10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

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

For the Quarterly Period Ended September 30, 2014

OR

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

For the transition period from to

Commission file number 001-35054

Marathon Petroleum Corporation

(Exact name of registrant as specified in its charter)

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

(419) 422-2121

(Registrant’s telephone number, including area code)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes  x    No  ¨

Indicate by check mark whether the registrant has submitted electronically 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 or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer	x	Accelerated filer	¨
Non-accelerated filer	¨  (Do not check if a smaller reporting company)	Smaller reporting company	¨

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 280,192,743 shares of Marathon Petroleum Corporation common stock outstanding as of October 31, 2014.

MARATHON PETROLEUM CORPORATION

Form 10-Q

Quarter Ended September 30, 2014

INDEX

	Page
PART I – FINANCIAL INFORMATION
Item 1.   Financial Statements:
Consolidated Statements of Income (Unaudited)	2
Consolidated Statements of Comprehensive Income (Unaudited)	3
Consolidated Balance Sheets (Unaudited)	4
Consolidated Statements of Cash Flows (Unaudited)	5
Consolidated Statements of Equity (Unaudited)	6
Notes to Consolidated Financial Statements (Unaudited)	7
Item 2.   Management’s Discussion and Analysis of Financial Condition and Results of Operations	29
Item 3.   Quantitative and Qualitative Disclosures about Market Risk	48
Item 4.   Controls and Procedures	49
Supplementary Statistics (Unaudited)	50
PART II – OTHER INFORMATION
Item 1.    Legal Proceedings	53
Item 1A. Risk Factors	53
Item 2.    Unregistered Sales of Equity Securities and Use of Proceeds	54
Item 6.    Exhibits	55
Signatures	56

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

1

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)	2014			2013			2014			2013
Revenues and other income:
Sales and other operating revenues (including consumer excise taxes)	$	25,438		$	26,256		$	75,567		$	75,263
Income from equity method investments	29			9			121			16
Net gain on disposal of assets	2			1			14			3
Other income	12			8			57			40
Total revenues and other income	25,481			26,274			75,759			75,322
Costs and expenses:
Cost of revenues (excludes items below)	21,935			23,553			65,571			65,907
Purchases from related parties	112			103			401			254
Consumer excise taxes	1,622			1,631			4,736			4,685
Depreciation and amortization	322			299			967			888
Selling, general and administrative expenses	342			305			1,004			912
Other taxes	86			82			288			259
Total costs and expenses	24,419			25,973			72,967			72,905
Income from operations	1,062			301			2,792			2,417
Net interest and other financial income (costs)	(50		)	(47		)	(144		)	(140		)
Income before income taxes	1,012			254			2,648			2,277
Provision for income taxes	333			81			898			775
Net income	679			173			1,750			1,502
Less net income attributable to noncontrolling interests	7			5			24			16
Net income attributable to MPC	$	672		$	168		$	1,726		$	1,486
Per Share Data (See Note 7)
Basic:
Net income attributable to MPC per share	$	2.38		$	0.54		$	5.99		$	4.63
Weighted average shares outstanding	282			309			288			321
Diluted:
Net income attributable to MPC per share	$	2.36		$	0.54		$	5.95		$	4.60
Weighted average shares outstanding	284			311			290			323
Dividends paid	$	0.50		$	0.42		$	1.34		$	1.12

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

2

Marathon Petroleum Corporation

Consolidated Statements of Comprehensive Income (Unaudited)

	Three Months Ended   September 30,						Nine Months Ended   September 30,
(In millions)	2014			2013			2014			2013
Net income	$	679		$	173		$	1,750		$	1,502
Other comprehensive income (loss):
Defined benefit postretirement and post-employment plans:
Actuarial changes, net of tax of ($1), $34, $0 and $169	(2		)	57			—			282
Prior service costs, net of tax of ($5), ($5), ($14) and ($14)	(8		)	(8		)	(24		)	(23		)
Other comprehensive income (loss)	(10		)	49			(24		)	259
Comprehensive income	669			222			1,726			1,761
Less comprehensive income attributable to noncontrolling interests	7			5			24			16
Comprehensive income attributable to MPC	$	662		$	217		$	1,702		$	1,745

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

3

Marathon Petroleum Corporation

Consolidated Balance Sheets (Unaudited)

(In millions, except share data)	September 30, 2014			December 31, 2013
Assets
Current assets:
Cash and cash equivalents	$	1,854		$	2,292
Receivables, less allowance for doubtful accounts of $10 and $9	5,271			5,559
Inventories	5,608			4,689
Other current assets	154			197
Total current assets	12,887			12,737
Equity method investments	862			463
Property, plant and equipment, net	15,999			13,921
Goodwill	1,537			938
Other noncurrent assets	420			326
Total assets	$	31,705		$	28,385
Liabilities
Current liabilities:
Accounts payable	$	8,726		$	8,234
Payroll and benefits payable	345			406
Consumer excise taxes payable	365			373
Accrued taxes	586			513
Long-term debt due within one year	26			23
Other current liabilities	324			275
Total current liabilities	10,372			9,824
Long-term debt	6,238			3,373
Deferred income taxes	2,165			2,304
Defined benefit postretirement plan obligations	937			771
Deferred credits and other liabilities	727			781
Total liabilities	20,439			17,053
Commitments and contingencies (see Note 22)
Equity
MPC stockholders’ equity:
Preferred stock, no shares issued and outstanding (par value $0.01 per share, 30 million shares authorized)	—			—
Common stock:
Issued - 363 million and 362 million shares (par value $0.01 per share, 1 billion shares authorized)	4			4
Held in treasury, at cost - 82 million and 65 million shares	(5,616		)	(4,155		)
Additional paid-in capital	9,833			9,768
Retained earnings	6,856			5,507
Accumulated other comprehensive loss	(228		)	(204		)
Total MPC stockholders’ equity	10,849			10,920
Noncontrolling interests	417			412
Total equity	11,266			11,332
Total liabilities and equity	$	31,705		$	28,385

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

4

Marathon Petroleum Corporation

Consolidated Statements of Cash Flows (Unaudited)

	Nine Months Ended   September 30,
(In millions)	2014			2013
Increase (decrease) in cash and cash equivalents
Operating activities:
Net income	$	1,750		$	1,502
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	967			888
Pension and other postretirement benefits, net	123			3
Deferred income taxes	(126		)	22
Net gain on disposal of assets	(14		)	(3		)
Equity method investments, net	(39		)	(4		)
Changes in the fair value of derivative instruments	(35		)	(54		)
Changes in:
Current receivables	424			(974		)
Inventories	(731		)	(1,330		)
Current accounts payable and accrued liabilities	318			2,028
All other, net	85			(28		)
Net cash provided by operating activities	2,722			2,050
Investing activities:
Additions to property, plant and equipment	(952		)	(733		)
Acquisitions, net of cash acquired	(2,831		)	(1,515		)
Disposal of assets	19			12
Investments—acquisitions, loans and contributions	(341		)	(113		)
—redemptions, repayments and return of capital	3			76
All other, net	78			22
Net cash used in investing activities	(4,024		)	(2,251		)
Financing activities:
Long-term debt – borrowings	2,903			—
– repayments	(32		)	(16		)
Debt issuance costs	(19		)	(2		)
Issuance of common stock	21			37
Common stock repurchased	(1,449		)	(2,341		)
Dividends paid	(386		)	(358		)
Distributions to noncontrolling interests	(20		)	(15		)
Tax settlement with Marathon Oil Corporation	—			39
Contingent consideration payment	(172		)	—
All other, net	18			15
Net cash provided by (used in) financing activities	864			(2,641		)
Net decrease in cash and cash equivalents	(438		)	(2,842		)
Cash and cash equivalents at beginning of period	2,292			4,860
Cash and cash equivalents at end of period	$	1,854		$	2,018

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

5

Marathon Petroleum Corporation

Consolidated Statements of Equity (Unaudited)

	MPC Stockholders’ Equity
(In millions)	Common Stock		Treasury Stock			Additional Paid-in Capital		Retained Earnings			Accumulated Other Comprehensive Income (Loss)			Noncontrolling Interests			Total Equity
Balance as of December 31, 2012	$	4	$	(1,253	)	$	9,527	$	3,880		$	(464	)	$	411		$	12,105
Net income	—		—			—		1,486			—			16			1,502
Dividends declared	—		—			—		(359		)	—			—			(359		)
Distributions to noncontrolling interests	—		—			—		—			—			(15		)	(15		)
Other comprehensive income	—		—			—		—			259			—			259
Shares repurchased	—		(2,441		)	100		—			—			—			(2,341		)
Shares issued (returned) - stock based compensation	—		(9		)	37		—			—			—			28
Stock-based compensation	—		—			45		—			—			1			46
Tax settlement with Marathon Oil Corporation	—		—			39		—			—			—			39
Balance as of September 30, 2013	$	4	$	(3,703	)	$	9,748	$	5,007		$	(205	)	$	413		$	11,264
Balance as of December 31, 2013	$	4	$	(4,155	)	$	9,768	$	5,507		$	(204	)	$	412		$	11,332
Net income	—		—			—		1,726			—			24			1,750
Dividends declared	—		—			—		(386		)	—			—			(386		)
Distributions to noncontrolling interests	—		—			—		—			—			(20		)	(20		)
Other comprehensive loss	—		—			—		—			(24		)	—			(24		)
Shares repurchased	—		(1,449		)	—		—			—			—			(1,449		)
Shares issued (returned)—stock based compensation	—		(12		)	21		—			—			—			9
Stock-based compensation	—		—			44		—			—			1			45
Other	—		—			—		9			—			—			9
Balance as of September 30, 2014	$	4	$	(5,616	)	$	9,833	$	6,856		$	(228	)	$	417		$	11,266
(Shares in millions)	Common Stock		Treasury Stock
Balance as of December 31, 2012	361		(28		)
Shares repurchased	—		(31		)
Shares issued - stock-based compensation	1		—
Balance as of September 30, 2013	362		(59		)
Balance as of December 31, 2013	362		(65		)
Shares repurchased	—		(17		)
Shares issued—stock-based compensation	1		—
Balance as of September 30, 2014	363		(82		)

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

6

Notes to Consolidated Financial Statements (Unaudited)

1. Description of the Business and Basis of Presentation

Description of the Business—As used in this report, the terms “MPC,” “we,” “us,” “the Company” or “our” may refer to Marathon Petroleum Corporation, one or more of its consolidated subsidiaries or all of them taken as a whole.

Our business consists of refining and marketing, retail marketing and pipeline transportation operations conducted primarily in the Midwest, Gulf Coast, East Coast and Southeast regions of the United States, through subsidiaries, including Marathon Petroleum Company LP, Speedway LLC 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 Securities and Exchange Commission applicable to interim period financial statements and do not include all of the information and disclosures required by United States generally accepted accounting principles (“U.S. 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, 2013. The results of operations for the three and nine months ended September 30, 2014 are not necessarily indicative of the results to be expected for the full year.

During the first quarter of 2014, we recorded an out-of-period adjustment for additional expenses related to the prior year's bonus programs of $29 million, included in total costs and expenses on the consolidated statements of income. The impact to our consolidated results of operations for the nine months ended September 30, 2014 and for the year ended December 31, 2013 was immaterial. We do not expect this adjustment to have a material impact to our results of operations for the year ended December 31, 2014.

2. Accounting Standards

Not Yet Adopted

In August 2014, the Financial Accounting Standards Board ("FASB") issued an accounting standards update requiring management to assess an entity's ability to continue as a going concern and to provide related footnote disclosures in certain circumstances. Management will be required to assess if there is substantial doubt about an entity's ability to continue as a going concern within one year after the date that the financial statements are issued. Disclosures will be required if conditions give rise to substantial doubt and the type of disclosure will be determined based on whether management's plans will be able to alleviate the substantial doubt. The accounting standards update will be effective for the first annual period ending after December 15, 2016, and for annual periods and interim periods thereafter with early application permitted.

In June 2014, the FASB issued an accounting standards update for the elimination of the concept of development stage entity ("DSE") from U.S. GAAP and removes the related incremental reporting. The standards update eliminates the additional financial statement requirements specific to a DSE. In addition, it amends the consolidation model by eliminating the special provisions in the variable interest entity rules for assessing the sufficiency of the equity of a DSE. The portion of the accounting standards update related to the amendment to the consolidation guidance will be effective on a retrospective basis for annual reporting periods beginning after December 15, 2015, and interim periods within those years, with early adoption permitted. The portion of the accounting standards update related to the removal of the DSE reporting requirements will be effective on a retrospective basis for annual reporting periods beginning after December 15, 2014, and interim periods within those years, with early adoption permitted. Adoption of this standards update in the first quarters of 2015 and 2016 is not expected to have an impact on our consolidated results of operations, financial position or cash flows.

7

In May 2014, the FASB issued an accounting standards update for revenue recognition that is aligned with the International Accounting Standards Board's revenue recognition standard issued on the same day. The guidance in the 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 then 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. The accounting standards update will be effective on a retrospective or modified retrospective basis for annual reporting periods beginning after December 15, 2016, and interim periods within those years, with no early adoption permitted. At this point, a final determination has not been made as to the impact of the adoption of this standards update in the first quarter of 2017. However, we do not expect it to have a material impact on our consolidated results of operations, financial position or cash flows.

In April 2014, the FASB issued an accounting standards update that redefines the criteria for determining discontinued operations and introduces new disclosures related to these disposals. The updated definition of a discontinued operation is the disposal of a component (or components) of an entity or the classification of a component (or components) of an entity as held for sale that represents a strategic shift for an entity and has (or will have) a major impact on an entity's operations and financial results. The standard requires disclosure of additional financial information for discontinued operations and individually material components not qualifying for discontinued operation presentation, as well as information regarding an entity's continuing involvement with the discontinued operation. The accounting standards update is effective prospectively for annual periods beginning on or after December 15, 2014, and interim periods within those years. Early adoption is permitted. Adoption of this standards update in the first quarter of 2015 is not expected to have an impact on our consolidated results of operations, financial position or cash flows.

3. MPLX LP

MPLX is a publicly traded master limited partnership that was formed by us to own, operate, develop and acquire pipelines and other midstream assets related to the transportation and storage of crude oil, refined products and other hydrocarbon-based products. We own a 73.6 percent interest in MPLX, including the two percent general partner interest. We consolidate this entity for financial reporting purposes since we have a controlling financial interest, and we record a noncontrolling interest for the interest owned by the public.

MPLX’s initial assets consisted of a 51 percent general partner interest in MPLX Pipe Line Holdings LP (“Pipe Line Holdings”), which owns a network of common carrier crude oil and product pipeline systems and associated storage assets in the Midwest and Gulf Coast regions of the United States, and a 100 percent interest in a butane storage cavern in West Virginia. On May 1, 2013, we sold a five percent interest in Pipe Line Holdings to MPLX for $100 million.

Effective March 1, 2014, we sold MPLX a 13 percent interest in Pipe Line Holdings for $310 million, increasing MPLX's ownership interest in Pipe Line Holdings to 69 percent. MPLX financed this transaction with $40 million of cash on-hand and $270 million of borrowings on its bank revolving credit agreement.

The sales of our interests in Pipeline Holdings to MPLX resulted in a change of our ownership in Pipeline Holdings, but not a change in control. We accounted for the sales as equity transactions and did not record a gain or loss.

4. Acquisitions and Investments

Acquisition of Hess' Retail Operations and Related Assets

On September 30, 2014, we acquired from Hess Corporation ("Hess") all of Hess' retail locations, transport operations and shipper history on various pipelines, including approximately 40,000 barrels per day on Colonial Pipeline for $2.82 billion. We refer to these assets as “Hess' Retail Operations and Related Assets.” The transaction was funded with a combination of debt and available cash.

The transaction provides for an adjustment for working capital, which has not been finalized with Hess. If a change is made for working capital, the fair value of the assets acquired will be revised.

8

The estimated fair values of assets acquired and liabilities assumed at the acquisition date, pending the completion of an independent appraisal and other evaluations, are as follows:

(In millions)
Cash and cash equivalents	$	39
Receivables	132
Inventories	178
Other current assets	5
Property, plant and equipment, net	2,062
Other noncurrent assets	103
Total assets acquired	2,519
Accounts payable	77
Payroll and benefits payable	4
Consumer excise taxes payable	80
Other current liabilities	10
Defined benefit postretirement plan obligations	2
Deferred credits and other liabilities	122
Total liabilities assumed	295
Net assets acquired excluding goodwill	2,224
Goodwill	600
Net assets acquired	$	2,824

The purchase price allocation resulted in the recognition of $600 million in goodwill by our Speedway segment, which is deductible for tax purposes. Goodwill recognized for the acquisition primarily relates to the expected benefits of a significantly expanded retail platform that should enable growth in new markets, as well as the potential for higher merchandise sales. We also expect strategic benefits from the financial and operational scale we expect to realize across our entire retail network. This acquisition significantly expands our Speedway presence from nine to 22 states throughout the East Coast and Southeast and is aligned with our strategy to grow higher-valued, stable cash flow businesses. This acquisition also enables us to further leverage our integrated refining and transportation operations, providing an outlet for an incremental 200,000 barrels per day of assured sales from our refining system.

Other noncurrent assets includes a $22 million intangible asset related to a trade name and $60 million related to favorable lease contract terms. Deferred credits and other liabilities includes $80 million related to unfavorable lease contract terms. The trade name is being amortized over its estimated useful life of two years based on the utilization of the assets. The favorable and unfavorable lease contract amounts are being amortized over the terms of the leases.

We recognized $12 million of acquisition-related costs associated with Hess' Retail Operations and Related Assets acquisition. These costs were expensed and were included in selling, general and administrative expenses.

Acquisition of Refinery and Related Logistics and Marketing Assets

On February 1, 2013, we acquired from BP Products North America Inc. and BP Pipelines (North America) Inc. (collectively, “BP”) the 451,000 barrel per calendar day refinery in Texas City, Texas, three intrastate natural gas liquid pipelines originating at the refinery, four light product terminals, branded-jobber marketing contract assignments for the supply of approximately 1,200 branded sites, a 1,040 megawatt electric cogeneration facility and a 50,000 barrel per day allocation of space on Colonial Pipeline. We refer to these assets as the “Galveston Bay Refinery and Related Assets.” We paid $1.49 billion for these assets, which included $935 million for inventory. The transaction was funded with cash on hand. Pursuant to the purchase and sale agreement, we may also be required to pay BP a contingent earnout of up to an additional $700 million over six years, subject to certain conditions. In July 2014, we paid BP $180 million for the first period's contingent earnout. On the consolidated statements of cash flows, $172 million of the contingent earnout payment is included as a financing activity with the remainder included as an operating activity. See Note 15 for additional information on the contingent consideration.

9

The following unaudited pro forma financial information presents consolidated results assuming the Galveston Bay Refinery and Related Assets acquisition occurred on January 1, 2012 and Hess' Retail Operations and Related Assets acquisition occurred on January 1, 2013. The pro forma financial information does not give effect to potential synergies that could result from the acquisitions and is not necessarily indicative of the results of future operations.

	Three Months Ended   September 30,				Nine Months Ended   September 30,
(In millions, except per share data)	2014		2013		2014		2013
Sales and other operating revenues (including consumer excise taxes)	$	28,284	$	29,317	$	84,232	$	86,386
Net income attributable to MPC	698		170		1,748		1,516
Net income attributable to MPC per share - basic	$	2.48	$	0.55	$	6.07	$	4.72
Net income attributable to MPC per share - diluted	2.46		0.55		6.03		4.69

The pro forma information includes adjustments to align accounting policies, an adjustment to depreciation expense to reflect the fair value of property, plant and equipment, increased amortization expense related to identifiable intangible assets, additional interest expense related to financing the acquisition of Hess' Retail Operations and Related Assets, as well as the related income tax effects.

Acquisitions of Convenience Stores

During 2013, Speedway acquired nine convenience stores located in Tennessee, western Indiana and western Pennsylvania. In connection with these acquisitions, our Speedway segment recorded $8 million of goodwill, which is deductible for income tax purposes.

The principal factors contributing to a purchase price resulting in goodwill included the acquired stores complementing our existing network in our Midwest market, access to our refined product transportation systems and the potential for higher merchandise sales.

Acquisition of Biodiesel Facility

On April 1, 2014, we purchased a facility in Cincinnati, Ohio from Felda Iffco Sdn Bhd, Malaysia for $40 million. The plant currently produces biodiesel, glycerin and other by-products. The capacity of the plant is approximately 60 million gallons per year.

Neither goodwill nor a gain from a bargain purchase was recognized in conjunction with the biodiesel facility acquisition.

Assuming the acquisitions of the convenience stores in 2013 and the biodiesel facility in 2014 had been made at the beginning of any period presented, the consolidated pro forma results would not be materially different from reported results.

Investments in Ethanol Companies

On August 1, 2013, we acquired from Mitsui & Co. (U.S.A.), Inc. its interests in three ethanol companies for $75 million. Under the purchase agreement, we acquired an additional 24 percent interest in The Andersons Clymers Ethanol LLC ("TACE"), bringing our ownership interest to 60 percent; a 34 percent interest in The Andersons Ethanol Investment LLC ("TAEI"), which holds a 50 percent ownership in The Andersons Marathon Ethanol LLC ("TAME"), bringing our direct and indirect ownership interest in TAME to 67 percent; and a 40 percent interest in The Andersons Albion Ethanol LLC ("TAAE"), which owns an ethanol production facility in Albion, Michigan. On October 1, 2013, our ownership interest in TAAE increased to 43 percent as a result of TAAE acquiring one of the owner's interest. We hold a noncontrolling interest in each of these entities and account for them using the equity method of accounting since the minority owners have substantive participating rights.

10

Investments in Pipeline Companies

In July 2014, we exercised our option to acquire a 35 percent ownership interest in Enbridge Inc.'s Southern Access Extension pipeline ("SAX") through our investment in Illinois Extension Pipeline Company, LLC ("Illinois Extension Pipeline"). During the nine months ended September 30, 2014, we made contributions of $97 million to Illinois Extension Pipeline to fund our portion of the construction costs incurred-to-date on the SAX project. We account for our ownership interest in Illinois Extension Pipeline as an equity method investment. See Note 22 for information on future contributions to Illinois Extension Pipeline.

In March 2014, we acquired from Chevron Raven Ridge Pipe Line Company an additional seven percent interest in Explorer Pipeline Company ("Explorer") for $77 million, bringing our ownership interest to 25 percent. As a result of this increase in our ownership, we now account for our investment in Explorer using the equity method of accounting rather than the cost method. The cumulative impact of the change was applied as an adjustment to 2014 retained earnings.

In November 2013, we agreed to serve as an anchor shipper for the Sandpiper pipeline project and fund 37.5 percent of the construction costs of the project, which will become part of Enbridge Energy Partners L.P.'s ("Enbridge Energy Partners") North Dakota System. In exchange for these commitments, we will earn an approximate 27 percent equity interest in Enbridge Energy Partners' North Dakota System when the Sandpiper pipeline is placed into service. We also have the option to increase our ownership interest to approximately 30 percent through additional investments in future system improvements. We made contributions of $149 million to North Dakota Pipeline Company LLC ("North Dakota Pipeline") during the nine months ended September 30, 2014. We have contributed $173 million since project inception. We account for our interest in North Dakota Pipeline using the equity method of accounting. See Note 22 for information on future contributions to North Dakota Pipeline.

5. Variable Interest Entity

As stated in Note 4, we have a 35 percent ownership interest in Illinois Extension Pipeline through our contributions to the SAX project. Illinois Extension Pipeline Company LLC is considered a variable interest entity ("VIE") because it is a development stage entity and the equity in the entity is not sufficient to fund the current stage of development, which is the construction of the SAX pipeline. Our maximum exposure to loss due to this VIE at September 30, 2014 was $97 million, which equates to our contributions to-date to fund our portion of the construction costs for the project.

We are not the primary beneficiary of this VIE and, therefore, do not consolidate it because we do not have the power to control the activities that significantly influence the economic activities of the entity. The activities that most significantly impact the VIE's economic performance during the construction phase are the actual construction costs and risks associated with the construction process. Through our vote, we have shared power to direct the construction activities, but do not have the sole ability to control the construction activities.

6. Related Party Transactions

Our related parties include:

• Centennial Pipeline LLC (“Centennial”), in which we have a 50 percent noncontrolling interest. Centennial owns a refined products pipeline and storage facility.

• Explorer, in which we have a 25 percent interest. Explorer owns and operates a refined products pipeline.

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

• LOOP LLC (“LOOP”), in which we have a 51 percent noncontrolling interest. LOOP owns and operates the only U.S. deepwater oil port.

• TAAE, in which we have a 43 percent noncontrolling interest, TACE, in which we have a 60 percent noncontrolling interest and TAME, in which we have a 67 percent direct and indirect noncontrolling interest. These companies each own an ethanol production facility.

• Other equity method investees.

Sales to related parties, which are included in sales and other operating revenues (including consumer excise taxes) on the consolidated statements of income, were as follows:

	Three Months Ended   September 30,				Nine Months Ended   September 30,
(In millions)	2014		2013		2014		2013
Other equity method investees	$	2	$	3	$	6	$	7

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Fees received for operating Centennial's pipeline, which are included in other income on the consolidated statements of income, were $1 million for the nine months ended September 2014 and 2013.

Purchases from related parties were as follows:

	Three Months Ended   September 30,				Nine Months Ended   September 30,
(In millions)	2014		2013		2014		2013
Centennial	$	—	$	4	$	7	$	4
Explorer	10		—		32		—
LOCAP	6		5		16		13
LOOP	12		11		77		32
TAAE	19		8		61		8
TACE	33		42		90		92
TAME	29		31		111		98
Other equity method investees	3		2		7		7
Total	$	112	$	103	$	401	$	254

Related party purchases from Centennial consist primarily of refinery feedstocks and refined product transportation costs. Related party purchases from Explorer consist primarily of refined product transportation costs. Related party purchases from LOCAP, LOOP and other equity method investees consist primarily of crude oil transportation costs and crude oil purchases. Related party purchases from TAAE, TACE and TAME consist of ethanol purchases.

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

(In millions)	September 30, 2014		December 31, 2013
Centennial	$	2	$	1
TAME	2		1
Total	$	4	$	2

We also had a long-term receivable from Centennial of $1 million at September 30, 2014 and of $2 million at December 31, 2013, which is included in other noncurrent assets on the consolidated balance sheets.

Payables to related parties, which are included in accounts payable on the consolidated balance sheets, were as follows:

(In millions)	September 30, 2014		December 31, 2013
Explorer	$	5	$	—
LOCAP	2		2
LOOP	4		3
TAAE	1		2
TACE	2		4
TAME	2		5
Other equity method investees	1		—
Total	$	17	$	16

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.

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

	Three Months Ended   September 30,				Nine Months Ended   September 30,
(In millions, except per share data)	2014		2013		2014		2013
Basic earnings per share:
Allocation of earnings:
Net income attributable to MPC	$	672	$	168	$	1,726	$	1,486
Income allocated to participating securities	1		—		3		2
Income available to common stockholders - basic	$	671	$	168	$	1,723	$	1,484
Weighted average common shares outstanding	282		309		288		321
Basic earnings per share	$	2.38	$	0.54	$	5.99	$	4.63
Diluted earnings per share:
Allocation of earnings:
Net income attributable to MPC	$	672	$	168	$	1,726	$	1,486
Income allocated to participating securities	1		—		3		2
Income available to common stockholders - diluted	$	671	$	168	$	1,723	$	1,484
Weighted average common shares outstanding	282		309		288		321
Effect of dilutive securities	2		2		2		2
Weighted average common shares, including dilutive effect	284		311		290		323
Diluted earnings per share	$	2.36	$	0.54	$	5.95	$	4.60

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)	2014	2013	2014	2013
Shares issued under stock-based compensation plans	—	1	—	1

8. Equity

On July 30, 2014, our board of directors approved an additional $2.0 billion share repurchase authorization expiring in July 2016. As of September 30, 2014, our board of directors had approved $8.0 billion in total share repurchase authorizations since January 1, 2012 and we have repurchased a total of $5.59 billion of our common stock, leaving $2.41 billion available for repurchases. Under these authorizations, we have acquired 82 million shares at an average cost per share of $68.41.

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

Total share repurchases were as follows for the three and nine months ended September 30, 2014 and 2013:

	Three Months Ended   September 30,				Nine Months Ended   September 30,
(In millions, except per share data)	2014		2013		2014		2013
Number of shares repurchased(a)	4		14		17		31
Cash paid for shares repurchased	$	301	$	1,028	$	1,449	$	2,341
Effective average cost per delivered share	$	85.15	$	70.73	$	87.25	$	76.01

^(a)  The nine months ended September 30, 2013 includes one million shares received under the November 2012 accelerated share repurchase program, which were paid for in 2012.

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At September 30, 2014, we had agreements to acquire additional common shares for $9 million, which were settled in early October 2014.

9. Segment Information

We have three reportable segments: Refining & Marketing; Speedway; and Pipeline Transportation. 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 refineries in the Gulf Coast and Midwest regions of the United States, purchases ethanol and refined products for resale and distributes refined products through various means, including barges, terminals and trucks that we own or operate. 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 – with the acquisition of Hess' retail operations effective September 30, 2014, sells transportation fuels and convenience products in retail markets in the Midwest, East Coast and Southeast.

• Pipeline Transportation – transports crude oil and other feedstocks to our refineries and other locations, delivers refined products to wholesale and retail market areas and includes the aggregated operations of MPLX and MPC’s retained pipeline assets and investments.

On February 1, 2013, we acquired the Galveston Bay Refinery and Related Assets, which are part of the Refining & Marketing and Pipeline Transportation segments. On September 30, 2014, we acquired Hess' Retail Operations and Related Assets, which are part of the Speedway and Refining & Marketing segments. Segment information for the periods prior to each acquisition do not include amounts for these operations. See Note 4.

Segment income represents income from operations attributable to the reportable segments. Corporate administrative expenses 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		Pipeline Transportation		Total
Three Months Ended September 30, 2014
Revenues:
Customer	$	21,568	$	3,854	$	16	$	25,438
Intersegment(a)	2,400		2		136		2,538
Segment revenues	$	23,968	$	3,856	$	152	$	27,976
Segment income from operations(b)	$	971	$	119	$	69	$	1,159
Income from equity method investments	17		—		12		29
Depreciation and amortization(c)	257		33		20		310
Capital expenditures and investments(d)(f)	318		2,707		224		3,249

(In millions)	Refining & Marketing		Speedway		Pipeline Transportation		Total
Three Months Ended September 30, 2013
Revenues:
Customer	$	22,481	$	3,755	$	20	$	26,256
Intersegment(a)	2,439		1		117		2,557
Segment revenues	$	24,920	$	3,756	$	137	$	28,813
Segment income from operations(b)	$	227	$	102	$	54	$	383
Income from equity method investments	8		—		1		9
Depreciation and amortization(c)	246		29		19		294
Capital expenditures and investments(d)	243		65		42		350

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(In millions)	Refining & Marketing		Speedway		Pipeline Transportation		Total
Nine Months Ended September 30, 2014
Revenues:
Customer	$	64,295	$	11,220	$	52	$	75,567
Intersegment(a)	7,223		4		396		7,623
Segment revenues	$	71,518	$	11,224	$	448	$	83,190
Segment income from operations(b)	$	2,593	$	271	$	222	$	3,086
Income from equity method investments	76		—		45		121
Depreciation and amortization(c)	782		90		58		930
Capital expenditures and investments(d)(f)	731		2,783		418		3,932

(In millions)	Refining & Marketing		Speedway		Pipeline Transportation		Total
Nine Months Ended September 30, 2013
Revenues:
Customer	$	64,245	$	10,964	$	60	$	75,269
Intersegment(a)	7,072		3		340		7,415
Segment revenues	$	71,317	$	10,967	$	400	$	82,684
Segment income from operations(b)	$	2,235	$	292	$	163	$	2,690
Income from equity method investments	7		—		9		16
Depreciation and amortization(c)	734		83		55		872
Capital expenditures and investments(d)(e)	1,797		177		173		2,147

^(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 Pipeline Transportation 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 and investments in affiliates.

^(e)  The Refining & Marketing and Pipeline Transportation segments include $1.29 billion and $70 million, respectively, for the acquisition of the Galveston Bay Refinery and Related Assets. See Note 4.

^(f)  The Speedway and Refining & Marketing segments include $2.63 billion and $54 million, respectively, for the acquisition of Hess' Retail Operations and Related Assets. See Note 4.

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)	2014			2013			2014			2013
Segment income from operations	$	1,159		$	383		$	3,086		$	2,690
Items not allocated to segments:
Corporate and other unallocated items(a)(b)	(76		)	(59		)	(204		)	(190		)
Pension settlement expenses(c)	(21		)	(23		)	(90		)	(83		)
Net interest and other financial income (costs)	(50		)	(47		)	(144		)	(140		)
Income before income taxes	$	1,012		$	254		$	2,648		$	2,277

^(a)  Corporate and other unallocated items consists primarily of MPC’s corporate administrative expenses and costs related to certain non-operating assets.

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

^(c)  See Note 20.

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

	Three Months Ended   September 30,				Nine Months Ended   September 30,
(In millions)	2014		2013		2014		2013
Segment capital expenditures and investments	$	3,249	$	350	$	3,932	$	2,147
Less: Investments in equity method investees	177		75		341		86
Plus: Items not allocated to segments:
Capital expenditures not allocated to segments	22		54		60		106
Capitalized interest	7		7		20		15
Total capital expenditures(a)(b)	$	3,101	$	336	$	3,671	$	2,182

^(a)  Capital expenditures include changes in capital accruals and acquisitions.

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

The following reconciles customer revenues to sales and other operating revenues (including consumer excise taxes) as reported in the consolidated statements of income:

	Three Months Ended   September 30,				Nine Months Ended   September 30,
(In millions)	2014		2013		2014		2013
Customer revenues (as reported above)	$	25,438	$	26,256	$	75,567	$	75,269
Corporate and other unallocated items	—		—		—		(6		)
Sales and other operating revenues (including consumer excise taxes)	$	25,438	$	26,256	$	75,567	$	75,263

Total assets by reportable segment were:

(In millions)	September 30, 2014		December 31, 2013
Refining & Marketing	$	20,207	$	19,573
Speedway	5,203		2,064
Pipeline Transportation	2,329		1,947
Corporate and Other	3,966		4,801
Total consolidated assets	$	31,705	$	28,385

10. Other Items

Net interest and other financial income (costs) was:

	Three Months Ended   September 30,						Nine Months Ended   September 30,
(In millions)	2014			2013			2014			2013
Interest:
Interest income	$	2		$	2		$	5		$	7
Interest expense	(56		)	(50		)	(154		)	(147		)
Interest capitalized	7			7			20			15
Total net interest	(47		)	(41		)	(129		)	(125		)
Other:
Net foreign currency gains (losses)	1			(1		)	—			—
Bank service and other fees	(4		)	(5		)	(15		)	(15		)
Total other	(3		)	(6		)	(15		)	(15		)
Net interest and other financial income (costs)	$	(50	)	$	(47	)	$	(144	)	$	(140	)

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11. Income Taxes

The combined federal, state and foreign income tax rate was 33 percent and 32 percent for the three months ended September 30, 2014 and 2013, respectively, and 34 percent for both the nine months ended September 30, 2014 and 2013. The effective tax rate for the three and nine months ended September 30, 2014 and 2013 is slightly less than the U.S. statutory rate of 35 percent primarily due to certain permanent benefit differences, including the domestic manufacturing deduction, partially offset by state and local tax expense.

Prior to the June 30, 2011 spinoff transaction from Marathon Oil Corporation (“Marathon Oil”), we were included in Marathon Oil’s income tax returns for all applicable years. During 2011, we anticipated a future settlement between Marathon Oil and us upon the filing of Marathon Oil’s consolidated U.S. federal and state income tax returns for the period prior to June 30, 2011. During the second quarter of 2013, we settled with Marathon Oil for the 2011 period based on filed tax returns, resulting in a $39 million increase to additional paid-in capital.

We are continuously undergoing examination of our income tax returns, which have been completed for our U.S. federal and state income tax returns through the 2009 and 2003 tax years, respectively. We had $16 million of unrecognized tax benefits as of September 30, 2014. Pursuant to our tax sharing agreement with Marathon Oil, the unrecognized tax benefits related to pre-spinoff operations for which Marathon Oil was the taxpayer remain the responsibility of Marathon Oil and we have indemnified Marathon Oil accordingly. See Note 22 for indemnification information.

12. Inventories

(In millions)	September 30, 2014		December 31, 2013
Crude oil and refinery feedstocks	$	2,405	$	1,797
Refined products	2,731		2,367
Materials and supplies	308		425
Merchandise	164		100
Total (at cost)	$	5,608	$	4,689

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 last-in, first-out (“LIFO”) method. There were no liquidations of LIFO inventories for the nine months ended September 30, 2014 and 2013.

13. Property, Plant and Equipment

(In millions)	September 30, 2014		December 31, 2013
Refining & Marketing	$	17,646	$	16,982
Speedway	4,477		2,344
Pipeline Transportation	1,995		1,921
Corporate and Other	594		546
Total	24,712		21,793
Less accumulated depreciation	8,713		7,872
Property, plant and equipment, net	$	15,999	$	13,921

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14. Goodwill

The changes in the carrying amount of goodwill for nine months ended September 30, 2014 were as follows:

(In millions)	Refining & Marketing			Speedway		Pipeline Transportation		Total
Balance as of December 31, 2013	$	551		$	225	$	162	$	938
Acquisition(a)	—			600		—		600
Disposition	(1		)	—		—		(1		)
Balance as of September 30, 2014	$	550		$	825	$	162	$	1,537

^(a)  See Note 4 for information on the acquisitions.

15. Fair Value Measurements

Fair Values—Recurring

The following tables present assets and liabilities accounted for at fair value on a recurring basis as of September 30, 2014 and December 31, 2013 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, 2014
	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	$	87	$	—	$	—	$	(55	)	$	32	$	60
Other assets	2		—		—		N/A			2		—
Total assets at fair value	$	89	$	—	$	—	$	(55	)	$	34	$	60
Commodity derivative instruments, liabilities	$	55	$	—	$	—	$	(55	)	$	—	$	—
Contingent consideration, liability(c)	—		—		475		N/A			475		—
Total liabilities at fair value	$	55	$	—	$	475	$	(55	)	$	475	$	—

	December 31, 2013
	Fair Value Hierarchy
(In millions)	Level 1		Level 2		Level 3		Netting and Collateral(a)			Net Carrying Value on Balance Sheet(b)		Collateral Pledged Not Offset
Commodity derivative instruments, assets	$	21	$	—	$	—	$	(21	)	$	—	$	61
Other assets	2		—		—		N/A			2		—
Total assets at fair value	$	23	$	—	$	—	$	(21	)	$	2	$	61
Commodity derivative instruments, liabilities	$	53	$	—	$	—	$	(53	)	$	—	$	—
Contingent consideration, liability(c)	—		—		625		N/A			625		—
Total liabilities at fair value	$	53	$	—	$	625	$	(53	)	$	625	$	—

^(a)  Represents the impact of netting assets, liabilities and cash collateral when a legal right of offset exists. As of September 30, 2014 and December 31, 2013, cash collateral of $0 million and $32 million, respectively, was netted with mark-to-market derivative liabilities.

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

^(c)  Includes $193 million and $159 million classified as current at September 30, 2014 and December 31, 2013, respectively.

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

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The contingent consideration represents the fair value as of September 30, 2014 of the amount we expect to pay to BP related to the earnout provision for the Galveston Bay Refinery and Related Assets acquisition. See Note 4. The fair value of the contingent consideration was estimated using an income approach and is therefore a Level 3 liability. The amount of cash to be paid under the arrangement is based on both a market-based crack spread and refinery throughput volumes for the months during which the contract applies, as well as established thresholds that cap the annual and total payment. The earnout payment cannot exceed $200 million per year for the first three years of the arrangement or $250 million per year for the last three years of the arrangement, with the total cumulative payment capped at $700 million over the six-year period. Any excess or shortfall from the annual cap for a current year’s earnout calculation will not affect subsequent years’ calculations. The fair value calculation used significant unobservable inputs, including (1) an estimate of refinery throughput volumes; (2) a range of internal and external crack spread forecasts from $14 to $15 per barrel; and (3) a range of risk-adjusted discount rates from five percent to 10 percent. An increase or decrease in crack spread forecasts or refinery throughput volume expectations may result in a corresponding increase or decrease in the fair value. Increases to the fair value as a result of increasing forecasts for both of these unobservable inputs, however, are limited as the earnout payment is subject to annual caps. An increase or decrease in the discount rate may result in a decrease or increase to the fair value, respectively. The fair value of the contingent consideration is reassessed each quarter, with changes in fair value recorded in cost of revenues.

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)	2014			2013			2014			2013
Beginning balance	$	647		$	611		$	625		$	—
Contingent consideration agreement	—			—			—			600
Contingent consideration payment	(180		)	—			(180		)	—
Unrealized (gains) losses included in net income	8			(5		)	30			6
Ending balance	$	475		$	606		$	475		$	606

We did not hold any Level 3 derivative instruments during the three and nine months ended September 30, 2014 and 2013. See Note 16 for the income statement impacts of our derivative instruments.

