months Ended September 30, 2017
Revenues:
Third party	$	37,485	$	14,070	$	1,665	$	53,220
Intersegment^(a)	8,302		3		1,076		9,381
Related party	452		6		—		458
Segment revenues	$	46,239	$	14,079	$	2,741	$	63,059
Segment income from operations^(b)	$	1,589	$	583	$	996	$	3,168
Income from equity method investments	10		54		139		203
Depreciation and amortization^(c)	805		197		528		1,530
Capital expenditures and investments^(d)(e)	570		221		2,017		2,808



(In millions)	Refining & Marketing		Speedway		Midstream		Total
Nine Months Ended September 30, 2016
Revenues:
Third party	$	31,192	$	13,663	$	1,324	$	46,179
Intersegment^(a)	7,872		2		911		8,785
Related party	5		—		—		5
Segment revenues	$	39,069	$	13,665	$	2,235	$	54,969
Segment income from operations^(b)(f)	$	1,191	$	569	$	752	$	2,512
Income from equity method investments^(c)	10		—		110		120
Depreciation and amortization^(c)	801		203		448		1,452
Capital expenditures and investments^(d)	756		191		1,179		2,126


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


^(b)	Corporate overhead expenses attributable to MPLX are included in the Midstream segment. Corporate overhead expenses are not allocated to the Refining & Marketing and Speedway segments.


^(c)	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.


^(d)	Capital expenditures include changes in capital accruals, acquisitions (including any goodwill) and investments in affiliates.


^(e)	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 nine months ended September 30, 2017.


^(f)	The Refining & Marketing and Speedway segments include inventory LCM benefits of $345 million and $25 million, respectively, for the nine months ended September 30, 2016.

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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 September 30,						Nine Months Ended September 30,
(In millions)	2017			2016			2017			2016
Segment income from operations	$	1,661		$	771		$	3,168		$	2,512
Items not allocated to segments:
Corporate and other unallocated items^(a)	(86		)	(65		)	(251		)	(194		)
Pension settlement expenses	(1		)	(4		)	(2		)	(7		)
Litigation^(b)	—			—			(86		)	—
Impairments^(c)	2			(267		)	21			(486		)
Net interest and other financial income (costs)	(157		)	(141		)	(465		)	(420		)
Income before income taxes	$	1,419		$	294		$	2,385		$	1,405


^(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.


^(b)	See Note 21 for further information on litigation matters.


^(c)	2017 includes MPC’s share of gains related to the sale of assets remaining from the Sandpiper pipeline project. 2016 relates to impairments of goodwill and equity method investments.

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



	Three Months Ended September 30,				Nine Months Ended September 30,
(In millions)	2017		2016		2017		2016
Segment capital expenditures and investments	$	759	$	732	$	2,808	$	2,126
Less investments in equity method investees^(a)	53		69		730		383
Plus items not allocated to segments:
Corporate and Other	19		14		53		59
Capitalized interest	13		15		39		47
Total capital expenditures^(b)	$	738	$	692	$	2,170	$	1,849


^(a)	The nine months ended September 30, 2017 includes an investment of $500 million in MarEn Bakken related to the Bakken Pipeline system. The nine months ended September 30, 2016 includes an adjustment of $143 million to the fair value of equity method investments acquired in connection with the MarkWest Merger.


^(b)	Capital expenditures include changes in capital accruals. See Note 17 for a reconciliation of total capital expenditures to additions to property, plant and equipment as reported in the consolidated statements of cash flows.

10. Other Items

Net interest and other financial income (costs) was:



	Three Months Ended September 30,						Nine Months Ended September 30,
(In millions)	2017			2016			2017			2016
Interest income	$	7		$	3		$	16		$	5
Interest expense	(172		)	(153		)	(508		)	(455		)
Interest capitalized	14			15			47			47
Other financial costs	(6		)	(6		)	(20		)	(17		)
Net interest and other financial income (costs)	$	(157	)	$	(141	)	$	(465	)	$	(420	)

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11. Income Taxes

The combined federal, state and foreign income tax rate was 29 percent and 26 percent for the three months ended September 30, 2017 and 2016, respectively, and 30 percent and 34 percent for the nine months ended September 30, 2017 and 2016, respectively. The effective tax rate for the three and nine months ended September 30, 2017 was less than the U.S. statutory rate of 35 percent primarily due to certain permanent tax differences related to net income attributable to noncontrolling interests, the domestic manufacturing deduction and equity compensation offset by state and local tax expense. The effective tax rate for the three months ended September 30, 2016 varies from the U.S. statutory rate of 35 percent primarily due to the effects of a lower forecasted annual effective tax rate as compared to the forecasted rate used for the first six months of 2016. The effective tax rate for the nine months ended September 30, 2016 is slightly less than the U.S. statutory rate of 35 percent primarily due to certain permanent tax differences related to the net income attributable to noncontrolling interests (including their proportional share of the goodwill impairment charge recorded by MPLX), the domestic manufacturing deduction and 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 September 30, 2017, we had $19 million of unrecognized tax benefits.

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 partnership transactions. Marathon Oil intends to file 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 the Marathon Oil IRS dispute discussed above. We intend to file a U.S. Tax Court petition in the fourth quarter of 2017 for tax years 2011-2014 to dispute these corollary adjustments. 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 21 for indemnification information.

12. Inventories



(In millions)	September 30, 2017		December 31, 2016
Crude oil and refinery feedstocks	$	2,147	$	2,208
Refined products	2,706		2,810
Materials and supplies	486		485
Merchandise	154		153
Total	$	5,493	$	5,656

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 liquidations of LIFO inventories for the nine months ended September 30, 2017.

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13. Property, Plant and Equipment



(In millions)	September 30, 2017		December 31, 2016^(a)
Refining & Marketing	$	19,174	$	18,590
Speedway	5,233		5,078
Midstream	14,489		13,521
Corporate and Other	822		817
Total	39,718		38,006
Less accumulated depreciation	13,682		12,241
Property, plant and equipment, net	$	26,036	$	25,765


^(a)	Prior period balances have been recast in connection with the March 1, 2017 contribution of assets to MPLX. See Note 1for additional information.

14. Fair Value Measurements

Fair Values—Recurring

The following tables present assets and liabilities accounted for at fair value on a recurring basis as of September 30, 2017 and December 31, 2016 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.



	September 30, 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	$	257	$	—	$	—	$	(257	)	$	—	$	22
Other assets	3		—		—		N/A			3		—
Total assets at fair value	$	260	$	—	$	—	$	(257	)	$	3	$	22

Commodity derivative instruments, liabilities^(c)	$	296	$	—	$	5	$	(296	)	$	5	$	—
Embedded derivatives in commodity contracts^(c)	—		—		52		—			52		—
Total liabilities at fair value	$	296	$	—	$	57	$	(296	)	$	57	$	—

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	December 31, 2016
	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	$	688	$	—	$	—	$	(688	)	$	—	$	126
Other assets	2		—		—		N/A			2		—
Total assets at fair value	$	690	$	—	$	—	$	(688	)	$	2	$	126

Commodity derivative instruments, liabilities	$	712	$	—	$	6	$	(712	)	$	6	$	—
Embedded derivatives in commodity contracts^(c)	—		—		54		—			54		—
Contingent consideration, liability^(d)	—		—		130		N/A			130		—
Total liabilities at fair value	$	712	$	—	$	190	$	(712	)	$	190	$	—


^(a)	Represents the impact of netting assets, liabilities and cash collateral when a legal right of offset exists. As of September 30, 2017, cash collateral of $39 million was netted with the mark-to-market derivative liabilities. As of December 31, 2016, $24 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 $15 million and $13 million classified as current at September 30, 2017 and December 31, 2016, respectively.


^(d)	Includes $130 million classified as current at December 31, 2016.

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 include 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 $0.27 to $1.22 per gallon and (2) the probability of renewal of 50 percent for the first five-year term and 75 percent for the second five-year term of the 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.

The contingent consideration represents the fair value of the remaining amount we expected to pay to BP related to the earnout provision associated with our 2013 acquisition of BP’s refinery in Texas City, Texas and related logistics and marketing assets. The fair value of the remaining contingent consideration as of December 31, 2016 was estimated using an income approach and was therefore a Level 3 liability. The fair value calculation used significant unobservable inputs including: (1) an estimate of forecasted monthly refinery throughput volumes; (2) an internal and external monthly crack spread forecast; and (3) a range of risk-adjusted discount rates. The fair value of the contingent consideration liability was reassessed each quarter, with changes in fair value recorded in cost of revenues. The balance of $131 million was paid on April 12, 2017. On the consolidated statements of cash flows for the nine months ended September 30, 2017, $89 million of the contingent earnout payment is included as a financing activity with the remainder included as an operating activity.

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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 September 30,						Nine Months Ended September 30,
(In millions)	2017			2016			2017			2016
Beginning balance	$	41		$	171		$	190		$	342
Contingent consideration payment	—			—			(131		)	(200		)
Unrealized and realized losses included in net income	22			6			8			33
Settlements of derivative instruments	(6		)	(1		)	(10		)	1
Ending balance	$	57		$	176		$	57		$	176

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	$	17		$	4		$	8		$	19
Contingent consideration agreement	—			2			1			11
Total	$	17		$	6		$	9		$	30

Fair Values – Reported

The following table summarizes financial instruments on the basis of their nature, characteristics and risk at September 30, 2017 and December 31, 2016, excluding the derivative financial instruments and contingent consideration reported above.



	September 30, 2017				December 31, 2016
(In millions)	Fair Value		Carrying Value		Fair Value		Carrying Value
Financial assets:
Investments	$	25	$	2	$	25	$	2
Other	25		25		21		21
Total financial assets	$	50	$	27	$	46	$	23
Financial liabilities:
Long-term debt^(a)	$	13,690	$	12,544	$	10,892	$	10,297
Deferred credits and other liabilities	121		107		121		109
Total financial liabilities	$	13,811	$	12,651	$	11,013	$	10,406


^(a)	Excludes capital leases and debt issuance costs; however, 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. We believe the carrying values of our current assets and liabilities approximate fair value. Our fair value assessment incorporates a variety of considerations, including (1) the short-term duration of the instruments, (2) our investment-grade credit rating and (3) our historical incurrence of and expected future insignificance of bad debt expense, which includes an evaluation of counterparty credit risk.

Fair values of our financial assets included in investments and other 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. Other financial assets primarily consist of environmental remediation receivables. Deferred credits and other liabilities primarily consist of a liability resulting from a financing arrangement for the construction of MPLX’s steam methane reformer (“SMR”) 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 a market approach, based upon the average of quotes for our debt from major financial institutions and a third-party valuation service. Because these quotes cannot be independently verified to the market, they are considered Level 3 inputs. Fair value of variable-rate long-term debt approximates the carrying value.

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15. Derivatives

For further information regarding the fair value measurement of derivative instruments, including any effect of master netting agreements or collateral, see Note 14. 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 gross fair values of derivative instruments, excluding cash collateral, and where they appear on the consolidated balance sheets as of September 30, 2017 and December 31, 2016:



(In millions)	September 30, 2017
Balance Sheet Location	Asset		Liability
Commodity derivatives
Other current assets	$	257	$	296
Other current liabilities^(a)	—		15
Deferred credits and other liabilities^(a)	—		42



(In millions)	December 31, 2016
Balance Sheet Location	Asset		Liability
Commodity derivatives
Other current assets	$	688	$	712
Other current liabilities^(a)	—		13
Deferred credits and other liabilities^(a)	—		47


^(a)	Includes embedded derivatives.

The tables below summarize open commodity derivative contracts for crude oil and refined products as of September 30, 2017.



	Position	Total Barrels (In thousands)
Crude Oil^(a)
Exchange-traded	Long	33,043
Exchange-traded	Short	(34,428	)


^{(a )}	94 percent of the exchange-traded contracts expire in the fourth quarter of 2017.



	Position	Total Gallons (In thousands)
Refined Products^(a)
Exchange-traded	Long	316,764
Exchange-traded	Short	(227,388	)
OTC	Short	(33,388	)


^{(a )}	100 percent of the exchange-traded contracts expire in the fourth quarter of 2017.

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



	Gain (Loss)						Gain (Loss)
(In millions)	Three Months Ended September 30,						Nine Months Ended September 30,
Income Statement Location	2017			2016			2017			2016
Sales and other operating revenues	$	(10	)	$	(3	)	$	8		$	(4	)
Cost of revenues	1			(20		)	(30		)	(91		)
Total	$	(9	)	$	(23	)	$	(22	)	$	(95	)

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16. Debt

Our outstanding borrowings at September 30, 2017 and December 31, 2016 consisted of the following:



(In millions)	September 30, 2017			December 31, 2016
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	—			—
Term loan agreement due 2019	—			200
Senior notes, 2.700% due December 2018	600			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
MPLX LP:
MPLX term loan facility due 2019	—			250
MPLX bank revolving credit facility due 2022	420			—
MPLX senior notes, 5.500%, due February 2023	710			710
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			—
MPLX senior notes, 5.200%, due March 2047	1,000			—
Capital lease obligations due 2017-2028	299			319
Total	13,269			11,069
Unamortized debt issuance costs	(61		)	(44		)
Unamortized discount^(a)	(426		)	(453		)
Amounts due within one year	(29		)	(28		)
Total long-term debt due after one year	$	12,753		$	10,544


^(a)	Includes $386 million and $420 million of unamortized discount as of September 30, 2017 and December 31, 2016, respectively, related to the difference between the fair value and the principal amount of assumed MarkWest debt.

During the nine months ended September 30, 2017, we borrowed and repaid $300 million under the commercial paper program. At September 30, 2017, we had no amounts outstanding under the commercial paper program.

At September 30, 2017, we had no amounts outstanding under our trade receivables securitization facility.

MPC Bank Revolving Credit Facilities

On July 21, 2017, we entered into credit agreements with a syndicate of lenders to replace MPC’s previous $2.5 billion four-year bank revolving credit facility and $1 billion 364-day revolving credit facility. The new credit agreements provide for a $2.5 billion five-year bank revolving credit facility that expires in July 2022 and a $1 billion 364-day bank revolving credit facility that expires in July 2018. The financial covenants and the interest rate terms contained in the new credit agreements are substantially the same as those contained in the previous bank revolving credit facilities.

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There were no borrowings or letters of credit outstanding under the MPC bank revolving credit facility at September 30, 2017.

MPC Term Loan Agreement

On March 31, 2017, we repaid the remaining $200 million outstanding under the MPC term loan agreement with available cash on hand. Under the provisions of the MPC term loan agreement, the loan may be prepaid in whole or in part without premium or penalty. The maturity date of the MPC term loan agreement was September 24, 2019.

MPLX Credit Agreement

On July 21, 2017, MPLX entered into a credit agreement to replace its previous $2 billion five-year bank revolving credit facility with a $2.25 billion five-year bank revolving credit facility that expires in July 2022. The financial covenants and the interest rate terms contained in the new credit agreement are substantially the same as those contained in the previous bank revolving credit facility.

Additionally, on July 19, 2017, MPLX prepaid the entire outstanding principal amount of its $250 million term loan with cash on hand.

During the nine months ended September 30, 2017, MPLX borrowed $420 million under the MPLX bank revolving credit facility, at an average interest rate of 2.7 percent, and made no repayments. At September 30, 2017, MPLX had $420 million outstanding borrowings and $3 million letters of credit outstanding under the MPLX bank revolving credit facility, resulting in total availability of $1.83 billion.

MPLX Senior Notes

On February 10, 2017, MPLX completed a public offering of $1.25 billion aggregate principal amount of 4.125% unsecured senior notes due March 2027 and $1.0 billion aggregate principal amount of 5.200% unsecured senior notes due March 2047. The net proceeds, which were approximately $2.22 billion after deducting underwriting discounts, were used by MPLX to fund the $1.5 billion cash portion of the consideration paid to MPC for the dropdown of assets on March 1, 2017, as well as for general partnership purposes. Interest is payable semi-annually in arrears on March 1 and September 1 of each year, commencing on September 1, 2017.

17. Supplemental Cash Flow Information



	Nine Months Ended September 30,
(In millions)	2017		2016
Net cash provided by operating activities included:
Interest paid (net of amounts capitalized)	$	446	$	400
Net income taxes paid to (refunded from) taxing authorities	383		28
Non-cash investing and financing activities:
Contribution of assets to joint venture^(a)	337		—


^(a)	MarkWest’s contribution of assets to Sherwood Midstream and Sherwood Midstream Holdings. See Note 4.

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:



	Nine Months Ended September 30,
(In millions)	2017			2016
Additions to property, plant and equipment per consolidated statements of cash flows	$	1,928		$	2,147
Asset retirement expenditures	1			4
Decrease in capital accruals	(9		)	(169		)
Total capital expenditures before acquisitions	1,920			1,982
Acquisitions^(a)	250			(133		)
Total capital expenditures	$	2,170		$	1,849


^(a)	The nine months ended September 30, 2017 reflects primarily the acquisition of the Ozark pipeline. The nine months ended September 30, 2016 reflects adjustments to the fair values of the property, plant and equipment, intangibles and goodwill acquired in connection with the MarkWest Merger.

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18. 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, 2015	$	(255	)	$	(70	)	$	4	$	3		$	(318	)
Other comprehensive income (loss) before reclassifications	(8		)	1			—		—			(7		)
Amounts reclassified from accumulated other comprehensive loss:
Amortization – prior service credit^(a)	(35		)	(2		)	—		—			(37		)
– actuarial loss^(a)	28			1			—		—			29
– settlement loss^(a)	7			—			—		—			7
Other^(b)	—			—			—		(1		)	(1		)
Tax effect	—			—			—		—			—
Other comprehensive income (loss)	(8		)	—			—		(1		)	(9		)
Balance as of September 30, 2016	$	(263	)	$	(70	)	$	4	$	2		$	(327	)



(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 income (loss) before reclassifications	(2		)	—			—		—			(2		)
Amounts reclassified from accumulated other comprehensive loss:
Amortization – prior service credit^(a)	(29		)	(2		)	—		—			(31		)
– actuarial loss/(gain)^(a)	27			(1		)	—		—			26
– settlement loss^(a)	2			—			—		—			2
Other^(b)	—			—			—		(2		)	(2		)
Tax effect	—			1			—		1			2
Other comprehensive income (loss)	(2		)	(2		)	—		(1		)	(5		)
Balance as of September 30, 2017	$	(235	)	$	(9	)	$	4	$	1		$	(239	)


^(a)	These accumulated other comprehensive loss components are included in the computation of net periodic benefit cost. See Note 19.


^(b)	This amount was reclassified out of accumulated other comprehensive loss and is included in selling, general and administrative on the consolidated statements of income.

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19. Defined Benefit Pension and Other Postretirement Plans

The following summarizes the components of net periodic benefit costs:



	Three Months Ended September 30,
	Pension Benefits						Other Benefits
(In millions)	2017			2016			2017		2016
Components of net periodic benefit cost:
Service cost	$	33		$	29		$	6	$	8
Interest cost	19			18			8		9
Expected return on plan assets	(25		)	(24		)	—		—
Amortization – prior service credit	(10		)	(12		)	—		(1		)
– actuarial loss	9			10			—		—
– settlement loss	1			4			—		—
Net periodic benefit cost	$	27		$	25		$	14	$	16



	Nine Months Ended September 30,
	Pension Benefits						Other Benefits
(In millions)	2017			2016			2017			2016
Components of net periodic benefit cost:
Service cost	$	99		$	86		$	19		$	24
Interest cost	56			55			23			26
Expected return on plan assets	(75		)	(73		)	—			—
Amortization – prior service credit	(29		)	(35		)	(2		)	(2		)
– actuarial loss/(gain)	27			28			(1		)	1
– settlement loss	2			7			—			—
Net periodic benefit cost	$	80		$	68		$	39		$	49

During the nine months ended September 30, 2017, we chose to make a $120 million voluntary contribution to our funded pension plans. Benefit payments related to unfunded pension and other postretirement benefit plans were $7 million and $23 million, respectively, during the nine months ended September 30, 2017.

20. Stock-Based Compensation Plans

Stock Option Awards

The following table presents a summary of our stock option award activity for the nine months ended September 30, 2017:



	Number of Shares		Weighted Average Exercise Price
Outstanding at December 31, 2016	9,531,440		$	28.93
Granted	1,214,112		50.57
Exercised	(1,356,217	)	21.89
Forfeited, canceled or expired	(78,386	)	41.97
Outstanding at September 30, 2017	9,310,949		32.66

The grant date fair value of stock option awards granted during the nine months ended September 30, 2017 was $13.42 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 Awards

The following table presents a summary of restricted stock award activity for the nine months ended September 30, 2017:



	Shares of Restricted Stock (“RS”)				Restricted Stock Units (“RSU”)
	Number of Shares		Weighted Average Grant Date Fair Value		Number of Units		Weighted Average Grant Date Fair Value
Outstanding at December 31, 2016	1,250,343		$	41.51	361,117		$	28.26
Granted	574,602		50.20		28,573		51.94
RS’s Vested/RSU’s Issued	(522,454	)	42.48		(79,635	)	24.54
Forfeited	(83,806	)	44.29		(13,750	)	50.20
Outstanding at September 30, 2017	1,218,685		45.00		296,305		30.52

Performance Unit Awards

The following table presents a summary of the activity for performance unit awards to be settled in shares for the nine months ended September 30, 2017:



	Number of Units		Weighted Average Grant Date Fair Value
Outstanding at December 31, 2016	6,255,178		$	0.78
Granted	2,584,750		0.92
Exercised	(1,854,728	)	0.85
Canceled	(99,658	)	0.78
Outstanding at September 30, 2017	6,885,542		0.81

The performance unit awards granted during the nine months ended September 30, 2017 have a grant date fair value of $0.92 per unit, as calculated using a Monte Carlo valuation model.

MPLX Awards

During the nine months ended September 30, 2017, MPLX granted equity-based compensation awards under the MPLX LP 2012 Incentive Compensation Plan. The compensation expense for these awards is not material to our consolidated financial statements.

21. 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 September 30, 2017 and December 31, 2016, accrued liabilities for remediation totaled $117 million and $132 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 $45 million and $58 million at September 30, 2017 and December 31, 2016, respectively.

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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.

MarkWest Environmental Proceeding – In July 2015, representatives from the EPA and the United States Department of Justice conducted a raid on a pipeline launcher/receiver site of MarkWest Liberty Midstream & Resources, L.L.C., a wholly-owned subsidiary of MPLX (“MarkWest Liberty Midstream”), utilized for pipeline maintenance operations in Washington County, Pennsylvania pursuant to a search warrant issued by a magistrate of the United States District Court for the Western District of Pennsylvania. As part of this initiative, the U.S. Attorney’s Office for the Western District of Pennsylvania, with the assistance of EPA’s Criminal Investigation Division proceeded with an investigation of MarkWest’s launcher/receiver, pipeline and compressor station operations. In response to the investigation, MarkWest initiated independent studies which demonstrated that there was no risk to worker safety and no threat of public harm associated with MarkWest Liberty Midstream’s launcher/receiver operations. These findings were supported by a subsequent inspection and review by the Occupational Safety and Health Administration. After providing these studies, and other substantial documentation related to MarkWest Liberty Midstream's pipeline and compressor stations, and arranging site visits and conducting several meetings with the government’s representatives, on September 13, 2016, the U.S. Attorney’s Office for the Western District of Pennsylvania rendered a declination decision, dropping its criminal investigation and declining to pursue charges in this matter.

MarkWest Liberty Midstream continues to discuss with the EPA and the State of Pennsylvania civil enforcement allegations associated with permitting or other related regulatory obligations for its launcher/receiver and compressor station facilities in the region. In connection with these discussions, MarkWest Liberty Midstream received an initial proposal from the EPA to settle all civil claims associated with this matter for the combination of a proposed cash penalty of approximately $2.4 million and proposed supplemental environmental projects with an estimated cost of approximately $3.6 million. MarkWest Liberty Midstream has submitted a response asserting that this action involves novel issues surrounding primarily minor source emissions from facilities that the agencies themselves considered de minimis and were not the subject of regulation and consequently that the settlement proposal is excessive. In connection with these negotiations, MarkWest Liberty Midstream has received a revised settlement proposal from the EPA which proposes to lower the proposed cash penalty to approximately $1.2 million and the estimated cost of proposed supplemental environmental projects to an estimated cost of approximately $1.6 million. MarkWest Liberty Midstream will continue to negotiate with the EPA regarding the amount and scope of the proposed settlement.

Other Lawsuits—On August 1, 2017, we entered into binding settlement agreements with the plaintiffs and co-defendants to settle four lawsuits brought forth by the plaintiffs alleging personal injuries from a fire that occurred at our Galveston Bay refinery on January 11, 2016. The other co-defendants in this litigation were contractors that were engaged by us to provide services at our Galveston Bay refinery. We recorded a liability for our losses under the settlement agreements which resulted in a charge of $86 million in the second quarter of 2017. We are vigorously pursuing recovery of such losses, as well as defense costs, through indemnification from a significant contractor who is not party to the settlement agreements.

In May 2015, the Kentucky attorney general filed a lawsuit against our wholly-owned subsidiary, 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 early 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 million during 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

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operations, financial position or cash flows. However, management does not believe the ultimate resolution of this litigation will have a material adverse effect.

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 $160 million as of September 30, 2017.

We hold an interest in a refined products pipeline through our investment in Centennial, and have guaranteed our portion of the payment of Centennial’s principal, interest and prepayment costs, if applicable, under a Master Shelf Agreement, which is scheduled to expire in 2024. The guarantee arose in order for Centennial to obtain adequate financing. Our maximum potential undiscounted payments under this agreement for debt principal totaled $22 million as of September 30, 2017.

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 September 30, 2017, our maximum potential undiscounted payments under this agreement for debt principal totaled $163 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. The maximum exposure under these arrangements is 50 percent of the amount of the debt, which was $139 million as of September 30, 2017.

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 $2 million as of September 30, 2017, 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 $93 million as of September 30, 2017, which primarily consist of a commitment to contribute cash to an equity method investee for certain catastrophic events, up to $50 million per event, 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.

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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 September 30, 2017, our contractual commitments to acquire property, plant and equipment and advance funds to equity method investees totaled $694 million.

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. As of September 30, 2017, management does not believe there are any indications that we will not be able to meet the construction milestones, that force majeure does not apply, or that such fees and charges will otherwise be triggered.

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Item 2: Management’s Discussion and Analysis of Financial Condition and Results of Operations

Management’s Discussion and Analysis of Financial Condition and Results of Operations should 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, 2016.

Management’s Discussion and Analysis of Financial Condition and Results of Operations includes various forward-looking statements concerning trends or events potentially affecting our business. You can identify our forward-looking statements by words such as “anticipate,” “believe,” “design,” “estimate,” “objective,” “expect,” “forecast,” “outlook,” “goal,” “guidance,” “imply,” “intend,” “plan,” “predict,” “prospective,” “project,” “opportunity,” “potential,” “position,” “pursue,” “strategy,” “seek,” “target,” “could,” “may,” “should,” “would,” “will” 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, which could cause future outcomes to differ materially from those set forth in forward-looking statements. For additional risk factors affecting our business, see Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended December 31, 2016.

Corporate Overview

We are an independent petroleum refining and marketing, retail and midstream services company. We currently own and operate seven refineries, all located in the United States, with an aggregate crude oil refining capacity of approximately 1.8 million barrels per calendar day. We are in the process of fully integrating two of our refineries, Galveston Bay and Texas City, into one complex called the Galveston Bay Refinery. We expect to complete this integration by the end of this year. Our refineries supply refined products to resellers and consumers within our market areas, including the Midwest, Gulf Coast, Northeast, East Coast and Southeast regions of the United States. We are one of the largest wholesale suppliers of gasoline and distillates to resellers within our market area.

We have two strong retail brands: Speedway^® and Marathon^®. We believe that Speedway LLC, a wholly-owned subsidiary, operates the second largest chain of company-owned and operated retail gasoline and convenience stores in the United States, with approximately 2,730 convenience stores in 21 states throughout the Midwest, East Coast and Southeast. The Marathon brand is an established motor fuel brand in the Midwest and Southeast regions of the United States, and is available through approximately 5,600 retail outlets operated by independent entrepreneurs in 20 states and the District of Columbia.

Through our ownership interests in MPLX and its wholly-owned subsidiary, MarkWest, we believe we are one of the largest processors of natural gas in the United States, the largest processor and fractionator in the Marcellus and Utica shale regions and we distribute refined products through one of the largest private domestic fleets of inland petroleum product barges. Our integrated midstream energy asset 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. Our assets include approximately 5.9 bcf/d of gathering capacity, 7.8 bcf/d of natural gas processing capacity and 570 mbpd of fractionation capacity. We own, lease or have ownership interests in approximately 10,800 miles of crude oil and refined product pipelines, an inland marine business and one of the largest light product terminal operations in the United States to deliver crude oil to our refineries and other locations and refined products from our refineries to wholesale and retail market areas.

In the first quarter of 2017, we revised our segment reporting in connection with the contribution of certain terminal, pipeline and storage assets to MPLX. The operating results for these assets are now reported in our Midstream segment. Previously, they were reported as part of our Refining & Marketing segment. Comparable prior period information has been recast to reflect our revised presentation. The results for the pipeline and storage assets were recast effective January 1, 2015 and the results for the terminal assets were recast effective April 1, 2016. Prior to these dates, these assets were not considered businesses for accounting purposes and, therefore, there are no financial results from which to recast segment results.