Fair Values – Nonrecurring

The following table shows the values of assets, by major category, measured at fair value on a nonrecurring basis in periods subsequent to their initial recognition.

	Nine Months Ended September 30,
	2014				2013
(In millions)	Fair Value		Impairment		Fair Value		Impairment
Property, plant and equipment, net	$	—	$	—	$	1	$	8
Other noncurrent assets	—		11		—		—

Based on the financial and operational status of a company in which we have an interest, we fully impaired our $11 million investment in that company during the second quarter of 2014. Our investment in this company was accounted for using the cost method and was included in our Refining & Marketing segment. The impairment is included in other income on the consolidated statements of income. The fair value of our investment in this cost company was measured using an income approach. This measurement is classified as Level 3.

Due to changing market conditions, we assessed one of our light products terminals for impairment. The terminal is operated by our Refining & Marketing segment. We recorded an impairment charge of $8 million for this terminal in 2013. The impairment is included in depreciation and amortization on the consolidated statements of income. The fair value of the terminal was measured using a market approach based on comparable area property values, which are Level 3 inputs.

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Fair Values – Reported

The following table summarizes financial instruments on the basis of their nature, characteristics and risk at September 30, 2014 and December 31, 2013, excluding the derivative financial instruments and contingent consideration reported above.

	September 30, 2014				December 31, 2013
(In millions)	Fair Value		Carrying Value		Fair Value		Carrying Value
Financial assets:
Investments	$	23	$	2	$	336	$	14
Other	31		29		31		30
Total financial assets	$	54	$	31	$	367	$	44
Financial liabilities:
Long-term debt(a)	$	6,224	$	5,886	$	3,306	$	3,001
Deferred credits and other liabilities	20		20		21		21
Total financial liabilities	$	6,244	$	5,906	$	3,327	$	3,022

^(a)  Excludes capital leases

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 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 from major financial institutions and a third-party service for our debt. 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.

16. Derivatives

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

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

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, 2014 and December 31, 2013:

	September 30, 2014
(In millions)	Asset		Liability		Balance Sheet Location
Commodity derivatives	$	87	$	55	Other current assets
	December 31, 2013
(In millions)	Asset		Liability		Balance Sheet Location
Commodity derivatives	$	21	$	53	Other current assets

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The table below summarizes open commodity derivative contracts as of September 30, 2014.

	Position	Total Barrels (In thousands)
Crude oil(a)
Exchange-traded	Long	10,346
Exchange-traded	Short	(23,186	)
Refined Products(b)
Exchange-traded	Long	1,695
Exchange-traded	Short	(3,281	)

^(a)  96 percent of these contracts expire in the fourth quarter of 2014.

^(b)  100 percent of these contracts expire in the fourth quarter of 2014.

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	2014		2013			2014			2013
Sales and other operating revenues	$	10	$	9		$	18		$	13
Cost of revenues	145		(170		)	(30		)	(179		)
Total	$	155	$	(161	)	$	(12	)	$	(166	)

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17. Debt

Our outstanding borrowings at September 30, 2014 and December 31, 2013 consisted of the following:

(In millions)	September 30, 2014			December 31, 2013
Marathon Petroleum Corporation:
Revolving credit agreement due 2017	$	—		$	—
Term loan agreement due 2019	700			—
3.500% senior notes due March 1, 2016	750			750
5.125% senior notes due March 1, 2021	1,000			1,000
3.625% senior notes due September 15, 2024	750			—
6.500% senior notes due March 1, 2041	1,250			1,250
4.750% senior notes due September 15, 2044	800			—
5.000% senior notes due September 15, 2054	400			—
Consolidated subsidiaries:
Capital lease obligations due 2014-2028	378			395
MPLX Operations LLC revolving credit agreement due 2017	255			—
Trade receivables securitization facility due 2016	—			—
Total	6,283			3,395
Unamortized discount	(26		)	(10		)
Fair value adjustments(a)	7			11
Amounts due within one year	(26		)	(23		)
Total long-term debt due after one year	$	6,238		$	3,373

^(a)  The $20 million gain on the termination of our interest rate swap agreements in 2012 is being amortized over the remaining life of the 3.50 percent senior notes.

There were no borrowings or letters of credit outstanding under the MPC revolving credit agreement or the trade receivables securitization facility at September 30, 2014. During the nine months ended September 30, 2014, MPLX borrowed $270 million under the MPLX Operations LLC revolving credit agreement (the "MPLX Credit Agreement"), at an average interest rate of 1.5 percent, per annum, and repaid $15 million of these borrowings. The borrowings were used to fund MPLX's March 2014 acquisition of an additional interest in Pipe Line Holdings. At September 30, 2014, MPLX had $255 million of borrowings and no letters of credit outstanding under the MPLX Credit Agreement, resulting in total unused loan availability of $245 million, or 49 percent of the borrowing capacity. The MPLX Credit Agreement is scheduled to mature on October 31, 2017.

Term Loan Agreement

On August 26, 2014, we entered into a $700 millionfive-year senior unsecured term loan credit agreement (the “Term Loan Agreement”) with a syndicate of lenders to fund a portion of the purchase price for the acquisition of Hess' Retail Operations and Related Assets. The Term Loan Agreement matures on September 24, 2019 and may be prepaid at any time without premium or penalty. We are obligated to pay certain customary fees under the Term Loan Agreement, including an annual administrative fee.

Amounts outstanding under the Term Loan Agreement bear interest at either of the following rates at our election (i) the sum of the Adjusted LIBO Rate (as defined in the Term Loan Agreement), plus a margin ranging between 0.875 percent to 1.75 percent, depending on our credit ratings, or (ii) the sum of the Base Rate (as defined in the Term Loan Agreement), plus a margin ranging between zero percent to 0.75 percent, depending on our credit ratings. The interest rate during the quarter ended September 30, 2014 was 1.3 percent.

The Term Loan Agreement contains representation and warranties, covenants and events of default that are substantially similar to those contained in the MPC revolving credit agreement, including a financial covenant, which 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 Term Loan Agreement) of no greater than 0.65 to 1.00.

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Senior Notes

On September 5, 2014, we completed a public offering of $1.95 billion in aggregate principal amount of senior unsecured notes (the "Senior Notes"), consisting of $750 million aggregate principal amount of our Senior Notes due 2024, $800 million aggregate principal amount of our Senior Notes due 2044 and $400 million aggregate principal amount of our Senior Notes due 2054. The net proceeds from the offering of the Senior Notes were approximately $1.915 billion, after deducting underwriting discounts and estimated offering expenses. The proceeds were used to fund a portion of the purchase price for the acquisition of Hess' Retail Operations and Related Assets. Interest on each series of Senior Notes is payable semi-annually in arrears on March 15 and September 15 of each year, commencing on March 15, 2015.

The Senior Notes are unsecured and unsubordinated obligations of ours and rank equally with all our other existing and future unsecured and unsubordinated indebtedness.

18. Supplemental Cash Flow Information

	Nine Months Ended   September 30,
(In millions)	2014		2013
Net cash provided by operating activities included:
Interest paid (net of amounts capitalized)	$	162	$	166
Net income taxes paid to taxing authorities	969		1,027
Non-cash investing and financing activities:
Capital lease obligations increase	$	—	$	61
Property, plant and equipment sold	4		43
Property, plant and equipment acquired	4		—
Acquisition:
Contingent consideration(a)	—		600
Payable to seller(a)	—		6

^(a)  Acquisition-date fair value of non-cash consideration associated with the Galveston Bay Refinery and Related Assets acquisition.

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)	2014		2013
Additions to property, plant and equipment per consolidated statements of cash flows	$	952	$	733
Non-cash additions to property, plant and equipment	4		—
Acquisitions(a)	2,714		1,386
Asset retirement expenditures	1		—
Increase in capital accruals	—		63
Total capital expenditures	$	3,671	$	2,182

^(a)  The 2014 acquisition includes the acquisition of Hess' Retail Operations and Related Assets. The 2013 acquisition includes the acquisition of the Galveston Bay Refinery and Related Assets. The acquisition numbers above include property, plant and equipment and intangibles. See Note 4.

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19. Accumulated Other Comprehensive Loss

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

(In millions)	Pension Benefits			Other Benefits			Gain on Cash Flow Hedge		Workers Compensation		Total
Balance as of December 31, 2012	$	(432	)	$	(36	)	$	4	$	—	$	(464	)
Other comprehensive income before reclassifications	172			3			—		2		177
Amounts reclassified from accumulated other comprehensive loss:
Amortization – prior service credit(a)	(34		)	(3		)	—		—		(37		)
– actuarial loss(a)	53			2			—		—		55
– settlement loss(a)	83			—			—		—		83
Tax effect	(19		)	—			—		—		(19		)
Other comprehensive income	255			2			—		2		259
Balance as of September 30, 2013	$	(177	)	$	(34	)	$	4	$	2	$	(205	)

(In millions)	Pension Benefits			Other Benefits			Gain on Cash Flow Hedge		Workers Compensation			Total
Balance as of December 31, 2013	$	(161	)	$	(50	)	$	4	$	3		$	(204	)
Other comprehensive income (loss) before reclassifications	(88		)	8			—		(2		)	(82		)
Amounts reclassified from accumulated other comprehensive loss:
Amortization – prior service credit(a)	(35		)	(3		)	—		—			(38		)
– actuarial loss(a)	38			2			—		—			40
– settlement loss(a)	90			—			—		—			90
Tax effect	(35		)	1			—		—			(34		)
Other comprehensive income (loss)	(30		)	8			—		(2		)	(24		)
Balance as of September 30, 2014	$	(191	)	$	(42	)	$	4	$	1		$	(228	)

^(a)  These accumulated other comprehensive loss components are included in the computation of net periodic benefit cost. See Note 20.

20. 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)	2014			2013			2014			2013
Components of net periodic benefit cost:
Service cost	$	24		$	24		$	7		$	7
Interest cost	18			19			7			6
Expected return on plan assets	(27		)	(28		)	—			—
Amortization – prior service credit	(12		)	(12		)	(1		)	(1		)
– actuarial loss	12			14			1			1
– settlement loss	21			23			—			—
Net periodic benefit cost	$	36		$	40		$	14		$	13

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	Nine Months Ended September 30,
	Pension Benefits						Other Benefits
(In millions)	2014			2013			2014			2013
Components of net periodic benefit cost:
Service cost	$	67		$	70		$	20		$	19
Interest cost	56			55			24			19
Expected return on plan assets	(81		)	(81		)	—			—
Amortization – prior service credit	(35		)	(34		)	(3		)	(3		)
– actuarial loss	38			53			2			2
– settlement loss	90			83			—			—
Net periodic benefit cost	$	135		$	146		$	43		$	37

During the nine months ended September 30, 2014, we made contributions of $16 million to our funded pension plans. Current benefit payments related to unfunded pension and other postretirement benefit plans were $22 million and $17 million, respectively, during the nine months ended September 30, 2014.

During the nine months ended September 30, 2014 and 2013, we determined that lump sum payments to employees retiring in the respective years will exceed the plans’ total service and interest costs for the year. Settlement losses are required to be recorded when lump sum payments exceed total service and interest costs. As a result, during the nine months ended September 30, 2014 and 2013, we recorded pension settlement expenses of $90 million and $83 million related to our cumulative lump sum payments made during the first nine months of 2014 and 2013, respectively.

21. 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, 2014:

	Number of Shares(a)		Weighted Average Exercise Price
Outstanding at December 31, 2013	5,147,837		$	40.08
Granted	446,310		85.02
Exercised	(696,159	)	32.12
Forfeited, canceled or expired	(20,761	)	49.67
Outstanding at September 30, 2014	4,877,227		45.28

^(a)  Includes an immaterial number of stock appreciation rights.

The grant date fair value of stock option awards granted during the nine months ended September 30, 2014 was $25.37 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. Beginning in the first quarter of 2014, the assumption for expected volatility of our stock price was refined to reflect a weighting of 50 percent of MPC’s common stock implied volatility and 50 percent of MPC's common stock historical volatility.

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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, 2014:

	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, 2013	624,122		$	61.11	385,079		$	33.96
Granted	240,882		87.81		19,827		86.79
RS's Vested/RSU's Issued	(324,697	)	55.47		(398	)	60.11
Forfeited	(25,943	)	70.10		(133	)	76.10
Outstanding at September 30, 2014	514,364		76.73		404,375		36.51

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, 2014:

	Number of Units
Outstanding at December 31, 2013	3,822,500
Granted	2,033,700
Settled	—
Canceled	—
Outstanding at September 30, 2014	5,856,200

The performance unit awards granted in 2014 have a grant date fair value of $0.85 per unit, as calculated using a Monte Carlo valuation model.

MPLX Awards

During the nine months ended September 30, 2014, 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.

22. 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, including those resulting from the acquisition of Hess' Retail Operations and Related Assets. For matters for which we have not recorded an accrued liability, we are unable to estimate a range of possible loss because the issues involved have not been fully developed through pleadings and discovery. 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.

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At September 30, 2014 and December 31, 2013, accrued liabilities for remediation totaled $182 million and $123 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, was $71 million and $51 million at September 30, 2014 and December 31, 2013, respectively.

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

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

We are a defendant in 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—We hold interests in an offshore oil port, LOOP, and a crude oil pipeline system, LOCAP. Both LOOP and LOCAP have secured various project financings with throughput and deficiency agreements. Under the agreements, we are 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 $172 million as of September 30, 2014.

We hold an interest in a refined products pipeline through our investment in Centennial, and have guaranteed 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 $39 million as of September 30, 2014.

We hold an interest in an ethanol production facility through our investment in TAME, and through our participation as a lender under TAME’s revolving credit agreement, have agreed to reimburse the bank for 50 percent of any amounts drawn on a letter of credit that has been issued to secure TAME’s repayment of the tax exempt bonds. The credit agreement expires in 2018. Our maximum potential undiscounted payments under this arrangement were $25 million at September 30, 2014.

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, 2014, 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.

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Other guarantees—We have entered into other guarantees with maximum potential undiscounted payments totaling $122 million as of September 30, 2014, 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, an indemnity to the co-lenders associated with an equity method investee’s credit agreement, and leases of assets containing general lease indemnities and guaranteed residual values.

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—At September 30, 2014, our contractual commitments to acquire property, plant and equipment and advance funds to equity method investees totaled $1.8 billion, which includes $520 million of contingent consideration associated with the acquisition of the Galveston Bay Refinery and Related Assets, $751 million for contributions to North Dakota Pipeline and $208 million for contributions to the SAX project. See Note 4 for additional information on our investments in North Dakota Pipeline and the SAX project. See Notes 4 and 15 for additional information on the contingent consideration.

23. Subsequent Event

On October 29, 2014, our board of directors authorized the sale of MPC's remaining 31 percent interest in Pipe Line Holdings to MPLX. Upon completion, we will account for the sale as an equity transaction and will not record a gain or loss.

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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 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, 2013.

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,” “estimate,” “objective,” “expect,” “forecast,” “goal,” “intend,” “plan,” “predict,” “project,” “potential,” “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, 2013.

Corporate Overview

We are an independent petroleum refining and marketing, retail marketing and pipeline transportation company. We currently own and operate seven refineries, all located in the United States, with an aggregate crude oil refining capacity of approximately 1.7 million barrels per calendar day. Our refineries supply refined products to resellers and consumers within our market areas, including the Midwest, Gulf Coast, East Coast and Southeast regions of the United States. We distribute refined products to our customers through one of the largest private domestic fleets of inland petroleum product barges, one of the largest terminal operations in the United States, and a combination of MPC-owned and third-party-owned trucking and rail assets. 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 2,740 convenience stores in 22 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 5,400 retail outlets operated by independent entrepreneurs in 19 states.

We currently own, lease or have ownership interests in approximately 8,300 miles of crude oil and refined product pipelines to deliver crude oil to our refineries and other locations and refined products to wholesale and retail market areas. We are one of the largest petroleum pipeline companies in the United States on the basis of total volumes delivered.

Our operations consist of three reportable operating segments: Refining & Marketing; Speedway; and Pipeline Transportation. 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 ethanol and refined products for resale and distributes refined products through various means, including barges, terminals and trucks that we own or operate. We sell refined products to wholesale marketing customers domestically and internationally, buyers on the spot market, our Speedway business segment and to independent entrepreneurs who operate Marathon^® retail outlets.

• Speedway—with the acquisition of Hess' retail operations effective September 30, 2014, sells transportation fuels and convenience products in the retail market in the Midwest, East Coast and Southeast. See Note 4 to the unaudited consolidated financial statements for additional information.

• Pipeline Transportation—transports crude oil and other feedstocks to our refineries and other locations, delivers refined products to wholesale and retail market areas and includes the aggregated operations of MPLX and MPC’s retained pipeline assets and investments.

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Executive Summary

Results

Select results for the three and nine months ended September 30, 2014 and 2013 are reflected in the following table.

	Three Months Ended   September 30,				Nine Months Ended   September 30,
(In millions, except per share data)	2014		2013		2014		2013
Income from Operations by segment
Refining & Marketing	$	971	$	227	$	2,593	$	2,235
Speedway	119		102		271		292
Pipeline Transportation	69		54		222		163
Net income attributable to MPC	$	672	$	168	$	1,726	$	1,486
Net income attributable to MPC per diluted share	$	2.36	$	0.54	$	5.95	$	4.60

Net income attributable to MPC increased $504 million, or $1.82 per diluted share, in the third quarter and $240 million, or $1.35 per diluted share, in the first nine months of 2014 compared to the same periods of 2013, primarily due to our Refining & Marketing segment.

Refining & Marketing segment income from operations increased $744 million in the third quarter and $358 million in the first nine months of 2014 compared to the same periods of 2013, primarily due to more favorable net product price realizations and higher U.S. Gulf Coast (“USGC”) and Chicago crack spreads, partially offset by increases in refinery direct operating costs in both periods of 2014 and narrower Light Louisiana Sweet ("LLS") - West Texas Intermediate ("WTI") and sweet/sour differentials in the first nine months of 2014.

Speedway segment income from operations increased $17 million in the third quarter and decreased $21 million in the first nine months of 2014 compared to the same periods of 2013. The increase in segment income for the third quarter was primarily due to increases in our gasoline, distillate and merchandise gross margins, partially offset by higher operating expenses. The decrease in segment income for the first nine months was primarily due to higher operating expenses and a decrease in our gasoline and distillate gross margin, partially offset by an increase in our merchandise gross margin.

Pipeline Transportation segment income from operations increased $15 million in the third quarter and $59 million in the first nine months of 2014 compared to the same periods of 2013, primarily due to higher pipeline transportation revenue and income from our pipeline affiliates, partially offset by increases in operating expenses primarily attributable to the proposed Cornerstone pipeline project for both periods of 2014 and pipeline maintenance in the third quarter of 2014.

MPLX LP

We own a 73.6 percent interest in MPLX, including the two percent general partner interest. Effective March 1, 2014, we sold MPLX a 13 percent interest in Pipe Line Holdings for $310 million, increasing MPLX's ownership interest in Pipe Line Holdings to 69 percent. MPLX financed this transaction with $40 million of cash on-hand and $270 million of borrowings on its bank revolving credit agreement. See Note 3 to the unaudited consolidated financial statements for additional information on MPLX.

The following table summarizes the cash distributions we received from MPLX during the first nine months of 2014 and 2013.

	Nine Months Ended   September 30,
(In millions)	2014		2013
Cash distributions received from MPLX:
General partner distributions, including incentive distribution rights	$	3	$	1
Limited partner distributions	53		40
Total	$	56	$	41

The market value of the 17,056,515 MPLX common units and 36,951,515 MPLX subordinated units we owned at September 30, 2014 was $3.18 billion based on the September 30, 2014 closing unit price of $58.94. Over time, we also believe there will be substantial value attributable to our general partnership interests.

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Acquisitions and Investments

On September 30, 2014, we acquired from Hess all of its retail locations, transport operations and shipper history on various pipelines, including approximately 40,000 barrels per day on Colonial Pipeline for $2.82 billion. We refer to these assets as “Hess' Retail Operations and Related Assets” and substantially all of these assets are part of our Speedway segment. This acquisition significantly expands our Speedway presence from nine to 22 states throughout the East Coast and Southeast and is aligned with our strategy to grow higher-valued, stable cash flow businesses. This acquisition also enables us to further leverage our integrated refining and transportation operations, providing an outlet for an incremental 200,000 barrels per day of assured sales from our refining system. The transaction was funded with a combination of debt and available cash. Our financial results and operating statistics for the periods prior to the acquisition do not include amounts for Hess' Retail Operations and Related Assets. See Note 4 to the unaudited consolidated financial statements for additional information on this acquisition.

On February 1, 2013, we acquired from BP the 451,000 barrel per calendar day refinery in Texas City, Texas, three intrastate natural gas liquid pipelines originating at the refinery, four light product terminals, branded-jobber marketing contract assignments for the supply of approximately 1,200 branded sites, a 1,040 megawatt electric cogeneration facility and a 50 thousand barrel per day ("mbpd") allocation of space on the Colonial Pipeline. We refer to these assets as the “Galveston Bay Refinery and Related Assets.” We paid $1.49 billion for these assets, which included $935 million for inventory. Pursuant to the purchase and sale agreement, we may also be required to pay BP a contingent earnout of up to an additional $700 million over six years, subject to certain conditions. In July 2014, we paid BP $180 million for the first period's contingent earnout. These assets are part of our Refining & Marketing and Pipeline Transportation segments. Our financial results and operating statistics for the periods prior to the acquisition do not include amounts for the Galveston Bay Refinery and Related Assets.

In July 2014, we exercised our option to acquire a 35 percent ownership interest in Enbridge Inc.'s SAX pipeline through our investment in Illinois Extension Pipeline. During the nine months ended September 30, 2014, we made contributions of $97 million to Illinois Extension Pipeline to fund our portion of the construction costs incurred-to-date on the SAX project.

In March 2014, we acquired from Chevron Raven Ridge Pipe Line Company an additional seven percent interest in Explorer for $77 million, bringing our ownership interest to 25 percent. Due to this increase in our ownership percentage, we now account for our investment in Explorer using the equity method of accounting and report Explorer as a related party. Explorer owns approximately 1,900 miles of refined products pipeline from Lake Charles, Louisiana to Hammond, Indiana.

In 2013, we agreed with Enbridge Energy Partners to serve as an anchor shipper for the Sandpiper pipeline, which will run from Beaver Lodge, North Dakota to Superior, Wisconsin. We also agreed to fund 37.5 percent of the construction of the Sandpiper pipeline project, which is currently estimated to cost $2.6 billion, of which approximately $1.0 billion is our share. We made contributions of $149 million during the first nine months of 2014 and have contributed $173 million since project inception. In exchange for our commitment to be an anchor shipper and our investment in the project, we will earn an approximate 27 percent equity interest in Enbridge Energy Partners' North Dakota System when the Sandpiper pipeline is placed into service. Enbridge Energy Partners' North Dakota System currently includes approximately 240 miles of crude oil gathering pipelines connected to a transportation pipeline that is approximately 730 miles long. We will also have the option to increase our ownership interest to approximately 30 percent through additional investments in future system improvements.

See Note 4 to the unaudited consolidated financial statements for additional information on these acquisitions and investments. See Note 22 to the unaudited consolidated financial statements for information regarding our future contributions to the SAX pipeline project and the Sandpiper pipeline project.

Share Repurchases

On July 30, 2014, our board of directors approved an additional $2.0 billion share repurchase authorization expiring in July 2016. During the first nine months of 2014, we paid $1.45 billion to acquire 17 million common shares through open market share repurchases. The effective average cost was $87.25 per delivered share. At September 30, 2014, we also had agreements to repurchase additional common shares for $9 million, which were settled in early October 2014. As of September 30, 2014, we had $2.41 billion of remaining repurchase authorization. See Note 8 to the unaudited consolidated financial statements.

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The above discussion contains forward-looking statements with respect to the estimated construction costs and completion of the Sandpiper and SAX pipeline projects and the share repurchase authorizations. Factors that could affect the estimated construction costs, timing and completion of the Sandpiper and SAX pipeline projects, include, but are not limited to, availability of materials and labor, unforeseen hazards such as weather conditions, delays in obtaining or conditions imposed by necessary government and third-party approvals and other risks customarily associated with construction projects. Factors that could affect the share repurchase authorizations and the timing of any repurchases include, but are not limited to, 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.

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 ultra-low sulfur diesel and 1 barrel of three percent residual fuel oil) are used for these crack-spread calculations.

The price of refined products has historically been set by reference to international Brent crude oil prices. In recent years, due to the growth in U.S. crude oil production, logistical constraints and other market factors the spread between Brent and LLS widened, which favorably impacted the LLS 6-3-2-1 crack spread. Recently, the Brent to LLS spread has narrowed significantly. To the extent there is a change in existing U.S. energy policy regarding crude oil exports, the spread between Brent and LLS could remain narrow. If this were to occur, it could reduce the LLS 6-3-2-1 crack spread.

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.

Historically, WTI has traded at prices similar to LLS. During 2011 and continuing through the first half of 2013, WTI traded at prices significantly less than LLS, which favorably impacted our Refining & Marketing gross margin. Logistical constraints in the U.S. mid-continent markets and other market factors acted to keep the price of WTI from rising with the prices of crude oil produced in other regions. However, due to a variety of domestic and international market conditions including the growth in pipeline capacity from Cushing, Oklahoma to the Gulf Coast region, the differential between WTI and LLS significantly narrowed during the second half of 2013 with a further narrowing broadly continuing through the first nine months of 2014.

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

The following table provides sensitivities showing the 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)	200
LLS-WTI differential sensitivity(c)(per $1.00/barrel change)	85
Natural gas price sensitivity (per $1.00/million British thermal unit change)	125

^(a) Weighted 38 percent Chicago and 62 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.

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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 types of crude oil and other charge and blendstocks processed;

• our refinery yields;

• the selling prices realized for refined products;

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

• the cost of products purchased for resale.

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. We had significant planned turnaround and major maintenance activities at our Catlettsburg, Kentucky; Galveston Bay, Texas; Garyville, Louisiana and Robinson, Illinois refineries during the first nine months of 2014 compared to activities at our Catlettsburg, Garyville and Galveston Bay refineries during the first nine months of 2013.

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, 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. Approximately two-thirds of Speedway’s gross margin was derived from merchandise sales in the third quarter and first nine months of 2014. Speedway's convenience stores offer a wide variety of merchandise, including prepared foods, beverages and non-food items.

Pipeline Transportation

The profitability of our pipeline transportation operations primarily depends on tariff rates and the volumes shipped through the pipelines. A majority of the crude oil and refined product shipments on our common carrier pipelines 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. 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. 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.

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Results of Operations

Consolidated Results of Operations

	Three Months Ended   September 30,									Nine Months Ended   September 30,
(In millions)	2014			2013			Variance			2014			2013			Variance
Revenues and other income:
Sales and other operating revenues (including consumer excise taxes)	$	25,438		$	26,256		$	(818	)	$	75,567		$	75,263		$	304
Income from equity method investments	29			9			20			121			16			105
Net gain on disposal of assets	2			1			1			14			3			11
Other income	12			8			4			57			40			17
Total revenues and other income	25,481			26,274			(793		)	75,759			75,322			437
Costs and expenses:
Cost of revenues (excludes items below)	21,935			23,553			(1,618		)	65,571			65,907			(336		)
Purchases from related parties	112			103			9			401			254			147
Consumer excise taxes	1,622			1,631			(9		)	4,736			4,685			51
Depreciation and amortization	322			299			23			967			888			79
Selling, general and administrative expenses	342			305			37			1,004			912			92
Other taxes	86			82			4			288			259			29
Total costs and expenses	24,419			25,973			(1,554		)	72,967			72,905			62
Income from operations	1,062			301			761			2,792			2,417			375
Net interest and other financial income (costs)	(50		)	(47		)	(3		)	(144		)	(140		)	(4		)
Income before income taxes	1,012			254			758			2,648			2,277			371
Provision for income taxes	333			81			252			898			775			123
Net income	679			173			506			1,750			1,502			248
Less net income attributable to noncontrolling interests	7			5			2			24			16			8
Net income attributable to MPC	$	672		$	168		$	504		$	1,726		$	1,486		$	240

Net income attributable to MPC increased $504 million in the third quarter and $240 million in the first nine months of 2014 compared to the same periods of 2013, primarily due to our Refining & Marketing segment income from operations, which increased$744 million in the third quarter and $358 million in the first nine months of 2014. The increases in Refining & Marketing segment income from operations were primarily due to more favorable net product price realizations and higher USGC and Chicago crack spreads, partially offset by increases in refinery direct operating costs in both periods of 2014 and narrower LLS-WTI and sweet/sour differentials in the first nine months of 2014.

Sales and other operating revenues (including consumer excise taxes) decreased $818 million in the third quarter and increased $304 million in the first nine months of 2014 compared to the same periods of 2013. The decrease in the third quarter was primarily due to lower refined product and crude oil sales prices and a decrease in refined product sales volumes. The increase in the first nine months was primarily due to an increase in refined product sales volumes, partially offset by lower refined product sales prices.

Income from equity method investments increased $20 million in the third quarter and $105 million in the first nine months of 2014 compared to the same periods of 2013, primarily due to increases in income from our ethanol affiliates of $10 million and $70 million, respectively, and increases in income from our pipeline affiliates of $12 million and $36 million, respectively. The increases in income from our ethanol affiliates includes the affects of our acquisition of interests in TAAE, TACE and TAEI in August 2013. The higher income from our pipeline affiliates is primarily due to increases from LOOP and Explorer, which is now accounted for as an equity method investment following our acquisition of an increased ownership interest in this pipeline company.

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Centennial experienced a significant reduction in shipment volumes in the second half of 2011 that has continued through the first nine months of 2014. At September 30, 2014, 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 current business conditions remain unchanged 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, 2014, our equity investment in Centennial was $35 million and we had a $39 million guarantee associated with 50 percent of Centennial's outstanding debt. See Note 22 to the unaudited consolidated financial statements for additional information on the debt guarantee.

Net gain on disposal of assets increased $11 million in the first nine months of 2014 compared to the first nine months of 2013, primarily due to the sale of two terminals.

Other income increased $17 million in the first nine months of 2014 compared to the first nine months of 2013, primarily due to higher gains on sales of excess Renewable Identification Numbers (“RINs”) of $33 million, partially offset by an $11 million impairment in 2014 of an investment in a company accounted for using the cost method.

Cost of revenues decreased $1.62 billion in the third quarter and $336 million in the first nine months of 2014 compared to the same periods of 2013. The decreases were primarily due to:

• decreases in refined product cost of sales of $1.68 billion for the third quarter and $1.29 billion for the first nine months, primarily due to a decrease in raw material costs, partially offset in the first nine months by an increase in refined product sales volumes; and

• increases in refinery direct operating costs, including costs associated with significant planned turnaround activity, of $152 million, or $0.87 per barrel of total refinery throughput, for the third quarter and $923 million, or $1.95 per barrel of total refinery throughput, for the first nine months.

Purchases from related parties increased $9 million in the third quarter and $147 million in the first nine months of 2014 compared to the same periods of 2013, primarily due to:

• acquisitions of ownership interests in TAAE in August 2013 and Explorer in March 2014, resulting in purchases from these companies totaling $29 million and $93 million in the third quarter and first nine months of 2014, respectively, being reported as purchases from related parties while purchases from these companies prior to these acquisitions were reported as cost of revenues;

• an increase in purchases from LOOP of $45 million in the first nine months of 2014; and

• an increase in purchases from TAME of $13 million in the first nine months;

• partially offset by a decrease in purchases from TACE of $9 million in the third quarter.

Depreciation and amortization increased $23 million in the third quarter and $79 million in the first nine months of 2014 compared to the same periods of 2013, primarily due to accelerated depreciation of equipment at two refineries, capital investments at our Galveston Bay refinery and the implementation of corporate-level information technology projects, partially offset in the first nine months of 2013 by an impairment of a light products terminal.

Selling, general and administrative expenses increased $37 million in the third quarter and $92 million in the first nine months of 2014 compared to the same periods of 2013, primarily due to increases in contract services, employee compensation and benefit expenses and credit card processing fees. The increase in the first nine months included an increase in pension settlement expenses of $7 million resulting from the level of employee lump sum retirement distributions that occurred during that period.

Other taxes increased $4 million in the third quarter and $29 million in the first nine months of 2014 compared to the same periods of 2013. The increase in the third quarter was primarily due to increases in property taxes of $11 million and environmental taxes of $10 million, partially offset by decreases in sales and use taxes of $10 million and other tax expenses. The increase in the first nine months was primarily due to increases in payroll taxes of $16 million, property taxes of $12 million and environmental taxes of $11 million, partially offset by decreases in other tax expenses.

Provision for income taxes increased $252 million in the third quarter and $123 million in the first nine months of 2014 compared to the same periods of 2013, primarily due to changes in income before income taxes, which increased$758 million in the third quarter and $371 million in the first nine months. The effective tax rates for the third quarter and first nine months of both 2014 and 2013 are slightly less than the U.S. statutory rate of 35 percent primarily due to certain permanent benefit differences, including the domestic manufacturing deduction, partially offset by state and local tax expense.

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The above discussion contains forward-looking statements with respect to the carrying value of our Centennial equity investment. Factors that could affect the carrying value of our Centennial equity investment include, but are not limited to, a change in 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. These factors, among others, could cause actual results to differ materially from those set forth in the forward-looking statements.

Segment Results

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

	Three Months Ended   September 30,				Nine Months Ended   September 30,
(In millions)	2014		2013		2014		2013
Refining & Marketing	$	23,968	$	24,920	$	71,518	$	71,317
Speedway	3,856		3,756		11,224		10,967
Pipeline Transportation	152		137		448		400
Segment revenues	$	27,976	$	28,813	$	83,190	$	82,684
Items included in both revenues and costs:
Consumer excise taxes	$	1,622	$	1,631	$	4,736	$	4,685

Refining & Marketing segment revenues decreased $952 million in the third quarter and increased $201 million in the first nine months of 2014 compared to the same periods of 2013. The decrease in the third quarter was primarily due to decreases in refined product sales prices and volumes and crude oil sales prices. The increase in the first nine months was primarily due to an increase in refined product sales volumes, partially offset by lower refined product sales prices. 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,
	2014		2013		2014		2013
Refining & Marketing segment:
Refined product sales volumes (thousands of barrels per day)(a)	2,140		2,148		2,079		2,052
Refined product sales destined for export (thousands of barrels per day)	299		246		273		192
Average refined product sales prices (dollars per gallon)	$	2.80	$	2.89	$	2.89	$	2.92

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

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)	2014		2013		2014		2013
Chicago spot unleaded regular gasoline	$	2.68	$	2.84	$	2.75	$	2.86
Chicago spot ultra-low sulfur diesel	2.82		3.02		2.92		3.04
USGC spot unleaded regular gasoline	2.65		2.78		2.70		2.76
USGC spot ultra-low sulfur diesel	2.79		3.01		2.88		2.98

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Refining & Marketing intersegment sales to our Speedway segment decreased $39 million in the third quarter and increased $151 million in the first nine months of 2014 compared to the same periods of 2013. The decrease in the third quarter was primarily due to lower refined product sales prices, partially offset by an increase in intersegment refined product sales volumes. The increase in the first nine months was primarily due to an increase in intersegment refined product sales volumes, partially offset by lower refined product sales prices. The table below shows our Refining & Marketing intersegment sales to our Speedway segment.

	Three Months Ended   September 30,				Nine Months Ended   September 30,
	2014		2013		2014		2013
Refining & Marketing intersegment sales to Speedway:
Intersegment sales (in millions)	$	2,400	$	2,439	$	7,223	$	7,072
Refined product sales volumes (millions of gallons)	789		774		2,285		2,207
Average refined product sales prices (dollars per gallon)	$	3.03	$	3.14	$	3.15	$	3.19

Speedway segment revenues increased $100 million in the third quarter and $257 million in the first nine months of 2014 compared to the same periods of 2013, primarily due to increases in gasoline and distillate sales of $93 million and $205 million, respectively, and increases in merchandise sales of $27 million and $62 million, respectively. The increases in gasoline and distillate sales were primarily due to volume increases of 39 million gallons and 92 million gallons, respectively, primarily due to an increase in the number of convenience stores, partially offset by decreases in gasoline and distillate selling prices of $0.05 per gallon. The increases in merchandise sales were primarily due to an increase in the number of convenience stores and higher same store sales.

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

	Three Months Ended   September 30,						Nine Months Ended   September 30,
	2014			2013			2014			2013
Convenience stores at period-end(a)	2,744			1,471
Gasoline & distillate sales (millions of gallons)	842			803			2,421			2,329
Average gasoline & distillate sales prices (dollars per gallon)	$	3.42		$	3.47		$	3.49		$	3.54
Merchandise sales (in millions)	$	870		$	843		$	2,422		$	2,360
Same store gasoline sales volume (period over period)	(0.8		%)	1.0		%	(1.0		%)	0.6		%
Same store merchandise sales (period over period)(b)	4.8		%	5.6		%	4.8		%	3.8		%

^(a) Includes 1,245 stores acquired on September 30, 2014 through the acquisition of Hess' Retail Operations and Related Assets. Segment results for the period prior to the acquisition do not include results from these operations.

^(b)  Excludes cigarettes.

Pipeline Transportation segment revenue increased $15 million in the third quarter and $48 million in the first nine months of 2014 compared to the same periods of 2013, primarily due to increases in revenue related to volume deficiency credits and higher average tariffs received on crude oil and refined products shipped, partially offset by lower crude oil and refined products pipeline throughput volumes. Crude oil pipeline throughput volumes decreased 52 mbpd in the third quarter and 78 mbpd in the first nine months of 2014 compared to the same periods of 2013 and refined products pipeline throughput volumes decreased 74 mbpd and 87 mbpd, respectively.

The following table includes throughput volumes for the Pipeline Transportation segment.

	Three Months Ended   September 30,		Nine Months Ended   September 30,
	2014	2013	2014	2013
Pipeline Throughputs (thousands of barrels per day):(a)
Crude oil pipelines	1,265	1,317	1,230	1,308
Refined products pipelines	839	913	843	930
Total	2,104	2,230	2,073	2,238

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

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

	Three Months Ended   September 30,						Nine Months Ended   September 30,
(In millions)	2014			2013			2014			2013
Income from Operations by segment
Refining & Marketing	$	971		$	227		$	2,593		$	2,235
Speedway	119			102			271			292
Pipeline Transportation(a)	69			54			222			163
Items not allocated to segments:
Corporate and other unallocated items(a)	(76		)	(59		)	(204		)	(190		)
Pension settlement expenses	(21		)	(23		)	(90		)	(83		)
Income from operations	1,062			301			2,792			2,417
Net interest and other financial income (costs)	(50		)	(47		)	(144		)	(140		)
Income before income taxes	$	1,012		$	254		$	2,648		$	2,277

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

Refining & Marketing segment income from operations increased $744 million in the third quarter and $358 million in the first nine months of 2014 compared to the same periods of 2013, primarily due to more favorable net product price realizations and higher USGC and Chicago crack spreads, partially offset by increases in refinery direct operating costs in both periods of 2014 and narrower LLS-WTI and sweet/sour differentials in the first nine months of 2014.

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)	2014		2013		2014		2013
Chicago LLS 6-3-2-1(a)(b)	$	9.43	$	7.34	$	10.05	$	8.75
USGC LLS 6-3-2-1(a)	8.26		6.02		8.35		5.96
Blended 6-3-2-1(a)(c)	8.70		6.52		9.00		7.02
LLS	101.05		109.97		103.61		109.46
WTI	97.25		105.81		99.62		98.20
LLS—WTI crude oil differential(a)	3.80		4.16		3.99		11.26
Sweet/Sour crude oil differential(a)(d)	6.59		6.55		7.05		8.23

^(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 38 percent/62 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 and first nine months of 2014 compared to the same periods of 2013:

• The Chicago LLS 6-3-2-1 crack spread increased $2.09 per barrel in the third quarter and $1.30 per barrel in the first nine months, which had positive impacts on segment income of $138 million and $226 million, respectively.

• The USGC LLS 6-3-2-1 crack spread increased $2.24 per barrel in the third quarter and $2.39 per barrel in the first nine months, which had positive impacts on segment income of $241 million and $705 million, respectively.

• The LLS-WTI crude oil differential narrowed $0.36 per barrel in the third quarter and $7.27 per barrel in the first nine months, which had negative impacts on segment income of $40 million and $759 million, respectively.

• The sweet/sour crude oil differential widened $0.04 per barrel in the third quarter and narrowed $1.18 per barrel in the first nine months, which had a positive impact on segment income of $8 million for the third quarter and a negative impact on segment income of $298 million for the first nine months.

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The above market indicators use spot market values and an estimated mix of crude purchases and products sold. Differences in our results compared to these market indicators, including product price realizations, mix and crude costs as well as other items like refinery yields and other feedstock variances, had estimated positive impacts on Refining & Marketing segment income of $548 million for the third quarter and $1.39 billion for the first nine months of 2014 compared to the same periods of 2013. We believe the more favorable net product price realizations as compared to spot market values comprised a significant portion of the increases in segment income for both the third quarter and the first nine months.