Our operations consist of 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 seven refineries in the Gulf Coast and Midwest regions of the United States, purchases refined products and ethanol for resale and distributes refined products through various means, including pipeline and marine transportation, terminal and storage 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.

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


•	Midstream – includes the operations of MPLX and certain other related operations. The Midstream segment gathers, processes and transports natural gas; gathers, transports, fractionates, stores and markets NGLs; and transports and stores crude oil and refined products, principally for the Refining & Marketing segment.

Strategic Actions to Enhance Shareholder Value

On January 3, 2017, we announced plans to significantly accelerate the dropdown of assets with an estimated $1.4 billion of MLP-eligible annual EBITDA to MPLX, subject to requisite approvals and regulatory clearances, including tax clearance, and market and other conditions. We expect these dropdowns to be valued consistent with recent industry precedent valuation multiples ranging between 7.0x and 9.0x EBITDA, subject to the MPLX conflicts committee review process and receipt of customary fairness opinions. We also expect MPLX to finance the dropdown transactions in the aggregate with debt and equity in approximately equal proportions. The equity financing is expected to be funded through MPLX common units issued to us. In conjunction with the closing of the dropdowns, we also expect to exchange our economic interests in the general partner of MPLX, including IDRs, for newly issued MPLX common units. These actions are designed to unlock the value inherent in our midstream platform and to provide an ongoing return of capital to shareholders in a manner consistent with maintaining an investment-grade credit profile. See “MPLX LP - Dropdowns to MPLX” for information on the first two of these dropdowns, which were completed on March 1, 2017 and September 1, 2017, and the remaining identified dropdown assets, with projected annual EBITDA of approximately $1 billion, which have been offered to MPLX.

Our January 3, 2017 announcement included conducting a full and thorough review of Speedway to ensure optimum value is being delivered to shareholders over the long term. On September 5, 2017, we announced that our board of directors, based on a recommendation from its independent special committee, determined that maintaining Speedway as a fully integrated business with MPC provides the best opportunity for enhancing long-term shareholder value. Key factors in the board of directors’ decision to maintain Speedway as an integrated business within MPC included substantial integration synergies, support of MPC’s investment grade credit profile and ability to return capital to shareholders and the strong value of cash flow diversification.

Executive Summary

Results

Select results for the three and nine months ended September 30, 2017 and 2016 are reflected in the following table.



	Three Months Ended September 30,						Nine Months Ended September 30,
(In millions, except per share data)	2017			2016			2017			2016
Refining & Marketing	$	1,097		$	252		$	1,589		$	1,191
Speedway	209			209			583			569
Midstream	355			310			996			752
Items not allocated to segments	(85		)	(336		)	$	(318	)	$	(687	)
Income from operations	$	1,576		$	435		$	2,850		$	1,825
Net income attributable to MPC	$	903		$	145		$	1,416		$	947
Net income attributable to MPC per diluted share	$	1.77		$	0.27		$	2.73		$	1.78

Net income attributable to MPC was $903 million, or $1.77 per diluted share, in the third quarter and $1.42 billion, or $2.73 per diluted share, in the first nine months of 2017 compared to $145 million, or $0.27 per diluted share, and $947 million, or $1.78 per diluted share, for the same periods of 2016.

Refining & Marketing segment income from operations increased $845 million in the third quarter and $398 million in the first nine months of 2017 compared to the same periods of 2016. The increase in the third quarter of 2017 as compared to 2016 was primarily a result of a $3.47 per barrel increase in gross margin. This favorable effect was due to significantly higher blended LLS-based crack spreads, partially offset by less favorable product price realizations as compared to spot market reference prices. The USGC and Chicago LLS blended 6-3-2-1 crack spread increased to $12.69 per barrel in the third quarter of 2017 from $8.08 per barrel in the third quarter of 2016, primarily due to an increase in the USGC crack spread. Refinery throughputs exceeded 2 million barrels per day in the third quarter of 2017 and crude oil capacity utilization was 102 percent for the third quarter of 2017 as compared to 100 percent for the third quarter of 2016. Segment results for the first nine months of 2016 included a non-cash benefit of $345 million related to the reversal of the Company’s LCM inventory valuation reserve. In the first nine months of 2017 as compared to 2016, excluding the LCM benefit, the favorable effect of higher blended LLS-based

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crack spreads was partially offset by less favorable product price realizations as compared to spot market reference prices. The USGC and Chicago LLS blended 6-3-2-1 crack spread increased to $9.87 per barrel in the first nine months of 2017 from $6.82 per barrel in the first nine months of 2016.

Speedway segment income from operations was comparable in the third quarter and increased $14 million in the first nine months of 2017 compared to the same periods of 2016. The third quarter of 2017 results reflect the benefits of Speedway’s new joint venture with Pilot Flying J and reduced operating expenses, offset by lower light product gross margin, primarily driven by lower sales volumes, and lower merchandise gross margin. Speedway’s light product margin was 17.72 cents per gallon in the third quarter of 2017 compared with 17.73 cents per gallon in the third quarter of 2016. Segment results for the first nine months of 2016 included a non-cash benefit of $25 million related to the reversal of the Company’s LCM inventory valuation reserve. In the first nine months of 2017 as compared to 2016, excluding the LCM benefit, the increase in segment income was primarily due to contributions from Speedway’s new joint venture with Pilot Flying J and reduced operating expenses, partially offset by the absence of a $24 million gain from the sale of a retail location in 2016 and lower light product gross margin, driven by lower volumes, and lower merchandise gross margin.

Midstream segment income from operations increased $45 million in the third quarter and $244 million in the first nine months of 2017 compared to the same periods of 2016. The increases were primarily due to higher natural gas gathering, processing and fractionation throughput volumes. The increase for the first nine months 2017 was also impacted by higher natural gas and NGL prices. Comparability of the Midstream segment's results to the first nine months of 2016 was also affected by the drop of certain terminal assets to MPLX during the first quarter of 2017. These assets were considered a business effective April 1, 2016 and the results of the light product terminals business are reflected in the Midstream segment from that date with an offsetting income from operations impact to the Refining & Marketing segment.

Items not allocated to segments includes an $86 million charge in the first nine months of 2017 to reflect binding settlement agreements with the plaintiffs and co-defendants to settle four lawsuits brought forth by the plaintiffs alleging personal injuries from a fire that occurred at our Galveston Bay refinery on January 11, 2016. The other co-defendants in this litigation were contractors that were engaged by us to provide services at our Galveston Bay refinery. We are vigorously pursuing recovery of such losses, as well as defense costs, through indemnification from a significant contractor who is not party to the settlement agreements. Items not allocated to segments in the third quarter and first nine months of 2017 also include a benefit of $2 million and $21 million, respectively, related to MPC’s share of gains from the sale of assets remaining from the canceled Sandpiper pipeline project. In the third quarter and the first nine months of 2016, unallocated items include impairment charges of $267 million and $356 million, respectively, related to equity method investments. The non-cash impairment charge in the third quarter of 2016 related to our equity investment in the Sandpiper pipeline project resulted from the indefinite deferral of this project. Impairment charges in the first nine months of 2016 also include $89 million related to an equity method investment held by MPLX and $130 million recorded by MPLX to impair a portion of the $2.21 billion of goodwill, as adjusted, recorded in connection with the MarkWest Merger.

MPLX LP

As of September 30, 2017, we owned a 30.4 percent interest in MPLX, including a two percent general partner interest.

On December 4, 2015, MPLX completed the MarkWest Merger. The total value of consideration transferred was $8.61 billion, consisting of $7.33 billion in equity and $1.28 billion in cash. At closing, we made a payment of $1.23 billion to MarkWest common unitholders and the remaining $50 million was paid in equal amounts, the first of which was paid in July 2016 and the second of which was paid in July 2017, in connection with the conversion of the MPLX Class B Units to MPLX common units. Our financial results and operating statistics reflect the results of MarkWest from the date of the MarkWest Merger.

Reorganization Transactions

On September 1, 2016, MPC, MPLX and various affiliates initiated a series of reorganization transactions in order to simplify MPLX’s ownership structure and its financial and tax reporting. In connection with these transactions, MPC contributed $225 million to MPLX and all of the issued and outstanding MPLX Class A Units, all of which were held by MarkWest Hydrocarbon, a subsidiary of MPLX, were exchanged for newly issued common units representing limited partner interests in MPLX. The simple average of the NYSE closing price of MPLX common units for the last 10 trading days preceding September 1, 2016 was used for purposes of these transactions. As a result of these transactions, MPC increased its ownership interest in MPLX by 7 million MPLX common units, or approximately 1 percent.

Private Placement of Preferred Units

On May 13, 2016, MPLX completed the private placement of approximately 30.8 million 6.5 percent Series A Convertible Preferred Units (the “MPLX Preferred Units”) for a cash price of $32.50 per unit. The aggregate net proceeds of approximately $984 million from the sale of the MPLX Preferred Units were used by MPLX for capital expenditures, repayment of debt and general partnership purposes.

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The MPLX Preferred Units rank senior to all MPLX common units with respect to distributions and rights upon liquidation. The holders of the MPLX Preferred Units are entitled to receive quarterly distributions equal to $0.528125 per unit commencing for the quarter ended June 30, 2016, with a prorated amount from the date of issuance. Following the second anniversary of the issuance of the MPLX Preferred Units, the holders of the MPLX Preferred Units will receive as a distribution the greater of $0.528125 per unit or the amount of per unit distributions paid to the holders of common units. The MPLX Preferred Units are convertible into MPLX common units on a one for one basis after three years, at the purchasers’ option, and after four years at MPLX’s option, subject to certain conditions.

The MPLX Preferred Units are considered redeemable securities due to the existence of redemption provisions upon a deemed liquidation event which is considered outside our control. Therefore, they are presented as temporary equity in the mezzanine section of the consolidated balance sheets. We have recorded the MPLX Preferred Units at their issuance date fair value, net of issuance costs. Since the MPLX Preferred Units are not currently redeemable and not probable of becoming redeemable in the future, adjustment to the initial carrying amount is not necessary and would only be required if it becomes probable that the security would become redeemable.

Dropdowns to MPLX

On September 27, 2017, our board of directors authorized us to offer MPLX Fuels Distribution LLC and MPLX Refining Logistics LLC to MPLX in exchange for cash and MPLX limited and general partnership units. MPLX Fuels Distribution LLC is structured to provide a broad range of scheduling and marketing services as MPC’s sole and exclusive agent. MPLX Refining Logistics LLC contains the integrated tank farm assets that support MPC’s refining operations. These essential logistics assets include: approximately 56 million barrels of storage (crude, finished products and intermediates), 619 tanks, 32 rail and truck racks, 18 docks and gasoline blenders. This offer, which represents the remaining identified dropdown assets under our strategic actions with projected annual EBITDA of $1 billion, is currently under review by the conflicts committee of the board of directors of the general partner of MPLX. Further return of capital to shareholders is planned with the after-tax cash proceeds from these remaining dropdowns, consistent with maintaining an investment grade credit profile. Once the terms of the dropdown are finalized, MPC will immediately initiate the offer of its general partner economic interests in MPLX, including IDRs, to MPLX in exchange for newly issued MPLX common units in conjunction with the closing of the dropdown. This exchange will provide a clear valuation of MPC’s general partner interest and is expected to reduce MPLX’s cost of capital for the long term. The transactions are expected to close in the first quarter of 2018, subject to requisite approvals and market conditions.

On September 1, 2017, we contributed our joint-interest ownership in certain pipelines and storage facilities to MPLX in exchange for total consideration of $1.05 billion. This consideration consisted of MPLX equity and $420 million in cash. We received approximately 19 million MPLX common units and 378 thousand general partner units from MPLX, which was determined by dividing $630 million by the volume weighted average NYSE price of MPLX common units for the 10 trading days preceding the closing date, pursuant to a Membership Interests Contributions Agreement. We also agreed to waive 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 total consideration of $2.0 billion. This consideration consisted of MPLX equity and $1.5 billion in cash. We received approximately 13 million common units and 264 thousand general partner units from MPLX, which was determined by dividing $504 million by the volume weighted average NYSE price of MPLX common units for the 10 trading days preceding the closing date, pursuant to the Membership Interests Contributions Agreement. 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 the transactions. 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 31, 2016, we contributed our inland marine business to MPLX in exchange for 23 million MPLX common units and 460 thousand general partner units. The number of units we received from MPLX was determined by dividing $600 million by the volume weighted average NYSE price of MPLX common units for the 10 trading days preceding March 14, 2016, pursuant to the Membership Interests Contribution Agreement. We also agreed to waive first-quarter 2016 common unit distributions, IDRs and general partner distributions, with respect to the common units issued in this transaction. The contribution of our inland marine business was accounted for as a transaction between entities under common control and we did not record a gain or loss.

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Public Offerings

On February 10, 2017, MPLX completed a public offering of $1.25 billion aggregate principal amount of 4.125% unsecured senior notes due March 2027 and $1.0 billion aggregate principal amount of 5.200% unsecured senior notes due March 2047. The net proceeds were used to fund the $1.5 billion cash portion of the consideration MPLX paid MPC for the dropdown of assets on March 1, 2017, as well as for general partnership purposes. See Note 16 to the unaudited consolidated financial statements for more information.

ATM Program

On August 4, 2016, MPLX entered into a Second Amended and Restated Distribution Agreement (the “Distribution Agreement”) providing for the continuous issuance of common units, in amounts, at prices and on terms to be determined by market conditions and other factors at the time of any offerings under its ATM Program. MPLX expects to use the net proceeds from sales under the ATM Program for general partnership purposes including repayment of debt and funding for acquisitions, working capital requirements and capital expenditures.

During the nine months ended September 30, 2017, MPLX issued an aggregate of 14 million common units under the ATM Program, generating net proceeds of approximately $473 million. As of September 30, 2017, $1.74 billion of MPLX common units remains available for issuance through the ATM Program under the Distribution Agreement.

Distributions from MPLX

The following table summarizes the cash distributions we received from MPLX during the first nine months of 2017 and 2016.



	Nine Months Ended September 30,
(In millions)	2017		2016
Cash distributions received from MPLX:
General partner distributions, including IDRs	$	205	$	134
Limited partner distributions	143		99
Total	$	348	$	233

The market value of the 118.1 million MPLX common units we owned at September 30, 2017 was $4.13 billion based on the September 29, 2017 closing unit price of $35.01. We also believe there is substantial value attributable to our two percent general partner interest, including the IDRs.

On October 25, 2017, MPLX declared a quarterly cash distribution of $0.5875 per common unit payable on November 14, 2017. As a result, MPLX will make distributions totaling $320 million to its limited and general partners. MPC’s portion of these distributions is approximately $150 million.

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

Acquisitions and Investments

On March 1, 2017, MPLX purchased the Ozark pipeline for approximately $219 million from Enbridge Pipelines (Ozark) LLC. 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.

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 currently expected to deliver in excess of 470 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 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 the joint venture, which equates to an approximate 9.2 percent indirect equity interest in the Bakken Pipeline system.

In connection with closing the transaction with ETP and SXL and the previous decision to indefinitely suspend the Sandpiper pipeline project, Enbridge Energy Partners canceled MPC’s transportation services agreement with respect to the Sandpiper pipeline and released MPC from paying any termination fee per that agreement.

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Effective January 1, 2017, MarkWest, and Antero Midstream formed a joint venture, Sherwood Midstream, to support the development of Antero Resources Corporation’s Marcellus Shale acreage in West Virginia. MarkWest has a 50 percent ownership interest in Sherwood Midstream. In connection with this transaction, MarkWest 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, MarkWest converted all of its ownership interests in 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, MarkWest and Sherwood Midstream formed 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 de-ethanization facilities owned by MarkWest. MarkWest 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. MarkWest 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, MarkWest only recognized a gain for the portion attributable to Antero Midstream’s indirect interest of approximately $2 million.

We account for the investments in Sherwood Midstream and Sherwood Midstream Holdings as part of our Midstream segment using the equity method of accounting and we continue to consolidate Ohio Fractionation.

See Note 5 to the unaudited consolidated financial statements for additional information related to the investments in Sherwood Midstream, Ohio Fractionation and Sherwood Midstream Holdings.

In the fourth quarter of 2016, Speedway and Pilot Flying J finalized the formation of a joint venture originally consisting of travel plazas, primarily in the Southeast region of the United States. The new entity, PFJ Southeast, originally consisted of 41 existing locations contributed by Speedway and 82 locations contributed by Pilot Flying J, all of which carry either the Pilot or Flying J brand and are operated by Pilot Flying J. Our non-cash contribution was $273 million based on the book value of the assets we contributed to the joint venture.

We currently have indirect ownership interests in two ocean vessel joint ventures with Crowley, which were established to own and operate Jones Act vessels in petroleum product service.

In September 2015, we acquired a 50 percent ownership interest in a joint venture, Crowley Ocean Partners, with Crowley. The joint venture owns and operates four new Jones Act product tankers, three of which are leased to MPC. Two of the vessels were delivered in 2015 and the remaining two were delivered in 2016. We have contributed a total of $141 million for the four vessels.

In May 2016, MPC and Crowley formed a new ocean vessel joint venture, Crowley Coastal Partners, in which MPC has a 50 percent ownership interest. MPC and Crowley each contributed their 50 percent ownership in Crowley Ocean Partners, discussed above, into Crowley Coastal Partners. In addition, we contributed $48 million in cash and Crowley contributed its 100 percent ownership interest in Crowley Blue Water Partners to Crowley Coastal Partners. Crowley Blue Water Partners is an entity that owns and operates three 750 Series ATB vessels that are leased to MPC. We account for our 50 percent interest in Crowley Coastal Partners as part of our Midstream segment using the equity method of accounting.

See Note 5 to the unaudited consolidated financial statements for information on Crowley Coastal Partners as a VIE and Note 21 to the unaudited consolidated financial statements for information on our conditional guarantee of the indebtedness of Crowley Ocean Partners and Crowley Blue Water Partners.

Share Repurchases

Since January 1, 2012, our board of directors has approved $13.0 billion in total share repurchase authorizations and we have repurchased a total of $9.06 billion of our common stock, leaving $3.94 billion available for repurchases. During the nine months ended September 30, 2017, we acquired 31 million common shares at an average cost per share of $52.16 under these authorizations. See Note 8 to the unaudited consolidated financial statements.

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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 affected 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.

Liquidity

As of September 30, 2017, we had cash and cash equivalents of $2.09 billion, excluding MPLX's cash and cash equivalents, $3.5 billion of unused bank revolving credit facilities and full availability under our $750 million trade receivables facility. As of September 30, 2017, we do not have any commercial paper borrowings outstanding. We do not intend to have outstanding commercial paper borrowings in excess of available capacity under our bank revolving credit facility. As of September 30, 2017, MPLX had cash and cash equivalents of $3 million and approximately $1.8 billion available through its bank revolving credit facility and $298 million available through its $500 million credit facility with MPC.

On July 21, 2017, we entered into credit agreements with a syndicate of lenders to replace MPC’s previous $2.5 billion four-year bank revolving credit facility and $1 billion 364-day revolving credit facility. The new credit agreements provide for a $2.5 billion five-year bank revolving credit facility that expires in July 2022 and a $1 billion 364-day bank revolving credit facility that expires in July 2018. In addition, on July 21, 2017, MPLX entered into a credit agreement to replace its previous $2 billion five-year bank revolving credit facility with a $2.25 billion five-year bank revolving credit facility that expires in July 2022. The financial covenants and the interest rate terms contained in the new credit agreements are substantially the same as those contained in the previous bank revolving credit facilities.

The above discussion contains forward-looking statements with respect to the announced strategic initiatives to enhance shareholder value, the ATM Program and our share repurchase authorizations. Factors that could affect our strategic initiatives include, but are not limited to, the time, costs and ability to obtain regulatory or other approvals and consents and otherwise consummate the strategic initiatives; the satisfaction or waiver of conditions in the agreements governing the strategic initiatives; our ability to achieve the strategic and other objectives related to the strategic initiatives; the impact of adverse market conditions affecting MPC’s and MPLX’s midstream businesses; adverse changes in laws including with respect to tax and regulatory matters; inability to agree with the MPLX conflicts committee with respect to the timing of and value attributed to assets identified for dropdown and/or the general partner economic interests. Factors that could affect the ATM program and the timing of any issuances under the ATM Program include, but are not limited to, market conditions, availability of liquidity and the market prices of MPLX common units. Factors that could affect the share repurchase authorizations and the timing of any repurchases include, but are not limited to, our ability to generate sufficient income and cash flow to effect the intended share repurchases, including within the expected timeframe, our ability to manage disruption in credit markets or changes to our credit rating, business conditions, availability of liquidity and the market price of our common stock. These factors, among others, could cause actual results to differ materially from those set forth in the forward-looking statements. For additional information on forward-looking statements and risks that can affect our business, see “Disclosures Regarding Forward-Looking Statements” and Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended December 31, 2016.

Overview of Segments

Refining & Marketing

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

Our Refining & Marketing gross 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 Midwest (Chicago) and USGC crack spreads that we believe most closely track our operations and slate of products. LLS prices and a 6-3-2-1 ratio of products (6 barrels of LLS crude oil producing 3 barrels of unleaded regular gasoline, 2 barrels of ULSD and 1 barrel of three percent residual fuel oil) are used for these crack-spread calculations.

Our refineries can process significant amounts of sour crude oil, which typically can be purchased at a discount to sweet crude oil. The amount of this discount, the sweet/sour differential, can vary significantly, causing our Refining & Marketing gross margin to differ from crack spreads based on sweet crude oil. In general, a larger sweet/sour differential will enhance our Refining & Marketing gross margin.

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

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



(In millions, after-tax)
LLS 6-3-2-1 crack spread sensitivity^(a)(per $1.00/barrel change)	$	450
Sweet/sour differential sensitivity^(b) (per $1.00/barrel change)	225
LLS-WTI differential sensitivity^(c) (per $1.00/barrel change)	80
Natural gas price sensitivity^(d) (per $1.00/million British thermal unit change)	130


^(a)	Weighted 40 percent Chicago and 60 percent USGC LLS 6-3-2-1 crack spreads and assumes all other differentials and pricing relationships remain unchanged.


^(b)	LLS (prompt) - [delivered cost of sour crude oil: Arab Light, Kuwait, Maya, Western Canadian Select and Mars].


^(c)	Assumes 20 percent of crude oil throughput volumes are WTI-based domestic crude oil.


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

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


•	the selling prices realized for refined products;


•	the types of crude oil and other charge and blendstocks processed;


•	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 carried at the lower of cost or market value. Costs of crude oil, refinery feedstocks and refined products are aggregated on a consolidated basis for purposes of assessing if the LIFO 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.

Speedway

Our retail marketing gross margin for gasoline and distillate, which is the price paid by consumers less the cost of refined products, including transportation, consumer excise taxes and bankcard processing fees, impacts the Speedway segment profitability. Numerous factors impact gasoline and distillate demand, including local competition, transportation fuel prices, seasonal demand fluctuations, the available wholesale supply, the level of economic activity in our marketing areas and weather conditions. Market demand increases for gasoline and distillate generally increase the product margin we can realize.

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

Midstream

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 profitability is affected by prevailing commodity prices primarily as a result of processing or conditioning 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.

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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. 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. 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 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.

Results of Operations

Consolidated Results of Operations



	Three Months Ended September 30,									Nine Months Ended September 30,
(In millions)	2017			2016			Variance			2017			2016			Variance
Revenues and other income:
Sales and other operating revenues (including consumer excise taxes)	$	19,053		$	16,616		$	2,437		$	53,220		$	46,179		$	7,041
Sales to related parties	157			2			$	155		458			5			$	453
Income (loss) from equity method investments	84			(208		)	292			224			(236		)	460
Net gain on disposal of assets	—			1			(1		)	12			26			(14		)
Other income	92			49			43			219			106			113
Total revenues and other income	19,386			16,460			2,926			54,133			46,080			8,053
Costs and expenses:
Cost of revenues (excludes items below)	14,605			12,944			1,661			41,913			35,475			6,438
Purchases from related parties	148			128			20			420			359			61
Inventory market valuation adjustment	—			—			—			—			(370		)	370
Consumer excise taxes	2,012			1,914			98			5,751			5,633			118
Impairment expense	—			—			—			—			130			(130		)
Depreciation and amortization	517			507			10			1,574			1,497			77
Selling, general and administrative expenses	412			420			(8		)	1,286			1,199			87
Other taxes	116			112			4			339			332			7
Total costs and expenses	17,810			16,025			1,785			51,283			44,255			7,028
Income from operations	1,576			435			1,141			2,850			1,825			1,025
Net interest and other financial income (costs)	(157		)	(141		)	(16		)	(465		)	(420		)	(45		)
Income before income taxes	1,419			294			1,125			2,385			1,405			980
Provision for income taxes	415			75			340			706			481			225
Net income	1,004			219			785			1,679			924			755
Less net income (loss) attributable to:
Redeemable noncontrolling interest	16			16			—			49			25			24
Noncontrolling interests	85			58			27			214			(48		)	262
Net income attributable to MPC	$	903		$	145		$	758		$	1,416		$	947		$	469

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Net income attributable to MPC increased $758 million in the third quarter and $469 million in the first nine months of 2017 compared to the same periods of 2016 primarily due to increases in income from operations for our Refining & Marketing and Midstream segments. Income from operations for the first nine months of 2016 includes a non-cash benefit of $370 million related to the reversal of the Company’s LCM inventory valuation reserve. Items not allocated to segments includes impairment charges of $267 million in the third quarter and $356 million in the first nine months of 2016 related to equity method investments. Items not allocated to segments for the first nine months of 2016 also includes $130 million recorded by MPLX to impair a portion of the $2.21 billion of goodwill, as adjusted, recorded in connection with the MarkWest Merger. See Segment Results for additional information.

Sales and other operating revenues (including consumer excise taxes) increased $2.44 billion in the third quarter and $7.04 billion in the first nine months of 2017 compared to the same periods of 2016. The increases were primarily due to higher average refined product sales prices, which increased $0.21 per gallon and $0.25 per gallon, respectively, and an increase in refined product sales volumes in the third quarter of 2017.

Sales to related parties increased $155 million in the third quarter and $453 million in the first nine months of 2017 compared to the same periods of 2016, mainly due to sales from our Refining & Marketing segment to PFJ Southeast, a joint venture with Pilot Flying J, which commenced in the fourth quarter of 2016.

Income (loss) from equity method investments improved $292 million in the third quarter and $460 million in the first nine months of 2017 compared to the same periods of 2016. The improvements in both periods are primarily due to the absence of impairment charges related to equity method investments of $267 million and $356 million in the third quarter and first nine months of 2016, respectively. In addition, the improvement for the first nine months reflects increases in income from new and existing pipeline, retail and marine affiliates. The amounts in the third quarter and first nine months of 2017 also include $2 million and $21 million, respectively, related to MPC’s share of gains from the sale of assets remaining from the canceled Sandpiper pipeline project, which was impaired in the third quarter of 2016.

Net gain on disposal of assets decreased $14 million in the first nine months of 2017 compared to the same period of 2016, mainly due to the sale of a Speedway retail location in the first quarter of 2016.

Other income increased $43 million in the third quarter and $113 million in the first nine months of 2017 compared to the same periods of 2016, primarily due to increases in RIN sales.

Cost of revenues increased $1.66 billion in the third quarter and $6.44 billion in the first nine months of 2017 compared to the same periods of 2016. The increases were primarily due to:


•	increases in refined product cost of sales of $1.77 billion and $6.36 billion, respectively, primarily due to increases in raw material costs;


•	an increase in refinery direct operating costs of $102 million in the first nine months primarily due to an increase in other manufacturing costs, including utilities; and


•	partially offset by a decrease in refinery direct operating costs of $67 million in the third quarter primarily due to a decrease in planned turnaround and major maintenance activity.

Purchases from related parties increased $20 million in the third quarter and $61 million in the first nine months of 2017 compared to the same periods of 2016, largely due to:


•	increases in transportation services provided by our marine joint ventures with Crowley of $5 million and $49 million, respectively; and


•	increases in volumes of ethanol purchased from TAME, TACE and TAAE of $9 million and $10 million, respectively.

Inventory market valuation adjustment decreased costs and expenses by $370 million in the first nine months of 2016 related to the reversal of the LCM inventory valuation reserve due to increased refined product prices during the second quarter of 2016.

Consumer excise taxes increased $98 million in the third quarter and $118 million in the first nine months of 2017 compared to the same period of 2016, mainly due to increases in tax rates in certain locations. In the first nine months, the increase was partially offset by a decrease in taxable refined product sales volumes.

Impairment expense reflects goodwill impairment charges of $130 million recorded by MPLX in the first nine months of 2016.

Depreciation and amortization increased $10 million in the third quarter and $77 million in the first nine months of 2017 compared to the same periods of 2016. The increase in the first nine months is primarily the result of the decommissioning of an MPLX gas processing facility in conjunction with an expansion project at the Houston Complex.

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Selling, general and administrative expenses decreased $8 million in the third quarter and increased $87 million in the first nine months of 2017 compared to the same periods of 2016. In the first nine months of 2017, we recognized an $86 million charge to reflect settlement agreements related to certain litigation matters.

Other taxes were consistent in the third quarter and first nine months of 2017 compared to the same periods of 2016.