The following table summarizes our refinery throughputs.

	Three Months Ended   September 30,		Nine Months Ended   September 30,
	2014	2013	2014	2013
Refinery Throughputs (thousands of barrels per day):
Crude oil refined	1,720	1,682	1,616	1,603
Other charge and blendstocks	160	195	172	202
Total	1,880	1,877	1,788	1,805
Sour crude oil throughput percent	52	53	52	53
WTI-priced crude oil throughput percent	16	21	18	22

Crude oil throughputs increased 38 mbpd in the third quarter and 13 mbpd in the first nine months of 2014 compared to the same periods of 2013, primarily attributable to the Galveston Bay refinery, partially offset by lower crude oil throughput at the Robinson refinery. Other charge and blendstocks throughputs decreased 35 mbpd in the third quarter and 30 mbpd in the first nine months of 2014 compared to the same periods of 2013 primarily attributable to the Garyville and Robinson refineries for both periods of 2014 and the Galveston Bay refinery for the third quarter of 2014. The decrease in the first nine months of 2014 was partially offset by higher other charge and blendstocks throughput at the Galveston Bay refinery.

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

	Three Months Ended   September 30,				Nine Months Ended   September 30,
	2014		2013		2014		2013
Refining & Marketing gross margin (dollars per barrel)(a)	$	14.55	$	9.25	$	15.02	$	12.42
Refinery direct operating costs (dollars per barrel):(b)
Planned turnaround and major maintenance	$	1.52	$	0.96	$	1.82	$	0.94
Depreciation and amortization	1.35		1.27		1.43		1.32
Other manufacturing(c)	4.33		4.10		4.96		4.00
Total	$	7.20	$	6.33	$	8.21	$	6.26

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

^(b)  Per barrel of total refinery throughputs.

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

Refinery direct operating costs increased $152 million, or $0.87 per barrel, in the third quarter and $923 million, or $1.95 per barrel, in the first nine months of 2014 compared to the same periods of 2013, which include increases in planned turnaround and major maintenance costs of $0.56 per barrel and $0.88 per barrel, respectively, and increases in other manufacturing costs of $0.23 per barrel and $0.96 per barrel, respectively. The increases in planned turnaround and major maintenance costs were primarily attributable to the Catlettsburg and Galveston Bay refineries for the third quarter and the Galveston Bay and Robinson refineries for the first nine months. The increases in other manufacturing costs were primarily attributable to higher energy costs for both periods and higher catalyst expenses and routine maintenance costs for the first nine months.

We purchase RINs to satisfy a portion of our Renewable Fuel Standard compliance. Our expense associated with purchased RINs decreased to $28 million in the third quarter and $121 million in the first nine months of 2014 from $78 million in the third quarter and $185 million in the first nine months of 2013. The decreases were primarily due to decreases in the average cost of ethanol and biomass-based biodiesel RINs and decreases in our estimated advanced biofuel and ethanol obligation volumes.

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Speedway segment income from operations increased $17 million in the third quarter and decreased $21 million in the first nine months of 2014 compared to the same periods of 2013. The increase in segment income for the third quarter was primarily due to an increase in our gasoline and distillate gross margin of $22 million, or $0.0192 per gallon, and an increase in our merchandise gross margin of $11 million, partially offset by higher operating expenses. The decrease in segment income for the first nine months was primarily due to higher operating expenses and a decrease in our gasoline and distillate gross margin of $18 million, or $0.0132 per gallon, partially offset by an increase in our merchandise gross margin of $31 million. Operating expenses were higher primarily due to an increase in the number of stores. The increases in merchandise gross margin were primarily due to a combination of higher merchandise and food sales and improved margins.

The following table includes margin statistics for the Speedway segment.

	Three Months Ended   September 30,						Nine Months Ended   September 30,
	2014			2013			2014			2013
Gasoline & distillate gross margin (dollars per gallon)(a)	$	0.1596		$	0.1404		$	0.1351		$	0.1483
Merchandise gross margin (in millions)	$	235		$	224		$	651		$	620
Merchandise gross margin percent	27.0		%	26.5		%	26.9		%	26.3		%

^(a)  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.

Pipeline Transportation segment income from operations increased $15 million in the third quarter and $59 million in the first nine months of 2014 compared to the same periods of 2013, primarily due to higher pipeline transportation revenue and increases in income from our pipeline affiliates, which for the first nine months was primarily attributable to our investment in LOOP, partially offset by increases in operating expenses primarily attributable to the proposed Cornerstone pipeline project for both periods of 2014 and pipeline maintenance costs in the third quarter of 2014.

Corporate and other unallocated items increased $17 million in the third quarter and $14 million in the first nine months of 2014 compared to the same periods of 2013, primarily due to costs incurred in connection with the acquisition of Hess' Retail Operations and Related Assets.

Liquidity and Capital Resources

Cash Flows

Our cash and cash equivalents balance was $1.85 billion at September 30, 2014 compared to $2.29 billion at December 31, 2013. Net cash provided by (used in) operating activities, investing activities and financing activities for the first nine months of 2014 and 2013 are presented in the following table.

	Nine Months Ended   September 30,
(In millions)	2014			2013
Net cash provided by (used in):
Operating activities	$	2,722		$	2,050
Investing activities(a)	(4,024		)	(2,251		)
Financing activities	864			(2,641		)
Total	$	(438	)	$	(2,842	)

^(a)  The nine months ended September 30, 2014 includes the acquisition of Hess' Retail Operations and Related Assets. The nine months ended September 30, 2013 includes the acquisition of the Galveston Bay Refinery and Related Assets. See Note 4 to the unaudited consolidated financial statements.

Net cash provided by operating activities increased$672 million in the first nine months of 2014 compared to the first nine months of 2013 primarily due to favorable changes in working capital of $306 million and an increase in net income of $248 million. Changes in working capital were a net $24 millionuse of cash in the first nine months of 2014 compared to a net $330 millionuse of cash in the first nine months of 2013. The net $24 millionuse of cash in the first nine months of 2014 was primarily due to an increase in inventories, partially offset by a decrease in current receivables and an increase in accounts payable. Changes from December 31, 2013 to September 30, 2014 per the consolidated balance sheets, excluding the impact of acquisitions, were as follows:

• Inventories increased$731 million from year-end 2013, primarily due to increases in crude oil and refined product inventory volumes.

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• Current receivables decreased$424 million from year-end 2013, primarily due to lower outstanding refined product and crude oil receivable volumes.

• Accounts payable increased$415 million from year-end 2013, primarily due to higher crude oil payable volumes.

The net $330 millionuse of cash in the first nine months of 2013 was primarily due to increases in crude oil and refined product inventory volumes and current receivables, partially offset by an increase in accounts payable. Changes from December 31, 2012 to September 30, 2013 per the consolidated balance sheets were as follows:

• Inventories, excluding the impact of the acquisition of the Galveston Bay Refinery and Related Assets, increased $1.33 billion from year-end 2012, primarily due to increases in crude oil and refined product inventory volumes.

• Current receivables increased $983 million from year-end 2012, primarily due to higher refined product receivable volumes attributable to an increase in refined product sales volumes, and an increase in income taxes receivable associated with federal income taxes.

• Accounts payable increased $2.18 billion from year-end 2012, primarily due to higher crude oil payable volumes related to the requirements of the Galveston Bay refinery acquired in February 2013 and higher crude oil prices at the end of the third quarter of 2013 compared to year-end 2012.

Net cash used in investing activities in the first nine months of 2014 was $1.77 billion higher than the first nine months of 2013, primarily due to the acquisition of Hess' Retail Operations and Related Assets and higher capital expenditures in our Refining & Marketing segment in the first nine months of 2014, partially offset by the Galveston Bay Refinery and Related Assets acquisition in February 2013.

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)	2014		2013
Additions to property, plant and equipment per consolidated statements of cash flows	$	952	$	733
Non-cash additions to property, plant and equipment	4		—
Acquisitions(a)	2,714		1,386
Asset retirement expenditures	1		—
Increase in capital accruals	—		63
Total capital expenditures	3,671		2,182
Investments in equity method investees	341		86
Total capital expenditures and investments	$	4,012	$	2,268

^(a)  The 2014 acquisition includes the acquisition of Hess' Retail Operations and Related Assets. The 2013 acquisition includes the acquisition of the Galveston Bay Refinery and Related Assets. The acquisition numbers above include property, plant and equipment and intangibles.

Capital expenditures and investments are summarized by segment below.

	Nine Months Ended   September 30,
(In millions)	2014		2013
Refining & Marketing(a)(b)	$	731	$	1,797
Speedway(b)	2,783		177
Pipeline Transportation(a)	418		173
Corporate and Other(c)	80		121
Total	$	4,012	$	2,268

^(a)  The nine months ended September 30, 2013 includes the acquisition of the Galveston Bay Refinery and Related Assets. See Note 4 to the unaudited consolidated financial statements.

^(b)  The nine months ended September 30, 2014 includes the acquisition of Hess' Retail Operations and Related Assets. See Note 4 to the unaudited consolidated financial statements.

^(c)  Includes capitalized interest of $20 million and $15 million for the nine months ended September 30, 2014 and 2013, respectively.

The acquisition of Hess' Retail Operations and Related Assets comprised 67 percent of our total capital spending in the first nine months of 2014. The acquisition of the Galveston Bay Refinery and Related Assets comprised 60 percent of our total capital spending in the first nine months of 2013.

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Net cash used in investments in affiliates increased$301 million for the first nine months of 2014 compared to the first nine months of 2013, primarily due to our contributions to North Dakota Pipeline of $149 million to fund the Sandpiper pipeline project, our contributions to Illinois Extension Pipeline of $97 million to fund the SAX pipeline project and our acquisition of an additional seven percent interest in Explorer for $77 million in the first nine months of 2014, partially offset by our acquisition of interests in TAAE, TACE and TAEI for $75 million in the first nine months of 2013.

Net cash provided by all other investing activities was $78 million for the first nine months of 2014 compared to $22 million for the first nine months of 2013, which consists primarily of sales of excess RINs of $74 million and $22 million, respectively.

Financing activities were a net $864 millionsource of cash in the first nine months of 2014 compared to a net $2.64 billionuse of cash in the first nine months of 2013. The sources of cash for the first nine months of 2014 consisted of long-term debt borrowings. The uses of cash for both periods were primarily for common stock repurchases under our share repurchase plans and dividend payments. The first nine months of 2014 includes payment for the first period's contingent earnout for the Galveston Bay Refinery and Related Assets.

Long-term debt borrowings and repayments were a net $2.87 billionsource of cash in the first nine months of 2014 compared to a $16 millionuse of cash in the first nine months of 2013. During the first nine months of 2014, we issued $1.95 billion in aggregate principal amount of senior unsecured notes and borrowed $700 million under a term loan credit agreement to finance the acquisition of Hess' Retail Operations and Related Assets. In addition, MPLX borrowed $270 million under its revolving credit agreement to fund the acquisition of an additional interest in Pipe Line Holdings and subsequently repaid $15 million.

Cash used in common stock repurchases decreased$892 million in the first nine months of 2014 compared to the first nine months of 2013. The table below summarizes our total share repurchases. See Note 8 to the unaudited consolidated financial statements for further discussion of the share repurchase plans.

	Nine Months Ended   September 30,
(In millions, except per share data)	2014		2013
Number of shares repurchased(a)	17		31
Cash paid for shares repurchased	$	1,449	$	2,341
Effective average cost per delivered share	$	87.25	$	76.01

^(a)  The nine months ended September 30, 2013 includes one million shares received under the November 2012 accelerated share repurchase program, which were paid for in 2012.

Cash used in dividend payments increased$28 million in the first nine months of 2014 compared to the first nine months of 2013, primarily due to increases in our dividend payments totaling $0.22 per common share, from $1.12 per share to $1.34 per share, partially offset by a decrease in the number of outstanding shares of our common stock attributable to share repurchases.

Derivative Instruments

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

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Capital Resources

Our liquidity totaled $5.65 billion at September 30, 2014 consisting of:

	September 30, 2014
(In millions)	Total Capacity		Outstanding Borrowings		Available Capacity
Revolving credit agreement(a)	$	2,500	$	—	$	2,500
Trade receivables securitization facility	1,300		—		1,300
Total	$	3,800	$	—	$	3,800
Cash and cash equivalents					1,854
Total liquidity					$	5,654

^(a)  Excludes MPLX’s $500 million revolving credit agreement, which had $245 million available as of September 30, 2014.

Because of the alternatives available to us, including internally generated cash flow and access to capital markets, 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 August 26, 2014, we entered into a $700 million five-year senior unsecured term loan credit agreement (the “Term Loan Agreement”) with a syndicate of lenders to fund a portion of the purchase price of Hess' Retail Operations and Related Assets. The Term Loan Agreement matures on September 24, 2019 and may be prepaid at any time without premium or penalty. We are obligated to pay certain customary fees under the Term Loan Agreement, including an annual administrative fee.

Amounts outstanding under the Term Loan Agreement bear interest at either of the following rates at our election (i) the sum of the Adjusted LIBO Rate (as defined in the Term Loan Agreement), plus a margin ranging between 0.875 percent to 1.75 percent, depending on our credit ratings, or (ii) the sum of the Base Rate (as defined in the Term Loan Agreement), plus a margin ranging between zero percent to 0.75 percent, depending on our credit ratings. The interest rate during the quarter ended September 30, 2014 was 1.3 percent.

On September 5, 2014, we completed a public offering of $1.95 billion in aggregate principal amount of senior unsecured notes (the "Senior Notes"), consisting of $750 million aggregate principal amount of our Senior Notes due 2024, $800 million aggregate principal amount of our Senior Notes due 2044 and $400 million aggregate principal amount of our Senior Notes due 2054. The net proceeds from the offering of the Senior Notes were approximately $1.915 billion, after deducting underwriting discounts and estimated offering expenses. The proceeds were used to fund a portion of the purchase price of Hess' Retail Operations and Related Assets. Interest on each series of Senior Notes is payable semi-annually in arrears on March 15 and September 15 of each year, commencing on March 15, 2015.

The Senior Notes are unsecured and unsubordinated obligations of ours and rank equally with all our other existing and future unsecured and unsubordinated indebtedness.

The Term Loan Agreement, our revolving credit agreement (the “MPC Credit Agreement”) and the 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 Term Loan Agreement and the MPC Credit Agreement 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 Term Loan Agreement and the MPC Credit Agreement) of no greater than 0.65 to 1.00. As of September 30, 2014, we were in compliance with this debt covenant with a ratio of Consolidated Net Debt to Total Capitalization of 0.32 to 1.00, as well as the other covenants contained in the Term Loan Agreement and the MPC Credit Agreement.

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). As of September 30, 2014, MPLX was in compliance with this debt covenant with a ratio of Consolidated Total Debt to Consolidated EBITDA of 1.7 to 1.0, as well as the other covenants contained in the MPLX Credit Agreement.

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Our intention is to maintain an investment grade credit profile. As of September 30, 2014, the credit ratings on our senior unsecured debt were at or above investment grade level as follows.

Rating Agency	Rating
Moody’s	Baa2 (stable outlook)
Standard & Poor’s	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 Term Loan Agreement, the MPC Credit Agreement, the MPLX Credit Agreement nor our trade receivables securitization 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 Term Loan Agreement, the MPC Credit Agreement and our trade receivables securitization facility. 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 securitization facility, impact our ability to purchase crude oil on an unsecured basis and could result in us having to post letters of credit under existing transportation services agreements.

Debt-to-Total-Capital Ratio

Our debt-to-total capital ratio (total debt to total debt-plus-equity) was 36 percent at September 30, 2014 and 23 percent at December 31, 2013.

(In millions)	September 30, 2014			December 31, 2013
Long-term debt due within one year	$	26		$	23
Long-term debt	6,238			3,373
Total debt	$	6,264		$	3,396
Calculation of debt-to-total-capital ratio:
Total debt	$	6,264		$	3,396
Total equity	11,266			11,332
Total capital	$	17,530		$	14,728
Debt-to-total-capital ratio	36		%	23		%

Capital Requirements

We have a capital and investment budget for 2014 of $2.43 billion, excluding capitalized interest and the acquisition of Hess' Retail Operations and Related Assets. The budget includes spending on refining, retail marketing, transportation, logistics and brand marketing projects as well as amounts designated for corporate activities. During the nine months ended September 30, 2014, our capital expenditures and investments were $1.31 billion, excluding capitalized interest and the $2.68 billion for the acquisition of Hess' Retail Operations and Related Assets. Other than the acquisition of Hess' Retail Operations and Related Assets, there have been no material changes to our 2014 capital and investment budget since our Annual Report on Form 10-K for the year ended December 31, 2013 was filed. We continuously evaluate our capital budget and make changes as conditions warrant.

Pursuant to the purchase and sale agreement for the Galveston Bay Refinery and Related Assets, we may be required to pay the seller a contingent earnout of up to an additional $700 million over six years, subject to certain conditions. In July 2014, we paid $180 million for the first period's contingent earnout. See Notes 4 and 15 to the unaudited consolidated financial statements.

As of September 30, 2014, MPLX had $255 million in borrowings outstanding under its revolving credit agreement.

During the nine months ended September 30, 2014, we made contributions of $16 million to our funded pension plans. While we have no required contributions, we may make additional contributions to our funded pension plans in 2014 depending on the anticipated funding status and plan asset performance.

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On October 29, 2014, our board of directors approved a $0.50 per share dividend, payable December 10, 2014 to stockholders of record at the close of business on November 19, 2014.

On July 30, 2014, our board of directors approved an additional $2.0 billion share repurchase authorization expiring in July 2016. During the first nine months of 2014, we paid $1.45 billion to acquire 17 million common shares through open market share repurchases. The effective average cost was $87.25 per delivered share. At September 30, 2014, we also had agreements to repurchase additional common shares for $9 million, which were settled in early October 2014. As of September 30, 2014, we had $2.41 billion of remaining repurchase authorization. See Note 8 to the unaudited consolidated financial statements.

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

The above discussion contains forward-looking statements with respect to share repurchase authorizations. Factors that could affect the share repurchase authorizations and the timing of any repurchases include, but are not limited to, 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.

Contractual Cash Obligations

As of September 30, 2014, 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 2014:

• our committed payments on long-term debt, including interest, increased $4.90 billion in connection with the acquisition of Hess' Retail Operations and Related Assets;

• we assumed operating lease commitments totaling $423 million in connection with the acquisition of Hess' Retail Operations and Related Assets;

• the MPLX Credit Agreement committed payments increased $264 million due to outstanding borrowings on the MPLX Credit Agreement, including interest and fees; and

• we exercised our option to acquire a 35 percent ownership interest in Enbridge Inc.'s SAX pipeline, which increased our committed payments by $208 million.

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 accounting principles generally accepted in the United States. 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 22 to the unaudited consolidated financial statements.

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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 and investment spending. The forward-looking statements about our capital and investment budget are based on current expectations, estimates and projections and are not guarantees of future performance. Actual results may differ materially from these expectations, estimates and projections and are subject to certain risks, uncertainties and other factors, some of which are beyond our control and are difficult to predict. Some factors that could cause actual results to differ materially include prices of and demand for crude oil and refinery feedstocks and refined products, actions of competitors, delays in obtaining necessary 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 and unforeseen hazards such as weather conditions, acts of war or terrorist acts and the governmental or military response, and other operating and economic considerations.

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 U.S. Environmental Protection Agency ("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 parts per million ("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 spend an estimated $750 million to $1 billion between 2014 and 2019 for capital expenditures necessary to comply with these standards.

There have been no other significant changes to our environmental matters and compliance costs during the nine months ended September 30, 2014.

Critical Accounting Estimates

There have been no significant changes to our critical accounting estimates during the nine months ended September 30, 2014.

Accounting Standards Not Yet Adopted

In August 2014, the FASB issued an accounting standards update requiring management to assess an entity's ability to continue as a going concern and to provide related footnote disclosures in certain circumstances. Management will be required to assess if there is substantial doubt about an entity's ability to continue as a going concern within one year after the date that the financial statements are issued. Disclosures will be required if conditions give rise to substantial doubt and the type of disclosure will be determined based on whether management's plans will be able to alleviate the substantial doubt. The accounting standards update will be effective for the first annual period ending after December 15, 2016 and for annual periods and interim periods thereafter with early application permitted.

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In June 2014, the FASB issued an accounting standards update for the elimination of the concept of development stage entity ("DSE") from U.S. GAAP and removes the related incremental reporting. The standards update eliminates the additional financial statement requirements specific to a DSE. In addition, it amends the consolidation model by eliminating the special provisions in the variable interest entity rules for assessing the sufficiency of the equity of a DSE. The portion of the accounting standards update related to the amendment to the consolidation guidance will be effective on a retrospective basis for annual reporting periods beginning after December 15, 2015, and interim periods within those years, with early adoption permitted. The portion of the accounting standards update related to the removal of the DSE reporting requirements will be effective on a retrospective basis for annual reporting periods beginning after December 15, 2014, and interim periods within those years, with early adoption permitted. Adoption of this standards update in the first quarters of 2015 and 2016 is not expected to have an impact on our consolidated results of operations, financial position or cash flows.

In May 2014, the FASB issued an accounting standards update for revenue recognition that is aligned with the International Accounting Standards Board's revenue recognition standard issued on the same day. The guidance in the 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 then 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. The accounting standards update will be effective on a retrospective or modified retrospective basis for annual reporting periods beginning after December 15, 2016, and interim periods within those years, with no early adoption permitted. At this point, a final determination has not been made as to the impact of the adoption of this standards update in the first quarter of 2017. However, we do not expect it to have a material impact on our consolidated results of operations, financial position or cash flows.

In April 2014, the FASB issued an accounting standards update that redefines the criteria for determining discontinued operations and introduces new disclosures related to these disposals. The updated definition of a discontinued operation is the disposal of a component(s) of an entity or the classification of a component(s) of an entity as held for sale that represents a strategic shift for an entity and has (or will have) a major impact on an entity's operations and financial results. The standard requires disclosure of additional financial information for discontinued operations and individually material components not qualifying for discontinued operation presentation, as well as information regarding an entity's continuing involvement with the discontinued operation. The accounting standards update is effective prospectively for annual periods beginning on or after December 15, 2014, and interim periods within those years. Early adoption is permitted. Adoption of this standards update in the first quarter of 2015 is not expected to have an impact on our consolidated results of operations, financial position or cash flows.

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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, 2013.

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

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, 2014 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, 2014
Crude	$	(128	)	$	(318	)	$	133	$	331
Refined products	(14		)	(35		)	14		35

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, 2014 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 as of September 30, 2014 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, 2014(b)		Change in Fair Value			Change in Net Income for the Nine Months Ended September 30, 2014
Long-term debt(a)
Fixed-rate	$	5,269	$	574	(c)	n/a
Variable-rate	955		n/a			2	(d)

^(a)  Excludes capital leases.

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

^(c)  Assumes a 100-basis-point decrease in the weighted average yield-to-maturity at September 30, 2014.

^(d)  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, 2014.

At September 30, 2014, our portfolio of long-term debt was comprised of fixed-rate instruments and variable-rate borrowings under the Term Loan Agreement and the MPLX Credit Agreement. 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 Term Loan Agreement and the MPLX Credit Agreement, 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, 2014, 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, 2014, 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)	2014			2013			2014			2013
Income from Operations by segment
Refining & Marketing	$	971		$	227		$	2,593		$	2,235
Speedway	119			102			271			292
Pipeline Transportation(a)	69			54			222			163
Items not allocated to segments:
Corporate and other unallocated items(a)	(76		)	(59		)	(204		)	(190		)
Pension settlement expenses	(21		)	(23		)	(90		)	(83		)
Income from operations	$	1,062		$	301		$	2,792		$	2,417
Capital Expenditures and Investments(b)(c)
Refining & Marketing	$	318		$	243		$	731		$	1,797
Speedway	2,707			65			2,783			177
Pipeline Transportation	224			42			418			173
Corporate and Other(d)	29			61			80			121
Total	$	3,278		$	411		$	4,012		$	2,268

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

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

^(c)  The three and nine months ended September 30, 2014 includes $2.68 billion for the acquisition of Hess' Retail Operations and Related Assets. The nine months ended September 30, 2013 includes $1.36 billion for the acquisition of the Galveston Bay Refinery and Related Assets. See Note 4 to the unaudited consolidated financial statements.

^(d)  Includes capitalized interest of $7 million for both the three months ended September 30, 2014 and 2013, and $20 million and $15 million for the nine months ended September 30, 2014 and 2013, respectively.

50

Supplementary Statistics (Unaudited)

	Three Months Ended   September 30,				Nine Months Ended   September 30,
	2014		2013		2014		2013
MPC Consolidated Refined Product Sales Volumes (thousands of barrels per day)(a)(b)	2,155		2,155		2,092		2,063
Refining & Marketing Operating Statistics(b)
Refining & Marketing refined product sales volume (thousands of barrels per day)(c)	2,140		2,148		2,079		2,052
Refining & Marketing gross margin (dollars per barrel)(d)	$	14.55	$	9.25	$	15.02	$	12.42
Crude oil capacity utilization percent(e)	100		99		94		97
Refinery throughputs (thousands of barrels per day):(f)
Crude oil refined	1,720		1,682		1,616		1,603
Other charge and blendstocks	160		195		172		202
Total	1,880		1,877		1,788		1,805
Sour crude oil throughput percent	52		53		52		53
WTI-priced crude oil throughput percent	16		21		18		22
Refined product yields (thousands of barrels per day):(f)
Gasoline	864		938		851		917
Distillates	598		578		574		570
Propane	36		39		36		37
Feedstocks and special products	330		259		280		227
Heavy fuel oil	24		31		27		31
Asphalt	63		70		52		57
Total	1,915		1,915		1,820		1,839
Refinery direct operating costs (dollars per barrel):(g)
Planned turnaround and major maintenance	$	1.52	$	0.96	$	1.82	$	0.94
Depreciation and amortization	1.35		1.27		1.43		1.32
Other manufacturing(h)	4.33		4.10		4.96		4.00
Total	$	7.20	$	6.33	$	8.21	$	6.26
Refining & Marketing Operating Statistics By Region - Gulf Coast(b)
Refinery throughputs (thousands of barrels per day):(i)
Crude oil refined	1,075		1,035		989		971
Other charge and blendstocks	155		175		174		181
Total	1,230		1,210		1,163		1,152
Sour crude oil throughput percent	66		64		64		65
WTI-priced crude oil throughput percent	1		7		2		8
Refined product yields (thousands of barrels per day):(i)
Gasoline	505		561		498		545
Distillates	389		370		366		363
Propane	25		24		24		23
Feedstocks and special products	310		241		275		214
Heavy fuel oil	8		21		13		20
Asphalt	19		23		13		14
Total	1,256		1,240		1,189		1,179
Refinery direct operating costs (dollars per barrel):(g)
Planned turnaround and major maintenance	$	1.15	$	0.86	$	1.77	$	0.77
Depreciation and amortization	1.10		1.01		1.16		1.04
Other manufacturing(h)	4.11		4.08		4.86		3.82
Total	$	6.36	$	5.95	$	7.79	$	5.63

51

Supplementary Statistics (Unaudited)
	Three Months Ended   September 30,						Nine Months Ended   September 30,
	2014			2013			2014			2013
Refining & Marketing Operating Statistics By Region - Midwest
Refinery throughputs (thousands of barrels per day):(i)
Crude oil refined	645			647			627			632
Other charge and blendstocks	38			56			43			55
Total	683			703			670			687
Sour crude oil throughput percent	30			35			33			35
WTI-priced crude oil throughput percent	41			43			42			43
Refined product yields (thousands of barrels per day):(i)
Gasoline	359			377			353			373
Distillates	209			208			208			207
Propane	13			15			13			14
Feedstocks and special products	51			54			49			46
Heavy fuel oil	16			10			14			11
Asphalt	44			47			39			43
Total	692			711			676			694
Refinery direct operating costs (dollars per barrel):(g)
Planned turnaround and major maintenance	$	2.10		$	1.08		$	1.78		$	1.17
Depreciation and amortization	1.75			1.66			1.80			1.72
Other manufacturing(h)	4.51			3.91			4.82			4.10
Total	$	8.36		$	6.65		$	8.40		$	6.99
Speedway Operating Statistics
Convenience stores at period-end(j)	2,744			1,471
Gasoline and distillate sales (millions of gallons)	842			803			2,421			2,329
Gasoline and distillate gross margin (dollars per gallon)(k)	$	0.1596		$	0.1404		$	0.1351		$	0.1483
Merchandise sales (in millions)	$	870		$	843		$	2,422		$	2,360
Merchandise gross margin (in millions)	$	235		$	224		$	651		$	620
Merchandise gross margin percent	27.0		%	26.5		%	26.9		%	26.3		%
Same store gasoline sales volume (period over period)	(0.8		%)	1.0		%	(1.0		%)	0.6		%
Same store merchandise sales (period over period)(l)	4.8		%	5.6		%	4.8		%	3.8		%
Pipeline Transportation Operating Statistics
Pipeline throughputs (thousands of barrels per day):(m)
Crude oil pipelines	1,265			1,317			1,230			1,308
Refined products pipelines	839			913			843			930
Total	2,104			2,230			2,073			2,238

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

^(b)  Includes the impact of the Galveston Bay Refinery and Related Assets beginning on the February 1, 2013 acquisition date.

^(c)  Includes intersegment sales.

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

^(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 33 mbpd and 36 mbpd for the three months ended September 30, 2014 and 2013, respectively, and 45 mbpd and 34 mbpd for the nine months ended September 30, 2014 and 2013, 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)  Includes 1,245 stores acquired on September 30, 2014 through the acquisition of Hess' Retail Operations and Related Assets. Segment results for the period prior to the acquisition do not include results from these operations.

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

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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 previously reported.

Litigation

We are a party to a number of lawsuits and other proceedings and cannot predict the outcome of every such matter with certainty. While it is possible that an adverse result in one or more of the lawsuits or proceedings in which we are a defendant could be material to us, based upon current information and our experience as a defendant in other matters, we believe that these lawsuits and proceedings, individually or in the aggregate, will not have a material adverse effect on our consolidated results of operations, financial position or cash flows.

Environmental Proceedings

As reported in our Annual Report on Form 10-K for the year ended December 31, 2013, we have been subject to a pending enforcement matter with the Illinois Environmental Protection Agency and the Illinois attorney general’s office since 2002 concerning self-reporting of possible emission exceedances and permitting issues related to storage tanks at the Robinson, Illinois refinery. As a result of these allegations, we tentatively agreed to pay a $150,000 civil penalty and undertake a supplemental environmental project involving the installation of ambient air monitors at the refinery. The consent order is not yet finalized, but the ultimate resolution of this matter will not have a material impact on our consolidated results of operations, financial position or cash flows.

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

Item 1A. Risk Factors

We are subject to various risks and uncertainties in the course of our business. Other than as discussed below, there have been no material changes to the risks or uncertainties found under Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended December 31, 2013.

An easing or lifting of the U.S. crude oil export ban could adversely affect crack spreads or crude oil price differentials and have a material adverse effect on our business, financial condition, results of operations and cash flows.

Since the 1970s, the U.S. has restricted the ability of producers to export domestic crude oil. As total crude oil production has increased in the U.S. in recent years, primarily due to the increase in shale crude oil production, there have been increasing calls by crude oil producers and others for an easing or lifting of the crude oil export ban. If the export ban were to be significantly eased or lifted, the price of domestic crude oil would likely rise, potentially impacting crack spreads and price differentials between domestic and foreign crude oils. A deterioration of crack spreads or price differentials between domestic and foreign crude oils could have a material adverse effect on our business, financial condition, results or operations and cash flows.

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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, 2014, 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)
07/01/2014-07/31/2014	1,147,903	$	78.41	1,121,300	$	2,620,803,663
08/01/2014-08/31/2014	819,981	$	86.52	819,600	2,549,895,143
09/01/2014-09/30/2014	1,590,810	$	89.20	1,590,700	2,408,008,738
Total	3,558,694	$	85.10	3,531,600

^(a)  The amounts in this column include 26,603, 381 and 110 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 July 30, 2014, we announced that our board of directors approved an additional $2.0 billion share repurchase authorization expiring in July 31, 2016, resulting in $8.0 billion of total share repurchase authorizations since January 1, 2012. This authorization is in addition to the previous authorization, announced September 26, 2013, which had approximately $408 million remaining as of September 30, 2014.

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Item 6. Exhibits

			Incorporated by Reference			Filed Herewith	Furnished Herewith
Exhibit Number	Exhibit Description	Form	Exhibit	Filing Date	SEC File No.
2.1	Amendment No. 1, effective as of September 30, 2014, to the Purchase Agreement by and between Speedway LLC and Hess Corporation, dated as of May 21, 2014	8-K	2.2	10/6/2014	001-35054
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	10-Q	3.2	8/8/2012	001-35054
4.1	First Supplemental Indenture, dated as of September 5, 2014, by and between Marathon Petroleum Corporation and The Bank of New York Mellon Trust Company, N.A., as trustee					X
10.1	Term Loan Agreement, dated August 26, 2014, by and among Marathon Petroleum Corporation, as borrower, The Royal Bank of Scotland PLC, as administrative agent, each of RBS Securities Inc., The Bank of Tokyo-Mitsubishi UFJ, Ltd. Barclays Bank PLC, Citigroup Global Markets Inc., and Morgan Stanley Senior Funding, Inc., as joint lead arrangers and joint bookrunners, The Bank of Tokyo-Mitsubishi UFJ, Ltd., as syndication agent, each of Barclays Bank PLC, Citigroup Global Markets Inc. and Morgan Stanley Senior Funding, Inc., as documentation agents, and several other commercial lending institutions that are parties thereto	8-K	10.1	8/29/2014	001-35054
31.1	Certification of President and Chief Executive Officer pursuant to Rule 13(a)-14 and 15(d)-14 under the Securities Exchange Act of 1934					X
31.2	Certification of Senior Vice President and Chief Financial Officer pursuant to Rule 13(a)-14 and 15(d)-14 under the Securities Exchange Act of 1934					X
32.1	Certification of President and Chief Executive Officer pursuant to 18 U.S.C. Section 1350						X
32.2	Certification of Senior Vice President and Chief Financial Officer pursuant to 18 U.S.C. Section 1350						X
101.INS	XBRL Instance Document					X
101.SCH	XBRL Taxonomy Extension Schema					X
101.PRE	XBRL Taxonomy Extension Presentation Linkbase					X
101.CAL	XBRL Taxonomy Extension Calculation Linkbase					X
101.DEF	XBRL Taxonomy Extension Definition Linkbase					X
101.LAB	XBRL Taxonomy Extension Label Linkbase					X

55

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.

November 3, 2014	MARATHON PETROLEUM CORPORATION
	By:	/s/ John J. Quaid
		John J. Quaid Vice President and Controller

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EX-4.1

Exhibit 4.1

FIRST SUPPLEMENTAL INDENTURE

THIS FIRST SUPPLEMENTAL INDENTURE, dated as of September 5, 2014 (this “Supplemental Indenture”), is between Marathon Petroleum Corporation, a corporation duly organized and existing under the laws of the State of Delaware (the “Company”), and The Bank of New York Mellon Trust Company, N.A., a national banking association, as trustee (the “Trustee”).

WITNESSETH

WHEREAS, pursuant to the Indenture, dated as of February 1, 2011, between the Company and the Trustee (the “Indenture”), the Company may from time to time issue and sell Securities in one or more series;

WHEREAS, the Company desires to create and authorize three new series of Securities entitled “3.625% Senior Notes due 2024” (the “2024 Notes”), limited initially to $750,000,000 in aggregate principal amount, “4.750% Senior Notes due 2044” (the “2044 Notes”), limited initially to $800,000,000 in aggregate principal amount, and “5.000% Senior Notes due 2054” (the “2054 Notes” and, together with the 2024 Notes and the 2044 Notes, the “Notes”), limited initially to $400,000,000 in aggregate principal amount, and to provide the terms and conditions upon which the Notes are to be executed, registered, authenticated, issued and delivered, the Company has duly authorized the execution and delivery of this Supplemental Indenture;

WHEREAS, the 2024 Notes, the 2044 Notes and the 2054 Notes are three series of Securities and are being issued under the Indenture, as supplemented by this Supplemental Indenture, and are subject to the terms contained therein and herein;

WHEREAS, the 2024 Notes, the 2044 Notes and the 2054 Notes are to be substantially in the form attached hereto as Exhibit A, Exhibit B and Exhibit C, respectively; and

WHEREAS, all acts and things necessary to make the Notes, when executed by the Company and authenticated and delivered by or on behalf of the Trustee as provided in the Indenture and this Supplemental Indenture, the valid, binding and legal obligations of the Company, and to make this Supplemental Indenture a legal, binding and enforceable agreement, have been done and performed.

NOW, THEREFORE, in order to declare the terms and conditions upon which the Notes are executed, registered, authenticated, issued and delivered, and in consideration of the foregoing premises and the purchase of such Notes by the Holders thereof, the Company and the Trustee mutually covenant and agree, for the equal and proportionate benefit of the Holders from time to time of the Notes, as follows:

Section 1.Definitions. Terms used in this Supplemental Indenture and not defined herein shall have the respective meanings given such terms in the Indenture.

Section 2.Creation and Authorization of Series.

(a)There is hereby created and authorized the following three new series of Securities to be offered and issued under the Indenture, to be designated as the “3.625% Senior Notes due 2024,” the “4.750% Senior Notes due 2044” and the “5.000% Senior Notes due 2054.”

(b)The 2024 Notes shall be limited initially to $750,000,000 in aggregate principal amount, the 2044 Notes shall be limited initially to $800,000,000 in aggregate principal amount and the 2054 Notes shall be limited initially to $400,000,000 in aggregate principal amount. Notwithstanding the foregoing initial aggregate principal amounts, the Company may, from time to time, without notice to or consent of the Holders of the Notes, increase the principal amounts of the Notes that may be issued under this Supplemental Indenture and issue such increased principal amounts (or any portion thereof), in which case any additional Notes so issued will have the same terms and conditions other than the public offering price, original interest accrual date and initial interest payment date, and the same CUSIP numbers as the applicable series of Notes previously issued, will be fungible with the applicable series of Notes previously issued for U.S. federal income tax purposes, and will carry the same right to receive accrued and unpaid interest as the Notes previously issued, and such additional notes will form a single series with the Notes of such series previously issued, including, without limitation, for purposes of waivers, amendments, redemptions and, if any, offers to purchase, and will rank equally and ratably with the Notes of such series previously issued.

(c)The date on which the principal is payable on each series of the Notes, unless accelerated pursuant to the Indenture, shall be as provided in the applicable form of security attached hereto as Exhibit A, Exhibit B or Exhibit C.

(d)The Notes shall bear interest as provided in the applicable form of security attached hereto as Exhibit A, Exhibit B or Exhibit C. The Interest Payment Dates and the Regular Record Dates for the determination of Holders of the Notes to whom such interest is payable shall be as provided in the applicable form of security attached hereto as Exhibit A, Exhibit B or Exhibit C.

(e)The Notes shall be redeemable at the option of the Company as set forth in the applicable form of security attached hereto as Exhibit A, Exhibit B or Exhibit C. The Notes shall be subject to special mandatory redemption by the Company as set forth in the applicable form of security attached hereto as Exhibit A, Exhibit B or Exhibit C, upon a Redemption Event (as defined in such form of security).

(f)The provisions of Article XII of the Indenture shall not be applicable to the Notes.

(g)The Notes will be issued only in fully registered form, without coupons, in denominations provided herein and in the applicable form of security attached hereto as Exhibit A, Exhibit B or Exhibit C.

(h)The Events of Default and covenants specified in the Indenture will apply to the Notes. In addition, with respect to the Notes of each series, the occurrence of the following event also shall constitute an “Event of Default”: if the Company fails to redeem the Notes of such series pursuant to the terms set forth in the applicable form of security attached hereto as Exhibit A, Exhibit B or Exhibit C upon a Redemption Event.

2

(i)With respect to the Notes of each series, any waiver or modification by the Company of the provisions relating to the special mandatory redemption upon a Redemption Event as set forth in the applicable form of security attached hereto as Exhibit A, Exhibit B or Exhibit C shall constitute a waiver or modification requiring the consent of the Holder of each Outstanding Security affected thereby under Section 9.02 of the Indenture.

(j)The defeasance and covenant defeasance provisions of Article XIII of the Indenture, including both Sections 13.02 and 13.03 of the Indenture, will apply to the Notes.

(k)The Notes of each series shall be issued in the form of one or more Global Securities substantially in the applicable form of security attached hereto as Exhibit A, Exhibit B or Exhibit C. The Company initially appoints The Depository Trust Company to act as Depositary with respect to the Notes. Additional provisions applicable to the Notes issued in the form of a Global Security are set forth in the applicable form of security attached hereto as Exhibit A, Exhibit B or Exhibit C.

(l)The Notes shall be issuable only in denominations of $2,000 and integral multiples of $1,000 in excess thereof.

(m)The Trustee will initially act as the Security Registrar for the Notes of each series and as the Paying Agent with respect to the Notes of each series. The Place of Payment will be The Bank of New York Mellon Trust Company, N.A., 101 Barclay Street, New York, New York 10286.

(n)Except as otherwise set forth herein and in the Notes, the terms of the Notes shall be as set forth in the Indenture, including those made part of the Indenture by reference to the Trust Indenture Act.

Section 3.Effect of Supplemental Indenture. The provisions of this Supplemental Indenture are intended to supplement those of the Indenture as in effect immediately prior to the execution and delivery hereof. The Indenture shall remain in full force and effect except to the extent that the provisions of the Indenture are expressly modified by the terms of this Supplemental Indenture.

Section 4.Governing Law. This Supplemental Indenture and the Notes shall be governed by and construed in accordance with the law of the State of New York, without giving effect to any principles of conflicts of laws thereunder to the extent the application of the laws of another jurisdiction would be required thereby.

Section 5.Trustee Not Responsible for Recitals or Issuance of Notes. The recitals and statements contained herein shall be taken as statements of the Company, and the Trustee assumes no responsibility for their correctness. The Trustee makes no representations as to the validity or sufficiency of this Supplemental Indenture or of the Notes other than with respect to the Trustee’s authentication and execution. The Trustee shall not be accountable for the use or application by the Company of the Notes or the proceeds thereof.

3

Section 6.Conflict with Trust Indenture Act. If any provision hereof limits, qualifies or conflicts with a provision of the Trust Indenture Act that is required under such Act to be a part of and govern this Supplemental Indenture, the latter provision shall control. If any provision of this Supplemental Indenture modifies or excludes any provision of the Trust Indenture Act that may be so modified or excluded, the latter provision shall be deemed to apply to this Supplemental Indenture as so modified or to be excluded, as the case may be.

Section 7.Counterparts. This Supplemental Indenture may be executed in any number of counterparts, each of which shall be an original; but such counterparts shall together constitute but one and the same instrument. The exchange of copies of this Supplemental Indenture and of signature pages by facsimile or electronic (i.e., “pdf” or “tif”) transmission shall constitute effective execution and delivery of this Supplemental Indenture for all purposes. Signatures of the parties hereto transmitted by facsimile or electronic (i.e., “pdf” or “tif”) transmission shall be deemed to be their original signatures for all purposes of the Supplemental Indenture as to the parties hereto and may be used in lieu of the original.

[The remainder of this page is left blank intentionally]

4

IN WITNESS WHEREOF, the parties hereto have caused this Supplemental Indenture to be duly executed as of the day and year first above written.

MARATHON PETROLEUM CORPORATION
By:	/s/ Timothy T. Griffith
	Name: Timothy T. Griffith
	Title: Vice President, Finance and Investor Relations, and Treasurer

THE BANK OF NEW YORK MELLON TRUST COMPANY, N.A., as Trustee
By:	/s/ Lawrence M. Kusch
	Name: Lawrence M. Kusch
	Title: Vice President

5

Exhibit AMARATHON PETROLEUM CORPORATION
3.625% Senior Notes due 2024

No. $[●] CUSIP No. 56585AAG7

THIS SECURITY IS A GLOBAL SECURITY WITHIN THE MEANING OF THE INDENTURE HEREINAFTER REFERRED TO AND IS REGISTERED IN THE NAME OF A DEPOSITARY OR NOMINEE THEREOF. THIS SECURITY MAY NOT BE EXCHANGED IN WHOLE OR IN PART FOR A SECURITY REGISTERED. AND NO TRANSFER OF THIS SECURITY IN WHOLE OR IN PART MAY BE REGISTERED, IN THE NAME OF ANY PERSON OTHER THAN SUCH DEPOSITARY OR A NOMINEE THEREOF, EXCEPT IN THE LIMITED CIRCUMSTANCES DESCRIBED IN THE INDENTURE.

UNLESS THIS CERTIFICATE IS PRESENTED BY AN AUTHORIZED REPRESENTATIVE OF THE DEPOSITORY TRUST COMPANY, A NEW YORK CORPORATION (“DTC”), TO THE ISSUER OR ITS AGENT FOR REGISTRATION OF TRANSFER, EXCHANGE, OR PAYMENT, AND ANY CERTIFICATE ISSUED IS REGISTERED IN THE NAME OF CEDE & CO. OR IN SUCH OTHER NAME AS IS REQUESTED BY AN AUTHORIZED REPRESENTATIVE OF DTC (AND ANY PAYMENT IS MADE TO CEDE & CO. OR TO SUCH OTHER ENTITY AS IS REQUESTED BY AN AUTHORIZED REPRESENTATIVE OF DTC), ANY TRANSFER, PLEDGE OR OTHER USE HEREOF FOR VALUE OR OTHERWISE BY OR TO ANY PERSON IS WRONGFUL INASMUCH AS THE REGISTERED OWNER HEREOF, CEDE & CO., HAS AN INTEREST HEREIN.

MARATHON PETROLEUM CORPORATION, a corporation duly organized and existing under the laws of the State of Delaware (herein called the “Company,” which term includes any successor Person under the Indenture hereinafter referred to), for value received, hereby promises to pay to [●] [Insert if Global Security: CEDE & CO.], or registered assigns, the principal sum of [●] Dollars ($[●]),or such greater or lesser amount as indicated on the Schedule of Exchanges of Securities attached hereto, on September 15, 2024, and to pay interest thereon from September 5, 2014 or from the most recent Interest Payment Date to which interest has been paid or duly provided for, semi-annually on March 15 and September 15 in each year commencing March 15, 2015, at the rate of 3.625% per annum, until the principal hereof is paid or made available for payment. The interest so payable, and punctually paid or duly provided for, on any Interest Payment Date will, as provided in such Indenture, be paid to the Person in whose name this Security (or one or more Predecessor Securities) is registered at the close of business on the Regular Record Date for such interest, which shall be the March 1 or

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September 1 (whether or not a Business Day), as the case may be, next preceding such Interest Payment Date. Any such interest not so punctually paid or duly provided for will forthwith cease to be payable to the Holder on such Regular Record Date and may either be paid to the Person in whose name this Security (or one or more Predecessor Securities) is registered at the close of business on a Special Record Date for the payment of such Defaulted Interest to be fixed by the Trustee, notice whereof shall be given to Holders of Securities of this series not less than 10 days prior to such Special Record Date, or be paid at any time in any other lawful manner not inconsistent with the requirements of any securities exchange on which the Securities of this series may be listed, and upon such notice as may be required by such exchange all as more fully provided in said Indenture. If an Interest Payment Date, a Stated Maturity or a Redemption Date with respect to this Security falls on a day that is not a Business Day, the payment will be made on the next Business Day and no interest will accrue for the period from and after such Interest Payment Date, Stated Maturity or Redemption Date.

Payment of the principal of (and premium, if any) and interest on this Security will be made at the office or agency of the Company maintained for that purpose in New York, New York, in such coin or currency of the United States of America as at the time of payment is legal tender for payment of public and private debts; provided, however, that (1) payments on any Global Security shall be made by electronic (same-day) funds transfer to the Depositary and (2) at the option of the Company payment of interest may be made by check mailed to the address of the Person entitled thereto as such address shall appear in the Security Register or by electronic funds transfer to an account maintained by the Person entitled thereto as specified in the Security Register, provided that such Person shall have given the Trustee written instructions.

Reference is hereby made to the further provisions of this Security set forth on the reverse hereof, which further provisions shall for all purposes have the same effect as if set forth at this place.

Unless the certificate of authentication hereon has been executed by the Trustee referred to on the reverse hereof by manual signature, this Security shall not be entitled to any benefit under the Indenture or be valid or obligatory for any purpose.

IN WITNESS WHEREOF, the Company has caused this instrument to be duly executed.

Dated:

MARATHON PETROLEUM CORPORATION,

By: ___________________________________

Attest: _________________________________

CERTIFICATE OF AUTHENTICATION

This is one of the Securities of the series designated therein referred to in the within-mentioned Indenture.

Dated:

THE BANK OF NEW YORK MELLON TRUST COMPANY, N.A.,as Trustee

By: ____________________________________

   Authorized Signatory

MARATHON PETROLEUM CORPORATION
3.625% Senior Notes due 2024

This Security is one of a duly authorized issue of securities of the Company (herein called the “Securities”), issued and to be issued in one or more series under an Indenture, dated as of February 1, 2011, as supplemented by the First Supplemental Indenture, dated as of September 5, 2014 (herein called the “Indenture,” which term shall have the meaning assigned to it in such instrument), between the Company and The Bank of New York Mellon Trust Company, N.A., as Trustee (herein called the “Trustee,” which term includes any successor trustee under the Indenture), and reference is hereby made to the Indenture for a statement of the respective rights, limitations of rights, duties and immunities thereunder of the Company, the Trustee and the Holders of the Securities and of the terms upon which the Securities are, and are to be, authenticated and delivered. This Security is one of the series designated on the face hereof initially limited in aggregate principal amount to $750,000,000.

Prior to June 15, 2024, the Securities of this series are subject to redemption upon not less than 30 days notice by mail, in whole at any time or in part from time to time, at the election of the Company, at a Redemption Price equal to the greater of (1) 100% of the principal amount of such Securities to be redeemed or (2) the sum of the present values of the remaining scheduled payments of principal and interest on the Securities to be redeemed (exclusive of interest accrued to the Redemption Date) discounted to the Redemption Date on a semiannual basis (assuming a 360-day year consisting of twelve 30-day months) at the then current Treasury Rate plus 20 basis points, plus, in either case, accrued and unpaid interest on the principal amount being redeemed to, but not including, the Redemption Date.

On or after June 15, 2024, the Securities of this series are subject to redemption upon not less than 30 days notice by mail, in whole at any time or in part from time to time, at the election of the Company, at a Redemption Price equal to 100% of the principal amount of such Securities to be redeemed plus accrued and unpaid interest on the principal amount being redeemed to, but not including, the Redemption Date.

“Business Day” means any Monday, Tuesday, Wednesday, Thursday or Friday that is not a day on which banking institutions in New York, New York or Findlay, Ohio are authorized or obligated by law or executive order to close.

“Comparable Treasury Issue” means the United States Treasury security selected by an Independent Investment Banker as having a maturity comparable to the remaining term (“Remaining Life”) of the Securities to be redeemed that would be utilized, at the time of selection and in accordance with customary financial practice, in pricing new issues of corporate debt securities of comparable maturity to the remaining term of such Securities.

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“Comparable Treasury Price” means, with respect to any Redemption Date, (1) the average, as determined by the Company, of the Reference Treasury Dealer Quotations for such Redemption Date, after excluding the highest and lowest Reference Treasury Dealer Quotations, or (2) if the the Company obtains fewer than six such Reference Treasury Dealer Quotations, the average of all such quotations.

“Independent Investment Banker” means one of the Reference Treasury Dealers that the Company appoints to act as the Independent Investment Banker from time to time.

“Reference Treasury Dealer” means each of RBS Securities Inc., Citigroup Global Markets Inc., Morgan Stanley & Co. LLC, a dealer in U.S. Government securities selected by Mitsubishi UFJ Securities (USA), Inc. and two additional dealers in U.S. Government securities selected by the Company (each a “Primary Treasury Dealer”) and their respective successors that the Company specifies from time to time; provided, however, that if any of them ceases to be a Primary Treasury Dealer, the Company shall substitute therefor another Primary Treasury Dealer.

“Reference Treasury Dealer Quotations” means, with respect to each Reference Treasury Dealer and any Redemption Date, the average, as determined by the Company, of the bid and asked prices for the Comparable Treasury Issue (expressed in each case as a percentage of its principal amount) quoted in writing to the the Company by such Reference Treasury Dealer at 5:00 p.m., New York City time, on the third Business Day preceding such Redemption Date.

“Treasury Rate” means, with respect to any Redemption Date, the rate per annum equal to: (1) the yield, under the heading which represents the average for the immediately preceding week, appearing in the most recently published statistical release designated “H.15(519)” or any successor publication which is published weekly by the Board of Governors of the Federal Reserve System and which establishes yields on actively traded United States Treasury securities adjusted to constant maturity under the caption “Treasury Constant Maturities,” for the maturity corresponding to the Comparable Treasury Issue; provided that, if no maturity is within three months before or after the Remaining Life of the Securities to be redeemed, yields for the two published maturities most closely corresponding to the Comparable Treasury Issue shall be determined and the Treasury Rate shall be interpolated or extrapolated from such yields on a straight line basis, rounding to the nearest month; or (2) if such release (or any successor release) is not published during the week preceding the calculation date or does not contain such yields, the rate per annum equal to the semiannual equivalent yield to maturity of the Comparable Treasury Issue, calculated using a price for the Comparable Treasury Issue (expressed as a percentage of its principal amount) equal to the Comparable Treasury Price for such Redemption Date. The Treasury Rate shall be calculated on the third Business Day preceding the Redemption Date.

Notice of the redemption will be mailed to holders of Securities by first-class mail at least 30 and not more than 60 days prior to the date fixed for redemption. If

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fewer than all of the Securities are to be redeemed, the Trustee will select, not more than 45 days prior to the Redemption Date, the particular Securities or portions thereof for redemption from the outstanding Securities not previously called by such method as the Trustee deems fair and appropriate.

Unless the Company defaults in payment of the redemption price, on or after the redemption date, interest will cease to accrue on the Securities or portions thereof called for redemption.

In the event of redemption of this Security in part only, a new Security or Securities of this series and of like tenor for the unredeemed portion hereof will be issued in the name of the Holder hereof upon the cancellation hereof.

In the event that (a) the Acquisition is not consummated on or prior to September 30, 2015 or (b) if prior to September 30, 2015 the Purchase Agreement is terminated, other than in connection with the consummation of the Acquisition and is not otherwise amended or replaced (each event, a “Redemption Event”), the Securities of this series will be redeemed at the special mandatory redemption price equal to 101% of the principal amount of such Securities plus accrued and unpaid interest from the date of initial issuance, or the most recent date to which interest has been paid or provided for, whichever is later, to, but excluding, the Special Mandatory Redemption Date.

The Company, either directly or through the Trustee on the Company’s behalf, will cause a notice of the special mandatory redemption to be sent, with a copy to the Trustee, not later than five Business Days after the occurrence of the Redemption Event to each Holder at its registered address. Such notice will also specify the Special Mandatory Redemption Date. If funds sufficient to pay the special mandatory redemption price of all Securities to be redeemed on the Special Mandatory Redemption Date are deposited with the Paying Agent on or before such Special Mandatory Redemption Date, and certain other conditions are satisfied, on and after such Special Mandatory Redemption Date, such Securities will cease to bear interest and all rights under such Securities shall terminate.

“Acquisition” means the pending acquisition of Hess Retail Holdings LLC by Speedway LLC pursuant to the Purchase Agreement.

“Purchase Agreement” means the purchase agreement, dated May 21, 2014, between Speedway LLC and Hess Corporation, pursuant to which Speedway LLC has agreed to purchase from Hess Corporation all of the outstanding membership interest of Hess Retail Holdings LLC.

“Special Mandatory Redemption Date” means the date no later than the tenth Business Day following the earlier to occur of (a) September 30, 2015 or (b) the date that the Purchase Agreement is terminated other than in connection with the consummation of the Acquisition and is not otherwise amended or replaced.

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The Indenture contains provisions for defeasance at any time of the entire indebtedness of this Security or of certain restrictive covenants and Events of Default with respect to this Security, in each case upon compliance with certain conditions set forth in the Indenture.

The Indenture contains provisions permitting the Company and the Trustee to modify the Indenture or any supplemental indenture without the consent of the Holders for one or more of the following purposes: (1) to evidence the succession of another corporation to the Company; (2) to add to the covenants of the Company; (3) to add additional events of default for the benefit of Holders of all or any series of Securities; (4) to add to or change provisions of the Indenture to allow for the issuance of Securities in other forms; (5) to add to, change or eliminate any of the provisions of the Indenture in respect of one or more series of Securities thereunder, under certain conditions specified therein; (6) to secure the Securities pursuant to the requirements of Section 10.05 of the Indenture or otherwise; (7) to establish the form or terms of Securities of any series as permitted by Sections 2.01 and 3.01 of the Indenture; (8) to evidence the appointment of a successor Trustee; and (9) to cure any ambiguity, to correct or supplement any provision of the Indenture which may be defective or inconsistent with any other provision of the Indenture, or to make any other provisions with respect to matters or questions arising under the Indenture as shall not adversely affect the interests of the Holders in any material respect.

The Indenture also permits, with certain exceptions as therein provided, the amendment thereof and the modification of the rights and obligations of the Company and the rights of the Holders of the Securities of each series to be affected under the Indenture at any time by the Company and the Trustee with the consent of the Holders of not less than a majority in principal amount of the Securities at the time Outstanding of each series to be affected. The Indenture also contains provisions permitting the Holders of specified percentages in principal amount of the Securities of each series at the time Outstanding, on behalf of the Holders of all Securities of such series, to waive compliance by the Company with certain provisions of the Indenture and certain past defaults under the Indenture and their consequences. Any such consent or waiver by the Holder of this Security shall be conclusive and binding upon such Holder and upon all future Holders of this Security and of any Security issued upon the registration of transfer hereof or in exchange herefor or in lieu hereof, whether or not notation of such consent or waiver is made upon this Security.

As provided in and subject to the provisions of the Indenture, the Holder of this Security shall not have the right to institute any proceeding with respect to the Indenture or for the appointment of a receiver or trustee or for any other remedy thereunder, unless such Holder shall have previously given the Trustee written notice of a continuing Event of Default with respect to the Securities of this series, the Holders of not less than 25% in principal amount of the Securities of this series at the time Outstanding shall have made written request to the Trustee to institute proceedings in respect of such Event of Default as Trustee and offered the Trustee reasonable indemnity,

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and the Trustee shall not have received from the Holders of a majority in principal amount of Securities of this series at the time Outstanding a direction inconsistent with such request, and shall have failed to institute any such proceeding, for 60 days after receipt of such notice, request and offer of indemnity. The foregoing shall not apply to any suit instituted by the Holder of this Security for the enforcement of any payment of principal hereof or any premium or interest hereon on or after the respective due dates expressed herein.

No reference herein to the Indenture and no provision of this Security or of the Indenture shall alter or impair the obligation of the Company, which is absolute and unconditional, to pay the principal of and any premium and interest on this Security at the times, place and rate, and in the coin or currency, herein prescribed.

As provided in the Indenture and subject to certain limitations therein set forth, the transfer of this Security is registrable in the Security Register, upon surrender of this Security for registration of transfer at the office or agency of the Company in any place where the principal of and any premium and interest on this Security are payable, duly endorsed by, or accompanied by a written instrument of transfer in form satisfactory to the Company and the Security Registrar duly executed by, the Holder hereof or his attorney duly authorized in writing, and thereupon one or more new Securities of this series and of like tenor, of authorized denominations and for the same aggregate principal amount, will be issued to the designated transferee or transferees.

The Securities of this series are issuable only in registered form without coupons in denominations of $2,000 and integral multiples of $1,000 in excess thereof. As provided in the Indenture and subject to certain limitations therein set forth, Securities of this series are exchangeable for a like aggregate principal amount of Securities of this series and of like tenor of a different authorized denomination, as requested by the Holder surrendering the same.

No service charge shall be made for any such registration of transfer or exchange, but, subject to any applicable provisions of the Indenture, the Company may require payment of a sum sufficient to cover any tax or other governmental charge payable in connection therewith.

Prior to due presentment of this Security for registration of transfer, the Company, the Trustee and any agent of the Company or the Trustee may treat the Person in whose name this Security is registered as the owner hereof for all purposes, whether or not this Security be overdue, and neither the Company, the Trustee nor any such agent shall be affected by notice to the contrary.

All terms used in this Security which are defined in the Indenture shall have the meaning assigned to them in the Indenture.

FORM OF ASSIGNMENT

ABBREVIATIONS

Customary abbreviations may be used in the name of a Securityholder or an assignee, such as TEN COM (=tenants in common), TEN ENT (=tenants by the entireties), JT TEN (=joint tenants with rights of survivorship and not as tenants in common), CUST (=custodian), and U/G/M/A (=Uniform Gift to Minors Act).

Additional abbreviations may also be used though not in the above list.

_________________

FOR VALUE RECEIVED, the undersigned hereby sell(s),
assign(s) and transfer(s) unto

_____________________________

Please insert Social Security or

other identifying number of assignee

PLEASE PRINT OR TYPEWRITE NAME AND ADDRESS, INCLUDING POSTAL ZIP CODE, OF ASSIGNEE

the within Security and all rights thereunder, hereby irrevocably constituting and appointing attorney to transfer said Security on the books of the Company, with full power of substitution in the premises.

Dated:

Notice: This signature to the assignment must correspond with the name as written on the face of the within instrument in every particular, without alteration or enlargement, or any change whatever.

SCHEDULE OF INCREASES OR DECREASES IN THE PRINCIPAL AMOUNT
OF SECURITIES

The original principal amount of this Security is [●] U.S. Dollars ($[●]). The following increases or decreases in the principal amount of this Security have been made:

Date of increase or decrease Amount of decrease in principal amount of this Security Amount of increase in principal amount of this Security Principal amount of this Security following such decrease or increase Signature of authorized signatory of Trustee or Depositary

Exhibit BMARATHON PETROLEUM CORPORATION 4.750% Senior Notes due 2044

No. $[●] CUSIP No. 56585AAH5

THIS SECURITY IS A GLOBAL SECURITY WITHIN THE MEANING OF THE INDENTURE HEREINAFTER REFERRED TO AND IS REGISTERED IN THE NAME OF A DEPOSITARY OR NOMINEE THEREOF. THIS SECURITY MAY NOT BE EXCHANGED IN WHOLE OR IN PART FOR A SECURITY REGISTERED. AND NO TRANSFER OF THIS SECURITY IN WHOLE OR IN PART MAY BE REGISTERED, IN THE NAME OF ANY PERSON OTHER THAN SUCH DEPOSITARY OR A NOMINEE THEREOF, EXCEPT IN THE LIMITED CIRCUMSTANCES DESCRIBED IN THE INDENTURE.

UNLESS THIS CERTIFICATE IS PRESENTED BY AN AUTHORIZED REPRESENTATIVE OF THE DEPOSITORY TRUST COMPANY, A NEW YORK CORPORATION (“DTC”), TO THE ISSUER OR ITS AGENT FOR REGISTRATION OF TRANSFER, EXCHANGE, OR PAYMENT, AND ANY CERTIFICATE ISSUED IS REGISTERED IN THE NAME OF CEDE & CO. OR IN SUCH OTHER NAME AS IS REQUESTED BY AN AUTHORIZED REPRESENTATIVE OF DTC (AND ANY PAYMENT IS MADE TO CEDE & CO. OR TO SUCH OTHER ENTITY AS IS REQUESTED BY AN AUTHORIZED REPRESENTATIVE OF DTC), ANY TRANSFER, PLEDGE OR OTHER USE HEREOF FOR VALUE OR OTHERWISE BY OR TO ANY PERSON IS WRONGFUL INASMUCH AS THE REGISTERED OWNER HEREOF, CEDE & CO., HAS AN INTEREST HEREIN.

MARATHON PETROLEUM CORPORATION, a corporation duly organized and existing under the laws of the State of Delaware (herein called the “Company,” which term includes any successor Person under the Indenture hereinafter referred to), for value received, hereby promises to pay to [●] [Insert if Global Security: CEDE & CO.], or registered assigns, the principal sum of [●] Dollars ($[●]),or such greater or lesser amount as indicated on the Schedule of Exchanges of Securities attached hereto, on September 15, 2044, and to pay interest thereon from September 5, 2014 or from the most recent Interest Payment Date to which interest has been paid or duly provided for, semi-annually on March 15 and September 15 in each year commencing March 15, 2015, at the rate of 4.750% per annum, until the principal hereof is paid or made available for payment. The interest so payable, and punctually paid or duly provided for, on any Interest Payment Date will, as provided in such Indenture, be paid to the Person in whose name this Security (or one or more Predecessor Securities) is registered at the close of business on the Regular Record Date for such interest, which shall be the March 1 or

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September 1 (whether or not a Business Day), as the case may be, next preceding such Interest Payment Date. Any such interest not so punctually paid or duly provided for will forthwith cease to be payable to the Holder on such Regular Record Date and may either be paid to the Person in whose name this Security (or one or more Predecessor Securities) is registered at the close of business on a Special Record Date for the payment of such Defaulted Interest to be fixed by the Trustee, notice whereof shall be given to Holders of Securities of this series not less than 10 days prior to such Special Record Date, or be paid at any time in any other lawful manner not inconsistent with the requirements of any securities exchange on which the Securities of this series may be listed, and upon such notice as may be required by such exchange all as more fully provided in said Indenture. If an Interest Payment Date, a Stated Maturity or a Redemption Date with respect to this Security falls on a day that is not a Business Day, the payment will be made on the next Business Day and no interest will accrue for the period from and after such Interest Payment Date, Stated Maturity or Redemption Date.

Payment of the principal of (and premium, if any) and interest on this Security will be made at the office or agency of the Company maintained for that purpose in New York, New York, in such coin or currency of the United States of America as at the time of payment is legal tender for payment of public and private debts; provided, however, that (1) payments on any Global Security shall be made by electronic (same-day) funds transfer to the Depositary and (2) at the option of the Company payment of interest may be made by check mailed to the address of the Person entitled thereto as such address shall appear in the Security Register or by electronic funds transfer to an account maintained by the Person entitled thereto as specified in the Security Register, provided that such Person shall have given the Trustee written instructions.

Reference is hereby made to the further provisions of this Security set forth on the reverse hereof, which further provisions shall for all purposes have the same effect as if set forth at this place.

Unless the certificate of authentication hereon has been executed by the Trustee referred to on the reverse hereof by manual signature, this Security shall not be entitled to any benefit under the Indenture or be valid or obligatory for any purpose.

IN WITNESS WHEREOF, the Company has caused this instrument to be duly executed.

Dated:

MARATHON PETROLEUM CORPORATION,

By: ___________________________________

Attest: _________________________________

CERTIFICATE OF AUTHENTICATION

This is one of the Securities of the series designated therein referred to in the within-mentioned Indenture.

Dated:

THE BANK OF NEW YORK MELLON TRUST COMPANY, N.A.,as Trustee

By:_____________________________________

   Authorized Signatory

MARATHON PETROLEUM CORPORATION4.750% Senior Notes due 2044

This Security is one of a duly authorized issue of securities of the Company (herein called the “Securities”), issued and to be issued in one or more series under an Indenture, dated as of February 1, 2011, as supplemented by the First Supplemental Indenture, dated as of September 5, 2014 (herein called the “Indenture,” which term shall have the meaning assigned to it in such instrument), between the Company and The Bank of New York Mellon Trust Company, N.A., as Trustee (herein called the “Trustee,” which term includes any successor trustee under the Indenture), and reference is hereby made to the Indenture for a statement of the respective rights, limitations of rights, duties and immunities thereunder of the Company, the Trustee and the Holders of the Securities and of the terms upon which the Securities are, and are to be, authenticated and delivered. This Security is one of the series designated on the face hereof initially limited in aggregate principal amount to $800,000,000.

Prior to March 15, 2044, the Securities of this series are subject to redemption upon not less than 30 days notice by mail, in whole at any time or in part from time to time, at the election of the Company, at a Redemption Price equal to the greater of (1) 100% of the principal amount of such Securities to be redeemed or (2) the sum of the present values of the remaining scheduled payments of principal and interest on the Securities to be redeemed (exclusive of interest accrued to the Redemption Date) discounted to the Redemption Date on a semiannual basis (assuming a 360-day year consisting of twelve 30-day months) at the then current Treasury Rate plus 25 basis points, plus, in either case, accrued and unpaid interest on the principal amount being redeemed to, but not including, the Redemption Date.

On or after March 15, 2044, the Securities of this series are subject to redemption upon not less than 30 days notice by mail, in whole at any time or in part from time to time, at the election of the Company, at a Redemption Price equal to 100% of the principal amount of such Securities to be redeemed plus accrued and unpaid interest on the principal amount being redeemed to, but not including, the Redemption Date.

“Business Day” means any Monday, Tuesday, Wednesday, Thursday or Friday that is not a day on which banking institutions in New York, New York or Findlay, Ohio are authorized or obligated by law or executive order to close.

“Comparable Treasury Issue” means the United States Treasury security selected by an Independent Investment Banker as having a maturity comparable to the remaining term (“Remaining Life”) of the Securities to be redeemed that would be utilized, at the time of selection and in accordance with customary financial practice, in pricing new issues of corporate debt securities of comparable maturity to the remaining term of such Securities.

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“Comparable Treasury Price” means, with respect to any Redemption Date, (1) the average, as determined by the Company, of the Reference Treasury Dealer Quotations for such Redemption Date, after excluding the highest and lowest Reference Treasury Dealer Quotations, or (2) if the the Company obtains fewer than six such Reference Treasury Dealer Quotations, the average of all such quotations.

“Independent Investment Banker” means one of the Reference Treasury Dealers that the Company appoints to act as the Independent Investment Banker from time to time.

“Reference Treasury Dealer” means each of RBS Securities Inc., Citigroup Global Markets Inc., Morgan Stanley & Co. LLC, a dealer in U.S. Government securities selected by Mitsubishi UFJ Securities (USA), Inc. and two additional dealers in U.S. Government securities selected by the Company (each a “Primary Treasury Dealer”) and their respective successors that the Company specifies from time to time; provided, however, that if any of them ceases to be a Primary Treasury Dealer, the Company shall substitute therefor another Primary Treasury Dealer.

“Reference Treasury Dealer Quotations” means, with respect to each Reference Treasury Dealer and any Redemption Date, the average, as determined by the Company, of the bid and asked prices for the Comparable Treasury Issue (expressed in each case as a percentage of its principal amount) quoted in writing to the the Company by such Reference Treasury Dealer at 5:00 p.m., New York City time, on the third Business Day preceding such Redemption Date.

“Treasury Rate” means, with respect to any Redemption Date, the rate per annum equal to: (1) the yield, under the heading which represents the average for the immediately preceding week, appearing in the most recently published statistical release designated “H.15(519)” or any successor publication which is published weekly by the Board of Governors of the Federal Reserve System and which establishes yields on actively traded United States Treasury securities adjusted to constant maturity under the caption “Treasury Constant Maturities,” for the maturity corresponding to the Comparable Treasury Issue; provided that, if no maturity is within three months before or after the Remaining Life of the Securities to be redeemed, yields for the two published maturities most closely corresponding to the Comparable Treasury Issue shall be determined and the Treasury Rate shall be interpolated or extrapolated from such yields on a straight line basis, rounding to the nearest month; or (2) if such release (or any successor release) is not published during the week preceding the calculation date or does not contain such yields, the rate per annum equal to the semiannual equivalent yield to maturity of the Comparable Treasury Issue, calculated using a price for the Comparable Treasury Issue (expressed as a percentage of its principal amount) equal to the Comparable Treasury Price for such Redemption Date. The Treasury Rate shall be calculated on the third Business Day preceding the Redemption Date.

Notice of the redemption will be mailed to holders of Securities by first-class mail at least 30 and not more than 60 days prior to the date fixed for redemption. If

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fewer than all of the Securities are to be redeemed, the Trustee will select, not more than 45 days prior to the Redemption Date, the particular Securities or portions thereof for redemption from the outstanding Securities not previously called by such method as the Trustee deems fair and appropriate.

Unless the Company defaults in payment of the redemption price, on or after the redemption date, interest will cease to accrue on the Securities or portions thereof called for redemption.

In the event of redemption of this Security in part only, a new Security or Securities of this series and of like tenor for the unredeemed portion hereof will be issued in the name of the Holder hereof upon the cancellation hereof.

In the event that (a) the Acquisition is not consummated on or prior to September 30, 2015 or (b) if prior to September 30, 2015 the Purchase Agreement is terminated, other than in connection with the consummation of the Acquisition and is not otherwise amended or replaced (each event, a “Redemption Event”), the Securities of this series will be redeemed at the special mandatory redemption price equal to 101% of the principal amount of such Securities plus accrued and unpaid interest from the date of initial issuance, or the most recent date to which interest has been paid or provided for, whichever is later, to, but excluding, the Special Mandatory Redemption Date.

The Company, either directly or through the Trustee on the Company’s behalf, will cause a notice of the special mandatory redemption to be sent, with a copy to the Trustee, not later than five Business Days after the occurrence of the Redemption Event to each Holder at its registered address. Such notice will also specify the Special Mandatory Redemption Date. If funds sufficient to pay the special mandatory redemption price of all Securities to be redeemed on the Special Mandatory Redemption Date are deposited with the Paying Agent on or before such Special Mandatory Redemption Date, and certain other conditions are satisfied, on and after such Special Mandatory Redemption Date, such Securities will cease to bear interest and all rights under such Securities shall terminate.

“Acquisition” means the pending acquisition of Hess Retail Holdings LLC by Speedway LLC pursuant to the Purchase Agreement.

“Purchase Agreement” means the purchase agreement, dated May 21, 2014, between Speedway LLC and Hess Corporation, pursuant to which Speedway LLC has agreed to purchase from Hess Corporation all of the outstanding membership interest of Hess Retail Holdings LLC.

“Special Mandatory Redemption Date” means the date no later than the tenth Business Day following the earlier to occur of (a) September 30, 2015 or (b) the date that the Purchase Agreement is terminated other than in connection with the consummation of the Acquisition and is not otherwise amended or replaced.

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The Indenture contains provisions for defeasance at any time of the entire indebtedness of this Security or of certain restrictive covenants and Events of Default with respect to this Security, in each case upon compliance with certain conditions set forth in the Indenture.

The Indenture contains provisions permitting the Company and the Trustee to modify the Indenture or any supplemental indenture without the consent of the Holders for one or more of the following purposes: (1) to evidence the succession of another corporation to the Company; (2) to add to the covenants of the Company; (3) to add additional events of default for the benefit of Holders of all or any series of Securities; (4) to add to or change provisions of the Indenture to allow for the issuance of Securities in other forms; (5) to add to, change or eliminate any of the provisions of the Indenture in respect of one or more series of Securities thereunder, under certain conditions specified therein; (6) to secure the Securities pursuant to the requirements of Section 10.05 of the Indenture or otherwise; (7) to establish the form or terms of Securities of any series as permitted by Sections 2.01 and 3.01 of the Indenture; (8) to evidence the appointment of a successor Trustee; and (9) to cure any ambiguity, to correct or supplement any provision of the Indenture which may be defective or inconsistent with any other provision of the Indenture, or to make any other provisions with respect to matters or questions arising under the Indenture as shall not adversely affect the interests of the Holders in any material respect.

The Indenture also permits, with certain exceptions as therein provided, the amendment thereof and the modification of the rights and obligations of the Company and the rights of the Holders of the Securities of each series to be affected under the Indenture at any time by the Company and the Trustee with the consent of the Holders of not less than a majority in principal amount of the Securities at the time Outstanding of each series to be affected. The Indenture also contains provisions permitting the Holders of specified percentages in principal amount of the Securities of each series at the time Outstanding, on behalf of the Holders of all Securities of such series, to waive compliance by the Company with certain provisions of the Indenture and certain past defaults under the Indenture and their consequences. Any such consent or waiver by the Holder of this Security shall be conclusive and binding upon such Holder and upon all future Holders of this Security and of any Security issued upon the registration of transfer hereof or in exchange herefor or in lieu hereof, whether or not notation of such consent or waiver is made upon this Security.

As provided in and subject to the provisions of the Indenture, the Holder of this Security shall not have the right to institute any proceeding with respect to the Indenture or for the appointment of a receiver or trustee or for any other remedy thereunder, unless such Holder shall have previously given the Trustee written notice of a continuing Event of Default with respect to the Securities of this series, the Holders of not less than 25% in principal amount of the Securities of this series at the time Outstanding shall have made written request to the Trustee to institute proceedings in respect of such Event of Default as Trustee and offered the Trustee reasonable indemnity,

5

and the Trustee shall not have received from the Holders of a majority in principal amount of Securities of this series at the time Outstanding a direction inconsistent with such request, and shall have failed to institute any such proceeding, for 60 days after receipt of such notice, request and offer of indemnity. The foregoing shall not apply to any suit instituted by the Holder of this Security for the enforcement of any payment of principal hereof or any premium or interest hereon on or after the respective due dates expressed herein.

No reference herein to the Indenture and no provision of this Security or of the Indenture shall alter or impair the obligation of the Company, which is absolute and unconditional, to pay the principal of and any premium and interest on this Security at the times, place and rate, and in the coin or currency, herein prescribed.

As provided in the Indenture and subject to certain limitations therein set forth, the transfer of this Security is registrable in the Security Register, upon surrender of this Security for registration of transfer at the office or agency of the Company in any place where the principal of and any premium and interest on this Security are payable, duly endorsed by, or accompanied by a written instrument of transfer in form satisfactory to the Company and the Security Registrar duly executed by, the Holder hereof or his attorney duly authorized in writing, and thereupon one or more new Securities of this series and of like tenor, of authorized denominations and for the same aggregate principal amount, will be issued to the designated transferee or transferees.

The Securities of this series are issuable only in registered form without coupons in denominations of $2,000 and integral multiples of $1,000 in excess thereof. As provided in the Indenture and subject to certain limitations therein set forth, Securities of this series are exchangeable for a like aggregate principal amount of Securities of this series and of like tenor of a different authorized denomination, as requested by the Holder surrendering the same.

No service charge shall be made for any such registration of transfer or exchange, but, subject to any applicable provisions of the Indenture, the Company may require payment of a sum sufficient to cover any tax or other governmental charge payable in connection therewith.

Prior to due presentment of this Security for registration of transfer, the Company, the Trustee and any agent of the Company or the Trustee may treat the Person in whose name this Security is registered as the owner hereof for all purposes, whether or not this Security be overdue, and neither the Company, the Trustee nor any such agent shall be affected by notice to the contrary.

All terms used in this Security which are defined in the Indenture shall have the meaning assigned to them in the Indenture.

FORM OF ASSIGNMENT

ABBREVIATIONS

Customary abbreviations may be used in the name of a Securityholder or an assignee, such as TEN COM (=tenants in common), TEN ENT (=tenants by the entireties), JT TEN (=joint tenants with rights of survivorship and not as tenants in common), CUST (=custodian), and U/G/M/A (=Uniform Gift to Minors Act).

Additional abbreviations may also be used though not in the above list.

_________________

FOR VALUE RECEIVED, the undersigned hereby sell(s),
assign(s) and transfer(s) unto

_____________________________

Please insert Social Security or

other identifying number of assignee

PLEASE PRINT OR TYPEWRITE NAME AND ADDRESS, INCLUDING POSTAL ZIP CODE, OF ASSIGNEE

the within Security and all rights thereunder, hereby irrevocably constituting and appointing attorney to transfer said Security on the books of the Company, with full power of substitution in the premises.

Dated:

Notice: This signature to the assignment must correspond with the name as written on the face of the within instrument in every particular, without alteration or enlargement, or any change whatever.

SCHEDULE OF INCREASES OR DECREASES IN THE PRINCIPAL AMOUNT
OF SECURITIES

The original principal amount of this Security is [●] U.S. Dollars ($[●]). The following increases or decreases in the principal amount of this Security have been made:

Date of increase or decrease Amount of decrease in principal amount of this Security Amount of increase in principal amount of this Security Principal amount of this Security following such decrease or increase Signature of authorized signatory of Trustee or Depositary

Exhibit CMARATHON PETROLEUM CORPORATION 5.000% Senior Notes due 2054

No. $[●] CUSIP No. 56585AAJ1

THIS SECURITY IS A GLOBAL SECURITY WITHIN THE MEANING OF THE INDENTURE HEREINAFTER REFERRED TO AND IS REGISTERED IN THE NAME OF A DEPOSITARY OR NOMINEE THEREOF. THIS SECURITY MAY NOT BE EXCHANGED IN WHOLE OR IN PART FOR A SECURITY REGISTERED. AND NO TRANSFER OF THIS SECURITY IN WHOLE OR IN PART MAY BE REGISTERED, IN THE NAME OF ANY PERSON OTHER THAN SUCH DEPOSITARY OR A NOMINEE THEREOF, EXCEPT IN THE LIMITED CIRCUMSTANCES DESCRIBED IN THE INDENTURE.

UNLESS THIS CERTIFICATE IS PRESENTED BY AN AUTHORIZED REPRESENTATIVE OF THE DEPOSITORY TRUST COMPANY, A NEW YORK CORPORATION (“DTC”), TO THE ISSUER OR ITS AGENT FOR REGISTRATION OF TRANSFER, EXCHANGE, OR PAYMENT, AND ANY CERTIFICATE ISSUED IS REGISTERED IN THE NAME OF CEDE & CO. OR IN SUCH OTHER NAME AS IS REQUESTED BY AN AUTHORIZED REPRESENTATIVE OF DTC (AND ANY PAYMENT IS MADE TO CEDE & CO. OR TO SUCH OTHER ENTITY AS IS REQUESTED BY AN AUTHORIZED REPRESENTATIVE OF DTC), ANY TRANSFER, PLEDGE OR OTHER USE HEREOF FOR VALUE OR OTHERWISE BY OR TO ANY PERSON IS WRONGFUL INASMUCH AS THE REGISTERED OWNER HEREOF, CEDE & CO., HAS AN INTEREST HEREIN.