Net interest and other financial costs increased $16 million in the third quarter and $45 million in the first nine months of 2017 compared to the same periods of 2016, primarily due to the MPLX senior notes issued in February 2017, partially offset by decreased borrowings on the MPC term loan agreement. The increase in the first nine months was also partially offset by decreased borrowings on the MPLX bank revolving credit facility.

Provision for income taxes increased $340 million in the third quarter and $225 million in the first nine months of 2017 compared to the same periods of 2016, primarily due to increases in income before income taxes of $1.13 billion in the third quarter and $980 million in the first nine months of 2017 as well as lower effective tax rates. The combined federal, state and foreign income tax rate was 29 percent and 26 percent for the three months ended September 30, 2017 and 2016, respectively, and 30 percent and 34 percent for the nine months ended September 30, 2017 and 2016, respectively. The effective tax rate for the three and nine months ended September 30, 2017 was less than the U.S. statutory rate of 35 percent primarily due to certain permanent tax differences related to net income attributable to noncontrolling interests, the domestic manufacturing deduction and equity compensation offset by state and local tax expense. The effective tax rate for the three months ended September 30, 2016 varies from the U.S. statutory rate of 35 percent primarily due to the effects of a lower forecasted annual effective tax rate as compared to the forecasted rate used for the first six months of 2016. The effective tax rate for the nine months ended September 30, 2016 is slightly less than the U.S. statutory rate of 35 percent primarily due to certain permanent tax differences related to the net income attributable to noncontrolling interests (including their proportional share of the goodwill impairment charge recorded by MPLX), the domestic manufacturing deduction and state and local tax expense.

Segment Results

Revenues

Revenues, including intersegment sales, are summarized by segment in the following table.



	Three Months Ended September 30,				Nine Months Ended September 30,
(In millions)	2017		2016		2017		2016
Refining & Marketing	$	16,632	$	14,084	$	46,239	$	39,069
Speedway	4,898		4,849		14,079		13,665
Midstream	954		830		2,741		2,235
Segment revenues	$	22,484	$	19,763	$	63,059	$	54,969
Items included in both revenues and costs:
Consumer excise taxes	$	2,012	$	1,914	$	5,751	$	5,633

Refining & Marketing segment revenues increased $2.55 billion in the third quarter and $7.17 billion in the first nine months of 2017 compared to the same periods of 2016. The increases were primarily due to increases in refined product sales prices in both periods and an increase in refined product sales volumes in the third quarter of 2017. The table below shows our Refining & Marketing segment refined product sales volumes, sales destined for export and average sales prices.



	Three Months Ended September 30,				Nine Months Ended September 30,
	2017		2016		2017		2016
Refining & Marketing segment:
Refined product sales volumes (mbpd)^(a)	2,357		2,307		2,263		2,265
Refined product sales destined for export (mbpd)	331		314		291		301
Average refined product sales prices (dollars per gallon)	$	1.72	$	1.51	$	1.68	$	1.43


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

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The table below shows the average refined product benchmark prices for our marketing areas.



	Three Months Ended September 30,				Nine Months Ended September 30,
(Dollars per gallon)	2017		2016		2017		2016
Chicago spot unleaded regular gasoline	$	1.58	$	1.40	$	1.52	$	1.31
Chicago spot ultra-low sulfur diesel	1.66		1.43		1.55		1.31
USGC spot unleaded regular gasoline	1.63		1.39		1.57		1.29
USGC spot ultra-low sulfur diesel	1.62		1.37		1.55		1.25

Refining & Marketing intersegment sales to our Speedway segment increased $106 million in the third quarter and $430 million in the first nine months of 2017 compared to the same periods of 2016. The increases were primarily due to higher refined product sales prices partially offset by lower volumes. The lower sales volumes to Speedway in both periods were mainly due to Speedway’s contribution of 41 travel centers to a new joint venture, PFJ Southeast, in the fourth quarter of 2016. The refined product sales to PFJ Southeast continue to be reported in the Refining & Marketing segment totals above, but are no longer considered sales to the Speedway segment. The table below shows our Refining & Marketing intersegment sales to our Speedway segment.



	Three Months Ended September 30,				Nine Months Ended September 30,
	2017		2016		2017		2016
Refining & Marketing intersegment sales to Speedway:
Intersegment sales (in millions)	$	2,904	$	2,798	$	8,302	$	7,872
Refined product sales volumes (millions of gallons)	1,431		1,544		4,198		4,510
Average refined product sales prices (dollars per gallon)	$	2.02	$	1.81	$	1.97	$	1.74

Speedway segment revenues increased $49 million in the third quarter and $414 million in the first nine months of 2017 compared to the same periods of 2016. The increase in revenues in the third quarter was primarily due to an increase in gasoline and distillate sales of $96 million, partially offset by a decrease in merchandise sales of $43 million. Average gasoline and distillate selling prices increased $0.22 per gallon which was partially offset by decreased gasoline and distillate sales volumes of 111 million gallons in the third quarter. The increase in revenues in the first nine months was primarily due to an increase in gasoline and distillate sales of $502 million, partially offset by a decrease in merchandise sales of $84 million. Average gasoline and distillate selling prices during the first nine months increased $0.24 per gallon which was partially offset by a decrease in sales volumes of 273 million gallons. The decreases in gasoline and distillate sales volumes and merchandise sales in both periods are primarily attributable to the contribution of 41 travel centers to PFJ Southeast in the fourth quarter of 2016. Speedway’s share of the results from PFJ Southeast are reported as income from equity method investments.

The following table includes certain revenue statistics for the Speedway segment.



	Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
Convenience stores at period-end^(a)	2,734			2,773
Gasoline & distillate sales (millions of gallons)^(a)	1,464			1,575			4,332			4,605
Average gasoline & distillate sales prices (dollars per gallon)	$	2.36		$	2.14		$	2.30		$	2.06
Merchandise sales (in millions)^(a)	$	1,295		$	1,338		$	3,693		$	3,777
Same store gasoline sales volume (period over period)	(3.1		%)	(0.6		%)	(1.6		%)	0.2		%
Same store merchandise sales (period over period)^(b)	0.3		%	4.0		%	1.5		%	3.0		%


^(a)	Third quarter and first nine months of 2017 statistics do not reflect any information for the 41 travel centers Speedway contributed to PFJ Southeast, whereas they are reflected in the same periods of 2016 statistics.


^(b)	Excludes cigarettes.

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Midstream segment revenue increased $124 million in the third quarter and $506 million in the first nine months of 2017 compared to the same periods of 2016. The increases were primarily due to increased revenue from higher natural gas and NGL processing and fractionation volumes and prices and the recently acquired Ozark pipeline. The comparison for the first nine months also reflects the absence of any revenues for the terminal services provided to the Refining & Marketing segment in the first quarter of 2016 versus the inclusion of revenues for these services in the first quarter of 2017. These assets were not considered a business prior to April 1, 2016, and therefore, no financial results for these assets were available from which to recast first quarter 2016 Midstream segment results.

The following table includes operating statistics for the Midstream segment.



	Three Months Ended September 30,				Nine Months Ended September 30,
	2017		2016		2017		2016
Midstream third party revenues (in millions)	$	585	$	484	$	1,665	$	1,324
Midstream intersegment sales to Refining & Marketing (in millions)	$	369	$	346	$	1,076	$	911
Crude oil and refined product pipeline throughputs (mbpd)^(a)	3,562		3,113		3,299		2,953
Average crude oil and refined products tariff rates (dollars per barrel)^(b)	$	0.60	$	0.60	$	0.62	$	0.60
Terminal throughput (mbpd)^(c)	1,496		1,517		1,470		1,510
Gathering system throughput (MMcf/d)	3,729		3,306		3,415		3,313
Natural gas processed (MMcf/d)	6,581		5,906		6,336		5,691
C2 (ethane) + NGLs (natural gas liquids) fractionated (mbpd)	397		348		384		330
Natural Gas NYMEX HH ($ per MMBtu)	$	2.96	$	2.80	$	3.05	$	2.34
C2 + NGL Pricing ($ per gallon)^(d)	$	0.66	$	0.46	$	0.62	$	0.44


^(a)	On owned common-carrier pipelines and private pipelines contributed to MPLX, excluding equity method investments.


^(b)	Average tariff rates calculated using pipeline transportation revenues divided by pipeline throughput barrels.


^(c)	Includes the results of the terminal assets beginning on April 1, 2016, the date the assets became a business.


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

Income from Operations

Income from operations by segment and income before income taxes are presented in the following table.



	Three Months Ended September 30,						Nine Months Ended September 30,
(In millions)	2017			2016			2017			2016
Income from Operations by segment
Refining & Marketing	$	1,097		$	252		$	1,589		$	1,191
Speedway	209			209			583			569
Midstream^(a)	355			310			996			752
Items not allocated to segments:
Corporate and other unallocated items^(a)	(86		)	(65		)	(251		)	(194		)
Pension settlement expenses	(1		)	(4		)	(2		)	(7		)
Litigation^(b)	—			—			(86		)	—
Impairments^(c)	2			(267		)	21			(486		)
Income from operations	1,576			435			2,850			1,825
Net interest and other financial income (costs)	(157		)	(141		)	(465		)	(420		)
Income before income taxes	$	1,419		$	294		$	2,385		$	1,405


^(a)	Corporate overhead expenses attributable to MPLX are included in the Midstream segment. Corporate overhead expenses are not allocated to the Refining & Marketing and Speedway segments.


^(b)	See Note 21 to the unaudited consolidated financial statements for further information on litigation matters.


^(c)	2017 includes MPC’s share of gains related to its investment in the canceled Sandpiper pipeline project. 2016 relates to impairments of goodwill and equity method investments.

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Refining & Marketing segment income from operations increased $845 million in the third quarter and $398 million in the first nine months of 2017 compared to the same periods of 2016. The increase in the third quarter of 2017 as compared to 2016 was primarily a result of a $3.47 per barrel increase in gross margin. This favorable effect was due to significantly higher blended LLS-based crack spreads, partially offset by less favorable product price realizations as compared to spot market reference prices. The USGC and Chicago LLS blended 6-3-2-1 crack spread increased to $12.69 per barrel in the third quarter of 2017 from $8.08 per barrel in the third quarter of 2016, primarily due to an increase in USGC crack spread. Refinery throughputs exceeded 2 million barrels per day in the third quarter of 2017 and crude oil capacity utilization was 102 percent for the third quarter of 2017 as compared to 100 percent for the third quarter of 2016. Segment results for the first nine months of 2016 included a non-cash benefit of $345 million related to the reversal of the Company’s LCM inventory valuation reserve. In the first nine months of 2017 as compared to 2016, excluding the LCM benefit, the favorable effect of higher blended LLS-based crack spreads was partially offset by less favorable product price realizations as compared to spot market reference prices. The USGC and Chicago LLS blended 6-3-2-1 crack spread increased to $9.87 per barrel in the first nine months of 2017 from $6.82 per barrel in the first nine months of 2016.

The following table presents certain market indicators that we believe are helpful in understanding the results of our Refining & Marketing segment’s business.



	Three Months Ended September 30,				Nine Months Ended September 30,
(Dollars per barrel)	2017		2016		2017		2016
Chicago LLS 6-3-2-1 crack spread^(a)(b)	$	12.38	$	8.70	$	9.34	$	7.48
USGC LLS 6-3-2-1 crack spread^(a)	12.89		7.66		10.23		6.38
Blended 6-3-2-1 crack spread^(a)(c)	12.69		8.08		9.87		6.82
LLS	51.61		46.52		51.72		43.19
WTI	48.20		44.94		49.36		41.53
LLS—WTI crude oil differential^(a)	3.42		1.58		2.35		1.66
Sweet/Sour crude oil differential^(a)(d)	5.42		6.28		5.91		6.65


^(a)	All spreads and differentials are measured against prompt LLS.


^(b)	Calculation utilizes USGC three percent residual fuel oil price as a proxy for Chicago three percent residual fuel oil price.


^(c)	Blended Chicago/USGC crack spread is 40 percent/60 percent based on our refining capacity by region.


^(d)	LLS (prompt) - [delivered cost of sour crude oil: Arab Light, Kuwait, Maya, Western Canadian Select and Mars].

Based on the market indicators above and our refinery throughputs, we estimate the following impacts on Refining & Marketing segment income from operations for the third quarter of 2017 compared to the third quarter of 2016:


•	The USGC LLS 6-3-2-1 crack spread increased $5.23 per barrel for the third quarter and $3.85 per barrel for the first nine months, which had positive impacts on segment income of $621 million in the third quarter and $1.26 billion in the first nine months.


•	The Chicago LLS 6-3-2-1 crack spread increased $3.68 per barrel for the third quarter and $1.86 per barrel for the first nine months, which had positive impacts on segment income of $302 million in the third quarter and $427 million in the first nine months.


•	The sweet/sour crude oil differential decreased $0.86 per barrel in the third quarter and $0.74 per barrel for the first nine months, which had negative impacts on segment income of $86 million in the third quarter and $156 million in the first nine months, partially offset by an increase in volume in the first nine months.


•	The LLS-WTI crude oil differential increased $1.84 per barrel for the third quarter and $0.69 per barrel for the first nine months which had positive impacts on segment income of $83 million in the third quarter and $67 million for the first nine months.

The above market indicators use spot market values and an estimated mix of crude purchases and product sales. Differences in our results compared to these market indicators, including the effects of product price realizations, the mix of crudes purchased and their costs, as well as the effects of inventory valuation adjustments, market structure on our crude oil acquisition prices, and other items like refinery yields and other feedstock variances, had an estimated negative impact on Refining & Marketing segment income of $234 million for the third quarter and $1.17 billion in the first nine months of 2017 compared to the same periods of 2016.

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The following table summarizes our refinery throughputs.



	Three Months Ended September 30,		Nine Months Ended September 30,
	2017	2016	2017	2016
Refinery Throughputs (thousands of barrels per day):
Crude oil refined	1,845	1,791	1,741	1,708
Other charge and blendstocks	172	135	176	156
Total	2,017	1,926	1,917	1,864
Sour crude oil throughput percent	57	59	61	60
WTI-priced crude oil throughput percent	23	20	20	20

Crude oil throughputs increased 54 mbpd in the third quarter and 33 mbpd in the first nine months of 2017 compared to the same periods of 2016. The increase in the third quarter of 2017 is primarily due to decreased turnaround activity at our Galveston Bay refinery in the third quarter of 2017 in addition to operational efficiencies resulting from turnaround activity performed subsequent to the third quarter of 2016 at our Robinson refinery. The increase in the first nine months is primarily due to operational efficiencies resulting from turnaround activity performed during and subsequent to the third quarter of 2016 at our Galveston Bay and Robinson refineries, respectively.

The following table includes certain key operating statistics for the Refining & Marketing segment.