MARATHON PETROLEUM CORPORATION, a corporation duly organized and existing under the laws of the State of Delaware (herein called the “Company,” which term includes any successor Person under the Indenture hereinafter referred to), for value received, hereby promises to pay to [●] [Insert if Global Security: CEDE & CO.], or registered assigns, the principal sum of [●] Dollars ($[●]),or such greater or lesser amount as indicated on the Schedule of Exchanges of Securities attached hereto, on September 15, 2054, and to pay interest thereon from September 5, 2014 or from the most recent Interest Payment Date to which interest has been paid or duly provided for, semi-annually on March 15 and September 15 in each year commencing March 15, 2015, at the rate of 5.000% per annum, until the principal hereof is paid or made available for payment. The interest so payable, and punctually paid or duly provided for, on any Interest Payment Date will, as provided in such Indenture, be paid to the Person in whose name this Security (or one or more Predecessor Securities) is registered at the close of business on the Regular Record Date for such interest, which shall be the March 1 or

2

September 1 (whether or not a Business Day), as the case may be, next preceding such Interest Payment Date. Any such interest not so punctually paid or duly provided for will forthwith cease to be payable to the Holder on such Regular Record Date and may either be paid to the Person in whose name this Security (or one or more Predecessor Securities) is registered at the close of business on a Special Record Date for the payment of such Defaulted Interest to be fixed by the Trustee, notice whereof shall be given to Holders of Securities of this series not less than 10 days prior to such Special Record Date, or be paid at any time in any other lawful manner not inconsistent with the requirements of any securities exchange on which the Securities of this series may be listed, and upon such notice as may be required by such exchange all as more fully provided in said Indenture. If an Interest Payment Date, a Stated Maturity or a Redemption Date with respect to this Security falls on a day that is not a Business Day, the payment will be made on the next Business Day and no interest will accrue for the period from and after such Interest Payment Date, Stated Maturity or Redemption Date.

Payment of the principal of (and premium, if any) and interest on this Security will be made at the office or agency of the Company maintained for that purpose in New York, New York, in such coin or currency of the United States of America as at the time of payment is legal tender for payment of public and private debts; provided, however, that (1) payments on any Global Security shall be made by electronic (same-day) funds transfer to the Depositary and (2) at the option of the Company payment of interest may be made by check mailed to the address of the Person entitled thereto as such address shall appear in the Security Register or by electronic funds transfer to an account maintained by the Person entitled thereto as specified in the Security Register, provided that such Person shall have given the Trustee written instructions.

Reference is hereby made to the further provisions of this Security set forth on the reverse hereof, which further provisions shall for all purposes have the same effect as if set forth at this place.

Unless the certificate of authentication hereon has been executed by the Trustee referred to on the reverse hereof by manual signature, this Security shall not be entitled to any benefit under the Indenture or be valid or obligatory for any purpose.

IN WITNESS WHEREOF, the Company has caused this instrument to be duly executed.

Dated:

MARATHON PETROLEUM CORPORATION,

By: ___________________________________

Attest: ________________________________

CERTIFICATE OF AUTHENTICATION

This is one of the Securities of the series designated therein referred to in the within-mentioned Indenture.

Dated:

THE BANK OF NEW YORK MELLON TRUST COMPANY, N.A.,as Trustee

By: ____________________________________

   Authorized Signatory

MARATHON PETROLEUM CORPORATION5.000% Senior Notes due 2054

This Security is one of a duly authorized issue of securities of the Company (herein called the “Securities”), issued and to be issued in one or more series under an Indenture, dated as of February 1, 2011, as supplemented by the First Supplemental Indenture, dated as of September 5, 2014 (herein called the “Indenture,” which term shall have the meaning assigned to it in such instrument), between the Company and The Bank of New York Mellon Trust Company, N.A., as Trustee (herein called the “Trustee,” which term includes any successor trustee under the Indenture), and reference is hereby made to the Indenture for a statement of the respective rights, limitations of rights, duties and immunities thereunder of the Company, the Trustee and the Holders of the Securities and of the terms upon which the Securities are, and are to be, authenticated and delivered. This Security is one of the series designated on the face hereof initially limited in aggregate principal amount to $400,000,000.

Prior to March 15, 2054, the Securities of this series are subject to redemption upon not less than 30 days notice by mail, in whole at any time or in part from time to time, at the election of the Company, at a Redemption Price equal to the greater of (1) 100% of the principal amount of such Securities to be redeemed or (2) the sum of the present values of the remaining scheduled payments of principal and interest on the Securities to be redeemed (exclusive of interest accrued to the Redemption Date) discounted to the Redemption Date on a semiannual basis (assuming a 360-day year consisting of twelve 30-day months) at the then current Treasury Rate plus 30 basis points, plus, in either case, accrued and unpaid interest on the principal amount being redeemed to, but not including, the Redemption Date.

On or after March 15, 2054, the Securities of this series are subject to redemption upon not less than 30 days notice by mail, in whole at any time or in part from time to time, at the election of the Company, at a Redemption Price equal to 100% of the principal amount of such Securities to be redeemed plus accrued and unpaid interest on the principal amount being redeemed to, but not including, the Redemption Date.

“Business Day” means any Monday, Tuesday, Wednesday, Thursday or Friday that is not a day on which banking institutions in New York, New York or Findlay, Ohio are authorized or obligated by law or executive order to close.

“Comparable Treasury Issue” means the United States Treasury security selected by an Independent Investment Banker as having a maturity comparable to the remaining term (“Remaining Life”) of the Securities to be redeemed that would be utilized, at the time of selection and in accordance with customary financial practice, in pricing new issues of corporate debt securities of comparable maturity to the remaining term of such Securities.

2

“Comparable Treasury Price” means, with respect to any Redemption Date, (1) the average, as determined by the Company, of the Reference Treasury Dealer Quotations for such Redemption Date, after excluding the highest and lowest Reference Treasury Dealer Quotations, or (2) if the the Company obtains fewer than six such Reference Treasury Dealer Quotations, the average of all such quotations.

“Independent Investment Banker” means one of the Reference Treasury Dealers that the Company appoints to act as the Independent Investment Banker from time to time.

“Reference Treasury Dealer” means each of RBS Securities Inc., Citigroup Global Markets Inc., Morgan Stanley & Co. LLC, a dealer in U.S. Government securities selected by Mitsubishi UFJ Securities (USA), Inc. and two additional dealers in U.S. Government securities selected by the Company (each a “Primary Treasury Dealer”) and their respective successors that the Company specifies from time to time; provided, however, that if any of them ceases to be a Primary Treasury Dealer, the Company shall substitute therefor another Primary Treasury Dealer.

“Reference Treasury Dealer Quotations” means, with respect to each Reference Treasury Dealer and any Redemption Date, the average, as determined by the Company, of the bid and asked prices for the Comparable Treasury Issue (expressed in each case as a percentage of its principal amount) quoted in writing to the the Company by such Reference Treasury Dealer at 5:00 p.m., New York City time, on the third Business Day preceding such Redemption Date.

“Treasury Rate” means, with respect to any Redemption Date, the rate per annum equal to: (1) the yield, under the heading which represents the average for the immediately preceding week, appearing in the most recently published statistical release designated “H.15(519)” or any successor publication which is published weekly by the Board of Governors of the Federal Reserve System and which establishes yields on actively traded United States Treasury securities adjusted to constant maturity under the caption “Treasury Constant Maturities,” for the maturity corresponding to the Comparable Treasury Issue; provided that, if no maturity is within three months before or after the Remaining Life of the Securities to be redeemed, yields for the two published maturities most closely corresponding to the Comparable Treasury Issue shall be determined and the Treasury Rate shall be interpolated or extrapolated from such yields on a straight line basis, rounding to the nearest month; or (2) if such release (or any successor release) is not published during the week preceding the calculation date or does not contain such yields, the rate per annum equal to the semiannual equivalent yield to maturity of the Comparable Treasury Issue, calculated using a price for the Comparable Treasury Issue (expressed as a percentage of its principal amount) equal to the Comparable Treasury Price for such Redemption Date. The Treasury Rate shall be calculated on the third Business Day preceding the Redemption Date.

Notice of the redemption will be mailed to holders of Securities by first-class mail at least 30 and not more than 60 days prior to the date fixed for redemption. If

3

fewer than all of the Securities are to be redeemed, the Trustee will select, not more than 45 days prior to the Redemption Date, the particular Securities or portions thereof for redemption from the outstanding Securities not previously called by such method as the Trustee deems fair and appropriate.

Unless the Company defaults in payment of the redemption price, on or after the redemption date, interest will cease to accrue on the Securities or portions thereof called for redemption.

In the event of redemption of this Security in part only, a new Security or Securities of this series and of like tenor for the unredeemed portion hereof will be issued in the name of the Holder hereof upon the cancellation hereof.

In the event that (a) the Acquisition is not consummated on or prior to September 30, 2015 or (b) if prior to September 30, 2015 the Purchase Agreement is terminated, other than in connection with the consummation of the Acquisition and is not otherwise amended or replaced (each event, a “Redemption Event”), the Securities of this series will be redeemed at the special mandatory redemption price equal to 101% of the principal amount of such Securities plus accrued and unpaid interest from the date of initial issuance, or the most recent date to which interest has been paid or provided for, whichever is later, to, but excluding, the Special Mandatory Redemption Date.

The Company, either directly or through the Trustee on the Company’s behalf, will cause a notice of the special mandatory redemption to be sent, with a copy to the Trustee, not later than five Business Days after the occurrence of the Redemption Event to each Holder at its registered address. Such notice will also specify the Special Mandatory Redemption Date. If funds sufficient to pay the special mandatory redemption price of all Securities to be redeemed on the Special Mandatory Redemption Date are deposited with the Paying Agent on or before such Special Mandatory Redemption Date, and certain other conditions are satisfied, on and after such Special Mandatory Redemption Date, such Securities will cease to bear interest and all rights under such Securities shall terminate.

“Acquisition” means the pending acquisition of Hess Retail Holdings LLC by Speedway LLC pursuant to the Purchase Agreement.

“Purchase Agreement” means the purchase agreement, dated May 21, 2014, between Speedway LLC and Hess Corporation, pursuant to which Speedway LLC has agreed to purchase from Hess Corporation all of the outstanding membership interest of Hess Retail Holdings LLC.

“Special Mandatory Redemption Date” means the date no later than the tenth Business Day following the earlier to occur of (a) September 30, 2015 or (b) the date that the Purchase Agreement is terminated other than in connection with the consummation of the Acquisition and is not otherwise amended or replaced.

4

The Indenture contains provisions for defeasance at any time of the entire indebtedness of this Security or of certain restrictive covenants and Events of Default with respect to this Security, in each case upon compliance with certain conditions set forth in the Indenture.

The Indenture contains provisions permitting the Company and the Trustee to modify the Indenture or any supplemental indenture without the consent of the Holders for one or more of the following purposes: (1) to evidence the succession of another corporation to the Company; (2) to add to the covenants of the Company; (3) to add additional events of default for the benefit of Holders of all or any series of Securities; (4) to add to or change provisions of the Indenture to allow for the issuance of Securities in other forms; (5) to add to, change or eliminate any of the provisions of the Indenture in respect of one or more series of Securities thereunder, under certain conditions specified therein; (6) to secure the Securities pursuant to the requirements of Section 10.05 of the Indenture or otherwise; (7) to establish the form or terms of Securities of any series as permitted by Sections 2.01 and 3.01 of the Indenture; (8) to evidence the appointment of a successor Trustee; and (9) to cure any ambiguity, to correct or supplement any provision of the Indenture which may be defective or inconsistent with any other provision of the Indenture, or to make any other provisions with respect to matters or questions arising under the Indenture as shall not adversely affect the interests of the Holders in any material respect.

The Indenture also permits, with certain exceptions as therein provided, the amendment thereof and the modification of the rights and obligations of the Company and the rights of the Holders of the Securities of each series to be affected under the Indenture at any time by the Company and the Trustee with the consent of the Holders of not less than a majority in principal amount of the Securities at the time Outstanding of each series to be affected. The Indenture also contains provisions permitting the Holders of specified percentages in principal amount of the Securities of each series at the time Outstanding, on behalf of the Holders of all Securities of such series, to waive compliance by the Company with certain provisions of the Indenture and certain past defaults under the Indenture and their consequences. Any such consent or waiver by the Holder of this Security shall be conclusive and binding upon such Holder and upon all future Holders of this Security and of any Security issued upon the registration of transfer hereof or in exchange herefor or in lieu hereof, whether or not notation of such consent or waiver is made upon this Security.

As provided in and subject to the provisions of the Indenture, the Holder of this Security shall not have the right to institute any proceeding with respect to the Indenture or for the appointment of a receiver or trustee or for any other remedy thereunder, unless such Holder shall have previously given the Trustee written notice of a continuing Event of Default with respect to the Securities of this series, the Holders of not less than 25% in principal amount of the Securities of this series at the time Outstanding shall have made written request to the Trustee to institute proceedings in respect of such Event of Default as Trustee and offered the Trustee reasonable indemnity,

5

and the Trustee shall not have received from the Holders of a majority in principal amount of Securities of this series at the time Outstanding a direction inconsistent with such request, and shall have failed to institute any such proceeding, for 60 days after receipt of such notice, request and offer of indemnity. The foregoing shall not apply to any suit instituted by the Holder of this Security for the enforcement of any payment of principal hereof or any premium or interest hereon on or after the respective due dates expressed herein.

No reference herein to the Indenture and no provision of this Security or of the Indenture shall alter or impair the obligation of the Company, which is absolute and unconditional, to pay the principal of and any premium and interest on this Security at the times, place and rate, and in the coin or currency, herein prescribed.

As provided in the Indenture and subject to certain limitations therein set forth, the transfer of this Security is registrable in the Security Register, upon surrender of this Security for registration of transfer at the office or agency of the Company in any place where the principal of and any premium and interest on this Security are payable, duly endorsed by, or accompanied by a written instrument of transfer in form satisfactory to the Company and the Security Registrar duly executed by, the Holder hereof or his attorney duly authorized in writing, and thereupon one or more new Securities of this series and of like tenor, of authorized denominations and for the same aggregate principal amount, will be issued to the designated transferee or transferees.

The Securities of this series are issuable only in registered form without coupons in denominations of $2,000 and integral multiples of $1,000 in excess thereof. As provided in the Indenture and subject to certain limitations therein set forth, Securities of this series are exchangeable for a like aggregate principal amount of Securities of this series and of like tenor of a different authorized denomination, as requested by the Holder surrendering the same.

No service charge shall be made for any such registration of transfer or exchange, but, subject to any applicable provisions of the Indenture, the Company may require payment of a sum sufficient to cover any tax or other governmental charge payable in connection therewith.

Prior to due presentment of this Security for registration of transfer, the Company, the Trustee and any agent of the Company or the Trustee may treat the Person in whose name this Security is registered as the owner hereof for all purposes, whether or not this Security be overdue, and neither the Company, the Trustee nor any such agent shall be affected by notice to the contrary.

All terms used in this Security which are defined in the Indenture shall have the meaning assigned to them in the Indenture.

SCHEDULE OF INCREASES OR DECREASES IN THE PRINCIPAL AMOUNT
OF SECURITIES

The original principal amount of this Security is [●] U.S. Dollars ($[●]). The following increases or decreases in the principal amount of this Security have been made:

Date of increase or decrease Amount of decrease in principal amount of this Security Amount of increase in principal amount of this Security Principal amount of this Security following such decrease or increase Signature of authorized signatory of Trustee or Depositary

FORM OF ASSIGNMENT

ABBREVIATIONS

Customary abbreviations may be used in the name of a Securityholder or an assignee, such as TEN COM (=tenants in common), TEN ENT (=tenants by the entireties), JT TEN (=joint tenants with rights of survivorship and not as tenants in common), CUST (=custodian), and U/G/M/A (=Uniform Gift to Minors Act).

Additional abbreviations may also be used though not in the above list.

_________________

FOR VALUE RECEIVED, the undersigned hereby sell(s),
assign(s) and transfer(s) unto

_____________________________

Please insert Social Security or

other identifying number of assignee

PLEASE PRINT OR TYPEWRITE NAME AND ADDRESS, INCLUDING POSTAL ZIP CODE, OF ASSIGNEE

the within Security and all rights thereunder, hereby irrevocably constituting and appointing attorney to transfer said Security on the books of the Company, with full power of substitution in the premises.

Dated:

Notice: This signature to the assignment must correspond with the name as written on the face of the within instrument in every particular, without alteration or enlargement, or any change whatever.

EX-31.1

Exhibit 31.1

MARATHON PETROLEUM CORPORATION

CERTIFICATION PURSUANT TO SECTION 302 OF

THE SARBANES-OXLEY ACT OF 2002

I, Gary R. Heminger, certify that:

1. I have reviewed this report on Form 10-Q of Marathon Petroleum Corporation;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:	November 3, 2014	/s/ Gary R. Heminger
		Gary R. Heminger
		President and Chief Executive Officer

EX-31.2

Exhibit 31.2

MARATHON PETROLEUM CORPORATION

CERTIFICATION PURSUANT TO SECTION 302 OF

THE SARBANES-OXLEY ACT OF 2002

I, Donald C. Templin, certify that:

1. I have reviewed this report on Form 10-Q of Marathon Petroleum Corporation;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:	November 3, 2014	/s/ Donald C. Templin
		Donald C. Templin
		Senior Vice President and Chief Financial Officer

EX-32.1

Exhibit 32.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Marathon Petroleum Corporation (the “Company”) on Form 10-Q for the period ending September 30, 2014 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Gary R. Heminger, President and Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that to the best of my knowledge:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

November 3, 2014

/s/ Gary R. Heminger

Gary R. Heminger

President and Chief Executive Officer

EX-32.2

Exhibit 32.2

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Marathon Petroleum Corporation (the “Company”) on Form 10-Q for the period ending September 30, 2014 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Donald C. Templin, Senior Vice President and Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that to the best of my knowledge:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

November 3, 2014

/s/ Donald C. Templin

Donald C. Templin

Senior Vice President and Chief Financial Officer

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Segment Information (Tables)

9 Months Ended

Sep. 30, 2014

Segment Reporting [Abstract]

Income From Operations Attributable To Operating Segments

(In millions)	Refining & Marketing		Speedway		Pipeline Transportation		Total
Three Months Ended September 30, 2014
Revenues:
Customer	$	21,568	$	3,854	$	16	$	25,438
Intersegment(a)	2,400		2		136		2,538
Segment revenues	$	23,968	$	3,856	$	152	$	27,976
Segment income from operations(b)	$	971	$	119	$	69	$	1,159
Income from equity method investments	17		—		12		29
Depreciation and amortization(c)	257		33		20		310
Capital expenditures and investments(d)(f)	318		2,707		224		3,249

(In millions)	Refining & Marketing		Speedway		Pipeline Transportation		Total
Three Months Ended September 30, 2013
Revenues:
Customer	$	22,481	$	3,755	$	20	$	26,256
Intersegment(a)	2,439		1		117		2,557
Segment revenues	$	24,920	$	3,756	$	137	$	28,813
Segment income from operations(b)	$	227	$	102	$	54	$	383
Income from equity method investments	8		—		1		9
Depreciation and amortization(c)	246		29		19		294
Capital expenditures and investments(d)	243		65		42		350

(In millions)	Refining & Marketing		Speedway		Pipeline Transportation		Total
Nine Months Ended September 30, 2014
Revenues:
Customer	$	64,295	$	11,220	$	52	$	75,567
Intersegment(a)	7,223		4		396		7,623
Segment revenues	$	71,518	$	11,224	$	448	$	83,190
Segment income from operations(b)	$	2,593	$	271	$	222	$	3,086
Income from equity method investments	76		—		45		121
Depreciation and amortization(c)	782		90		58		930
Capital expenditures and investments(d)(f)	731		2,783		418		3,932

(In millions)	Refining & Marketing		Speedway		Pipeline Transportation		Total
Nine Months Ended September 30, 2013
Revenues:
Customer	$	64,245	$	10,964	$	60	$	75,269
Intersegment(a)	7,072		3		340		7,415
Segment revenues	$	71,317	$	10,967	$	400	$	82,684
Segment income from operations(b)	$	2,235	$	292	$	163	$	2,690
Income from equity method investments	7		—		9		16
Depreciation and amortization(c)	734		83		55		872
Capital expenditures and investments(d)(e)	1,797		177		173		2,147

^(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 Pipeline Transportation 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 and investments in affiliates.

^(e)  The Refining & Marketing and Pipeline Transportation segments include $1.29 billion and $70 million, respectively, for the acquisition of the Galveston Bay Refinery and Related Assets. See Note 4.

^(f)  The Speedway and Refining & Marketing segments include $2.63 billion and $54 million, respectively, for the acquisition of Hess' Retail Operations and Related Assets. See Note 4.

Reconciliation Of Segment Income From Operations To Income Before Income Taxes

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

	Three Months Ended   September 30,						Nine Months Ended   September 30,
(In millions)	2014			2013			2014			2013
Segment income from operations	$	1,159		$	383		$	3,086		$	2,690
Items not allocated to segments:
Corporate and other unallocated items(a)(b)	(76		)	(59		)	(204		)	(190		)
Pension settlement expenses(c)	(21		)	(23		)	(90		)	(83		)
Net interest and other financial income (costs)	(50		)	(47		)	(144		)	(140		)
Income before income taxes	$	1,012		$	254		$	2,648		$	2,277

^(a)  Corporate and other unallocated items consists primarily of MPC’s corporate administrative expenses and costs related to certain non-operating assets.

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

^(c)  See Note 20.

Reconciliation Of Segment Capital Expenditures And Investments To Total Capital Expenditures

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

	Three Months Ended   September 30,				Nine Months Ended   September 30,
(In millions)	2014		2013		2014		2013
Segment capital expenditures and investments	$	3,249	$	350	$	3,932	$	2,147
Less: Investments in equity method investees	177		75		341		86
Plus: Items not allocated to segments:
Capital expenditures not allocated to segments	22		54		60		106
Capitalized interest	7		7		20		15
Total capital expenditures(a)(b)	$	3,101	$	336	$	3,671	$	2,182

^(a)  Capital expenditures include changes in capital accruals and acquisitions.

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

Reconciliation Of Total Revenues To Sales And Other Operating Revenues

The following reconciles customer revenues to sales and other operating revenues (including consumer excise taxes) as reported in the consolidated statements of income:

	Three Months Ended   September 30,				Nine Months Ended   September 30,
(In millions)	2014		2013		2014		2013
Customer revenues (as reported above)	$	25,438	$	26,256	$	75,567	$	75,269
Corporate and other unallocated items	—		—		—		(6		)
Sales and other operating revenues (including consumer excise taxes)	$	25,438	$	26,256	$	75,567	$	75,263

Total Assets By Reportable Segment

Total assets by reportable segment were:

(In millions)	September 30, 2014		December 31, 2013
Refining & Marketing	$	20,207	$	19,573
Speedway	5,203		2,064
Pipeline Transportation	2,329		1,947
Corporate and Other	3,966		4,801
Total consolidated assets	$	31,705	$	28,385

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Acquisitions and Investments (Acquisition of Hess' Retail Operations and Related Assets) (Details) (USD $) In Millions, unless otherwise specified						0 Months Ended	3 Months Ended	9 Months Ended
	Sep. 30, 2014	Dec. 31, 2013	Sep. 30, 2014 Speedway	Jun. 30, 2014 Speedway Store	Dec. 31, 2013 Speedway	Sep. 30, 2014 Hess' Retail Operations and Related Assets	Sep. 30, 2014 Hess' Retail Operations and Related Assets BPD	Sep. 30, 2014 Hess' Retail Operations and Related Assets Trade Names	Sep. 30, 2014 Hess' Retail Operations and Related Assets Lease Agreements	Sep. 30, 2014 Hess' Retail Operations and Related Assets Above Market Leases	Sep. 30, 2014 Hess' Retail Operations and Related Assets Speedway Store
Business Acquisition [Line Items]
Allocation of space on Colonial Pipeline (in barrels per day)							40,000
Cash paid for acquisition						$ 2,820
Goodwill	1,537	938	825		225		600
Reason for business combination							This acquisition significantly expands our Speedway presence from nine to 22 states throughout the East Coast and Southeast and is aligned with our strategy to grow higher-valued, stable cash flow businesses. This acquisition also enables us to further leverage our integrated refining and transportation operations, providing an outlet for an incremental 200,000 barrels per day of assured sales from our refining system.
Number of states in which entity operates				9							22
Finite-lived intangibles								22
Other noncurrent assets							103		60
Deferred credits and other liabilities							122			80
Finite-lived intangible asset, useful life								2 years
Acquisition-related costs							$ 12

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Accumulated Other Comprehensive Loss (Tables)

9 Months Ended

Sep. 30, 2014

Equity [Abstract]

Changes in Accumulated Other Comprehensive Loss by Component

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

(In millions)	Pension Benefits			Other Benefits			Gain on Cash Flow Hedge		Workers Compensation		Total
Balance as of December 31, 2012	$	(432	)	$	(36	)	$	4	$	—	$	(464	)
Other comprehensive income before reclassifications	172			3			—		2		177
Amounts reclassified from accumulated other comprehensive loss:
Amortization – prior service credit(a)	(34		)	(3		)	—		—		(37		)
– actuarial loss(a)	53			2			—		—		55
– settlement loss(a)	83			—			—		—		83
Tax effect	(19		)	—			—		—		(19		)
Other comprehensive income	255			2			—		2		259
Balance as of September 30, 2013	$	(177	)	$	(34	)	$	4	$	2	$	(205	)

(In millions)	Pension Benefits			Other Benefits			Gain on Cash Flow Hedge		Workers Compensation			Total
Balance as of December 31, 2013	$	(161	)	$	(50	)	$	4	$	3		$	(204	)
Other comprehensive income (loss) before reclassifications	(88		)	8			—		(2		)	(82		)
Amounts reclassified from accumulated other comprehensive loss:
Amortization – prior service credit(a)	(35		)	(3		)	—		—			(38		)
– actuarial loss(a)	38			2			—		—			40
– settlement loss(a)	90			—			—		—			90
Tax effect	(35		)	1			—		—			(34		)
Other comprehensive income (loss)	(30		)	8			—		(2		)	(24		)
Balance as of September 30, 2014	$	(191	)	$	(42	)	$	4	$	1		$	(228	)

^(a)  These accumulated other comprehensive loss components are included in the computation of net periodic benefit cost. See Note 20.

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Equity - Additional Information (Detail) (USD $) Share data in Millions, except Per Share data, unless otherwise specified	3 Months Ended			9 Months Ended			33 Months Ended	1 Months Ended	0 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013	Sep. 30, 2014	Oct. 31, 2014 Scenario, Forecast	Jul. 30, 2014 Share Repurchase Authorization July 2014	Jul. 30, 2014 Share Repurchase Authorization July 2014	Sep. 30, 2013 Accelerated Share Repurchase Program November 2012
Equity, Class of Treasury Stock [Line Items]
Stock repurchase plan authorized amount	$ 8,000,000,000			$ 8,000,000,000			$ 8,000,000,000			$ 2,000,000,000
Ending date of share repurchase authorization									Jul. 30, 2016
Cash paid for shares repurchased	301,000,000	1,028,000,000		1,449,000,000		2,341,000,000	5,590,000,000	9,000,000
Stock repurchase plan remaining authorized amount	$ 2,410,000,000			$ 2,410,000,000			$ 2,410,000,000
Number of shares repurchased	4	14	[1]	17	[1]	31	82				1
Effective average cost per delivered share	$ 85.15	$ 70.73		$ 87.25		$ 76.01	$ 68.41

[1] The nine months ended September 30, 2013 includes one million shares received under the November 2012 accelerated share repurchase program, which were paid for in 2012.

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Acquisitions and Investments (Schedule of Assets Acquired and Liabilities Assumed - Hess Retail) (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014	Dec. 31, 2013
Business Acquisition [Line Items]
Goodwill	$ 1,537	$ 938
Hess' Retail Operations and Related Assets
Business Acquisition [Line Items]
Cash and cash equivalents	39
Receivables	132
Inventories	178
Other current assets	5
Property, plant and equipment, net	2,062
Other noncurrent assets	103
Total assets acquired	2,519
Accounts payable	77
Payroll and benefits payable	4
Consumer excise taxes payable	80
Other current liabilities	10
Defined benefit postretirement plan obligations	2
Deferred credits and other liabilities	122
Total liabilities assumed	295
Net assets acquired excluding goodwill	2,224
Goodwill	600
Net assets acquired	$ 2,824

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Other Items - Net Interest And Other Financial Income (Costs) (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Interest:
Interest income	$ 2	$ 2	$ 5	$ 7
Interest expense	(56)	(50)	(154)	(147)
Interest capitalized	7	7	20	15
Total net interest	(47)	(41)	(129)	(125)
Other:
Net foreign currency gains (losses)	1	(1)	0	0
Bank service and other fees	(4)	(5)	(15)	(15)
Total other	(3)	(6)	(15)	(15)
Net interest and other financial income (costs)	$ (50)	$ (47)	$ (144)	$ (140)

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Stock-Based Compensation Plans - Summary of Performance Unit Awards (Detail) (Performance Unit Awards)	9 Months Ended
	Sep. 30, 2014
Performance Unit Awards
Number of Units
Outstanding, beginning balance	3,822,500
Granted	2,033,700
Settled	0
Canceled	0
Outstanding, ending balance	5,856,200

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Debt (Tables)

9 Months Ended

Sep. 30, 2014

Debt Disclosure [Abstract]

Outstanding Borrowings

Our outstanding borrowings at September 30, 2014 and December 31, 2013 consisted of the following:

(In millions)	September 30, 2014			December 31, 2013
Marathon Petroleum Corporation:
Revolving credit agreement due 2017	$	—		$	—
Term loan agreement due 2019	700			—
3.500% senior notes due March 1, 2016	750			750
5.125% senior notes due March 1, 2021	1,000			1,000
3.625% senior notes due September 15, 2024	750			—
6.500% senior notes due March 1, 2041	1,250			1,250
4.750% senior notes due September 15, 2044	800			—
5.000% senior notes due September 15, 2054	400			—
Consolidated subsidiaries:
Capital lease obligations due 2014-2028	378			395
MPLX Operations LLC revolving credit agreement due 2017	255			—
Trade receivables securitization facility due 2016	—			—
Total	6,283			3,395
Unamortized discount	(26		)	(10		)
Fair value adjustments(a)	7			11
Amounts due within one year	(26		)	(23		)
Total long-term debt due after one year	$	6,238		$	3,373

^(a)  The $20 million gain on the termination of our interest rate swap agreements in 2012 is being amortized over the remaining life of the 3.50 percent senior notes.

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Supplementary Statistics

9 Months Ended

Sep. 30, 2014

Text Block [Abstract]

Supplementary Statistics

Supplementary Statistics (Unaudited)

	Three Months Ended   September 30,						Nine Months Ended   September 30,
(In millions)	2014			2013			2014			2013
Income from Operations by segment
Refining & Marketing	$	971		$	227		$	2,593		$	2,235
Speedway	119			102			271			292
Pipeline Transportation(a)	69			54			222			163
Items not allocated to segments:
Corporate and other unallocated items(a)	(76		)	(59		)	(204		)	(190		)
Pension settlement expenses	(21		)	(23		)	(90		)	(83		)
Income from operations	$	1,062		$	301		$	2,792		$	2,417
Capital Expenditures and Investments(b)(c)
Refining & Marketing	$	318		$	243		$	731		$	1,797
Speedway	2,707			65			2,783			177
Pipeline Transportation	224			42			418			173
Corporate and Other(d)	29			61			80			121
Total	$	3,278		$	411		$	4,012		$	2,268

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

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

^(c)  The three and nine months ended September 30, 2014 includes $2.68 billion for the acquisition of Hess' Retail Operations and Related Assets. The nine months ended September 30, 2013 includes $1.36 billion for the acquisition of the Galveston Bay Refinery and Related Assets. See Note 4 to the unaudited consolidated financial statements.

^(d)  Includes capitalized interest of $7 million for both the three months ended September 30, 2014 and 2013, and $20 million and $15 million for the nine months ended September 30, 2014 and 2013, respectively.

Supplementary Statistics (Unaudited)

	Three Months Ended   September 30,				Nine Months Ended   September 30,
	2014		2013		2014		2013
MPC Consolidated Refined Product Sales Volumes (thousands of barrels per day)(a)(b)	2,155		2,155		2,092		2,063
Refining & Marketing Operating Statistics(b)
Refining & Marketing refined product sales volume (thousands of barrels per day)(c)	2,140		2,148		2,079		2,052
Refining & Marketing gross margin (dollars per barrel)(d)	$	14.55	$	9.25	$	15.02	$	12.42
Crude oil capacity utilization percent(e)	100		99		94		97
Refinery throughputs (thousands of barrels per day):(f)
Crude oil refined	1,720		1,682		1,616		1,603
Other charge and blendstocks	160		195		172		202
Total	1,880		1,877		1,788		1,805
Sour crude oil throughput percent	52		53		52		53
WTI-priced crude oil throughput percent	16		21		18		22
Refined product yields (thousands of barrels per day):(f)
Gasoline	864		938		851		917
Distillates	598		578		574		570
Propane	36		39		36		37
Feedstocks and special products	330		259		280		227
Heavy fuel oil	24		31		27		31
Asphalt	63		70		52		57
Total	1,915		1,915		1,820		1,839
Refinery direct operating costs (dollars per barrel):(g)
Planned turnaround and major maintenance	$	1.52	$	0.96	$	1.82	$	0.94
Depreciation and amortization	1.35		1.27		1.43		1.32
Other manufacturing(h)	4.33		4.10		4.96		4.00
Total	$	7.20	$	6.33	$	8.21	$	6.26
Refining & Marketing Operating Statistics By Region - Gulf Coast(b)
Refinery throughputs (thousands of barrels per day):(i)
Crude oil refined	1,075		1,035		989		971
Other charge and blendstocks	155		175		174		181
Total	1,230		1,210		1,163		1,152
Sour crude oil throughput percent	66		64		64		65
WTI-priced crude oil throughput percent	1		7		2		8
Refined product yields (thousands of barrels per day):(i)
Gasoline	505		561		498		545
Distillates	389		370		366		363
Propane	25		24		24		23
Feedstocks and special products	310		241		275		214
Heavy fuel oil	8		21		13		20
Asphalt	19		23		13		14
Total	1,256		1,240		1,189		1,179
Refinery direct operating costs (dollars per barrel):(g)
Planned turnaround and major maintenance	$	1.15	$	0.86	$	1.77	$	0.77
Depreciation and amortization	1.10		1.01		1.16		1.04
Other manufacturing(h)	4.11		4.08		4.86		3.82
Total	$	6.36	$	5.95	$	7.79	$	5.63

Supplementary Statistics (Unaudited)
	Three Months Ended   September 30,						Nine Months Ended   September 30,
	2014			2013			2014			2013
Refining & Marketing Operating Statistics By Region - Midwest
Refinery throughputs (thousands of barrels per day):(i)
Crude oil refined	645			647			627			632
Other charge and blendstocks	38			56			43			55
Total	683			703			670			687
Sour crude oil throughput percent	30			35			33			35
WTI-priced crude oil throughput percent	41			43			42			43
Refined product yields (thousands of barrels per day):(i)
Gasoline	359			377			353			373
Distillates	209			208			208			207
Propane	13			15			13			14
Feedstocks and special products	51			54			49			46
Heavy fuel oil	16			10			14			11
Asphalt	44			47			39			43
Total	692			711			676			694
Refinery direct operating costs (dollars per barrel):(g)
Planned turnaround and major maintenance	$	2.10		$	1.08		$	1.78		$	1.17
Depreciation and amortization	1.75			1.66			1.80			1.72
Other manufacturing(h)	4.51			3.91			4.82			4.10
Total	$	8.36		$	6.65		$	8.40		$	6.99
Speedway Operating Statistics
Convenience stores at period-end(j)	2,744			1,471
Gasoline and distillate sales (millions of gallons)	842			803			2,421			2,329
Gasoline and distillate gross margin (dollars per gallon)(k)	$	0.1596		$	0.1404		$	0.1351		$	0.1483
Merchandise sales (in millions)	$	870		$	843		$	2,422		$	2,360
Merchandise gross margin (in millions)	$	235		$	224		$	651		$	620
Merchandise gross margin percent	27.0		%	26.5		%	26.9		%	26.3		%
Same store gasoline sales volume (period over period)	(0.8		%)	1.0		%	(1.0		%)	0.6		%
Same store merchandise sales (period over period)(l)	4.8		%	5.6		%	4.8		%	3.8		%
Pipeline Transportation Operating Statistics
Pipeline throughputs (thousands of barrels per day):(m)
Crude oil pipelines	1,265			1,317			1,230			1,308
Refined products pipelines	839			913			843			930
Total	2,104			2,230			2,073			2,238

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

^(b)  Includes the impact of the Galveston Bay Refinery and Related Assets beginning on the February 1, 2013 acquisition date.

^(c)  Includes intersegment sales.

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

^(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 33 mbpd and 36 mbpd for the three months ended September 30, 2014 and 2013, respectively, and 45 mbpd and 34 mbpd for the nine months ended September 30, 2014 and 2013, 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)  Includes 1,245 stores acquired on September 30, 2014 through the acquisition of Hess' Retail Operations and Related Assets. Segment results for the period prior to the acquisition do not include results from these operations.

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

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Income Taxes - Additional Information (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Income Tax Disclosure [Abstract]
Combined federal, state and foreign income tax rate	33.00%	32.00%	34.00%	34.00%
Statutory rate applied to income before income taxes			35.00%
Tax settlement with Marathon Oil Corporation			$ 39	$ 39
Unrecognized benefits	$ 16		$ 16

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Segment Information - Income From Operations Attributable To Operating Segments (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended				9 Months Ended
	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013
Segment Reporting Information [Line Items]
Revenues	$ 25,438		$ 26,256		$ 75,567		$ 75,263
Income from operations	1,062		301		2,792		2,417
Income (loss) from equity method investments	29		9		121		16
Depreciation and amortization	322		299		967		888
Capital expenditures and investments	3,278	[1],[2],[3]	411	[1],[2],[3]	4,012	[1],[2],[3]	2,268	[1],[2],[3]
Galveston Bay Refinery and Related Assets
Segment Reporting Information [Line Items]
Capital expenditures and investments							1,360	[2],[3]
Hess' Retail Operations and Related Assets
Segment Reporting Information [Line Items]
Capital expenditures and investments					2,680	[3]
Intersegment Eliminations
Segment Reporting Information [Line Items]
Revenues	2,538	[4]	2,557	[4]	7,623	[4]	7,415	[4]
Operating Segments
Segment Reporting Information [Line Items]
Revenues	27,976		28,813		83,190		82,684
Income from operations	1,159	[5]	383	[5]	3,086	[5]	2,690	[5]
Income (loss) from equity method investments	29		9		121		16
Depreciation and amortization	310	[6]	294	[6]	930	[6]	872	[6]
Capital expenditures and investments	3,249	[3],[7]	350	[3]	3,932	[3],[7]	2,147	[3],[8]
Refining & Marketing
Segment Reporting Information [Line Items]
Revenues	21,568		22,481		64,295		64,245
Refining & Marketing | Intersegment Eliminations
Segment Reporting Information [Line Items]
Revenues	2,400	[4]	2,439	[4]	7,223	[4]	7,072	[4]
Refining & Marketing | Operating Segments
Segment Reporting Information [Line Items]
Revenues	23,968		24,920		71,518		71,317
Income from operations	971		227		2,593		2,235
Income (loss) from equity method investments	17		8		76		7
Depreciation and amortization	257	[6]	246	[6]	782	[6]	734	[6]
Capital expenditures and investments	318	[3],[7]	243	[3]	731	[3],[7]	1,797	[2],[3],[8]
Refining & Marketing | Operating Segments | Galveston Bay Refinery and Related Assets
Segment Reporting Information [Line Items]
Capital expenditures and investments							1,290	[2],[3]
Refining & Marketing | Operating Segments | Hess' Retail Operations and Related Assets
Segment Reporting Information [Line Items]
Capital expenditures and investments					54	[3]
Speedway
Segment Reporting Information [Line Items]
Revenues	3,854		3,755		11,220		10,964
Speedway | Intersegment Eliminations
Segment Reporting Information [Line Items]
Revenues	2	[4]	1	[4]	4	[4]	3	[4]
Speedway | Operating Segments
Segment Reporting Information [Line Items]
Revenues	3,856		3,756		11,224		10,967
Income from operations	119		102		271		292
Income (loss) from equity method investments	0		0		0		0
Depreciation and amortization	33	[6]	29	[6]	90	[6]	83	[6]
Capital expenditures and investments	2,707	[3],[7]	65	[3]	2,783	[3],[7]	177	[3]
Speedway | Operating Segments | Hess' Retail Operations and Related Assets
Segment Reporting Information [Line Items]
Capital expenditures and investments					2,630	[3]
Pipeline Transportation
Segment Reporting Information [Line Items]
Revenues	16		20		52		60
Pipeline Transportation | Intersegment Eliminations
Segment Reporting Information [Line Items]
Revenues	136	[4]	117	[4]	396	[4]	340	[4]
Pipeline Transportation | Operating Segments
Segment Reporting Information [Line Items]
Revenues	152		137		448		400
Income from operations	69	[5]	54	[5]	222	[5]	163	[5]
Income (loss) from equity method investments	12		1		45		9
Depreciation and amortization	20	[6]	19	[6]	58	[6]	55	[6]
Capital expenditures and investments	224	[3]	42	[3]	418	[3]	173	[2],[3],[8]
Pipeline Transportation | Operating Segments | Galveston Bay Refinery and Related Assets
Segment Reporting Information [Line Items]
Capital expenditures and investments							70	[2],[3]
Reportable Segment
Segment Reporting Information [Line Items]
Revenues	$ 25,438		$ 26,256		$ 75,567		$ 75,269

[1] Includes capitalized interest of $7 million for both the three months ended September 30, 2014 and 2013, and $20 million and $15 million for the nine months ended September 30, 2014 and 2013, respectively.

[2] The nine months ended September 30, 2013 includes $1.36 billion for the acquisition of the Galveston Bay Refinery and Related Assets. See Note 4 to the unaudited consolidated financial statements.

[3] Capital expenditures include changes in capital accruals, acquisitions and investments in affiliates.

[4] Management believes intersegment transactions were conducted under terms comparable to those with unaffiliated parties

[5] Corporate overhead expenses attributable to MPLX are included in the Pipeline Transportation segment. Corporate overhead expenses are not allocated to the Refining & Marketing and Speedway segments.

[6] 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.

[7] The Speedway and Refining & Marketing segments include $2.63 billion and $54 million, respectively, for the acquisition of Hess' Retail Operations and Related Assets. See Note 4.

[8] The Refining & Marketing and Pipeline Transportation segments include $1.29 billion and $70 million, respectively, for the acquisition of the Galveston Bay Refinery and Related Assets. See Note 4.

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Derivatives - Classification of Gross Fair Values of Derivative Instruments, Excluding Cash Collateral (Detail) (Commodity derivatives, Other current assets, USD $) In Millions, unless otherwise specified	Sep. 30, 2014	Dec. 31, 2013
Commodity derivatives | Other current assets
Derivatives, Fair Value [Line Items]
Asset	$ 87	$ 21
Liability	$ 55	$ 53

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Acquisitions and Investments (Schedule of Acquisition Related Pro Forma Financial Information) (Details) (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Business Combinations [Abstract]
Sales and other operating revenues (including consumer excise taxes)	$ 28,284	$ 29,317	$ 84,232	$ 86,386
Net income attributable to MPC	$ 698	$ 170	$ 1,748	$ 1,516
Net income attributable to MPC per share - basic	$ 2.48	$ 0.55	$ 6.07	$ 4.72
Net income attributable to MPC per share - diluted	$ 2.46	$ 0.55	$ 6.03	$ 4.69

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Segment Information - Reconciliation Of Total Revenues To Sales And Other Operating Revenues (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Segment Reporting, Revenue Reconciling Item [Line Items]
Sales and other operating revenues (including consumer excise taxes)	$ 25,438	$ 26,256	$ 75,567	$ 75,263
Corporate and Other
Segment Reporting, Revenue Reconciling Item [Line Items]
Sales and other operating revenues (including consumer excise taxes)	0	0	0	(6)
Reportable Segment
Segment Reporting, Revenue Reconciling Item [Line Items]
Sales and other operating revenues (including consumer excise taxes)	$ 25,438	$ 26,256	$ 75,567	$ 75,269

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Fair Value Measurements - Reconciliation of Net Beginning and Ending Balances Recorded for Net Assets and Liabilities Classified as Level 3 (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	$ 647	$ 611	$ 625	$ 0
Contingent consideration agreement	0	0	0	600
Contingent consideration payment	(180)	0	(180)	0
Unrealized (gains) losses included in net income	8	(5)	30	6
Ending balance	$ 475	$ 606	$ 475	$ 606

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Inventories - Additional Information (Detail) (USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013
Inventory Disclosure [Abstract]
Impact on revenues and costs as a result of LIFO liquidations	$ 0	$ 0

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Fair Value Measurements Fair Value Measurements - Assets Measured at Fair Value on Nonrecurring Basis (Details) (Fair Value, Measurements, Nonrecurring, USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013
Fair Value, Measurements, Nonrecurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Property, plant, and equipment, fair value	$ 0	$ 1
Impairment of long-lived assets held-for-use	0	8
Other assets, fair value	0	0
Other asset impairment charges	$ 11	$ 0

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Segment Information Segment Information - Total Assets By Reportable Segment (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014	Dec. 31, 2013
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	$ 31,705	$ 28,385
Operating Segments | Refining & Marketing
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	20,207	19,573
Operating Segments | Speedway
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	5,203	2,064
Operating Segments | Pipeline Transportation
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	2,329	1,947
Corporate and Other
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	$ 3,966	$ 4,801

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Equity - Share Repurchases Transacted Through ASR Programs and Open Market Transactions (Detail) (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended			9 Months Ended			33 Months Ended
	Sep. 30, 2014	Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013	Sep. 30, 2014
Equity, Class of Treasury Stock [Line Items]
Number of shares repurchased	4	14	[1]	17	[1]	31	82
Cash paid for shares repurchased	$ 301	$ 1,028		$ 1,449		$ 2,341	$ 5,590
Effective average cost per delivered share	$ 85.15	$ 70.73		$ 87.25		$ 76.01	$ 68.41
Accelerated Share Repurchase Program November 2012
Equity, Class of Treasury Stock [Line Items]
Number of shares repurchased						1

[1] The nine months ended September 30, 2013 includes one million shares received under the November 2012 accelerated share repurchase program, which were paid for in 2012.

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Derivatives

9 Months Ended

Sep. 30, 2014

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivatives

Derivatives

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

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

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, 2014 and December 31, 2013:

	September 30, 2014
(In millions)	Asset		Liability		Balance Sheet Location
Commodity derivatives	$	87	$	55	Other current assets
	December 31, 2013
(In millions)	Asset		Liability		Balance Sheet Location
Commodity derivatives	$	21	$	53	Other current assets

The table below summarizes open commodity derivative contracts as of September 30, 2014.

	Position	Total Barrels (In thousands)
Crude oil(a)
Exchange-traded	Long	10,346
Exchange-traded	Short	(23,186	)
Refined Products(b)
Exchange-traded	Long	1,695
Exchange-traded	Short	(3,281	)

^(a)  96 percent of these contracts expire in the fourth quarter of 2014.

^(b)  100 percent of these contracts expire in the fourth quarter of 2014.

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	2014		2013			2014			2013
Sales and other operating revenues	$	10	$	9		$	18		$	13
Cost of revenues	145		(170		)	(30		)	(179		)
Total	$	155	$	(161	)	$	(12	)	$	(166	)

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Stock-Based Compensation Plans (Tables)

9 Months Ended

Sep. 30, 2014

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

Summary of Stock Option Award Activity

The following table presents a summary of our stock option award activity for the nine months ended September 30, 2014:

	Number of Shares(a)		Weighted Average Exercise Price
Outstanding at December 31, 2013	5,147,837		$	40.08
Granted	446,310		85.02
Exercised	(696,159	)	32.12
Forfeited, canceled or expired	(20,761	)	49.67
Outstanding at September 30, 2014	4,877,227		45.28

^(a)  Includes an immaterial number of stock appreciation rights.

Summary of Restricted Stock Award Activity

The following table presents a summary of restricted stock award activity for the nine months ended September 30, 2014:

	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, 2013	624,122		$	61.11	385,079		$	33.96
Granted	240,882		87.81		19,827		86.79
RS's Vested/RSU's Issued	(324,697	)	55.47		(398	)	60.11
Forfeited	(25,943	)	70.10		(133	)	76.10
Outstanding at September 30, 2014	514,364		76.73		404,375		36.51

Schedule of Performance Unit Awards

The following table presents a summary of the activity for performance unit awards to be settled in shares for the nine months ended September 30, 2014:

	Number of Units
Outstanding at December 31, 2013	3,822,500
Granted	2,033,700
Settled	—
Canceled	—
Outstanding at September 30, 2014	5,856,200

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Property, Plant and Equipment (Tables)

9 Months Ended

Sep. 30, 2014

Property, Plant and Equipment [Abstract]

Summary Of Property, Plant And Equipment

(In millions)	September 30, 2014		December 31, 2013
Refining & Marketing	$	17,646	$	16,982
Speedway	4,477		2,344
Pipeline Transportation	1,995		1,921
Corporate and Other	594		546
Total	24,712		21,793
Less accumulated depreciation	8,713		7,872
Property, plant and equipment, net	$	15,999	$	13,921

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Segment Information - Reconciliation Of Segment Capital Expenditures And Investments To Total Capital Expenditures (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended				9 Months Ended
	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013
Reconciliation Of Segment Capital Expenditures And Investments To Total Capital Expenditures [Line Items]
Capital expenditures and investments	$ 3,278	[1],[2],[3]	$ 411	[1],[2],[3]	$ 4,012	[1],[2],[3]	$ 2,268	[1],[2],[3]
Plus: Items not allocated to segments:
Capital expenditures	3,101	[4],[5]	336	[4],[5]	3,671	[4],[5]	2,182	[4],[5]
Operating Segments
Reconciliation Of Segment Capital Expenditures And Investments To Total Capital Expenditures [Line Items]
Capital expenditures and investments	3,249	[3],[6]	350	[3]	3,932	[3],[6]	2,147	[3],[7]
Less: Investments in equity method investees	177		75		341		86
Corporate and Other
Reconciliation Of Segment Capital Expenditures And Investments To Total Capital Expenditures [Line Items]
Capital expenditures and investments	29	[1],[3]	61	[1],[3]	80	[1],[3]	121	[1],[3]
Plus: Items not allocated to segments:
Capital expenditures not allocated to segments	22		54		60		106
Capitalized interest	$ 7		$ 7		$ 20		$ 15

[1] Includes capitalized interest of $7 million for both the three months ended September 30, 2014 and 2013, and $20 million and $15 million for the nine months ended September 30, 2014 and 2013, respectively.

[2] The nine months ended September 30, 2013 includes $1.36 billion for the acquisition of the Galveston Bay Refinery and Related Assets. See Note 4 to the unaudited consolidated financial statements.

[3] Capital expenditures include changes in capital accruals, acquisitions and investments in affiliates.

[4] See Note 18 for a reconciliation of total capital expenditures to additions to property, plant and equipment as reported in the consolidated statements of cash flows.

[5] Capital expenditures include changes in capital accruals and acquisitions.

[6] The Speedway and Refining & Marketing segments include $2.63 billion and $54 million, respectively, for the acquisition of Hess' Retail Operations and Related Assets. See Note 4.

[7] The Refining & Marketing and Pipeline Transportation segments include $1.29 billion and $70 million, respectively, for the acquisition of the Galveston Bay Refinery and Related Assets. See Note 4.

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Supplemental Cash Flow Information - Reconciliation of Additions to Property, Plant and Equipment to Total Capital Expenditures (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended				9 Months Ended
	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013
Supplemental Cash Flow Elements [Abstract]
Additions to property, plant and equipment per consolidated statements of cash flows					$ 952		$ 733
Non-cash additions to property, plant and equipment					4		0
Acquisitions					2,714	[1]	1,386	[1]
Asset retirement expenditures					1		0
Increase in capital accruals					0		63
Total capital expenditures	$ 3,101	[2],[3]	$ 336	[2],[3]	$ 3,671	[2],[3]	$ 2,182	[2],[3]

[1] The 2014 acquisition includes the acquisition of Hess' Retail Operations and Related Assets. The 2013 acquisition includes the acquisition of the Galveston Bay Refinery and Related Assets. The acquisition numbers above include property, plant and equipment and intangibles. See Note 4.

[2] See Note 18 for a reconciliation of total capital expenditures to additions to property, plant and equipment as reported in the consolidated statements of cash flows.

[3] Capital expenditures include changes in capital accruals and acquisitions.

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Income per Common Share (Tables)

9 Months Ended

Sep. 30, 2014

Earnings Per Share [Abstract]

Summary of Earnings Per Common Share

	Three Months Ended   September 30,				Nine Months Ended   September 30,
(In millions, except per share data)	2014		2013		2014		2013
Basic earnings per share:
Allocation of earnings:
Net income attributable to MPC	$	672	$	168	$	1,726	$	1,486
Income allocated to participating securities	1		—		3		2
Income available to common stockholders - basic	$	671	$	168	$	1,723	$	1,484
Weighted average common shares outstanding	282		309		288		321
Basic earnings per share	$	2.38	$	0.54	$	5.99	$	4.63
Diluted earnings per share:
Allocation of earnings:
Net income attributable to MPC	$	672	$	168	$	1,726	$	1,486
Income allocated to participating securities	1		—		3		2
Income available to common stockholders - diluted	$	671	$	168	$	1,723	$	1,484
Weighted average common shares outstanding	282		309		288		321
Effect of dilutive securities	2		2		2		2
Weighted average common shares, including dilutive effect	284		311		290		323
Diluted earnings per share	$	2.36	$	0.54	$	5.95	$	4.60

Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share

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

	Three Months Ended   September 30,		Nine Months Ended   September 30,
(In millions)	2014	2013	2014	2013
Shares issued under stock-based compensation plans	—	1	—	1

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Description of the Business and Basis of Presentation Basis of Presentation (Details) (Total costs and expenses, Increase in prior year bonus expense, USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2014
Total costs and expenses | Increase in prior year bonus expense
Quantifying Misstatement in Current Year Financial Statements [Line Items]
Quantifying misstatement in current year financial statements, amount	$ 29

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Related Party Transactions - Payables To Related Parties (Detail) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014	Dec. 31, 2013
Related Party Transaction [Line Items]
Payables to related parties	$ 17	$ 16
Explorer
Related Party Transaction [Line Items]
Payables to related parties	5	0
LOCAP
Related Party Transaction [Line Items]
Payables to related parties	2	2
LOOP
Related Party Transaction [Line Items]
Payables to related parties	4	3
TAAE
Related Party Transaction [Line Items]
Payables to related parties	1	2
TACE
Related Party Transaction [Line Items]
Payables to related parties	2	4
TAME
Related Party Transaction [Line Items]
Payables to related parties	2	5
Other equity method investees
Related Party Transaction [Line Items]
Payables to related parties	$ 1	$ 0

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Acquisitions and Investments (Investments in Pipeline Companies) (Details) (USD $) In Millions, unless otherwise specified	9 Months Ended		0 Months Ended		9 Months Ended	12 Months Ended
	Sep. 30, 2014 Illinois Extension Pipeline Company LLC	Jul. 01, 2014 Illinois Extension Pipeline Company LLC	Mar. 04, 2014 Explorer Pipeline	Sep. 30, 2014 Explorer Pipeline	Sep. 30, 2014 North Dakota Pipeline	Sep. 30, 2014 North Dakota Pipeline	Jan. 02, 2016 North Dakota Pipeline Class A Units Scenario, Forecast	Jan. 02, 2016 North Dakota Pipeline Class A Units Scenario, Forecast Maximum
Schedule of Equity Method Investments [Line Items]
Equity method investments, ownership percentage		35.00%		25.00%	37.50%	37.50%	27.00%	30.00%
Cash paid to acquire equity method investments	$ 97		$ 77		$ 149	$ 173
Ownership percentage acquired			7.00%

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Supplemental Cash Flow Information (Tables)

9 Months Ended

Sep. 30, 2014

Supplemental Cash Flow Elements [Abstract]

Summary of Supplemental Cash Flow Information

	Nine Months Ended   September 30,
(In millions)	2014		2013
Net cash provided by operating activities included:
Interest paid (net of amounts capitalized)	$	162	$	166
Net income taxes paid to taxing authorities	969		1,027
Non-cash investing and financing activities:
Capital lease obligations increase	$	—	$	61
Property, plant and equipment sold	4		43
Property, plant and equipment acquired	4		—
Acquisition:
Contingent consideration(a)	—		600
Payable to seller(a)	—		6

^(a)  Acquisition-date fair value of non-cash consideration associated with the Galveston Bay Refinery and Related Assets acquisition.

Reconciliation of Additions to Property, Plant and Equipment to Total Capital Expenditures

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

	Nine Months Ended   September 30,
(In millions)	2014		2013
Additions to property, plant and equipment per consolidated statements of cash flows	$	952	$	733
Non-cash additions to property, plant and equipment	4		—
Acquisitions(a)	2,714		1,386
Asset retirement expenditures	1		—
Increase in capital accruals	—		63
Total capital expenditures	$	3,671	$	2,182

^(a)  The 2014 acquisition includes the acquisition of Hess' Retail Operations and Related Assets. The 2013 acquisition includes the acquisition of the Galveston Bay Refinery and Related Assets. The acquisition numbers above include property, plant and equipment and intangibles. See Note 4.

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Consolidated Statement of Equity - Shares In Millions	Total		Common Stock	Treasury Stock
Number of shares held in treasury (beginning balance) at Dec. 31, 2012				(28)
Number of common shares issued (beginning balance) at Dec. 31, 2012			361
Number of shares issued - stock-based compensation			1
Number of shares repurchased	(31)			(31)
Number of shares held in treasury (ending balance) at Sep. 30, 2013				(59)
Number of common shares issued (ending balance) at Sep. 30, 2013			362
Number of shares held in treasury (beginning balance) at Dec. 31, 2013	(65)			(65)
Number of common shares issued (beginning balance) at Dec. 31, 2013	362		362
Number of shares issued - stock-based compensation			1
Number of shares repurchased	(17)	[1]		(17)
Number of shares held in treasury (ending balance) at Sep. 30, 2014	(82)			(82)
Number of common shares issued (ending balance) at Sep. 30, 2014	363		363

[1] The nine months ended September 30, 2013 includes one million shares received under the November 2012 accelerated share repurchase program, which were paid for in 2012.

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Variable Interest Entity (Details) (Illinois Extension Pipeline Company LLC, Variable Interest Entity, Not Primary Beneficiary, USD $) In Millions, unless otherwise specified	Sep. 30, 2014
Illinois Extension Pipeline Company LLC | Variable Interest Entity, Not Primary Beneficiary
Variable Interest Entity [Line Items]
VIE, maximum loss exposure, amount	$ 97

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Goodwill (Tables)

9 Months Ended

Sep. 30, 2014

Goodwill and Intangible Assets Disclosure [Abstract]

Schedule of Goodwill

The changes in the carrying amount of goodwill for nine months ended September 30, 2014 were as follows:

(In millions)	Refining & Marketing			Speedway		Pipeline Transportation		Total
Balance as of December 31, 2013	$	551		$	225	$	162	$	938
Acquisition(a)	—			600		—		600
Disposition	(1		)	—		—		(1		)
Balance as of September 30, 2014	$	550		$	825	$	162	$	1,537

^(a)  See Note 4 for information on the acquisitions.

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Defined Benefit Pension and Other Postretirement Plans

9 Months Ended

Sep. 30, 2014

Compensation and Retirement Disclosure [Abstract]

Defined Benefit Pension and Other Postretirement Plans

Defined Benefit Pension and Other Postretirement Plans

The following summarizes the components of net periodic benefit costs:

	Three Months Ended September 30,
	Pension Benefits						Other Benefits
(In millions)	2014			2013			2014			2013
Components of net periodic benefit cost:
Service cost	$	24		$	24		$	7		$	7
Interest cost	18			19			7			6
Expected return on plan assets	(27		)	(28		)	—			—
Amortization – prior service credit	(12		)	(12		)	(1		)	(1		)
– actuarial loss	12			14			1			1
– settlement loss	21			23			—			—
Net periodic benefit cost	$	36		$	40		$	14		$	13

	Nine Months Ended September 30,
	Pension Benefits						Other Benefits
(In millions)	2014			2013			2014			2013
Components of net periodic benefit cost:
Service cost	$	67		$	70		$	20		$	19
Interest cost	56			55			24			19
Expected return on plan assets	(81		)	(81		)	—			—
Amortization – prior service credit	(35		)	(34		)	(3		)	(3		)
– actuarial loss	38			53			2			2
– settlement loss	90			83			—			—
Net periodic benefit cost	$	135		$	146		$	43		$	37

During the nine months ended September 30, 2014, we made contributions of $16 million to our funded pension plans. Current benefit payments related to unfunded pension and other postretirement benefit plans were $22 million and $17 million, respectively, during the nine months ended September 30, 2014.

During the nine months ended September 30, 2014 and 2013, we determined that lump sum payments to employees retiring in the respective years will exceed the plans’ total service and interest costs for the year. Settlement losses are required to be recorded when lump sum payments exceed total service and interest costs. As a result, during the nine months ended September 30, 2014 and 2013, we recorded pension settlement expenses of $90 million and $83 million related to our cumulative lump sum payments made during the first nine months of 2014 and 2013, respectively.

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Accumulated Other Comprehensive Loss

9 Months Ended

Sep. 30, 2014

Equity [Abstract]

Accumulated Other Comprehensive Loss

Accumulated Other Comprehensive Loss

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

(In millions)	Pension Benefits			Other Benefits			Gain on Cash Flow Hedge		Workers Compensation		Total
Balance as of December 31, 2012	$	(432	)	$	(36	)	$	4	$	—	$	(464	)
Other comprehensive income before reclassifications	172			3			—		2		177
Amounts reclassified from accumulated other comprehensive loss:
Amortization – prior service credit(a)	(34		)	(3		)	—		—		(37		)
– actuarial loss(a)	53			2			—		—		55
– settlement loss(a)	83			—			—		—		83
Tax effect	(19		)	—			—		—		(19		)
Other comprehensive income	255			2			—		2		259
Balance as of September 30, 2013	$	(177	)	$	(34	)	$	4	$	2	$	(205	)

(In millions)	Pension Benefits			Other Benefits			Gain on Cash Flow Hedge		Workers Compensation			Total
Balance as of December 31, 2013	$	(161	)	$	(50	)	$	4	$	3		$	(204	)
Other comprehensive income (loss) before reclassifications	(88		)	8			—		(2		)	(82		)
Amounts reclassified from accumulated other comprehensive loss:
Amortization – prior service credit(a)	(35		)	(3		)	—		—			(38		)
– actuarial loss(a)	38			2			—		—			40
– settlement loss(a)	90			—			—		—			90
Tax effect	(35		)	1			—		—			(34		)
Other comprehensive income (loss)	(30		)	8			—		(2		)	(24		)
Balance as of September 30, 2014	$	(191	)	$	(42	)	$	4	$	1		$	(228	)

^(a)  These accumulated other comprehensive loss components are included in the computation of net periodic benefit cost. See Note 20.

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Defined Benefit Pension and Other Postretirement Plans - Additional Information (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Pension settlement expenses	$ (21)	$ (23)	$ (90)	$ (83)
Pension Benefits | Funded Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Employer contributions			16
Pension Benefits | Unfunded Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, benefits paid			22
Other Benefits
Defined Benefit Plan Disclosure [Line Items]
Pension settlement expenses	0	0	0	0
Other Benefits | Unfunded Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, benefits paid			$ 17

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Acquisitions and Investments (Acquisition of Refinery and Related Logistics and Marketing Assets) (Detail) (USD $)	9 Months Ended		1 Months Ended	3 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Feb. 01, 2013 Galveston Bay Refinery and Related Assets site Pipeline Terminal BPCD MW BPD	Sep. 30, 2014 Galveston Bay Refinery and Related Assets
Business Acquisition [Line Items]
Refinery capacity (in barrels per calendar day)			451,000
Intrastate natural gas liquid pipelines (in number of pipelines)			3
Number of light product terminals (in number of terminals)			4
Number of branded sites (in number of sites)			1,200
Electric cogeneration capacity, megawatt			1,040
Allocation of space on Colonial Pipeline (in barrels per day)			50,000
Cash paid for acquisition			$ 1,490,000,000	$ 180,000,000
Inventories			935,000,000
Total cumulative payment capped over six-year period			700,000,000
Term of payment of maximum earnout provision payable to the company, years			6 years
Contingent consideration payment	$ 172,000,000	$ 0

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Fair Value Measurements (Tables)

9 Months Ended

Sep. 30, 2014

Fair Value Disclosures [Abstract]

Assets and Liabilities Accounted for at Fair Value on Recurring Basis

The following tables present assets and liabilities accounted for at fair value on a recurring basis as of September 30, 2014 and December 31, 2013 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, 2014
	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	$	87	$	—	$	—	$	(55	)	$	32	$	60
Other assets	2		—		—		N/A			2		—
Total assets at fair value	$	89	$	—	$	—	$	(55	)	$	34	$	60
Commodity derivative instruments, liabilities	$	55	$	—	$	—	$	(55	)	$	—	$	—
Contingent consideration, liability(c)	—		—		475		N/A			475		—
Total liabilities at fair value	$	55	$	—	$	475	$	(55	)	$	475	$	—

	December 31, 2013
	Fair Value Hierarchy
(In millions)	Level 1		Level 2		Level 3		Netting and Collateral(a)			Net Carrying Value on Balance Sheet(b)		Collateral Pledged Not Offset
Commodity derivative instruments, assets	$	21	$	—	$	—	$	(21	)	$	—	$	61
Other assets	2		—		—		N/A			2		—
Total assets at fair value	$	23	$	—	$	—	$	(21	)	$	2	$	61
Commodity derivative instruments, liabilities	$	53	$	—	$	—	$	(53	)	$	—	$	—
Contingent consideration, liability(c)	—		—		625		N/A			625		—
Total liabilities at fair value	$	53	$	—	$	625	$	(53	)	$	625	$	—

^(a)  Represents the impact of netting assets, liabilities and cash collateral when a legal right of offset exists. As of September 30, 2014 and December 31, 2013, cash collateral of $0 million and $32 million, respectively, was netted with mark-to-market derivative liabilities.

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

^(c)  Includes $193 million and $159 million classified as current at September 30, 2014 and December 31, 2013, respectively.

Reconciliation of Net Beginning and Ending Balances Recorded for Net Assets and Liabilities Classified as Level 3

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

	Three Months Ended   September 30,						Nine Months Ended   September 30,
(In millions)	2014			2013			2014			2013
Beginning balance	$	647		$	611		$	625		$	—
Contingent consideration agreement	—			—			—			600
Contingent consideration payment	(180		)	—			(180		)	—
Unrealized (gains) losses included in net income	8			(5		)	30			6
Ending balance	$	475		$	606		$	475		$	606

Fair Value Measurements, Nonrecurring

	Nine Months Ended September 30,
	2014				2013
(In millions)	Fair Value		Impairment		Fair Value		Impairment
Property, plant and equipment, net	$	—	$	—	$	1	$	8
Other noncurrent assets	—		11		—		—

Financial Instruments at Fair Value, Excluding Derivative Financial Instruments and Contingent Consideration

The following table summarizes financial instruments on the basis of their nature, characteristics and risk at September 30, 2014 and December 31, 2013, excluding the derivative financial instruments and contingent consideration reported above.

	September 30, 2014				December 31, 2013
(In millions)	Fair Value		Carrying Value		Fair Value		Carrying Value
Financial assets:
Investments	$	23	$	2	$	336	$	14
Other	31		29		31		30
Total financial assets	$	54	$	31	$	367	$	44
Financial liabilities:
Long-term debt(a)	$	6,224	$	5,886	$	3,306	$	3,001
Deferred credits and other liabilities	20		20		21		21
Total financial liabilities	$	6,244	$	5,906	$	3,327	$	3,022

^(a)  Excludes capital leases

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Stock-Based Compensation Plans

9 Months Ended

Sep. 30, 2014

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

Stock-Based Compensation Plans

Stock-Based Compensation Plans

Stock Option Awards

The following table presents a summary of our stock option award activity for the nine months ended September 30, 2014:

	Number of Shares(a)		Weighted Average Exercise Price
Outstanding at December 31, 2013	5,147,837		$	40.08
Granted	446,310		85.02
Exercised	(696,159	)	32.12
Forfeited, canceled or expired	(20,761	)	49.67
Outstanding at September 30, 2014	4,877,227		45.28

^(a)  Includes an immaterial number of stock appreciation rights.

The grant date fair value of stock option awards granted during the nine months ended September 30, 2014 was $25.37 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. Beginning in the first quarter of 2014, the assumption for expected volatility of our stock price was refined to reflect a weighting of 50 percent of MPC’s common stock implied volatility and 50 percent of MPC's common stock historical volatility.

Restricted Stock Awards

The following table presents a summary of restricted stock award activity for the nine months ended September 30, 2014:

	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, 2013	624,122		$	61.11	385,079		$	33.96
Granted	240,882		87.81		19,827		86.79
RS's Vested/RSU's Issued	(324,697	)	55.47		(398	)	60.11
Forfeited	(25,943	)	70.10		(133	)	76.10
Outstanding at September 30, 2014	514,364		76.73		404,375		36.51

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, 2014:

	Number of Units
Outstanding at December 31, 2013	3,822,500
Granted	2,033,700
Settled	—
Canceled	—
Outstanding at September 30, 2014	5,856,200

The performance unit awards granted in 2014 have a grant date fair value of $0.85 per unit, as calculated using a Monte Carlo valuation model.

MPLX Awards

During the nine months ended September 30, 2014, 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.

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Commitments and Contingencies

9 Months Ended

Sep. 30, 2014

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies

We are the subject of, or a party to, a number of pending or threatened legal actions, contingencies and commitments involving a variety of matters, including laws and regulations relating to the environment. Some of these matters are discussed below, including those resulting from the acquisition of Hess' Retail Operations and Related Assets. For matters for which we have not recorded an accrued liability, we are unable to estimate a range of possible loss because the issues involved have not been fully developed through pleadings and discovery. 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, 2014 and December 31, 2013, accrued liabilities for remediation totaled $182 million and $123 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, was $71 million and $51 million at September 30, 2014 and December 31, 2013, respectively.

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

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

We are a defendant in 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—We hold interests in an offshore oil port, LOOP, and a crude oil pipeline system, LOCAP. Both LOOP and LOCAP have secured various project financings with throughput and deficiency agreements. Under the agreements, we are 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 $172 million as of September 30, 2014.

We hold an interest in a refined products pipeline through our investment in Centennial, and have guaranteed 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 $39 million as of September 30, 2014.

We hold an interest in an ethanol production facility through our investment in TAME, and through our participation as a lender under TAME’s revolving credit agreement, have agreed to reimburse the bank for 50 percent of any amounts drawn on a letter of credit that has been issued to secure TAME’s repayment of the tax exempt bonds. The credit agreement expires in 2018. Our maximum potential undiscounted payments under this arrangement were $25 million at September 30, 2014.

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, 2014, 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 $122 million as of September 30, 2014, 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, an indemnity to the co-lenders associated with an equity method investee’s credit agreement, and leases of assets containing general lease indemnities and guaranteed residual values.

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—At September 30, 2014, our contractual commitments to acquire property, plant and equipment and advance funds to equity method investees totaled $1.8 billion, which includes $520 million of contingent consideration associated with the acquisition of the Galveston Bay Refinery and Related Assets, $751 million for contributions to North Dakota Pipeline and $208 million for contributions to the SAX project. See Note 4 for additional information on our investments in North Dakota Pipeline and the SAX project. See Notes 4 and 15 for additional information on the contingent consideration.

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Consolidated Statements of Equity (USD $) In Millions, unless otherwise specified	Total	Common Stock	Treasury Stock	Additional Paid-in Capital	Retained Earnings	Accumulated Other Comprehensive Income (Loss)	Noncontrolling Interests
Beginning balance at Dec. 31, 2012	$ 12,105	$ 4	$ (1,253)	$ 9,527	$ 3,880	$ (464)	$ 411
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,502				1,486		16
Dividends declared	(359)				(359)
Distributions to noncontrolling interests	(15)						(15)
Other comprehensive loss	259					259
Shares repurchased	(2,341)		(2,441)	100
Shares returned - stock based compensation			(9)
Shares issued - stock based compensation				37
Net shares issued — stock based compensation	28
Stock-based compensation	46			45			1
Tax settlement with Marathon Oil Corporation	39			39
Ending balance at Sep. 30, 2013	11,264	4	(3,703)	9,748	5,007	(205)	413
Beginning balance at Dec. 31, 2013	11,332	4	(4,155)	9,768	5,507	(204)	412
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,750				1,726		24
Dividends declared	(386)				(386)
Distributions to noncontrolling interests	(20)						(20)
Other comprehensive loss	(24)					(24)
Shares repurchased	(1,449)		(1,449)	0
Shares returned - stock based compensation			(12)
Shares issued - stock based compensation				21
Net shares issued — stock based compensation	9
Stock-based compensation	45			44			1
Tax settlement with Marathon Oil Corporation	39
Other	9				9
Ending balance at Sep. 30, 2014	$ 11,266	$ 4	$ (5,616)	$ 9,833	$ 6,856	$ (228)	$ 417

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Subsequent Event

9 Months Ended

Sep. 30, 2014

Subsequent Events [Abstract]

Subsequent Events

Subsequent Event

On October 29, 2014, our board of directors authorized the sale of MPC's remaining 31 percent interest in Pipe Line Holdings to MPLX. Upon completion, we will account for the sale as an equity transaction and will not record a gain or loss.

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Goodwill (Details) (USD $) In Millions, unless otherwise specified	9 Months Ended		12 Months Ended
	Sep. 30, 2014		Dec. 31, 2013
Goodwill [Line Items]
Goodwill, beginning balance	$ 938
Goodwill acquired during period	600
Goodwill, disposition	(1)
Goodwill, ending balance	1,537
Refining & Marketing
Goodwill [Line Items]
Goodwill, beginning balance	551
Goodwill acquired during period	0
Goodwill, disposition	(1)
Goodwill, ending balance	550
Speedway
Goodwill [Line Items]
Goodwill, beginning balance	225
Goodwill acquired during period	600	[1]	8
Goodwill, disposition	0
Goodwill, ending balance	825		225
Pipeline Transportation
Goodwill [Line Items]
Goodwill, beginning balance	162
Goodwill acquired during period	0
Goodwill, disposition	0
Goodwill, ending balance	$ 162

[1] See Note 4 for information on the acquisitions.

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Other Items (Tables)

9 Months Ended

Sep. 30, 2014

Other Income and Expenses [Abstract]

Net Interest And Other Financial Income (Costs)

Net interest and other financial income (costs) was:

	Three Months Ended   September 30,						Nine Months Ended   September 30,
(In millions)	2014			2013			2014			2013
Interest:
Interest income	$	2		$	2		$	5		$	7
Interest expense	(56		)	(50		)	(154		)	(147		)
Interest capitalized	7			7			20			15
Total net interest	(47		)	(41		)	(129		)	(125		)
Other:
Net foreign currency gains (losses)	1			(1		)	—			—
Bank service and other fees	(4		)	(5		)	(15		)	(15		)
Total other	(3		)	(6		)	(15		)	(15		)
Net interest and other financial income (costs)	$	(50	)	$	(47	)	$	(144	)	$	(140	)

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MPLX LP (Detail) (USD $) In Millions, unless otherwise specified	0 Months Ended					0 Months Ended			6 Months Ended
	Mar. 01, 2014 MPLX Pipe Line Holdings LP	May 01, 2013 MPLX Pipe Line Holdings LP	Mar. 01, 2014 MPLX LP MPLX Revolver	Mar. 01, 2014 MPLX LP Cash and cash equivalents	Oct. 31, 2012 MPLX LP Butane Cavern	Mar. 01, 2014 MPLX LP MPLX Pipe Line Holdings LP	Sep. 30, 2014 MPLX LP General Partner and Limited Partner	Sep. 30, 2014 MPLX LP General Partner	Apr. 30, 2013 MPLX LP General Partner MPLX Pipe Line Holdings LP
Noncontrolling Interest [Line Items]
MPC's partnership interest in MPLX (in percentage)							73.60%	2.00%
Ownership interest (in percentage)						69.00%			51.00%
MPLX's partnership percent indirect interest in assets					100.00%
Additional interest sold	13.00%	5.00%
Proceeds from sale of ownership interest	$ 310	$ 100
Cash paid for acquisition			$ 270	$ 40

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Segment Information - Additional Information (Detail)	9 Months Ended
	Sep. 30, 2014 Segment
Segment Reporting [Abstract]
Number of reportable segments	3

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Consolidated Statements of Income (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Revenues and other income:
Sales and other operating revenues (including consumer excise taxes)	$ 25,438	$ 26,256	$ 75,567	$ 75,263
Income from equity method investments	29	9	121	16
Net gain on disposal of assets	2	1	14	3
Other income	12	8	57	40
Total revenues and other income	25,481	26,274	75,759	75,322
Costs and expenses:
Cost of revenues (excludes items below)	21,935	23,553	65,571	65,907
Purchases from related parties	112	103	401	254
Consumer excise taxes	1,622	1,631	4,736	4,685
Depreciation and amortization	322	299	967	888
Selling, general and administrative expenses	342	305	1,004	912
Other taxes	86	82	288	259
Total costs and expenses	24,419	25,973	72,967	72,905
Income from operations	1,062	301	2,792	2,417
Net interest and other financial income (costs)	(50)	(47)	(144)	(140)
Income before income taxes	1,012	254	2,648	2,277
Provision for income taxes	333	81	898	775
Net income	679	173	1,750	1,502
Less net income attributable to noncontrolling interests	7	5	24	16
Net income attributable to MPC	$ 672	$ 168	$ 1,726	$ 1,486
Basic:
Net income attributable to MPC per share	$ 2.38	$ 0.54	$ 5.99	$ 4.63
Weighted average shares outstanding (in shares)	282	309	288	321
Diluted:
Net income attributable to MPC per share	$ 2.36	$ 0.54	$ 5.95	$ 4.60
Weighted average shares outstanding (in shares)	284	311	290	323
Dividends paid (in USD per share)	$ 0.50	$ 0.42	$ 1.34	$ 1.12

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Derivatives (Tables)

9 Months Ended

Sep. 30, 2014

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Classification of Fair Values of Derivative Instruments, Excluding Cash Collateral

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, 2014 and December 31, 2013:

	September 30, 2014
(In millions)	Asset		Liability		Balance Sheet Location
Commodity derivatives	$	87	$	55	Other current assets
	December 31, 2013
(In millions)	Asset		Liability		Balance Sheet Location
Commodity derivatives	$	21	$	53	Other current assets

Open Commodity Derivative Contracts

The table below summarizes open commodity derivative contracts as of September 30, 2014.

	Position	Total Barrels (In thousands)
Crude oil(a)
Exchange-traded	Long	10,346
Exchange-traded	Short	(23,186	)
Refined Products(b)
Exchange-traded	Long	1,695
Exchange-traded	Short	(3,281	)

^(a)  96 percent of these contracts expire in the fourth quarter of 2014.

^(b)  100 percent of these contracts expire in the fourth quarter of 2014.

Effect of Commodity Derivative Instruments in Statements of Income

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

	Gain (Loss)					Gain (Loss)
(In millions)	Three Months Ended September 30,					Nine Months Ended September 30,
Income Statement Location	2014		2013			2014			2013
Sales and other operating revenues	$	10	$	9		$	18		$	13
Cost of revenues	145		(170		)	(30		)	(179		)
Total	$	155	$	(161	)	$	(12	)	$	(166	)

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Supplemental Cash Flow Information - Summary of Supplemental Cash Flow Information (Detail) (USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013
Net cash provided by operating activities included:
Interest paid (net of amounts capitalized)	$ 162	$ 166
Net income taxes paid to taxing authorities	969	1,027
Non-cash investing and financing activities:
Capital lease obligations increase	0	61
Property, plant and equipment sold	4	43
Property, plant and equipment acquired	4	0
Acquisition:
Contingent consideration	0	600	[1]
Payable to seller	$ 0	$ 6	[1]

[1] Acquisition-date fair value of non-cash consideration associated with the Galveston Bay Refinery and Related Assets acquisition.