	Three Months Ended September 30,				Nine Months Ended September 30,
	2017		2016		2017		2016
Refining & Marketing gross margin (dollars per barrel)^(a)(b)	$	14.14	$	10.67	$	12.42	$	11.11
Refinery direct operating costs (dollars per barrel):^(c)
Planned turnaround and major maintenance	$	1.20	$	1.62	$	1.69	$	1.72
Depreciation and amortization	1.34		1.42		1.44		1.46
Other manufacturing^(d)	3.83		4.01		4.10		4.03
Total	$	6.37	$	7.05	$	7.23	$	7.21


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


^(b)	Excludes LCM inventory valuation adjustments. Comparable prior period information for gross margin has been recast in connection with the contribution of certain pipeline assets to MPLX on March 1, 2017.


^(c)	Per barrel of total refinery throughputs.


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

Refinery direct operating costs decreased $0.68 per barrel in the third quarter of 2017 compared to the third quarter of 2016 primarily due to decreases in planned turnaround and major maintenance and other manufacturing costs of $0.42 per barrel and $0.18 per barrel, respectively. The decrease in planned turnaround and major maintenance costs for the third quarter of 2017 was largely attributable to lower turnaround costs incurred by the Galveston Bay and Garyville refineries, partially offset by an increase in turnaround costs incurred by the Catlettsburg refinery. Other manufacturing costs per barrel decreased in the third quarter as increased refinery throughputs offset increases in utilities and operating costs. Refinery direct operating costs increased $0.02 in the first nine months of 2017 compared to the same period of 2016, mainly due to an increase in other manufacturing costs of $0.07 per barrel, partially offset by a decrease in planned turnaround and major maintenance of $0.03 per barrel. Other manufacturing costs increased in the first nine months primarily due to increased utilities and catalyst costs. The decrease in planned turnaround and major maintenance for the first nine months of 2017 reflects lower turnaround costs incurred by the Galveston Bay and Robinson refineries, partially offset by higher turnaround costs incurred by the Texas City and Catlettsburg refineries.

We purchase RINs to satisfy a portion of our Renewable Fuel Standard compliance. Our expense associated with RINs increased to $127 million in the third quarter and $328 million in the first nine months of 2017 from $80 million in the third quarter and $221 million in the first nine months of 2016. The increases for both periods of 2017 were primarily due to higher weighted average RIN costs driven by higher market prices for purchased RINs and increases in the number of RINs purchased.

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lower sales volumes, and lower merchandise gross margins. Speedway’s light product margin was 17.72 cents per gallon in the third quarter of 2017 compared with 17.73 cents per gallon in the third quarter of 2016. Segment results for the first nine months of 2016 included a $25 million non-cash benefit related to the reversal of the Company’s LCM charge. In the first nine months of 2017 as compared to 2016, excluding the LCM benefit, the increase in segment income was primarily due to contributions from Speedway’s new joint venture with Pilot Flying J and reduced operating expenses partially offset by the absence of a $24 million gain from the sale of a retail location in 2016 and lower light product gross margin, driven by lower volumes, and lower merchandise gross margin.

The following table includes margin statistics for the Speedway segment.



	Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
Gasoline and distillate sales (millions of gallons)^(a)	1,464			1,575			4,332			4,605
Gasoline & distillate gross margin (dollars per gallon)^(a)(b)(c)	$	0.1772		$	0.1773		$	0.1727		$	0.1668
Merchandise gross margin (in millions)^(a)	$	374		$	386		$	1,065		$	1,085
Merchandise gross margin percent^(a)	28.9		%	28.9		%	28.8		%	28.7		%


^(a)	Third quarter and first nine months of 2017 statistics do not reflect any information for the 41 travel centers Speedway contributed to PFJ Southeast, whereas they are reflected in the same periods of 2016 statistics.


^(b)	The price paid by consumers less the cost of refined products, including transportation, consumer excise taxes and bankcard processing fees, divided by gasoline and distillate sales volume.


^(c)	Excludes LCM inventory valuation adjustments.

Corporate and other unallocated items increased $21 million in the third quarter and $57 million in the first nine months of 2017, largely due to higher corporate expenses and increases in employee benefit expenses in both periods, in addition to lower allocation of corporate costs to the segments in the first nine months of 2017.

Items not allocated to segments includes an $86 million charge in the first nine months of 2017 to reflect binding settlement agreements related to certain litigation matters. Items not allocated to segments also include benefits of $2 million and $21 million in the third quarter and first nine months of 2017, respectively, related to MPC’s share of gains from the sale of assets remaining from the canceled Sandpiper pipeline project. In the third quarter and the first nine months of 2016, unallocated items include impairment charges of $267 million and $356 million, respectively, related to equity method investments. The non-cash impairment charge in the third quarter related to MPC’s equity investment in the Sandpiper pipeline project resulted from the indefinite deferral of this project. Impairment charges in the first nine months of 2016 also include $89 million related to an equity method investment held by MPLX and $130 million recorded by MPLX to impair a portion of the $2.21 billion of goodwill, as adjusted, recorded in connection with the MarkWest Merger.

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Liquidity and Capital Resources

Cash Flows

Our cash and cash equivalents balance was $2.09 billion at September 30, 2017 compared to $887 million at December 31, 2016. Net cash provided by (used in) operating activities, investing activities and financing activities for the first nine months of 2017 and 2016 are presented in the following table.



	Nine Months Ended September 30,
(In millions)	2017			2016
Net cash provided by (used in):
Operating activities	$	3,863		$	3,002
Investing activities	(2,615		)	(2,217		)
Financing activities	(47		)	(1,203		)
Total	$	1,201		$	(418	)

Net cash provided by operating activities increased $861 million in the first nine months of 2017 compared to the first nine months of 2016, primarily due to a favorable change in working capital of $517 million and an increase in operating results. Changes in working capital, excluding changes in short-term debt, were a net $622 million source of cash in the first nine months of 2017 compared to a net $105 million source of cash in the first nine months of 2016. The changes in working capital for the first nine months of 2017 were primarily due to an increase in accounts payables and accrued liabilities and a decrease in inventories partially offset by an increase in current receivables. Changes from December 31, 2016 to September 30, 2017 per the consolidated balance sheets were as follows:


•	Accounts payable increased $566 million from year-end 2016, primarily due higher crude oil prices and volumes purchased.


•	Current receivables increased $283 million from year-end 2016, primarily due to higher refined product prices slightly offset by lower volumes.


•	Inventories decreased $163 million from year-end 2016, primarily due to decreases in refined product and crude inventories.

The changes in working capital for the first nine months of 2016 were primarily due to increases in accounts payable and accrued liabilities and a decrease in inventories, excluding the Company’s non-cash reversal of the LCM inventory valuation reserve, partially offset by an increase in current receivables. Changes from December 31, 2015 to September 30, 2016 per the consolidated balance sheets were as follows:


•	Accounts payable increased $312 million from year-end 2015, primarily due to higher crude oil prices and higher volumes.


•	Current receivables increased $209 million from year-end 2015, primarily due to higher refined product and crude oil prices.


•	Excluding the change in the Company’s LCM inventory valuation reserve of $370 million, inventories decreased $71 million primarily due to a decrease in refined product inventory volumes.

Net cash used in investing activities was $398 million higher in the first nine months of 2017 compared to the first nine months of 2016 primarily due to investments and acquisitions made by MPLX during the first nine months, which are described further below.

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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 to reported total capital expenditures and investments follows.



	Nine Months Ended September 30,
(In millions)	2017			2016
Additions to property, plant and equipment per consolidated statements of cash flows	$	1,928		$	2,147
Asset retirement expenditures	1			4
Decrease in capital accruals	(9		)	(169		)
Total capital expenditures	1,920			1,982
Acquisitions^(a)	250			10
Investments in equity method investees^(b)	730			240
Total capital expenditures and investments	$	2,900		$	2,232


^(a)	The nine months ended September 30, 2017 includes the $220 million acquisition of the Ozark pipeline. The nine months ended September 30, 2016 includes adjustments to the fair values of the property, plant and equipment, intangibles and goodwill acquired in connection with the MarkWest Merger.


^(b)	The nine months ended September 30, 2017 includes an investment of $500 million in MarEn Bakken related to the Bakken Pipeline system. The nine months ended September 30, 2016 excludes an adjustment of $143 million to the fair value of equity method investments acquired in connection with the MarkWest Merger.

Capital expenditures and investments are summarized by segment below.



	Nine Months Ended September 30,
(In millions)	2017		2016
Refining & Marketing	$	570	$	756
Speedway	221		191
Midstream^(a)	2,017		1,179
Corporate and Other^(b)	92		106
Total	$	2,900	$	2,232


^(a)	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.


^(b)	Includes capitalized interest of $39 million and $47 million for the nine months ended September 30, 2017 and 2016, respectively.

Net cash contributed to equity method investments increased $446 million for the first nine months of 2017 compared to the first nine months of 2016, primarily due to MPLX’s investment of $500 million for a partial interest in the Bakken Pipeline system. Net cash used for acquisitions increased primarily due to MPLX’s acquisition of the Ozark pipeline for $219 million. Net cash used for additions to property, plant and equipment decreased $219 million mainly due to decreased capital expenditures in Refining & Marketing and Corporate and Other. Cash from disposal of assets decreased $24 million largely due to the absence of a sale of a Speedway retail location in the first nine months 2016. The net cash from all other investing activities increased $102 million primarily due to increased RIN sales.

Financing activities were a net $47 million use of cash in the first nine months of 2017 compared to a net $1.20 billion use of cash in the first nine months of 2016. In the first nine months of 2017, sources of cash from financing activities included long-term debt borrowings, proceeds from issuances of MPLX common units and contributions from noncontrolling interests which were more than offset by uses of cash in financing activities including common stock repurchases, dividend payments, distributions to noncontrolling interests, long-term debt repayments and a portion of the contingent consideration payment to the seller of the Galveston Bay refinery.

Long-term debt borrowings and repayments, including debt issuance costs, were a net $2.16 billion source of cash in the first nine months of 2017 compared to a net $1.41 billion use of cash in the first nine months of 2016. During the first nine months of 2017, MPLX issued $2.25 billion of senior notes, borrowed $420 million under the MPLX bank revolving credit agreement, repaid the remaining $250 million under the MPLX term loan agreement and we repaid the remaining $200 million balance under the MPC term loan agreement. During the first nine months of 2016, MPLX repaid amounts outstanding under the MPLX bank revolving credit facility.

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Cash used in common stock repurchases increased $1.45 billion in the first nine months of 2017 compared to the first nine months of 2016 as cash proceeds from the dropdowns of certain terminal, pipeline and storage assets to MPLX on March 1, 2017 and joint-interest ownership in certain pipelines and storage facilities on September 1, 2017 supported share repurchases of $1.62 billion in the first nine months of 2017. The table below summarizes our total share repurchases for these periods. See Note 8 to the unaudited consolidated financial statements for further discussion of the share repurchase authorizations.



	Nine Months Ended September 30,
(In millions, except per share data)	2017		2016
Number of shares repurchased	31		4
Cash paid for shares repurchased	$	1,622	$	177
Effective average cost per delivered share	$	52.16	$	41.14

Cash used in dividend payments increased $49 million in the first nine months of 2017 compared to the first nine months of 2016, primarily due to a $0.12 per share increase in our quarterly dividend payment, partially offset by a decrease in the number of outstanding shares of our common stock attributable to share repurchases. Our dividend payments were $1.12 per common share in the first nine months of 2017 compared to $1.00 per common share in the first nine months of 2016.

Cash used in distributions to noncontrolling interests increased $116 million in the first nine months of 2017 compared to the first nine months of 2016. The distributions increased primarily due to an increase in total MPLX common units outstanding and distributions paid on the MPLX Preferred Units.

Cash provided by contributions from noncontrolling interests increased $124 million in the first nine months of 2017 compared to the first nine months of 2016, primarily due to MarkWest’s sale of a noncontrolling interest in Ohio Fractionation to Sherwood Midstream.

Derivative Instruments

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

Capital Resources

Our liquidity totaled $6.34 billion at September 30, 2017 consisting of:



	September 30, 2017
(In millions)	Total Capacity		Outstanding Borrowings		Available Capacity
Bank revolving credit facility^(a)	$	2,500	$	—	$	2,500
364 day bank revolving credit facility	1,000		—		$	1,000
Trade receivables facility	750		—		750
Total	$	4,250	$	—	$	4,250
Cash and cash equivalents^(b)					$	2,085
Total liquidity					$	6,335


^(a)	Excludes MPLX’s $2.25 billion bank revolving credit facility, which had approximately $1.8 billion available as of September 30, 2017.


^(b)	Excludes $3 million of MPLX cash and cash equivalents.

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.

On July 21, 2017, we entered into credit agreements with a syndicate of lenders to replace MPC’s previous $2.5 billion four-year bank revolving credit facility and $1 billion 364-day revolving credit facility. The new credit agreements provide for a $2.5 billion five-year bank revolving credit facility that expires in July 2022 and a $1 billion 364-day bank revolving credit facility that expires in July 2018. In addition, on July 21, 2017, MPLX entered into a credit agreement to replace its previous $2 billion five-year bank revolving credit facility with a $2.25 billion five-year bank revolving credit facility that expires in July 2022. The financial covenants and the interest rate terms contained in the new credit agreements are substantially the same as those contained in the previous bank revolving credit facilities.

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As discussed in the “Strategic Actions to Enhance Shareholder Value” section in the Corporate Overview, we expect MPLX to finance the planned dropdown transactions in the aggregate with debt and equity in approximately equal proportions. The equity financing will be funded through MPLX common units issued to us. After-tax cash proceeds from the dropdowns are expected to fund the return of capital to MPC shareholders in a manner consistent with maintaining an investment-grade credit profile.

On February 10, 2017, MPLX completed a public offering of $1.25 billion aggregate principal amount of 4.125% unsecured senior notes due March 2027 and $1.0 billion aggregate principal amount of 5.200% unsecured senior notes due March 2047. Interest is payable semi-annually in arrears on March 1^st and September 1^st of each year, commencing on September 1, 2017.

We established 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 September 30, 2017, we had no commercial paper borrowings outstanding.

The MPC bank revolving credit facility and MPLX credit agreement, which provides for the MPLX bank revolving credit facility (“MPLX Credit Agreement”), 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 bank revolving credit facility 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 bank revolving credit facility) of no greater than 0.65 to 1.00. As of September 30, 2017, we were in compliance with this financial covenant with a ratio of Consolidated Net Debt to Total Capitalization of 0.25 to 1.00, as well as the other covenants contained in the MPC bank revolving credit facility.

The financial covenant included in the MPLX Credit Agreement 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. As of September 30, 2017, MPLX was in compliance with this debt covenant with a ratio of Consolidated Total Debt to Consolidated EBITDA of 3.4 to 1.0, as well as the other covenants contained in the MPLX Credit Agreement.