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Consolidated Balance Sheets (Parenthetical) (USD $) In Millions, except Share data, unless otherwise specified	Sep. 30, 2014	Dec. 31, 2013
Statement of Financial Position [Abstract]
Allowance for doubtful accounts	$ 10	$ 9
Preferred stock:
Shares issued	0	0
Shares outstanding	0	0
Par value	$ 0.01
Shares authorized	30,000,000
Common stock:
Shares issued	363,000,000	362,000,000
Par value	$ 0.01
Shares authorized	1,000,000,000
Treasury stock	(82,000,000)	(65,000,000)

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Debt Term Loan (Details) (MPC Term Loan, USD $) In Millions, unless otherwise specified	0 Months Ended	3 Months Ended
	Aug. 26, 2014	Sep. 30, 2014	Aug. 26, 2014
Debt Instrument [Line Items]
Maximum borrowing capacity			$ 700
Debt instrument, term	5 years
Description of variable rate basis	Adjusted LIBO Rate (as defined in the Term Loan Agreement)
Interest rate during period		1.30%
Maximum
Debt Instrument [Line Items]
Ratio of indebtedness to net capital	0.65		0.65
London Interbank Offered Rate (LIBOR) | Minimum
Debt Instrument [Line Items]
Basis spread on variable rate	0.875%
London Interbank Offered Rate (LIBOR) | Maximum
Debt Instrument [Line Items]
Basis spread on variable rate	1.75%
Base Rate | Minimum
Debt Instrument [Line Items]
Basis spread on variable rate	0.00%
Base Rate | Maximum
Debt Instrument [Line Items]
Basis spread on variable rate	0.75%

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Acquisitions and Investments (Acquisition of Biodiesel Facility) (Details) (Felda Iffco Sdn Bhd [Member], USD $) In Millions, unless otherwise specified	1 Months Ended
	Apr. 30, 2014	Apr. 01, 2014 gallons_per_year
Felda Iffco Sdn Bhd [Member]
Business Acquisition [Line Items]
Cash paid for acquisition	$ 40
Plant capacity volume		60,000,000

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Defined Benefit Pension and Other Postretirement Plans - Components of Net Periodic Benefit Costs (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Pension Benefits
Components of net periodic benefit cost:
Service cost	$ 24	$ 24	$ 67	$ 70
Interest cost	18	19	56	55
Expected return on plan assets	(27)	(28)	(81)	(81)
Amortization – prior service credit	(12)	(12)	(35)	(34)
Amortization – actuarial loss	12	14	38	53
Amortization - settlement loss	21	23	90	83
Net periodic benefit cost	36	40	135	146
Other Benefits
Components of net periodic benefit cost:
Service cost	7	7	20	19
Interest cost	7	6	24	19
Expected return on plan assets	0	0	0	0
Amortization – prior service credit	(1)	(1)	(3)	(3)
Amortization – actuarial loss	1	1	2	2
Amortization - settlement loss	0	0	0	0
Net periodic benefit cost	$ 14	$ 13	$ 43	$ 37

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Acquisitions and Investments (Tables)

9 Months Ended

Sep. 30, 2014

Business Combinations [Abstract]

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

The estimated fair values of assets acquired and liabilities assumed at the acquisition date, pending the completion of an independent appraisal and other evaluations, are as follows:

(In millions)
Cash and cash equivalents	$	39
Receivables	132
Inventories	178
Other current assets	5
Property, plant and equipment, net	2,062
Other noncurrent assets	103
Total assets acquired	2,519
Accounts payable	77
Payroll and benefits payable	4
Consumer excise taxes payable	80
Other current liabilities	10
Defined benefit postretirement plan obligations	2
Deferred credits and other liabilities	122
Total liabilities assumed	295
Net assets acquired excluding goodwill	2,224
Goodwill	600
Net assets acquired	$	2,824

Business Acquisition, Pro Forma Information [Table Text Block]

The following unaudited pro forma financial information presents consolidated results assuming the Galveston Bay Refinery and Related Assets acquisition occurred on January 1, 2012 and Hess' Retail Operations and Related Assets acquisition occurred on January 1, 2013. The pro forma financial information does not give effect to potential synergies that could result from the acquisitions and is not necessarily indicative of the results of future operations.

	Three Months Ended   September 30,				Nine Months Ended   September 30,
(In millions, except per share data)	2014		2013		2014		2013
Sales and other operating revenues (including consumer excise taxes)	$	28,284	$	29,317	$	84,232	$	86,386
Net income attributable to MPC	698		170		1,748		1,516
Net income attributable to MPC per share - basic	$	2.48	$	0.55	$	6.07	$	4.72
Net income attributable to MPC per share - diluted	2.46		0.55		6.03		4.69

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Related Party Transactions - Purchases from Related Parties (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Related Party Transaction [Line Items]
Purchases from related parties	$ 112	$ 103	$ 401	$ 254
Centennial
Related Party Transaction [Line Items]
Purchases from related parties	0	4	7	4
Explorer
Related Party Transaction [Line Items]
Purchases from related parties	10	0	32	0
LOCAP
Related Party Transaction [Line Items]
Purchases from related parties	6	5	16	13
LOOP
Related Party Transaction [Line Items]
Purchases from related parties	12	11	77	32
TAAE
Related Party Transaction [Line Items]
Purchases from related parties	19	8	61	8
TACE
Related Party Transaction [Line Items]
Purchases from related parties	33	42	90	92
TAME
Related Party Transaction [Line Items]
Purchases from related parties	29	31	111	98
Other equity method investees
Related Party Transaction [Line Items]
Purchases from related parties	$ 3	$ 2	$ 7	$ 7

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Property, Plant and Equipment

9 Months Ended

Sep. 30, 2014

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment

Property, Plant and Equipment

(In millions)	September 30, 2014		December 31, 2013
Refining & Marketing	$	17,646	$	16,982
Speedway	4,477		2,344
Pipeline Transportation	1,995		1,921
Corporate and Other	594		546
Total	24,712		21,793
Less accumulated depreciation	8,713		7,872
Property, plant and equipment, net	$	15,999	$	13,921

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Related Party Transactions (Tables)

9 Months Ended

Sep. 30, 2014

Related Party Transactions [Abstract]

Sales To Related Parties

Sales to related parties, which are included in sales and other operating revenues (including consumer excise taxes) on the consolidated statements of income, were as follows:

	Three Months Ended   September 30,				Nine Months Ended   September 30,
(In millions)	2014		2013		2014		2013
Other equity method investees	$	2	$	3	$	6	$	7

Purchases From Related Parties

Purchases from related parties were as follows:

	Three Months Ended   September 30,				Nine Months Ended   September 30,
(In millions)	2014		2013		2014		2013
Centennial	$	—	$	4	$	7	$	4
Explorer	10		—		32		—
LOCAP	6		5		16		13
LOOP	12		11		77		32
TAAE	19		8		61		8
TACE	33		42		90		92
TAME	29		31		111		98
Other equity method investees	3		2		7		7
Total	$	112	$	103	$	401	$	254

Receivables From Related Parties

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

(In millions)	September 30, 2014		December 31, 2013
Centennial	$	2	$	1
TAME	2		1
Total	$	4	$	2

Payables To Related Parties

Payables to related parties, which are included in accounts payable on the consolidated balance sheets, were as follows:

(In millions)	September 30, 2014		December 31, 2013
Explorer	$	5	$	—
LOCAP	2		2
LOOP	4		3
TAAE	1		2
TACE	2		4
TAME	2		5
Other equity method investees	1		—
Total	$	17	$	16

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Accumulated Other Comprehensive Loss - Changes in Accumulated Other Comprehensive Loss by Component (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014		Sep. 30, 2013
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance			$ (204)		$ (464)
Other comprehensive income (loss) before reclassifications			(82)		177
Amounts reclassified from accumulated other comprehensive loss:
Amortization - prior service credit			(38)	[1]	(37)	[1]
Amortization of actuarial loss			40	[1]	55	[1]
Other Comprehensive Income Loss Reclassification Adjustment From Aoci Pension And Other Postretirement Benefit Plans For Settlement Gain Loss Before Tax			90	[1]	83	[1]
Tax effect			(34)		(19)
Other comprehensive income (loss)	(10)	49	(24)		259
Ending balance	(228)	(205)	(228)		(205)
Accumulated Defined Benefit Plans Adjustment | Pension Benefits
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance			(161)		(432)
Other comprehensive income (loss) before reclassifications			(88)		172
Amounts reclassified from accumulated other comprehensive loss:
Amortization - prior service credit			(35)	[1]	(34)	[1]
Amortization of actuarial loss			38	[1]	53	[1]
Other Comprehensive Income Loss Reclassification Adjustment From Aoci Pension And Other Postretirement Benefit Plans For Settlement Gain Loss Before Tax			90	[1]	83	[1]
Tax effect			(35)		(19)
Other comprehensive income (loss)			(30)		255
Ending balance	(191)	(177)	(191)		(177)
Accumulated Defined Benefit Plans Adjustment | Other Benefits
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance			(50)		(36)
Other comprehensive income (loss) before reclassifications			8		3
Amounts reclassified from accumulated other comprehensive loss:
Amortization - prior service credit			(3)	[1]	(3)	[1]
Amortization of actuarial loss			2	[1]	2	[1]
Other Comprehensive Income Loss Reclassification Adjustment From Aoci Pension And Other Postretirement Benefit Plans For Settlement Gain Loss Before Tax			0		0
Tax effect			1		0
Other comprehensive income (loss)			8		2
Ending balance	(42)	(34)	(42)		(34)
Gain on Cash Flow Hedge
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance			4		4
Other comprehensive income (loss) before reclassifications			0		0
Amounts reclassified from accumulated other comprehensive loss:
Tax effect			0		0
Other comprehensive income (loss)			0		0
Ending balance	4	4	4		4
Workers Compensation
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance			3		0
Other comprehensive income (loss) before reclassifications			(2)		2
Amounts reclassified from accumulated other comprehensive loss:
Tax effect			0		0
Other comprehensive income (loss)			(2)		2
Ending balance	$ 1	$ 2	$ 1		$ 2

[1] These accumulated other comprehensive loss components are included in the computation of net periodic benefit cost. See Note 20.

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Fair Value Measurements

9 Months Ended

Sep. 30, 2014

Fair Value Disclosures [Abstract]

Fair Value Measurements

Fair Value Measurements

Fair Values—Recurring

The following tables present assets and liabilities accounted for at fair value on a recurring basis as of September 30, 2014 and December 31, 2013 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, 2014
	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	$	87	$	—	$	—	$	(55	)	$	32	$	60
Other assets	2		—		—		N/A			2		—
Total assets at fair value	$	89	$	—	$	—	$	(55	)	$	34	$	60
Commodity derivative instruments, liabilities	$	55	$	—	$	—	$	(55	)	$	—	$	—
Contingent consideration, liability(c)	—		—		475		N/A			475		—
Total liabilities at fair value	$	55	$	—	$	475	$	(55	)	$	475	$	—

	December 31, 2013
	Fair Value Hierarchy
(In millions)	Level 1		Level 2		Level 3		Netting and Collateral(a)			Net Carrying Value on Balance Sheet(b)		Collateral Pledged Not Offset
Commodity derivative instruments, assets	$	21	$	—	$	—	$	(21	)	$	—	$	61
Other assets	2		—		—		N/A			2		—
Total assets at fair value	$	23	$	—	$	—	$	(21	)	$	2	$	61
Commodity derivative instruments, liabilities	$	53	$	—	$	—	$	(53	)	$	—	$	—
Contingent consideration, liability(c)	—		—		625		N/A			625		—
Total liabilities at fair value	$	53	$	—	$	625	$	(53	)	$	625	$	—

^(a)  Represents the impact of netting assets, liabilities and cash collateral when a legal right of offset exists. As of September 30, 2014 and December 31, 2013, cash collateral of $0 million and $32 million, respectively, was netted with mark-to-market derivative liabilities.

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

^(c)  Includes $193 million and $159 million classified as current at September 30, 2014 and December 31, 2013, respectively.

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

The contingent consideration represents the fair value as of September 30, 2014 of the amount we expect to pay to BP related to the earnout provision for the Galveston Bay Refinery and Related Assets acquisition. See Note 4. The fair value of the contingent consideration was estimated using an income approach and is therefore a Level 3 liability. The amount of cash to be paid under the arrangement is based on both a market-based crack spread and refinery throughput volumes for the months during which the contract applies, as well as established thresholds that cap the annual and total payment. The earnout payment cannot exceed $200 million per year for the first three years of the arrangement or $250 million per year for the last three years of the arrangement, with the total cumulative payment capped at $700 million over the six-year period. Any excess or shortfall from the annual cap for a current year’s earnout calculation will not affect subsequent years’ calculations. The fair value calculation used significant unobservable inputs, including (1) an estimate of refinery throughput volumes; (2) a range of internal and external crack spread forecasts from $14 to $15 per barrel; and (3) a range of risk-adjusted discount rates from five percent to 10 percent. An increase or decrease in crack spread forecasts or refinery throughput volume expectations may result in a corresponding increase or decrease in the fair value. Increases to the fair value as a result of increasing forecasts for both of these unobservable inputs, however, are limited as the earnout payment is subject to annual caps. An increase or decrease in the discount rate may result in a decrease or increase to the fair value, respectively. The fair value of the contingent consideration is reassessed each quarter, with changes in fair value recorded in cost of revenues.

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)	2014			2013			2014			2013
Beginning balance	$	647		$	611		$	625		$	—
Contingent consideration agreement	—			—			—			600
Contingent consideration payment	(180		)	—			(180		)	—
Unrealized (gains) losses included in net income	8			(5		)	30			6
Ending balance	$	475		$	606		$	475		$	606

We did not hold any Level 3 derivative instruments during the three and nine months ended September 30, 2014 and 2013. See Note 16 for the income statement impacts of our derivative instruments.

Fair Values – Nonrecurring

The following table shows the values of assets, by major category, measured at fair value on a nonrecurring basis in periods subsequent to their initial recognition.

	Nine Months Ended September 30,
	2014				2013
(In millions)	Fair Value		Impairment		Fair Value		Impairment
Property, plant and equipment, net	$	—	$	—	$	1	$	8
Other noncurrent assets	—		11		—		—

Based on the financial and operational status of a company in which we have an interest, we fully impaired our $11 million investment in that company during the second quarter of 2014. Our investment in this company was accounted for using the cost method and was included in our Refining & Marketing segment. The impairment is included in other income on the consolidated statements of income. The fair value of our investment in this cost company was measured using an income approach. This measurement is classified as Level 3.

Due to changing market conditions, we assessed one of our light products terminals for impairment. The terminal is operated by our Refining & Marketing segment. We recorded an impairment charge of $8 million for this terminal in 2013. The impairment is included in depreciation and amortization on the consolidated statements of income. The fair value of the terminal was measured using a market approach based on comparable area property values, which are Level 3 inputs.

Fair Values – Reported

The following table summarizes financial instruments on the basis of their nature, characteristics and risk at September 30, 2014 and December 31, 2013, excluding the derivative financial instruments and contingent consideration reported above.

	September 30, 2014				December 31, 2013
(In millions)	Fair Value		Carrying Value		Fair Value		Carrying Value
Financial assets:
Investments	$	23	$	2	$	336	$	14
Other	31		29		31		30
Total financial assets	$	54	$	31	$	367	$	44
Financial liabilities:
Long-term debt(a)	$	6,224	$	5,886	$	3,306	$	3,001
Deferred credits and other liabilities	20		20		21		21
Total financial liabilities	$	6,244	$	5,906	$	3,327	$	3,022

^(a)  Excludes capital leases

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 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 from major financial institutions and a third-party service for our debt. 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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Income Per Common Share - Summary of Earnings Per Common Share (Detail) (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Basic earnings per share:
Net income attributable to MPC	$ 672	$ 168	$ 1,726	$ 1,486
Income allocated to participating securities, basic	1	0	3	2
Income available to common stockholders - basic	671	168	1,723	1,484
Weighted average common shares outstanding (in shares)	282	309	288	321
Basic (in USD per share)	$ 2.38	$ 0.54	$ 5.99	$ 4.63
Diluted earnings per share:
Net income attributable to MPC	672	168	1,726	1,486
Income allocated to participating securities, diluted	1	0	3	2
Income available to common stockholders - diluted	$ 671	$ 168	$ 1,723	$ 1,484
Weighted average common shares outstanding (in shares)	282	309	288	321
Effect of dilutive securities (in shares)	2	2	2	2
Weighted average common shares, including dilutive effect (in shares)	284	311	290	323
Diluted (in USD per share)	$ 2.36	$ 0.54	$ 5.95	$ 4.60

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Supplementary Statistics - Operating Statistics (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended				9 Months Ended
	Sep. 30, 2014 BPD		Sep. 30, 2013 BPD		Sep. 30, 2014 BPD		Sep. 30, 2013 BPD
Operating Statistics [Line Items ]
MPC Consolidated Refined Product Sales Volumes (thousands of barrels per day)	2,155,000	[1],[2]	2,155,000	[1],[2]	2,092,000	[1],[2]	2,063,000	[1],[2]
Refining & Marketing
Refining & Marketing Operating Statistics
Refining & Marketing refined product sales volume (thousands of barrels per day)	2,140,000	[1],[3]	2,148,000	[1],[3]	2,079,000	[1],[4]	2,052,000	[1],[4]
Refining & Marketing gross margin (dollars per barrel)	14.55	[1],[5]	9.25	[1],[5]	15.02	[1],[5]	12.42	[1],[5]
Crude oil capacity utilization percent	100.00%	[1],[6]	99.00%	[1],[6]	94.00%	[1],[6]	97.00%	[1],[6]
Refinery throughputs (thousands of barrels per day)	1,880,000	[1],[7]	1,877,000	[1],[7]	1,788,000	[1],[7]	1,805,000	[1],[7]
Sour crude oil throughput percent	52.00%	[1]	53.00%	[1]	52.00%	[1]	53.00%	[1]
WTI-priced crude oil throughput percent	16.00%	[1]	21.00%	[1]	18.00%	[1]	22.00%	[1]
Refined product yields (thousands of barrels per day)	1,915,000	[1],[7]	1,915,000	[1],[7]	1,820,000	[1],[7]	1,839,000	[1],[7]
Inter-refinery transfers	33,000		36,000		45,000		34,000
Refinery direct operating costs (dollars per barrel):
Planned turnaround and major maintenance	1.52	[1],[8]	0.96	[1],[8]	1.82	[1],[8]	0.94	[1],[8]
Depreciation and amortization	1.35	[1],[8]	1.27	[1],[8]	1.43	[1],[8]	1.32	[1],[8]
Other manufacturing	4.33	[1],[8],[9]	4.10	[1],[8],[9]	4.96	[1],[8],[9]	4.00	[1],[8],[9]
Total	7.20	[1],[8]	6.33	[1],[8]	8.21	[1],[8]	6.26	[1],[8]
Refining & Marketing | Crude oil refined
Refining & Marketing Operating Statistics
Refinery throughputs (thousands of barrels per day)	1,720,000	[1],[7]	1,682,000	[1],[7]	1,616,000	[1],[7]	1,603,000	[1],[7]
Refining & Marketing | Other charge and blendstocks
Refining & Marketing Operating Statistics
Refinery throughputs (thousands of barrels per day)	160,000	[1],[7]	195,000	[1],[7]	172,000	[1],[7]	202,000	[1],[7]
Refining & Marketing | Gasoline
Refining & Marketing Operating Statistics
Refined product yields (thousands of barrels per day)	864,000	[1],[7]	938,000	[1],[7]	851,000	[1],[7]	917,000	[1],[7]
Refining & Marketing | Distillates
Refining & Marketing Operating Statistics
Refined product yields (thousands of barrels per day)	598,000	[1],[7]	578,000	[1],[7]	574,000	[1],[7]	570,000	[1],[7]
Refining & Marketing | Propane
Refining & Marketing Operating Statistics
Refined product yields (thousands of barrels per day)	36,000	[1],[7]	39,000	[1],[7]	36,000	[1],[7]	37,000	[1],[7]
Refining & Marketing | Feedstocks and special products
Refining & Marketing Operating Statistics
Refined product yields (thousands of barrels per day)	330,000	[1],[7]	259,000	[1],[7]	280,000	[1],[7]	227,000	[1],[7]
Refining & Marketing | Heavy fuel oil
Refining & Marketing Operating Statistics
Refined product yields (thousands of barrels per day)	24,000	[1],[7]	31,000	[1],[7]	27,000	[1],[7]	31,000	[1],[7]
Refining & Marketing | Asphalt
Refining & Marketing Operating Statistics
Refined product yields (thousands of barrels per day)	63,000	[1],[7]	70,000	[1],[7]	52,000	[1],[7]	57,000	[1],[7]
Refining & Marketing | Gulf Coast:
Refining & Marketing Operating Statistics
Refinery throughputs (thousands of barrels per day)	1,230,000	[1],[10]	1,210,000	[1],[10]	1,163,000	[1],[10]	1,152,000	[1],[10]
Sour crude oil throughput percent	66.00%	[1]	64.00%	[1]	64.00%	[1]	65.00%	[1]
WTI-priced crude oil throughput percent	1.00%	[1]	7.00%	[1]	2.00%	[1]	8.00%	[1]
Refined product yields (thousands of barrels per day)	1,256,000	[1],[10]	1,240,000	[1],[10]	1,189,000	[1],[10]	1,179,000	[1],[10]
Refinery direct operating costs (dollars per barrel):
Planned turnaround and major maintenance	1.15	[1],[8]	0.86	[1],[8]	1.77	[1],[8]	0.77	[1],[8]
Depreciation and amortization	1.10	[1],[8]	1.01	[1],[8]	1.16	[1],[8]	1.04	[1],[8]
Other manufacturing	4.11	[1],[8],[9]	4.08	[1],[8],[9]	4.86	[1],[8],[9]	3.82	[1],[8],[9]
Total	6.36	[1],[8]	5.95	[1],[8]	7.79	[1],[8]	5.63	[1],[8]
Refining & Marketing | Gulf Coast: | Crude oil refined
Refining & Marketing Operating Statistics
Refinery throughputs (thousands of barrels per day)	1,075,000	[1],[10]	1,035,000	[1],[10]	989,000	[1],[10]	971,000	[1],[10]
Refining & Marketing | Gulf Coast: | Other charge and blendstocks
Refining & Marketing Operating Statistics
Refinery throughputs (thousands of barrels per day)	155,000	[1],[10]	175,000	[1],[10]	174,000	[1],[10]	181,000	[1],[10]
Refining & Marketing | Gulf Coast: | Gasoline
Refining & Marketing Operating Statistics
Refined product yields (thousands of barrels per day)	505,000	[1],[10]	561,000	[1],[10]	498,000	[1],[10]	545,000	[1],[10]
Refining & Marketing | Gulf Coast: | Distillates
Refining & Marketing Operating Statistics
Refined product yields (thousands of barrels per day)	389,000	[1],[10]	370,000	[1],[10]	366,000	[1],[10]	363,000	[1],[10]
Refining & Marketing | Gulf Coast: | Propane
Refining & Marketing Operating Statistics
Refined product yields (thousands of barrels per day)	25,000	[1],[10]	24,000	[1],[10]	24,000	[1],[10]	23,000	[1],[10]
Refining & Marketing | Gulf Coast: | Feedstocks and special products
Refining & Marketing Operating Statistics
Refined product yields (thousands of barrels per day)	310,000	[1],[10]	241,000	[1],[10]	275,000	[1],[10]	214,000	[1],[10]
Refining & Marketing | Gulf Coast: | Heavy fuel oil
Refining & Marketing Operating Statistics
Refined product yields (thousands of barrels per day)	8,000	[1],[10]	21,000	[1],[10]	13,000	[1],[10]	20,000	[1],[10]
Refining & Marketing | Gulf Coast: | Asphalt
Refining & Marketing Operating Statistics
Refined product yields (thousands of barrels per day)	19,000	[1],[10]	23,000	[1],[10]	13,000	[1],[10]	14,000	[1],[10]
Refining & Marketing | Midwest:
Refining & Marketing Operating Statistics
Refinery throughputs (thousands of barrels per day)	683,000	[10]	703,000	[10]	670,000	[10]	687,000	[10]
Sour crude oil throughput percent	30.00%		35.00%		33.00%		35.00%
WTI-priced crude oil throughput percent	41.00%		43.00%		42.00%		43.00%
Refined product yields (thousands of barrels per day)	692,000	[10]	711,000	[10]	676,000	[10]	694,000	[10]
Refinery direct operating costs (dollars per barrel):
Planned turnaround and major maintenance	2.10	[8]	1.08	[8]	1.78	[1],[8]	1.17	[1],[8]
Depreciation and amortization	1.75	[8]	1.66	[8]	1.80	[8]	1.72	[8]
Other manufacturing	4.51	[8],[9]	3.91	[8],[9]	4.82	[1],[8],[9]	4.10	[1],[8],[9]
Total	8.36	[8]	6.65	[8]	8.40	[8]	6.99	[8]
Refining & Marketing | Midwest: | Crude oil refined
Refining & Marketing Operating Statistics
Refinery throughputs (thousands of barrels per day)	645,000	[10]	647,000	[10]	627,000	[10]	632,000	[10]
Refining & Marketing | Midwest: | Other charge and blendstocks
Refining & Marketing Operating Statistics
Refinery throughputs (thousands of barrels per day)	38,000	[10]	56,000	[10]	43,000	[10]	55,000	[10]
Refining & Marketing | Midwest: | Gasoline
Refining & Marketing Operating Statistics
Refined product yields (thousands of barrels per day)	359,000	[10]	377,000	[10]	353,000	[10]	373,000	[10]
Refining & Marketing | Midwest: | Distillates
Refining & Marketing Operating Statistics
Refined product yields (thousands of barrels per day)	209,000	[10]	208,000	[10]	208,000	[10]	207,000	[10]
Refining & Marketing | Midwest: | Propane
Refining & Marketing Operating Statistics
Refined product yields (thousands of barrels per day)	13,000	[10]	15,000	[10]	13,000	[10]	14,000	[10]
Refining & Marketing | Midwest: | Feedstocks and special products
Refining & Marketing Operating Statistics
Refined product yields (thousands of barrels per day)	51,000	[10]	54,000	[10]	49,000	[10]	46,000	[10]
Refining & Marketing | Midwest: | Heavy fuel oil
Refining & Marketing Operating Statistics
Refined product yields (thousands of barrels per day)	16,000	[10]	10,000	[10]	14,000	[10]	11,000	[10]
Refining & Marketing | Midwest: | Asphalt
Refining & Marketing Operating Statistics
Refined product yields (thousands of barrels per day)	44,000	[10]	47,000	[10]	39,000	[10]	43,000	[10]
Speedway
Speedway Operating Statistics
Convenience stores at period-end(j)	2,744	[11]	1,471		2,744	[11]	1,471
Gasoline and distillate sales (millions of gallons)	842,000,000		803,000,000		2,421,000,000		2,329,000,000
Gasoline and distillate gross margin (dollars per gallon)	0.1596	[12]	0.1404	[13]	0.1351	[12]	0.1483	[12]
Merchandise sales (in millions)	$ 870		$ 843		$ 2,422		$ 2,360
Merchandise gross margin (in millions)	$ 235		$ 224		$ 651		$ 620
Merchandise margin percent	27.00%		26.50%		26.90%		26.30%
Same store gasoline sales volume (period over period) percentage	(0.80%)		1.00%		(1.00%)		0.60%
Merchandise sales excluding cigarettes (period over period) percentage	4.80%	[13]	5.60%	[13]	4.80%	[13]	3.80%	[13]
Speedway | Hess' Retail Operations and Related Assets
Speedway Operating Statistics
Convenience stores at period-end(j)	1,245	[11]			1,245	[11]
Pipeline Transportation
Pipeline Transportation Operating Statistics
Pipeline throughputs (thousands of barrels per day)	2,104,000	[14]	2,230,000	[14]	2,073,000	[14]	2,238,000	[14]
Pipeline Transportation | Crude oil pipelines
Pipeline Transportation Operating Statistics
Pipeline throughputs (thousands of barrels per day)	1,265,000	[14]	1,317,000	[14]	1,230,000	[14]	1,308,000	[14]
Pipeline Transportation | Refined products pipelines
Pipeline Transportation Operating Statistics
Pipeline throughputs (thousands of barrels per day)	839,000	[14]	913,000	[14]	843,000	[14]	930,000	[14]

[1] Includes the impact of the Galveston Bay Refinery and Related Assets beginning on the February 1, 2013 acquisition date.

[2] Total average daily volumes of refined product sales to wholesale, branded and retail (Speedway segment) customers.

[3] Includes intersegment sales.

[4] The nine months ended September 30, 2013 includes $1.36 billion for the acquisition of the Galveston Bay Refinery and Related Assets. See Note 4 to the unaudited consolidated financial statements.

[5] Sales revenue less cost of refinery inputs and purchased products, divided by total refinery throughputs.

[6] Based on calendar day capacity, which is an annual average that includes downtime for planned maintenance and other normal operating activities.

[7] Excludes inter-refinery volumes of 33 mbpd and 36 mbpd for the three months ended September 30, 2014 and 2013, respectively, and 45 mbpd and 34 mbpd for the nine months ended September 30, 2014 and 2013, respectively.

[8] Per barrel of total refinery throughputs.

[9] Includes utilities, labor, routine maintenance and other operating costs.

[10] Includes inter-refinery transfer volumes.

[11] Includes 1,245 stores acquired on September 30, 2014 through the acquisition of Hess' Retail Operations and Related Assets. Segment results for the period prior to the acquisition do not include results from these operations.

[12] 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.

[13] Excludes cigarettes.

[14] On owned common-carrier pipelines, excluding equity method investments.

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Consolidated Statements of Cash Flows (USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013
Operating activities:
Net income	$ 1,750	$ 1,502
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	967	888
Pension and other postretirement benefits, net	123	3
Deferred income taxes	(126)	22
Net gain on disposal of assets	(14)	(3)
Equity method investments, net	(39)	(4)
Changes in the fair value of derivative instruments	(35)	(54)
Changes in:
Current receivables	424	(974)
Inventories	(731)	(1,330)
Current accounts payable and accrued liabilities	318	2,028
All other, net	85	(28)
Net cash provided by operating activities	2,722	2,050
Investing activities:
Additions to property, plant and equipment	(952)	(733)
Acquisitions, net of cash acquired	(2,831)	(1,515)
Disposal of assets	19	12
Investments—acquisitions, loans and contributions	(341)	(113)
Investments—redemptions and repayments	3	76
All other, net	78	22
Net cash used in investing activities	(4,024)	(2,251)
Financing activities:
Long-term debt – borrowings	2,903	0
Long-term debt – repayments	(32)	(16)
Debt issuance costs	(19)	(2)
Issuance of common stock	21	37
Common stock repurchased	(1,449)	(2,341)
Dividends paid	(386)	(358)
Distributions to noncontrolling interests	(20)	(15)
Tax settlement with Marathon Oil Corporation	0	39
Contingent consideration payment	(172)	0
All other, net	18	15
Net cash provided by (used in) financing activities	864	(2,641)
Net decrease in cash and cash equivalents	(438)	(2,842)
Cash and cash equivalents at beginning of period	2,292	4,860
Cash and cash equivalents at end of period	$ 1,854	$ 2,018

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Consolidated Statements of Comprehensive Income (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Statement of Comprehensive Income [Abstract]
Net income	$ 679	$ 173	$ 1,750	$ 1,502
Defined benefit postretirement and post-employment plans:
Actuarial changes, net of tax of ($1), $34, $0 and $169	(2)	57	0	282
Prior service costs, net of tax of ($5), ($5), ($14) and ($14)	(8)	(8)	(24)	(23)
Other comprehensive income (loss)	(10)	49	(24)	259
Comprehensive income	669	222	1,726	1,761
Less comprehensive income attributable to noncontrolling interests	7	5	24	16
Comprehensive income attributable to MPC	$ 662	$ 217	$ 1,702	$ 1,745

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Equity

9 Months Ended

Sep. 30, 2014

Equity [Abstract]

Equity

Equity

On July 30, 2014, our board of directors approved an additional $2.0 billion share repurchase authorization expiring in July 2016. As of September 30, 2014, our board of directors had approved $8.0 billion in total share repurchase authorizations since January 1, 2012 and we have repurchased a total of $5.59 billion of our common stock, leaving $2.41 billion available for repurchases. Under these authorizations, we have acquired 82 million shares at an average cost per share of $68.41.

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

Total share repurchases were as follows for the three and nine months ended September 30, 2014 and 2013:

	Three Months Ended   September 30,				Nine Months Ended   September 30,
(In millions, except per share data)	2014		2013		2014		2013
Number of shares repurchased(a)	4		14		17		31
Cash paid for shares repurchased	$	301	$	1,028	$	1,449	$	2,341
Effective average cost per delivered share	$	85.15	$	70.73	$	87.25	$	76.01

^(a)  The nine months ended September 30, 2013 includes one million shares received under the November 2012 accelerated share repurchase program, which were paid for in 2012.

At September 30, 2014, we had agreements to acquire additional common shares for $9 million, which were settled in early October 2014.

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Stock-Based Compensation Plans - Summary of Restricted Stock Award Activity (Detail) (USD $)	9 Months Ended
	Sep. 30, 2014
Restricted Stock
Number of Shares
Outstanding, beginning balance	624,122
Granted	240,882
RS's Vested/RSU's Issued	(324,697)
Forfeited	(25,943)
Outstanding, ending balance	514,364
Weighted Average Grant Date Fair Value
Outstanding, beginning balance (in USD per share)	$ 61.11
Granted (in USD per share)	$ 87.81
RS's Vested/RSU's Issued (in USD per share)	$ 55.47
Forfeited (in USD per share)	$ 70.10
Outstanding, ending balance (in USD per share)	$ 76.73
Restricted Stock Units
Number of Shares
Outstanding, beginning balance	385,079
Granted	19,827
RS's Vested/RSU's Issued	(398)
Forfeited	(133)
Outstanding, ending balance	404,375
Weighted Average Grant Date Fair Value
Outstanding, beginning balance (in USD per share)	$ 33.96
Granted (in USD per share)	$ 86.79
RS's Vested/RSU's Issued (in USD per share)	$ 60.11
Forfeited (in USD per share)	$ 76.10
Outstanding, ending balance (in USD per share)	$ 36.51

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Debt - Additional Information (Detail) (USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2014	Dec. 31, 2013
MPLX Revolver | MPLX Operations LLC | Letter of Credit
Line of Credit Facility [Line Items]
Borrowings outstanding	$ 0
Line of Credit | MPC Revolver
Line of Credit Facility [Line Items]
Long-term debt, gross	0	0
Line of credit facility, expiration date	Sep. 14, 2017
Line of Credit | MPLX Revolver | MPLX Operations LLC
Line of Credit Facility [Line Items]
Long-term debt, gross	255	0
Line of credit facility, borrowings during period	270
Interest rate during period	1.50%
Line of credit facility, repayments during period	15
Borrowings outstanding	255
Remaining borrowing capacity	$ 245
Remaining borrowing capacity, percentage	49.00%
Line of credit facility, expiration date	Oct. 31, 2017

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Derivatives - Effect of Commodity Derivative Instruments in Statements of Income (Detail) (Commodity derivatives, USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss)	$ 155	$ (161)	$ (12)	$ (166)
Sales and other operating revenues
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss)	10	9	18	13
Cost of revenues
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss)	$ 145	$ (170)	$ (30)	$ (179)

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Document and Entity Information	9 Months Ended
	Sep. 30, 2014	Oct. 31, 2014
Document Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2014
Document Fiscal Year Focus	2014
Document Fiscal Period Focus (Q1,Q2,Q3,FY)	Q3
Trading Symbol	MPC
Entity Registrant Name	Marathon Petroleum Corp
Entity Central Index Key	0001510295
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		280,192,743

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Segment Information

9 Months Ended

Sep. 30, 2014

Segment Reporting [Abstract]

Segment Information

Segment Information

We have three reportable segments: Refining & Marketing; Speedway; and Pipeline Transportation. 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 refineries in the Gulf Coast and Midwest regions of the United States, purchases ethanol and refined products for resale and distributes refined products through various means, including barges, terminals and trucks that we own or operate. 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 – with the acquisition of Hess' retail operations effective September 30, 2014, sells transportation fuels and convenience products in retail markets in the Midwest, East Coast and Southeast.

• Pipeline Transportation – transports crude oil and other feedstocks to our refineries and other locations, delivers refined products to wholesale and retail market areas and includes the aggregated operations of MPLX and MPC’s retained pipeline assets and investments.

On February 1, 2013, we acquired the Galveston Bay Refinery and Related Assets, which are part of the Refining & Marketing and Pipeline Transportation segments. On September 30, 2014, we acquired Hess' Retail Operations and Related Assets, which are part of the Speedway and Refining & Marketing segments. Segment information for the periods prior to each acquisition do not include amounts for these operations. See Note 4.

Segment income represents income from operations attributable to the reportable segments. Corporate administrative expenses 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		Pipeline Transportation		Total
Three Months Ended September 30, 2014
Revenues:
Customer	$	21,568	$	3,854	$	16	$	25,438
Intersegment(a)	2,400		2		136		2,538
Segment revenues	$	23,968	$	3,856	$	152	$	27,976
Segment income from operations(b)	$	971	$	119	$	69	$	1,159
Income from equity method investments	17		—		12		29
Depreciation and amortization(c)	257		33		20		310
Capital expenditures and investments(d)(f)	318		2,707		224		3,249

(In millions)	Refining & Marketing		Speedway		Pipeline Transportation		Total
Three Months Ended September 30, 2013
Revenues:
Customer	$	22,481	$	3,755	$	20	$	26,256
Intersegment(a)	2,439		1		117		2,557
Segment revenues	$	24,920	$	3,756	$	137	$	28,813
Segment income from operations(b)	$	227	$	102	$	54	$	383
Income from equity method investments	8		—		1		9
Depreciation and amortization(c)	246		29		19		294
Capital expenditures and investments(d)	243		65		42		350

(In millions)	Refining & Marketing		Speedway		Pipeline Transportation		Total
Nine Months Ended September 30, 2014
Revenues:
Customer	$	64,295	$	11,220	$	52	$	75,567
Intersegment(a)	7,223		4		396		7,623
Segment revenues	$	71,518	$	11,224	$	448	$	83,190
Segment income from operations(b)	$	2,593	$	271	$	222	$	3,086
Income from equity method investments	76		—		45		121
Depreciation and amortization(c)	782		90		58		930
Capital expenditures and investments(d)(f)	731		2,783		418		3,932

(In millions)	Refining & Marketing		Speedway		Pipeline Transportation		Total
Nine Months Ended September 30, 2013
Revenues:
Customer	$	64,245	$	10,964	$	60	$	75,269
Intersegment(a)	7,072		3		340		7,415
Segment revenues	$	71,317	$	10,967	$	400	$	82,684
Segment income from operations(b)	$	2,235	$	292	$	163	$	2,690
Income from equity method investments	7		—		9		16
Depreciation and amortization(c)	734		83		55		872
Capital expenditures and investments(d)(e)	1,797		177		173		2,147

^(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 Pipeline Transportation 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 and investments in affiliates.

^(e)  The Refining & Marketing and Pipeline Transportation segments include $1.29 billion and $70 million, respectively, for the acquisition of the Galveston Bay Refinery and Related Assets. See Note 4.

^(f)  The Speedway and Refining & Marketing segments include $2.63 billion and $54 million, respectively, for the acquisition of Hess' Retail Operations and Related Assets. See Note 4.

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)	2014			2013			2014			2013
Segment income from operations	$	1,159		$	383		$	3,086		$	2,690
Items not allocated to segments:
Corporate and other unallocated items(a)(b)	(76		)	(59		)	(204		)	(190		)
Pension settlement expenses(c)	(21		)	(23		)	(90		)	(83		)
Net interest and other financial income (costs)	(50		)	(47		)	(144		)	(140		)
Income before income taxes	$	1,012		$	254		$	2,648		$	2,277

^(a)  Corporate and other unallocated items consists primarily of MPC’s corporate administrative expenses and costs related to certain non-operating assets.

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

^(c)  See Note 20.

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

	Three Months Ended   September 30,				Nine Months Ended   September 30,
(In millions)	2014		2013		2014		2013
Segment capital expenditures and investments	$	3,249	$	350	$	3,932	$	2,147
Less: Investments in equity method investees	177		75		341		86
Plus: Items not allocated to segments:
Capital expenditures not allocated to segments	22		54		60		106
Capitalized interest	7		7		20		15
Total capital expenditures(a)(b)	$	3,101	$	336	$	3,671	$	2,182

^(a)  Capital expenditures include changes in capital accruals and acquisitions.

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

The following reconciles customer revenues to sales and other operating revenues (including consumer excise taxes) as reported in the consolidated statements of income:

	Three Months Ended   September 30,				Nine Months Ended   September 30,
(In millions)	2014		2013		2014		2013
Customer revenues (as reported above)	$	25,438	$	26,256	$	75,567	$	75,269
Corporate and other unallocated items	—		—		—		(6		)
Sales and other operating revenues (including consumer excise taxes)	$	25,438	$	26,256	$	75,567	$	75,263

Total assets by reportable segment were:

(In millions)	September 30, 2014		December 31, 2013
Refining & Marketing	$	20,207	$	19,573
Speedway	5,203		2,064
Pipeline Transportation	2,329		1,947
Corporate and Other	3,966		4,801
Total consolidated assets	$	31,705	$	28,385

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Inventories - Summary Of Inventories (Detail) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014	Dec. 31, 2013
Inventory Disclosure [Abstract]
Crude oil and refinery feedstocks	$ 2,405	$ 1,797
Refined products	2,731	2,367
Materials and supplies	308	425
Merchandise	164	100
Total (at cost)	$ 5,608	$ 4,689

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Derivatives - Open Commodity Derivative Contracts (Detail)	9 Months Ended
	Sep. 30, 2014
Crude Oil Exchange-Traded
Derivative [Line Items]
Percentage of derivative contracts expiring in the period	96.00%
Derivative contract expiration date	Dec. 31, 2014
Crude Oil Exchange-Traded | Long
Derivative [Line Items]
Notional Contracts (in thousands of Total Barrels)	10,346,000	[1]
Crude Oil Exchange-Traded | Short
Derivative [Line Items]
Notional Contracts (in thousands of Total Barrels)	23,186,000	[1]
Refined Products Exchange-Traded
Derivative [Line Items]
Percentage of derivative contracts expiring in the period	100.00%
Derivative contract expiration date	Dec. 31, 2014
Refined Products Exchange-Traded | Long
Derivative [Line Items]
Notional Contracts (in thousands of Total Barrels)	1,695,000	[2]
Refined Products Exchange-Traded | Short
Derivative [Line Items]
Notional Contracts (in thousands of Total Barrels)	3,281,000	[2]

[1] 96 percent of these contracts expire in the fourth quarter of 2014.