As disclosed in Note 2 to the unaudited consolidated financial statements, we expect the adoption of the lease accounting standard update to result in the recognition of a significant lease obligation. The MPC bank revolving credit facility and the MPLX Credit Agreement both contain provisions under which the effects of the new accounting standard are not recognized for purposes of financial covenant calculations.

Our intention is to maintain an investment-grade credit profile. As of September 30, 2017, the credit ratings on our senior unsecured debt were at or above investment grade level 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- (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.

Neither the MPC bank revolving credit facility, MPLX Credit Agreement nor our trade receivables facility contain 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 ratings would increase the applicable interest rates, yields and other fees payable under the MPC bank revolving credit facility, MPLX Credit Agreement, our trade receivables facility and debt held by our ocean vessel joint venture with Crowley. 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 or result in us having to post letters of credit under existing transportation services agreements.

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Debt-to-Total-Capital Ratio

Our debt-to-total capital ratio (total debt to total debt-plus-equity) was 38 percent at September 30, 2017 and 33 percent at December 31, 2016.



(In millions)	September 30, 2017			December 31, 2016
Debt due within one year	$	29		$	28
Long-term debt	12,753			10,544
Total debt	$	12,782		$	10,572
Calculation of debt-to-total-capital ratio:
Total debt	$	12,782		$	10,572
Redeemable noncontrolling interest	1,000			1,000
Total equity	19,802			20,203
Total capital	$	33,584		$	31,775
Debt-to-total-capital ratio	38		%	33		%

Capital Requirements

Our board originally approved a 2017 capital spending and investment plan of $1.7 billion for MPC, excluding MPLX. This budget includes spending on refining and marketing, retail and non-MPLX midstream projects as well as amounts designated for corporate projects. The remaining midstream projects are included in the MPLX budget. During the first quarter of 2017, MPLX updated its plan for organic growth capital to a range of $1.8 billion to $2.0 billion, up from $1.4 billion to $1.7 billion. The increase includes capital to support the development of additional natural gas processing facilities, including the Argo I plant in the Delaware Basin and the Sherwood Complex in the Northeast, and an expansion of the Ozark pipeline. MPLX anticipates its organic growth capital spending for the year to be below the forecasted range. MPLX maintenance capital is forecast to be approximately $150 million, an increase of $50 million versus previous guidance, primarily due to expenditures related to assets MPLX acquired during the quarter. Approximately $100 million of these increases will result in a corresponding reduction to MPC’s capital spending plan as the spending relates to the assets that were contributed to MPLX on March 1, 2017. During the nine months ended September 30, 2017, our capital expenditures and investments totaled $2.14 billion, excluding MPLX’s acquisitions of a partial interest in the Bakken Pipeline system for $500 million and the Ozark pipeline for approximately $220 million and capitalized interest. We continuously evaluate our capital budget and make changes as conditions warrant.

During the second quarter of 2017, we paid BP $131 million for the fourth year’s contingent earnout related to our 2013 acquisition of the Galveston Bay refinery. This second quarter payment represents the final payment under the agreement. See Note 14 to the unaudited consolidated financial statements.

Centennial experienced a significant reduction in shipment volumes in the second half of 2011 that has continued through the third quarter of 2017. At September 30, 2017, Centennial was not shipping product. As a result, we continued to evaluate the carrying value of our equity investment in Centennial. We concluded that no impairment was required given our assessment of its fair value based on market participant assumptions for various potential uses and future cash flows of Centennial’s assets. If market conditions were to change and the owners of Centennial are unable to find an alternative use for the assets, there could be a future impairment of our Centennial interest. As of September 30, 2017, our equity investment in Centennial was $36 million and we had a $22 million guarantee associated with 50 percent of Centennial’s outstanding debt. See Note 21 to the unaudited consolidated financial statements for additional information on the debt guarantee.

During the nine months ended September 30, 2017, we chose to make a $120 million voluntary contribution to our funded pension plans. We may choose to make voluntary contributions for future years at our discretion.

On October 25, 2017, our board of directors approved a dividend of $0.40 per share on common stock. The dividend is payable December 11, 2017, to shareholders of record as of the close of business on November 16, 2017.

During the first nine months of 2017, we paid $1.62 billion to acquire 31 million common shares through open market share repurchases at an effective average cost of $52.16 per delivered share. These share repurchases were supported by cash proceeds from the dropdowns of certain terminal, pipeline and storage assets to MPLX on March 1, 2017 and joint-interest ownership in certain pipelines and storage facilities on September 1, 2017. Additionally, we plan to repurchase approximately $550 million of common shares in the fourth quarter of 2017, subject to maintaining our investment grade profile. See Note 8 to the unaudited consolidated financial statements.

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

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.

Contractual Cash Obligations

As of September 30, 2017, our contractual cash obligations included long-term debt, capital and operating lease obligations, purchase obligations and other long-term liabilities. During the first nine months of 2017, our long-term debt commitments increased $3.87 billion due to the public offering of MPLX senior notes in February 2017 and borrowings of $420 million under the MPLX bank revolving credit agreement, partially offset by repayment of outstanding borrowings of $250 million and $200 million under the MPLX term loan agreement and MPC term loan agreement, respectively.

In the first nine months of 2017, our transportation services agreement for the Sandpiper pipeline was terminated and we entered into two new transportation services agreements. As a result, we had a net decrease in our long-term transportation commitments of $1.67 billion which affected the years 2018 to 2021 and beyond.

There were no other material changes to our contractual cash obligations outside the ordinary course of business.

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 21 to the unaudited consolidated financial statements.

Our opinions concerning liquidity and capital resources and our ability to avail ourselves in the future of the financing options mentioned in the above forward-looking statements are based on currently available information. If this information proves to be inaccurate, future availability of financing may be adversely affected. Factors that affect the availability of financing include our performance (as measured by various factors, including cash provided by operating activities), the state of worldwide debt and equity markets, investor perceptions and expectations of past and future performance, the global financial climate, and, in particular, with respect to borrowings, the levels of our outstanding debt and credit ratings by rating agencies. The discussion of liquidity and capital resources above also contains forward-looking statements regarding expected capital requirements, including our capital budget and investment spending, costs for projects under construction, project completion dates and expectations or projections about strategies and goals for growth, upgrades and expansion, the carrying value of our Centennial equity investment, future contributions to our funded pension plans and share repurchases. Some factors that could cause actual results to differ materially from those included in our forward-looking statements regarding capital requirements include: the availability of liquidity; business conditions; a further decline or improvement in the long-term outlook of the potential uses of Centennial’s assets and the pursuit of different strategic alternatives for such assets; our ability to achieve the strategic and other objectives related to the strategic initiatives discussed herein; adverse changes in laws including with respect to tax and regulatory matters; inability to agree with the MPLX conflicts committee with respect to the timing of and value attributed to assets identified for dropdown and/or the general partner economic interests; our ability to generate sufficient income and cash flow to effect the intended share repurchases, including within the expected timeframe; our ability to manage disruptions in credit markets or changes to our credit rating; the potential impact on our share price if we are unable to effect the intended share repurchases; changes to the expected construction costs and timing of projects; delays in obtaining third-party approvals; changes in labor, materials and equipment costs and availability; planned and unplanned outages; the delay of, cancellation of or failure to implement planned capital projects; project cost overruns; disruptions or interruptions of our refining operations due to the shortage of skilled labor or unforeseen hazards such as weather conditions, acts of war or terrorist acts and the governmental or military response; civil protests and resulting legal/regulatory uncertainty regarding environmental and social issues, including pipeline infrastructure, may prevent or delay the construction and operation of such infrastructure and realization of associated revenues; continued/further volatility in and/or degradation of market and industry conditions; the availability and pricing of crude oil and other feedstocks; slower growth in domestic and Canadian crude supply; completion of pipeline capacity to areas outside the U.S. Midwest; consumer demand for refined products; transportation logistics; the

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reliability of processing units and other equipment; MPC's ability to successfully implement growth opportunities; modifications to MPLX earnings and distribution growth objectives; 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; adverse results in litigation; changes to MPC's capital budget; other risk factors inherent to MPC's industry. These factors, among others, could cause actual results to differ materially from those set forth in the forward-looking statements. For additional information on forward-looking statements and risks that can affect our business, see “Disclosures Regarding Forward-Looking Statements” and Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended December 31, 2016.

Transactions with Related Parties

We believe that transactions with related parties were conducted under terms comparable to those with unrelated parties.

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. We anticipate that we will have estimated capital expenditures of $650 million between 2014 and 2020 to comply with these standards, which includes approximately $210 million in 2017.

There have been no other significant changes to our environmental matters and compliance costs during the nine months ended September 30, 2017.

Critical Accounting Estimates

There have been no significant changes to our critical accounting estimates during the three months ended September 30, 2017.

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, 2016.

See Notes 14 and 15 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.

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 September 30, 2017 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 September 30, 2017
Crude	$	(12	)	$	(31	)	$	13		$	33
Refined products	15			37			(15		)	(37		)
Embedded derivatives	(5		)	(13		)	5			13

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 September 30, 2017 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 capital leases, as of September 30, 2017 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 September 30, 2017^(a)		Change in Fair Value^(b)		Change in Net Income for the Three Months Ended September 30, 2017^(c)
Long-term debt
Fixed-rate	$	13,270	$	1,148	n/a
Variable-rate	420		n/a		2


^(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 September 30, 2017.


^(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 nine months ended September 30, 2017.

At September 30, 2017, our portfolio of long-term debt was comprised of fixed-rate instruments and variable-rate borrowings under the MPLX bank revolving credit facility. 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 the MPLX term loan facility, but may affect our results of operations and cash flows.

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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) and 15(d)-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 September 30, 2017, 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 September 30, 2017, 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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Supplementary Statistics (Unaudited)



	Three Months Ended September 30,						Nine Months Ended September 30,
(In millions)	2017			2016			2017			2016
Income from Operations by segment
Refining & Marketing^(a)(b)	$	1,097		$	252		$	1,589		$	1,191
Speedway^(b)	209			209			583			569
Midstream^(a)(c)	355			310			996			752
Items not allocated to segments:
Corporate and other unallocated items^(a)(c)	(86		)	(65		)	(251		)	(194		)
Pension settlement expenses	(1		)	(4		)	(2		)	(7		)
Litigation	—			—			(86		)	—
Impairments^(d)	2			(267		)	21			(486		)
Income from operations	$	1,576		$	435		$	2,850		$	1,825
Capital Expenditures and Investments^(e)
Refining & Marketing	$	198		$	251		$	570		$	756
Speedway	108			71			221			191
Midstream^(f)	453			410			2,017			1,179
Corporate and Other^(g)	32			29			92			106
Total	$	791		$	761		$	2,900		$	2,232

^(a)

We revised our operating segment presentation in the first quarter of 2017 in connection with the contribution of certain terminal, pipeline and storage assets to MPLX. The operating results for these assets, which were previously included in the Refining & Marketing segment, are now included in the Midstream segment. Comparable prior period information has been recast to reflect our revised presentation. The results for the pipeline and storage assets were recast effective January 1, 2015, and the results for the terminal assets were recast effective April 1, 2016. Prior to these dates, these assets were not considered businesses and, therefore, there are no financial results from which to recast segment results.


^(b)	The Refining & Marketing and Speedway segments include inventory LCM benefits of $345 million and $25 million, respectively, for the nine months ended September 30, 2016.


^(c)	Corporate overhead expenses attributable to MPLX are included in the Midstream segment. Corporate overhead expenses are not allocated to the Refining & Marketing and Speedway segments.


^(d)	2017 includes MPC’s share of gains related to the sale of assets remaining from the Sandpiper pipeline project. 2016 relates to impairments of goodwill and equity method investments.


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


^(f)	The nine months ended September 30, 2017 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.


^(g)	Includes capitalized interest of $13 million and $15 million for the three months ended September 30, 2017 and 2016, respectively, and $39 million and $47 million for the nine months ended September 30, 2017 and 2016, respectively.

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Supplementary Statistics (Unaudited)



	Three Months Ended September 30,				Nine Months Ended September 30,
	2017		2016		2017		2016
MPC Consolidated Refined Product Sales Volumes (mbpd)^(a)	2,357		2,316		2,272		2,274
Refining & Marketing Operating Statistics
Refining & Marketing refined product sales volume (mbpd)^(b)	2,357		2,307		2,263		2,265
Refining & Marketing gross margin (dollars per barrel)^(c)(d)	$	14.14	$	10.67	$	12.42	$	11.11
Crude oil capacity utilization percent^(e)	102		100		96		95
Refinery throughputs (mbpd):^(f)
Crude oil refined	1,845		1,791		1,741		1,708
Other charge and blendstocks	172		135		176		156
Total	2,017		1,926		1,917		1,864
Sour crude oil throughput percent	57		59		61		60
WTI-priced crude oil throughput percent	23		20		20		20
Refined product yields (mbpd):^(f)
Gasoline	939		907		910		908
Distillates	673		647		627		616
Propane	38		38		35		35
Feedstocks and special products	298		253		285		245
Heavy fuel oil	45		43		36		36
Asphalt	67		70		64		58
Total	2,060		1,958		1,957		1,898
Refinery direct operating costs (dollars per barrel):^(g)
Planned turnaround and major maintenance	$	1.20	$	1.62	$	1.69	$	1.72
Depreciation and amortization	1.34		1.42		1.44		1.46
Other manufacturing^(h)	3.83		4.01		4.10		4.03
Total	$	6.37	$	7.05	$	7.23	$	7.21
Refining & Marketing Operating Statistics By Region - Gulf Coast
Refinery throughputs (mbpd):⁽ⁱ⁾
Crude oil refined	1,123		1,073		1,041		1,057
Other charge and blendstocks	217		185		219		199
Total	1,340		1,258		1,260		1,256
Sour crude oil throughput percent	69		72		75		73
WTI-priced crude oil throughput percent	14		8		10		7
Refined product yields (mbpd):⁽ⁱ⁾
Gasoline	538		511		525		530
Distillates	438		411		393		407
Propane	25		27		25		26
Feedstocks and special products	326		289		310		283
Heavy fuel oil	31		30		24		24
Asphalt	19		17		17		15
Total	1,377		1,285		1,294		1,285
Refinery direct operating costs (dollars per barrel):^(g)
Planned turnaround and major maintenance	$	0.90	$	2.05	$	1.86	$	1.87
Depreciation and amortization	1.05		1.14		1.15		1.13
Other manufacturing^(h)	3.52		3.70		3.81		3.62
Total	$	5.47	$	6.89	$	6.82	$	6.62

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Supplementary Statistics (Unaudited)
	Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
Refining & Marketing Operating Statistics By Region – Midwest
Refinery throughputs (mbpd):⁽ⁱ⁾
Crude oil refined	722			718			700			651
Other charge and blendstocks	35			39			31			37
Total	757			757			731			688
Sour crude oil throughput percent	38			39			41			39
WTI-priced crude oil throughput percent	38			39			34			41
Refined product yields (mbpd):⁽ⁱ⁾
Gasoline	401			396			385			378
Distillates	235			236			234			209
Propane	14			13			11			11
Feedstocks and special products	50			51			47			40
Heavy fuel oil	15			13			13			12
Asphalt	48			53			47			43
Total	763			762			737			693
Refinery direct operating costs (dollars per barrel):^(g)
Planned turnaround and major maintenance	$	1.60		$	0.72		$	1.22		$	1.26
Depreciation and amortization	1.72			1.72			1.80			1.90
Other manufacturing^(h)	3.96			4.04			4.19			4.29
Total	$	7.28		$	6.48		$	7.21		$	7.45
Speedway Operating Statistics^(j)
Convenience stores at period-end	2,734			2,773
Gasoline and distillate sales (millions of gallons)	1,464			1,575			4,332			4,605
Gasoline and distillate gross margin (dollars per gallon)^(k)	$	0.1772		$	0.1773		$	0.1727		$	0.1668
Merchandise sales (in millions)	$	1,295		$	1,338		$	3,693		$	3,777
Merchandise gross margin (in millions)	$	374		$	386		$	1,065		$	1,085
Merchandise gross margin percent	28.9		%	28.9		%	28.8		%	28.7		%
Same store gasoline sales volume (period over period)	(3.1		%)	(0.6		%)	(1.6		%)	0.2		%
Same store merchandise sales (period over period)^(l)	0.3		%	4.0		%	1.5		%	3.0		%
Midstream Operating Statistics
Crude oil and refined product pipeline throughputs (mbpd)^(m)	3,562			3,113			3,299			2,953
Terminal throughput (mbpd)⁽ⁿ⁾	1,496			1,517			1,470			1,510
Gathering system throughput (MMcf/d)^(o)	3,729			3,306			3,415			3,313
Natural gas processed (MMcf/d)^(o)	6,581			5,906			6,336			5,691
C2 (ethane) + NGLs (natural gas liquids) fractionated (mbpd)^(o)	397			348			384			330


^(a)	Total average daily volumes of refined product sales to wholesale, branded and retail customers.


^(b)	Includes intersegment sales.


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


^(d)	Excludes LCM inventory valuation adjustments. Comparable prior period information for gross margin has been recast in connection with the contribution of certain pipeline assets to MPLX on March 1, 2017.


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


^(f)	Excludes inter-refinery volumes of 80 mbpd and 89 mbpd for the three months ended September 30, 2017 and 2016, respectively, and 74 mbpd and 80 mbpd for the nine months ended September 30, 2017 and 2016, respectively.


^(g)	Per barrel of total refinery throughputs.


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


⁽ⁱ⁾	Includes inter-refinery transfer volumes.


^(j)	Third quarter and year-to-date 2017 operating statistics do not reflect any information for the 41 travel centers contributed to PFJ Southeast, whereas they are reflected in the third quarter and year-to-date 2016 operating statistics.


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


^(l)	Excludes cigarettes.


^(m)	Includes common-carrier pipelines and private pipelines contributed to MPLX, excluding equity method investments.


⁽ⁿ⁾	Includes the results of the terminal assets contributed to MPLX from the date the assets became a business, April 1, 2016.


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

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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. Specific matters discussed below are either new proceedings or material developments in proceedings, other than items arising in the ordinary course of business, previously reported in our Annual Report on Form 10-K for the year ended December 31, 2016.

Environmental Proceedings

As previously reported in our Annual Report on Form 10-K for the year ended December 31, 2016, in July 2015, representatives from the EPA and the United States Department of Justice conducted a raid on a MarkWest Liberty Midstream pipeline launcher/receiver site utilized for pipeline maintenance operations in Washington County, Pennsylvania pursuant to a search warrant issued by a magistrate of the United States District Court for the Western District of Pennsylvania. As part of this initiative, the U.S. Attorney’s Office for the Western District of Pennsylvania, proceeded with an investigation of MarkWest Liberty Midstream’s launcher/receiver, pipeline and compressor station operations. In response to the investigation, MarkWest initiated independent studies which demonstrated that there was no risk to worker safety and no threat of public harm associated with MarkWest Liberty Midstream’s launcher/receiver operations. These findings were supported by a subsequent inspection and review by the Occupational Safety and Health Administration. After providing these studies, and other substantial documentation related to MarkWest Liberty Midstream's pipeline and compressor stations, and arranging site visits and conducting several meetings with the government’s representatives, on September 13, 2016, the U.S. Attorney’s Office for the Western District of Pennsylvania rendered a declination decision, dropping its criminal investigation and declining to pursue charges in this matter.

MarkWest Liberty Midstream continues to discuss with the EPA and the State of Pennsylvania civil enforcement allegations associated with permitting or other related regulatory obligations for its launcher/receiver and compressor station facilities in the region. In connection with these discussions, MarkWest Liberty Midstream received an initial proposal from the EPA to settle all civil claims associated with this matter for the combination of a proposed cash penalty of approximately $2.4 million and proposed supplemental environmental projects with an estimated cost of approximately $3.6 million. MarkWest Liberty Midstream has submitted a response asserting that this action involves novel issues surrounding primarily minor source emissions from facilities that the agencies themselves considered de minimis and were not the subject of regulation and consequently that the settlement proposal is excessive. In connection with these negotiations, MarkWest Liberty Midstream has received a revised settlement proposal from the EPA which proposes to lower the proposed cash penalty to approximately $1.2 million and the estimated cost of proposed supplemental environmental projects to an estimated cost of approximately $1.6 million. MarkWest Liberty Midstream will continue to negotiate with EPA regarding the amount and scope of the proposed settlement.

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Item 1A. Risk Factors

We are subject to various risks and uncertainties in the course of our business. The discussion of such risks and uncertainties may be found under Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended December 31, 2016.

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 September 30, 2017, 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)
07/01/17-07/31/17	1,494	$	55.07	—	$	4,394,094,425
08/01/17-08/31/17	297	56.36		—	4,394,094,425
09/01/17-09/30/17	8,404,202	53.85		8,402,789	3,941,635,450
Total	8,405,993	53.85		8,402,789


^(a)	The amounts in this column include 1,494 shares, 297 shares and 1,413 shares of our common stock delivered by employees to MPC, upon vesting of restricted stock, to satisfy tax withholding requirements in July, August and September, respectively.

^(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 May 31, 2017, we announced that our board of directors had approved a $3.0 billion share repurchase authorization and extended the remaining balance under the previous repurchase authorization announced on July 30, 2015, with both such outstanding authorizations having no expiration date. These authorizations, together with prior authorizations, result in a total of $13.0 billion of share repurchase authorizations since January 1, 2012.

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Item 5. Other Information

MPLX LP Executive Change in Control Severance Benefits Plan

Effective October 26, 2017, the board of directors of Marathon Petroleum Corporation (the “Corporation”) and the board of directors of MPLX GP LLC, the general partner (the “General Partner”) of MPLX LP (“the Partnership”), adopted the MPLX LP Executive Change in Control Severance Benefits Plan (the “MPLX Plan”).

The purpose of the MPLX Plan is to recognize the contributions of the senior executives who provide services to the Corporation or the Partnership and to assure the continued provision of services by these senior executives. The MPLX Plan is intended to operate as a companion plan to the Marathon Petroleum Corporation Amended and Restated Executive Change in Control Severance Benefits Plan (the “MPC Plan”). It is intended that the MPLX Plan shall not result in a duplication of benefits in the event a participant would be eligible to receive benefits under both the MPLX Plan and the MPC Plan. The following is a summary of the MPLX Plan:


•	The MPLX Plan applies to certain senior executives who provide services to the Partnership, the Corporation or any of their respective subsidiaries or affiliates.

•

A participant is generally entitled to receive benefits under the MPLX Plan if within two years following a Partnership Change in Control (as defined in the MPLX Plan), the participant’s employment is terminated without cause or for good reason, with good reason generally being defined in the MPLX Plan as a reduction in the participant’s roles, responsibilities, pay or benefits or the participant is required to relocate more than 50 miles from his or her current location. However, benefits are not payable if the termination is for cause or due to mandatory retirement, death, disability or resignation (other than for good reason) by the participant.

•

In addition to any earned but unpaid salary, a lump sum cash amount equal to the value of the participant’s unused vacation days and any normal post-termination compensation and benefits under the retirement, insurance and other compensation and benefit plans in which the participant participates, upon a Partnership Change in Control and Qualified Termination (as defined in the MPLX Plan), participants are eligible to receive: (i) a cash payment equal to three times the sum of the participant’s base salary and the highest bonus paid in the three years before the Qualified Termination or, if higher, in the three years before the Partnership Change in Control; (ii) life and health insurance benefits for up to 36 months after termination at the active employee cost; (iii) benefits that are equivalent to the retiree medical and life benefit provided under the MPC Plan; and (iv) a cash payment that is equivalent to the supplemental retirement benefit and supplemental savings benefit provided under the MPC Plan.

•

Participants who incur a Qualified Termination or who separate from service with all of the Partnership, the General Partner and any applicable buyer or successor entity within two years after the Partnership Change in Control under circumstances that would have resulted in a Qualified Termination had such separation occurred at the time of the Partnership Change in Control and participants who remain in service with the Corporation (and its affiliates) following the Partnership Change in Control may become eligible for the following benefits: (i) all Partnership equity awards that vest based solely upon the passage of time will be become vested and exercisable; and (ii) all Partnership equity awards that vest based on the attainment of performance goals will become vested as to the entire award with payment as follows (a) with respect to the period prior to the Partnership Change in Control (“Pre-CiC Period”), the award will be determined using actual performance during the Pre-CiC Period; and (b) with respect to the period after the Partnership Change in Control, the award will be determined assuming performance goals were satisfied at target levels. Participants who incur a Qualified Termination and participants who remain in or commence services with the Partnership, General Partner or any applicable buyer or successor entity (or any of their affiliates) following the Partnership Change in Control are eligible for the following benefits: (i) all Corporation equity awards will become vested and exercisable; (ii) the vesting of any Corporation equity awards that otherwise would vest based on the attainment of performance goals shall remain subject to the attainment of applicable performance goals at the end of the regularly scheduled performance period.

•

The Corporation and the General Partner may at any time amend or terminate the MPLX Plan, provided that, for a period of two years following a Partnership Change in Control, the MPLX Plan may not be amended in a manner adverse to a participant with respect to that Partnership Change in Control. Any amendment or termination shall be set out in an instrument in writing and executed by an appropriate officer.

The foregoing description of the MPLX Plan is summary in nature and subject to, and qualified in its entirety by, the full text of the MPLX Plan, a copy of which is attached as Exhibit 10.4 to this Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2017 and is incorporated herein by reference.

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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.

3.1

Restated Certificate of Incorporation of Marathon Petroleum Corporation

8-K

3.1

6/22/2011

001-35054

3.2

Amended and Restated Bylaws of Marathon Petroleum Corporation

8-K

3.1

6/5/2017

001-35054

10.1

$2,500,000,000 Five-Year Revolving Credit Agreement, dated July 21, 2017, by and among Marathon Petroleum Corporation, as borrower, JPMorgan Chase Bank, N.A., as administrative agent, each of JPMorgan Chase Bank, N.A., Wells Fargo Securities, LLC, Barclays Bank PLC, Citigroup Global Markets Inc., Merrill Lynch, Pierce, Fenner & Smith Incorporated, Mizuho Bank, Ltd., The Bank of Tokyo-Mitsubishi UFJ, Ltd., and RBC Capital Markets, as joint lead arrangers and joint bookrunners, Wells Fargo Bank, National Association, as syndication agent, each of Bank of America, N.A., Barclays Bank PLC, Citigroup Global Markets Inc., Mizuho Bank, Ltd., The Bank of Tokyo-Mitsubishi UFJ, Ltd., and Royal Bank of Canada, as documentation agents, and several other commercial lending institutions that are party thereto.

8-K

10.1

7/27/2017

001-35054

10.2

$1,000,000,000 364-Day Revolving Credit Agreement, dated July 21, 2017, by and among Marathon Petroleum Corporation, as borrower, JPMorgan Chase Bank, N.A., as administrative agent, each of JPMorgan Chase Bank, N.A., Wells Fargo Securities, LLC, Barclays Bank PLC, Citigroup Global Markets Inc., Merrill Lynch, Pierce, Fenner & Smith Incorporated, Mizuho Bank, Ltd., The Bank of Tokyo-Mitsubishi UFJ, Ltd., and RBC Capital Markets, as joint lead arrangers and joint bookrunners, Wells Fargo Bank, National Association, as syndication agent, each of Bank of America, N.A., Barclays Bank PLC, Citigroup Global Markets Inc., Mizuho Bank, Ltd., The Bank of Tokyo-Mitsubishi UFJ, Ltd., and Royal Bank of Canada, as documentation agents, and several other commercial lending institutions that are party thereto.

8-K

10.2

7/27/2017

001-35054

10.3

Credit Agreement, dated as of July 21, 2017, among MPLX LP, as borrower, Wells Fargo Bank, National Association, as administrative agent, each of Wells Fargo Securities, LLC, JPMorgan Chase Bank, N.A., Barclays Bank PLC, Citigroup Global Markets Inc., Merrill Lynch, Pierce, Fenner & Smith Incorporated, Mizuho Bank, Ltd., The Bank of Tokyo-Mitsubishi UFJ, Ltd. and RBC Capital Markets, as joint lead arrangers and joint bookrunners, JPMorgan Chase Bank, N.A., as syndication agent, each of Bank of America, N.A., Barclays Bank PLC, Citigroup Global Markets Inc., Mizuho Bank, Ltd., The Bank of Tokyo-Mitsubishi UFJ, Ltd., and Royal Bank of Canada, as documentation agents, and the other lenders and issuing banks that are parties thereto.

8-K

10.3

7/27/2017

001-35054

10.4

MPLX LP Executive Change in Control Severance Benefits Plan

31.1

Certification of Chief Executive Officer pursuant to Rule 13(a)-14 and 15(d)-14 under the Securities Exchange Act of 1934

31.2

Certification of Chief Financial Officer pursuant to Rule 13(a)-14 and 15(d)-14 under the Securities Exchange Act of 1934

32.1

Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350

32.2

Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350

101.INS

XBRL Instance Document

101.SCH

XBRL Taxonomy Extension Schema

101.PRE

XBRL Taxonomy Extension Presentation Linkbase

101.CAL

XBRL Taxonomy Extension Calculation Linkbase

101.DEF

XBRL Taxonomy Extension Definition Linkbase

101.LAB

XBRL Taxonomy Extension Label Linkbase

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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.



October 30, 2017	MARATHON PETROLEUM CORPORATION

	By:	/s/ John J. Quaid
		John J. Quaid Vice President and Controller