[2] 100 percent of these contracts expire in the fourth quarter of 2014.

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Consolidated Statements of Comprehensive Income (Parenthetical) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Statement of Comprehensive Income [Abstract]
Actuarial changes, tax	$ (1)	$ 34	$ 0	$ 169
Prior service costs, tax	$ (5)	$ (5)	$ (14)	$ (14)

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MPLX LP

9 Months Ended

Sep. 30, 2014

Noncontrolling Interest [Abstract]

MPLX LP

MPLX LP

MPLX is a publicly traded master limited partnership that was formed by us to own, operate, develop and acquire pipelines and other midstream assets related to the transportation and storage of crude oil, refined products and other hydrocarbon-based products. We own a 73.6 percent interest in MPLX, including the two percent general partner interest. We consolidate this entity for financial reporting purposes since we have a controlling financial interest, and we record a noncontrolling interest for the interest owned by the public.

MPLX’s initial assets consisted of a 51 percent general partner interest in MPLX Pipe Line Holdings LP (“Pipe Line Holdings”), which owns a network of common carrier crude oil and product pipeline systems and associated storage assets in the Midwest and Gulf Coast regions of the United States, and a 100 percent interest in a butane storage cavern in West Virginia. On May 1, 2013, we sold a five percent interest in Pipe Line Holdings to MPLX for $100 million.

Effective March 1, 2014, we sold MPLX a 13 percent interest in Pipe Line Holdings for $310 million, increasing MPLX's ownership interest in Pipe Line Holdings to 69 percent. MPLX financed this transaction with $40 million of cash on-hand and $270 million of borrowings on its bank revolving credit agreement.

The sales of our interests in Pipeline Holdings to MPLX resulted in a change of our ownership in Pipeline Holdings, but not a change in control. We accounted for the sales as equity transactions and did not record a gain or loss.

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Accounting Standards

9 Months Ended

Sep. 30, 2014

Accounting Changes and Error Corrections [Abstract]

Accounting Standards

Accounting Standards

Not Yet Adopted

In August 2014, the Financial Accounting Standards Board ("FASB") issued an accounting standards update requiring management to assess an entity's ability to continue as a going concern and to provide related footnote disclosures in certain circumstances. Management will be required to assess if there is substantial doubt about an entity's ability to continue as a going concern within one year after the date that the financial statements are issued. Disclosures will be required if conditions give rise to substantial doubt and the type of disclosure will be determined based on whether management's plans will be able to alleviate the substantial doubt. The accounting standards update will be effective for the first annual period ending after December 15, 2016, and for annual periods and interim periods thereafter with early application permitted.

In June 2014, the FASB issued an accounting standards update for the elimination of the concept of development stage entity ("DSE") from U.S. GAAP and removes the related incremental reporting. The standards update eliminates the additional financial statement requirements specific to a DSE. In addition, it amends the consolidation model by eliminating the special provisions in the variable interest entity rules for assessing the sufficiency of the equity of a DSE. The portion of the accounting standards update related to the amendment to the consolidation guidance will be effective on a retrospective basis for annual reporting periods beginning after December 15, 2015, and interim periods within those years, with early adoption permitted. The portion of the accounting standards update related to the removal of the DSE reporting requirements will be effective on a retrospective basis for annual reporting periods beginning after December 15, 2014, and interim periods within those years, with early adoption permitted. Adoption of this standards update in the first quarters of 2015 and 2016 is not expected to have an impact on our consolidated results of operations, financial position or cash flows.

In May 2014, the FASB issued an accounting standards update for revenue recognition that is aligned with the International Accounting Standards Board's revenue recognition standard issued on the same day. The guidance in the 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 then 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. The accounting standards update will be effective on a retrospective or modified retrospective basis for annual reporting periods beginning after December 15, 2016, and interim periods within those years, with no early adoption permitted. At this point, a final determination has not been made as to the impact of the adoption of this standards update in the first quarter of 2017. However, we do not expect it to have a material impact on our consolidated results of operations, financial position or cash flows.

In April 2014, the FASB issued an accounting standards update that redefines the criteria for determining discontinued operations and introduces new disclosures related to these disposals. The updated definition of a discontinued operation is the disposal of a component (or components) of an entity or the classification of a component (or components) of an entity as held for sale that represents a strategic shift for an entity and has (or will have) a major impact on an entity's operations and financial results. The standard requires disclosure of additional financial information for discontinued operations and individually material components not qualifying for discontinued operation presentation, as well as information regarding an entity's continuing involvement with the discontinued operation. The accounting standards update is effective prospectively for annual periods beginning on or after December 15, 2014, and interim periods within those years. Early adoption is permitted. Adoption of this standards update in the first quarter of 2015 is not expected to have an impact on our consolidated results of operations, financial position or cash flows.

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Goodwill

9 Months Ended

Sep. 30, 2014

Goodwill and Intangible Assets Disclosure [Abstract]

Goodwill

Goodwill

The changes in the carrying amount of goodwill for nine months ended September 30, 2014 were as follows:

(In millions)	Refining & Marketing			Speedway		Pipeline Transportation		Total
Balance as of December 31, 2013	$	551		$	225	$	162	$	938
Acquisition(a)	—			600		—		600
Disposition	(1		)	—		—		(1		)
Balance as of September 30, 2014	$	550		$	825	$	162	$	1,537

^(a)  See Note 4 for information on the acquisitions.

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Other Items

9 Months Ended

Sep. 30, 2014

Other Income and Expenses [Abstract]

Other Items

Other Items

Net interest and other financial income (costs) was:

	Three Months Ended   September 30,						Nine Months Ended   September 30,
(In millions)	2014			2013			2014			2013
Interest:
Interest income	$	2		$	2		$	5		$	7
Interest expense	(56		)	(50		)	(154		)	(147		)
Interest capitalized	7			7			20			15
Total net interest	(47		)	(41		)	(129		)	(125		)
Other:
Net foreign currency gains (losses)	1			(1		)	—			—
Bank service and other fees	(4		)	(5		)	(15		)	(15		)
Total other	(3		)	(6		)	(15		)	(15		)
Net interest and other financial income (costs)	$	(50	)	$	(47	)	$	(144	)	$	(140	)

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Fair Value Measurements - Assets and Liabilities Accounted for at Fair Value on Recurring Basis (Detail) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014		Dec. 31, 2013
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash collateral netted with derivative liabilities	$ 0		$ 32
Liabilities, current	193		159
Fair Value, Measurements, Recurring
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Commodity derivative instruments, assets - netting and collateral	(55)	[1]	(21)	[1]
Commodity derivative instruments, assets - net	32	[2]	0	[2]
Commodity derivative instruments, assets - collateral pledged not offset	60		61
Other assets	2		2
Total assets at fair value	34		2
Commodity derivative instruments, liabilities - netting and collateral	(55)	[1]	(53)	[1]
Commodity derivative instruments, liabilities - net	0	[2]	0	[2]
Commodity derivative instruments, liabilities - collateral pledged not offset	0		0
Contingent consideration, liability	475	[3]	625	[3]
Total liabilities at fair value	475		625
Fair Value, Measurements, Recurring | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Commodity derivative instruments, assets - gross	87		21
Other assets	2		2
Total assets at fair value	89		23
Commodity derivative instruments, liabilities - gross	55		53
Contingent consideration, liability	0		0
Total liabilities at fair value	55		53
Fair Value, Measurements, Recurring | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Commodity derivative instruments, assets - gross	0		0
Other assets	0		0
Total assets at fair value	0		0
Commodity derivative instruments, liabilities - gross	0		0
Contingent consideration, liability	0		0
Total liabilities at fair value	0		0
Fair Value, Measurements, Recurring | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Commodity derivative instruments, assets - gross	0		0
Other assets	0		0
Total assets at fair value	0		0
Commodity derivative instruments, liabilities - gross	0		0
Contingent consideration, liability	475	[3]	625	[3]
Total liabilities at fair value	$ 475		$ 625

[1] Represents the impact of netting assets, liabilities and cash collateral when a legal right of offset exists. As of September 30, 2014 and December 31, 2013, cash collateral of $0 million and $32 million, respectively, was netted with mark-to-market derivative liabilities.

[2] We have no derivative contracts that are subject to master netting arrangements that are reflected gross on the balance sheet.

[3] Includes $193 million and $159 million classified as current at September 30, 2014 and December 31, 2013, respectively.

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Related Party Transactions

9 Months Ended

Sep. 30, 2014

Related Party Transactions [Abstract]

Related Party Transactions

Related Party Transactions

Our related parties include:

• Centennial Pipeline LLC (“Centennial”), in which we have a 50 percent noncontrolling interest. Centennial owns a refined products pipeline and storage facility.

• Explorer, in which we have a 25 percent interest. Explorer owns and operates a refined products pipeline.

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

• LOOP LLC (“LOOP”), in which we have a 51 percent noncontrolling interest. LOOP owns and operates the only U.S. deepwater oil port.

• TAAE, in which we have a 43 percent noncontrolling interest, TACE, in which we have a 60 percent noncontrolling interest and TAME, in which we have a 67 percent direct and indirect noncontrolling interest. These companies each own an ethanol production facility.

• Other equity method investees.

Sales to related parties, which are included in sales and other operating revenues (including consumer excise taxes) on the consolidated statements of income, were as follows:

	Three Months Ended   September 30,				Nine Months Ended   September 30,
(In millions)	2014		2013		2014		2013
Other equity method investees	$	2	$	3	$	6	$	7

Fees received for operating Centennial's pipeline, which are included in other income on the consolidated statements of income, were $1 million for the nine months ended September 2014 and 2013.

Purchases from related parties were as follows:

	Three Months Ended   September 30,				Nine Months Ended   September 30,
(In millions)	2014		2013		2014		2013
Centennial	$	—	$	4	$	7	$	4
Explorer	10		—		32		—
LOCAP	6		5		16		13
LOOP	12		11		77		32
TAAE	19		8		61		8
TACE	33		42		90		92
TAME	29		31		111		98
Other equity method investees	3		2		7		7
Total	$	112	$	103	$	401	$	254

Related party purchases from Centennial consist primarily of refinery feedstocks and refined product transportation costs. Related party purchases from Explorer consist primarily of refined product transportation costs. Related party purchases from LOCAP, LOOP and other equity method investees consist primarily of crude oil transportation costs and crude oil purchases. Related party purchases from TAAE, TACE and TAME consist of ethanol purchases.

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

(In millions)	September 30, 2014		December 31, 2013
Centennial	$	2	$	1
TAME	2		1
Total	$	4	$	2

We also had a long-term receivable from Centennial of $1 million at September 30, 2014 and of $2 million at December 31, 2013, which is included in other noncurrent assets on the consolidated balance sheets.

Payables to related parties, which are included in accounts payable on the consolidated balance sheets, were as follows:

(In millions)	September 30, 2014		December 31, 2013
Explorer	$	5	$	—
LOCAP	2		2
LOOP	4		3
TAAE	1		2
TACE	2		4
TAME	2		5
Other equity method investees	1		—
Total	$	17	$	16

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Acquisitions and Investments (Investments in Ethanol Companies) (Details) (USD $) In Millions, unless otherwise specified						1 Months Ended
	Sep. 30, 2014 TACE	Sep. 30, 2014 TAME	Sep. 30, 2014 TAME TAEI	Sep. 30, 2014 TAAE	Oct. 01, 2013 TAAE	Aug. 01, 2013 Ethanol Interests From Mitsui Company	Aug. 01, 2013 Ethanol Interests From Mitsui TACE	Aug. 01, 2013 Ethanol Interests From Mitsui TAEI	Aug. 01, 2013 Ethanol Interests From Mitsui TAAE
Schedule of Equity Method Investments [Line Items]
Number of businesses in which ownership interests acquired						3
Cash paid to acquire equity method investments						$ 75
Ownership percentage acquired							24.00%	34.00%	40.00%
Equity method investments, ownership percentage	60.00%	67.00%	50.00%	43.00%	43.00%

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Acquisitions and Investments

9 Months Ended

Sep. 30, 2014

Business Combinations [Abstract]

Acquisitions and Investments

Acquisitions and Investments

Acquisition of Hess' Retail Operations and Related Assets

On September 30, 2014, we acquired from Hess Corporation ("Hess") all of Hess' retail locations, transport operations and shipper history on various pipelines, including approximately 40,000 barrels per day on Colonial Pipeline for $2.82 billion. We refer to these assets as “Hess' Retail Operations and Related Assets.” The transaction was funded with a combination of debt and available cash.

The transaction provides for an adjustment for working capital, which has not been finalized with Hess. If a change is made for working capital, the fair value of the assets acquired will be revised.

The estimated fair values of assets acquired and liabilities assumed at the acquisition date, pending the completion of an independent appraisal and other evaluations, are as follows:

(In millions)
Cash and cash equivalents	$	39
Receivables	132
Inventories	178
Other current assets	5
Property, plant and equipment, net	2,062
Other noncurrent assets	103
Total assets acquired	2,519
Accounts payable	77
Payroll and benefits payable	4
Consumer excise taxes payable	80
Other current liabilities	10
Defined benefit postretirement plan obligations	2
Deferred credits and other liabilities	122
Total liabilities assumed	295
Net assets acquired excluding goodwill	2,224
Goodwill	600
Net assets acquired	$	2,824

The purchase price allocation resulted in the recognition of $600 million in goodwill by our Speedway segment, which is deductible for tax purposes. Goodwill recognized for the acquisition primarily relates to the expected benefits of a significantly expanded retail platform that should enable growth in new markets, as well as the potential for higher merchandise sales. We also expect strategic benefits from the financial and operational scale we expect to realize across our entire retail network. This acquisition significantly expands our Speedway presence from nine to 22 states throughout the East Coast and Southeast and is aligned with our strategy to grow higher-valued, stable cash flow businesses. This acquisition also enables us to further leverage our integrated refining and transportation operations, providing an outlet for an incremental 200,000 barrels per day of assured sales from our refining system.

Other noncurrent assets includes a $22 million intangible asset related to a trade name and $60 million related to favorable lease contract terms. Deferred credits and other liabilities includes $80 million related to unfavorable lease contract terms. The trade name is being amortized over its estimated useful life of two years based on the utilization of the assets. The favorable and unfavorable lease contract amounts are being amortized over the terms of the leases.

We recognized $12 million of acquisition-related costs associated with Hess' Retail Operations and Related Assets acquisition. These costs were expensed and were included in selling, general and administrative expenses.

Acquisition of Refinery and Related Logistics and Marketing Assets

On February 1, 2013, we acquired from BP Products North America Inc. and BP Pipelines (North America) Inc. (collectively, “BP”) the 451,000 barrel per calendar day refinery in Texas City, Texas, three intrastate natural gas liquid pipelines originating at the refinery, four light product terminals, branded-jobber marketing contract assignments for the supply of approximately 1,200 branded sites, a 1,040 megawatt electric cogeneration facility and a 50,000 barrel per day allocation of space on Colonial Pipeline. We refer to these assets as the “Galveston Bay Refinery and Related Assets.” We paid $1.49 billion for these assets, which included $935 million for inventory. The transaction was funded with cash on hand. Pursuant to the purchase and sale agreement, we may also be required to pay BP a contingent earnout of up to an additional $700 million over six years, subject to certain conditions. In July 2014, we paid BP $180 million for the first period's contingent earnout. On the consolidated statements of cash flows, $172 million of the contingent earnout payment is included as a financing activity with the remainder included as an operating activity. See Note 15 for additional information on the contingent consideration.

The following unaudited pro forma financial information presents consolidated results assuming the Galveston Bay Refinery and Related Assets acquisition occurred on January 1, 2012 and Hess' Retail Operations and Related Assets acquisition occurred on January 1, 2013. The pro forma financial information does not give effect to potential synergies that could result from the acquisitions and is not necessarily indicative of the results of future operations.

	Three Months Ended   September 30,				Nine Months Ended   September 30,
(In millions, except per share data)	2014		2013		2014		2013
Sales and other operating revenues (including consumer excise taxes)	$	28,284	$	29,317	$	84,232	$	86,386
Net income attributable to MPC	698		170		1,748		1,516
Net income attributable to MPC per share - basic	$	2.48	$	0.55	$	6.07	$	4.72
Net income attributable to MPC per share - diluted	2.46		0.55		6.03		4.69

The pro forma information includes adjustments to align accounting policies, an adjustment to depreciation expense to reflect the fair value of property, plant and equipment, increased amortization expense related to identifiable intangible assets, additional interest expense related to financing the acquisition of Hess' Retail Operations and Related Assets, as well as the related income tax effects.

Acquisitions of Convenience Stores

During 2013, Speedway acquired nine convenience stores located in Tennessee, western Indiana and western Pennsylvania. In connection with these acquisitions, our Speedway segment recorded $8 million of goodwill, which is deductible for income tax purposes.

The principal factors contributing to a purchase price resulting in goodwill included the acquired stores complementing our existing network in our Midwest market, access to our refined product transportation systems and the potential for higher merchandise sales.

Acquisition of Biodiesel Facility

On April 1, 2014, we purchased a facility in Cincinnati, Ohio from Felda Iffco Sdn Bhd, Malaysia for $40 million. The plant currently produces biodiesel, glycerin and other by-products. The capacity of the plant is approximately 60 million gallons per year.

Neither goodwill nor a gain from a bargain purchase was recognized in conjunction with the biodiesel facility acquisition.

Assuming the acquisitions of the convenience stores in 2013 and the biodiesel facility in 2014 had been made at the beginning of any period presented, the consolidated pro forma results would not be materially different from reported results.

Investments in Ethanol Companies

On August 1, 2013, we acquired from Mitsui & Co. (U.S.A.), Inc. its interests in three ethanol companies for $75 million. Under the purchase agreement, we acquired an additional 24 percent interest in The Andersons Clymers Ethanol LLC ("TACE"), bringing our ownership interest to 60 percent; a 34 percent interest in The Andersons Ethanol Investment LLC ("TAEI"), which holds a 50 percent ownership in The Andersons Marathon Ethanol LLC ("TAME"), bringing our direct and indirect ownership interest in TAME to 67 percent; and a 40 percent interest in The Andersons Albion Ethanol LLC ("TAAE"), which owns an ethanol production facility in Albion, Michigan. On October 1, 2013, our ownership interest in TAAE increased to 43 percent as a result of TAAE acquiring one of the owner's interest. We hold a noncontrolling interest in each of these entities and account for them using the equity method of accounting since the minority owners have substantive participating rights.

Investments in Pipeline Companies

In July 2014, we exercised our option to acquire a 35 percent ownership interest in Enbridge Inc.'s Southern Access Extension pipeline ("SAX") through our investment in Illinois Extension Pipeline Company, LLC ("Illinois Extension Pipeline"). During the nine months ended September 30, 2014, we made contributions of $97 million to Illinois Extension Pipeline to fund our portion of the construction costs incurred-to-date on the SAX project. We account for our ownership interest in Illinois Extension Pipeline as an equity method investment. See Note 22 for information on future contributions to Illinois Extension Pipeline.

In March 2014, we acquired from Chevron Raven Ridge Pipe Line Company an additional seven percent interest in Explorer Pipeline Company ("Explorer") for $77 million, bringing our ownership interest to 25 percent. As a result of this increase in our ownership, we now account for our investment in Explorer using the equity method of accounting rather than the cost method. The cumulative impact of the change was applied as an adjustment to 2014 retained earnings.

In November 2013, we agreed to serve as an anchor shipper for the Sandpiper pipeline project and fund 37.5 percent of the construction costs of the project, which will become part of Enbridge Energy Partners L.P.'s ("Enbridge Energy Partners") North Dakota System. In exchange for these commitments, we will earn an approximate 27 percent equity interest in Enbridge Energy Partners' North Dakota System when the Sandpiper pipeline is placed into service. We also have the option to increase our ownership interest to approximately 30 percent through additional investments in future system improvements. We made contributions of $149 million to North Dakota Pipeline Company LLC ("North Dakota Pipeline") during the nine months ended September 30, 2014. We have contributed $173 million since project inception. We account for our interest in North Dakota Pipeline using the equity method of accounting. See Note 22 for information on future contributions to North Dakota Pipeline.

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Variable Interest Entity

9 Months Ended

Sep. 30, 2014

Variable Interest Entity [Abstract]

Variable Interest Entity Disclosure

Variable Interest Entity

As stated in Note 4, we have a 35 percent ownership interest in Illinois Extension Pipeline through our contributions to the SAX project. Illinois Extension Pipeline Company LLC is considered a variable interest entity ("VIE") because it is a development stage entity and the equity in the entity is not sufficient to fund the current stage of development, which is the construction of the SAX pipeline. Our maximum exposure to loss due to this VIE at September 30, 2014 was $97 million, which equates to our contributions to-date to fund our portion of the construction costs for the project.

We are not the primary beneficiary of this VIE and, therefore, do not consolidate it because we do not have the power to control the activities that significantly influence the economic activities of the entity. The activities that most significantly impact the VIE's economic performance during the construction phase are the actual construction costs and risks associated with the construction process. Through our vote, we have shared power to direct the construction activities, but do not have the sole ability to control the construction activities.

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Income per Common Share

9 Months Ended

Sep. 30, 2014

Earnings Per Share [Abstract]

Income per Common Share

Income per Common Share

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

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

	Three Months Ended   September 30,				Nine Months Ended   September 30,
(In millions, except per share data)	2014		2013		2014		2013
Basic earnings per share:
Allocation of earnings:
Net income attributable to MPC	$	672	$	168	$	1,726	$	1,486
Income allocated to participating securities	1		—		3		2
Income available to common stockholders - basic	$	671	$	168	$	1,723	$	1,484
Weighted average common shares outstanding	282		309		288		321
Basic earnings per share	$	2.38	$	0.54	$	5.99	$	4.63
Diluted earnings per share:
Allocation of earnings:
Net income attributable to MPC	$	672	$	168	$	1,726	$	1,486
Income allocated to participating securities	1		—		3		2
Income available to common stockholders - diluted	$	671	$	168	$	1,723	$	1,484
Weighted average common shares outstanding	282		309		288		321
Effect of dilutive securities	2		2		2		2
Weighted average common shares, including dilutive effect	284		311		290		323
Diluted earnings per share	$	2.36	$	0.54	$	5.95	$	4.60

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)	2014	2013	2014	2013
Shares issued under stock-based compensation plans	—	1	—	1

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Related Party Transactions - Sales to Related Parties (Detail) (Other equity method investees, USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Other equity method investees
Related Party Transaction [Line Items]
Sales to related parties	$ 2	$ 3	$ 6	$ 7

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Fair Value Measurements - Narrative (Detail) (USD $)	3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended					9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014 Fair Value, Measurements, Recurring Derivative	Sep. 30, 2013 Fair Value, Measurements, Recurring Derivative	Sep. 30, 2014 Fair Value, Measurements, Recurring Derivative	Sep. 30, 2013 Fair Value, Measurements, Recurring Derivative	Sep. 30, 2014 Fair Value, Measurements, Recurring Contingent Consideration	Sep. 30, 2013 Fair Value, Measurements, Recurring Contingent Consideration	Sep. 30, 2014 Fair Value, Measurements, Recurring Contingent Consideration	Sep. 30, 2013 Fair Value, Measurements, Recurring Contingent Consideration	Sep. 30, 2014 Fair Value, Measurements, Nonrecurring	Sep. 30, 2013 Fair Value, Measurements, Nonrecurring	Feb. 01, 2013 Galveston Bay Refinery and Related Assets	Sep. 30, 2014 Galveston Bay Refinery and Related Assets Fair Value, Measurements, Recurring Minimum	Sep. 30, 2014 Galveston Bay Refinery and Related Assets Fair Value, Measurements, Recurring Maximum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Maximum earnout payment, year one															$ 200,000,000
Maximum earnout payment, year two															200,000,000
Maximum earnout payment, year three															200,000,000
Maximum earnout payment, year four															250,000,000
Maximum earnout payment, year five															250,000,000
Maximum earnout payment, year six															250,000,000
Total cumulative payment capped over six-year period															700,000,000
Range of internal and external crack spread forecast per barrel																14	15
Discount rate																5.00%	10.00%
Unrealized (gains) losses included in net income	8,000,000	(5,000,000)	30,000,000	6,000,000	0	0	0	0	8,000,000	(5,000,000)	30,000,000	6,000,000
Other asset impairment charges													11,000,000	0
Impairment of long-lived assets held-for-use													$ 0	$ 8,000,000

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Related Party Transactions - Receivables From Related Parties (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014	Dec. 31, 2013
Related Party Transaction [Line Items]
Current receivables from related parties	$ 4	$ 2
Centennial
Related Party Transaction [Line Items]
Current receivables from related parties	2	1
TAME
Related Party Transaction [Line Items]
Current receivables from related parties	$ 2	$ 1

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Stock-Based Compensation Plans - Narrative (Detail) (USD $)	9 Months Ended
	Sep. 30, 2014
Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant date fair value (in USD per share)	$ 25.37
Implied volatility rate weighting (in percentage)	50.00%
Historical volatility rate weighting (in percentage)	50.00%
Performance Unit Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant date fair value (in USD per unit)	$ 0.85

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Related Party Transactions - Additional Information (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2014 Centennial	Sep. 30, 2013 Centennial	Sep. 30, 2014 Centennial	Sep. 30, 2013 Centennial	Dec. 31, 2013 Centennial	Sep. 30, 2014 Explorer	Sep. 30, 2014 LOCAP	Sep. 30, 2014 LOOP	Sep. 30, 2014 TAAE	Oct. 01, 2013 TAAE	Sep. 30, 2014 TACE	Sep. 30, 2014 TAME
Related Party Transaction [Line Items]
Equity method investments, ownership percentage	50.00%		50.00%			25.00%	59.00%	51.00%	43.00%	43.00%	60.00%	67.00%
Operating pipeline revenue from related parties included in other income, Centennial	$ 0	$ 0	$ 1	$ 1
Long-term receivable from related party	$ 1		$ 1		$ 2

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Debt - Outstanding Borrowings (Detail) (USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2014		Dec. 31, 2013
Debt Instrument [Line Items]
Total	$ 6,283		$ 3,395
Unamortized discount	(26)		(10)
Fair value adjustments	7	[1]	11	[1]
Amounts due within one year	(26)		(23)
Total long-term debt due after one year	6,238		3,373
Interest Rate Swap
Debt Instrument [Line Items]
Deferred gain on discontinuation of interest rate fair value hedge	20
Consolidated subsidiaries: | Capital Lease Obligations
Debt Instrument [Line Items]
Capital lease obligations	378		395
Debt instrument maturity year, start	Jan. 01, 2014
Debt instrument maturity year, end	Dec. 31, 2028
MPC Revolver | Line of Credit
Debt Instrument [Line Items]
Long-term debt, gross	0		0
Line of credit facility, expiration date	Sep. 14, 2017
MPC Term Loan | Unsecured Debt
Debt Instrument [Line Items]
Long-term debt, gross	700		0
Line of credit facility, expiration date	Sep. 30, 2019
3.500% senior notes due March 1, 2016 | Senior Notes
Debt Instrument [Line Items]
Long-term debt, gross	750		750
Debt instrument, maturity date	Mar. 01, 2016
Debt instrument, interest rate	3.50%
5.125% senior notes due March 1, 2021 | Senior Notes
Debt Instrument [Line Items]
Long-term debt, gross	1,000		1,000
Debt instrument, maturity date	Mar. 01, 2021
Debt instrument, interest rate	5.125%
3.625% senior notes due September 15, 2024 | Senior Notes
Debt Instrument [Line Items]
Long-term debt, gross	750		0
Debt instrument, maturity date	Sep. 15, 2024
Debt instrument, interest rate	3.625%
6.500% senior notes due March 1, 2041 | Senior Notes
Debt Instrument [Line Items]
Long-term debt, gross	1,250		1,250
Debt instrument, maturity date	Mar. 01, 2041
Debt instrument, interest rate	6.50%
4.750% senior notes due September 15, 2044 | Senior Notes
Debt Instrument [Line Items]
Long-term debt, gross	800		0
Debt instrument, maturity date	Sep. 15, 2044
Debt instrument, interest rate	4.75%
5.000% senior notes due September 15, 2054 | Senior Notes
Debt Instrument [Line Items]
Long-term debt, gross	400		0
Debt instrument, maturity date	Sep. 15, 2054
Debt instrument, interest rate	5.00%
MPLX Revolver | MPLX Operations LLC | Line of Credit
Debt Instrument [Line Items]
Long-term debt, gross	255		0
Line of credit facility, expiration date	Oct. 31, 2017
Trade Receivables Securitization | Consolidated subsidiaries: | Secured Debt
Debt Instrument [Line Items]
Long-term debt, gross	$ 0		$ 0
Line of credit facility, expiration date	Dec. 31, 2016

[1] The $20 million gain on the termination of our interest rate swap agreements in 2012 is being amortized over the remaining life of the 3.50 percent senior notes.

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Description of the Business and Basis of Presentation (Policies)

9 Months Ended

Sep. 30, 2014

Accounting Policies [Abstract]

Use of estimates

These interim consolidated financial statements are unaudited; however, in the opinion of our management, these statements reflect all adjustments necessary for a fair statement of the results for the periods reported. All such adjustments are of a normal, recurring nature unless otherwise disclosed. These interim consolidated financial statements, including the notes, have been prepared in accordance with the rules of the Securities and Exchange Commission applicable to interim period financial statements and do not include all of the information and disclosures required by United States generally accepted accounting principles (“U.S. GAAP”) for complete financial statements.

Inventories

Inventories are carried at the lower of cost or market value. The cost of inventories of crude oil and refinery feedstocks, refined products and merchandise is determined primarily under the last-in, first-out (“LIFO”) method.

Derivative instruments

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

Stock-based compensation arrangements

The fair value of stock options granted to our employees is estimated on the date of the grant using the Black Scholes option-pricing model, which employs various assumptions. Beginning in the first quarter of 2014, the assumption for expected volatility of our stock price was refined to reflect a weighting of 50 percent of MPC’s common stock implied volatility and 50 percent of MPC's common stock historical volatility.

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Supplementary Statistics (Tables)

9 Months Ended

Sep. 30, 2014

Text Block [Abstract]

Supplementary Statistics

Supplementary Statistics (Unaudited)

	Three Months Ended   September 30,						Nine Months Ended   September 30,
(In millions)	2014			2013			2014			2013
Income from Operations by segment
Refining & Marketing	$	971		$	227		$	2,593		$	2,235
Speedway	119			102			271			292
Pipeline Transportation(a)	69			54			222			163
Items not allocated to segments:
Corporate and other unallocated items(a)	(76		)	(59		)	(204		)	(190		)
Pension settlement expenses	(21		)	(23		)	(90		)	(83		)
Income from operations	$	1,062		$	301		$	2,792		$	2,417
Capital Expenditures and Investments(b)(c)
Refining & Marketing	$	318		$	243		$	731		$	1,797
Speedway	2,707			65			2,783			177
Pipeline Transportation	224			42			418			173
Corporate and Other(d)	29			61			80			121
Total	$	3,278		$	411		$	4,012		$	2,268

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

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

^(c)  The three and nine months ended September 30, 2014 includes $2.68 billion for the acquisition of Hess' Retail Operations and Related Assets. The nine months ended September 30, 2013 includes $1.36 billion for the acquisition of the Galveston Bay Refinery and Related Assets. See Note 4 to the unaudited consolidated financial statements.

^(d)  Includes capitalized interest of $7 million for both the three months ended September 30, 2014 and 2013, and $20 million and $15 million for the nine months ended September 30, 2014 and 2013, respectively.

Operating Statistics

Supplementary Statistics (Unaudited)

	Three Months Ended   September 30,				Nine Months Ended   September 30,
	2014		2013		2014		2013
MPC Consolidated Refined Product Sales Volumes (thousands of barrels per day)(a)(b)	2,155		2,155		2,092		2,063
Refining & Marketing Operating Statistics(b)
Refining & Marketing refined product sales volume (thousands of barrels per day)(c)	2,140		2,148		2,079		2,052
Refining & Marketing gross margin (dollars per barrel)(d)	$	14.55	$	9.25	$	15.02	$	12.42
Crude oil capacity utilization percent(e)	100		99		94		97
Refinery throughputs (thousands of barrels per day):(f)
Crude oil refined	1,720		1,682		1,616		1,603
Other charge and blendstocks	160		195		172		202
Total	1,880		1,877		1,788		1,805
Sour crude oil throughput percent	52		53		52		53
WTI-priced crude oil throughput percent	16		21		18		22
Refined product yields (thousands of barrels per day):(f)
Gasoline	864		938		851		917
Distillates	598		578		574		570
Propane	36		39		36		37
Feedstocks and special products	330		259		280		227
Heavy fuel oil	24		31		27		31
Asphalt	63		70		52		57
Total	1,915		1,915		1,820		1,839
Refinery direct operating costs (dollars per barrel):(g)
Planned turnaround and major maintenance	$	1.52	$	0.96	$	1.82	$	0.94
Depreciation and amortization	1.35		1.27		1.43		1.32
Other manufacturing(h)	4.33		4.10		4.96		4.00
Total	$	7.20	$	6.33	$	8.21	$	6.26
Refining & Marketing Operating Statistics By Region - Gulf Coast(b)
Refinery throughputs (thousands of barrels per day):(i)
Crude oil refined	1,075		1,035		989		971
Other charge and blendstocks	155		175		174		181
Total	1,230		1,210		1,163		1,152
Sour crude oil throughput percent	66		64		64		65
WTI-priced crude oil throughput percent	1		7		2		8
Refined product yields (thousands of barrels per day):(i)
Gasoline	505		561		498		545
Distillates	389		370		366		363
Propane	25		24		24		23
Feedstocks and special products	310		241		275		214
Heavy fuel oil	8		21		13		20
Asphalt	19		23		13		14
Total	1,256		1,240		1,189		1,179
Refinery direct operating costs (dollars per barrel):(g)
Planned turnaround and major maintenance	$	1.15	$	0.86	$	1.77	$	0.77
Depreciation and amortization	1.10		1.01		1.16		1.04
Other manufacturing(h)	4.11		4.08		4.86		3.82
Total	$	6.36	$	5.95	$	7.79	$	5.63

Supplementary Statistics (Unaudited)
	Three Months Ended   September 30,						Nine Months Ended   September 30,
	2014			2013			2014			2013
Refining & Marketing Operating Statistics By Region - Midwest
Refinery throughputs (thousands of barrels per day):(i)
Crude oil refined	645			647			627			632
Other charge and blendstocks	38			56			43			55
Total	683			703			670			687
Sour crude oil throughput percent	30			35			33			35
WTI-priced crude oil throughput percent	41			43			42			43
Refined product yields (thousands of barrels per day):(i)
Gasoline	359			377			353			373
Distillates	209			208			208			207
Propane	13			15			13			14
Feedstocks and special products	51			54			49			46
Heavy fuel oil	16			10			14			11
Asphalt	44			47			39			43
Total	692			711			676			694
Refinery direct operating costs (dollars per barrel):(g)
Planned turnaround and major maintenance	$	2.10		$	1.08		$	1.78		$	1.17
Depreciation and amortization	1.75			1.66			1.80			1.72
Other manufacturing(h)	4.51			3.91			4.82			4.10
Total	$	8.36		$	6.65		$	8.40		$	6.99
Speedway Operating Statistics
Convenience stores at period-end(j)	2,744			1,471
Gasoline and distillate sales (millions of gallons)	842			803			2,421			2,329
Gasoline and distillate gross margin (dollars per gallon)(k)	$	0.1596		$	0.1404		$	0.1351		$	0.1483
Merchandise sales (in millions)	$	870		$	843		$	2,422		$	2,360
Merchandise gross margin (in millions)	$	235		$	224		$	651		$	620
Merchandise gross margin percent	27.0		%	26.5		%	26.9		%	26.3		%
Same store gasoline sales volume (period over period)	(0.8		%)	1.0		%	(1.0		%)	0.6		%
Same store merchandise sales (period over period)(l)	4.8		%	5.6		%	4.8		%	3.8		%
Pipeline Transportation Operating Statistics
Pipeline throughputs (thousands of barrels per day):(m)
Crude oil pipelines	1,265			1,317			1,230			1,308
Refined products pipelines	839			913			843			930
Total	2,104			2,230			2,073			2,238

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

^(b)  Includes the impact of the Galveston Bay Refinery and Related Assets beginning on the February 1, 2013 acquisition date.

^(c)  Includes intersegment sales.

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

^(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 33 mbpd and 36 mbpd for the three months ended September 30, 2014 and 2013, respectively, and 45 mbpd and 34 mbpd for the nine months ended September 30, 2014 and 2013, 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)  Includes 1,245 stores acquired on September 30, 2014 through the acquisition of Hess' Retail Operations and Related Assets. Segment results for the period prior to the acquisition do not include results from these operations.

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

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Inventories

9 Months Ended

Sep. 30, 2014

Inventory Disclosure [Abstract]

Inventories

Inventories

(In millions)	September 30, 2014		December 31, 2013
Crude oil and refinery feedstocks	$	2,405	$	1,797
Refined products	2,731		2,367
Materials and supplies	308		425
Merchandise	164		100
Total (at cost)	$	5,608	$	4,689

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 last-in, first-out (“LIFO”) method. There were no liquidations of LIFO inventories for the nine months ended September 30, 2014 and 2013.

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Debt

9 Months Ended

Sep. 30, 2014

Debt Disclosure [Abstract]

Debt

Debt

Our outstanding borrowings at September 30, 2014 and December 31, 2013 consisted of the following:

(In millions)	September 30, 2014			December 31, 2013
Marathon Petroleum Corporation:
Revolving credit agreement due 2017	$	—		$	—
Term loan agreement due 2019	700			—
3.500% senior notes due March 1, 2016	750			750
5.125% senior notes due March 1, 2021	1,000			1,000
3.625% senior notes due September 15, 2024	750			—
6.500% senior notes due March 1, 2041	1,250			1,250
4.750% senior notes due September 15, 2044	800			—
5.000% senior notes due September 15, 2054	400			—
Consolidated subsidiaries:
Capital lease obligations due 2014-2028	378			395
MPLX Operations LLC revolving credit agreement due 2017	255			—
Trade receivables securitization facility due 2016	—			—
Total	6,283			3,395
Unamortized discount	(26		)	(10		)
Fair value adjustments(a)	7			11
Amounts due within one year	(26		)	(23		)
Total long-term debt due after one year	$	6,238		$	3,373

^(a)  The $20 million gain on the termination of our interest rate swap agreements in 2012 is being amortized over the remaining life of the 3.50 percent senior notes.

There were no borrowings or letters of credit outstanding under the MPC revolving credit agreement or the trade receivables securitization facility at September 30, 2014. During the nine months ended September 30, 2014, MPLX borrowed $270 million under the MPLX Operations LLC revolving credit agreement (the "MPLX Credit Agreement"), at an average interest rate of 1.5 percent, per annum, and repaid $15 million of these borrowings. The borrowings were used to fund MPLX's March 2014 acquisition of an additional interest in Pipe Line Holdings. At September 30, 2014, MPLX had $255 million of borrowings and no letters of credit outstanding under the MPLX Credit Agreement, resulting in total unused loan availability of $245 million, or 49 percent of the borrowing capacity. The MPLX Credit Agreement is scheduled to mature on October 31, 2017.

Term Loan Agreement

On August 26, 2014, we entered into a $700 millionfive-year senior unsecured term loan credit agreement (the “Term Loan Agreement”) with a syndicate of lenders to fund a portion of the purchase price for the acquisition of Hess' Retail Operations and Related Assets. The Term Loan Agreement matures on September 24, 2019 and may be prepaid at any time without premium or penalty. We are obligated to pay certain customary fees under the Term Loan Agreement, including an annual administrative fee.

Amounts outstanding under the Term Loan Agreement bear interest at either of the following rates at our election (i) the sum of the Adjusted LIBO Rate (as defined in the Term Loan Agreement), plus a margin ranging between 0.875 percent to 1.75 percent, depending on our credit ratings, or (ii) the sum of the Base Rate (as defined in the Term Loan Agreement), plus a margin ranging between zero percent to 0.75 percent, depending on our credit ratings. The interest rate during the quarter ended September 30, 2014 was 1.3 percent.

The Term Loan Agreement contains representation and warranties, covenants and events of default that are substantially similar to those contained in the MPC revolving credit agreement, including a financial covenant, which 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 Term Loan Agreement) of no greater than 0.65 to 1.00.

Senior Notes

On September 5, 2014, we completed a public offering of $1.95 billion in aggregate principal amount of senior unsecured notes (the "Senior Notes"), consisting of $750 million aggregate principal amount of our Senior Notes due 2024, $800 million aggregate principal amount of our Senior Notes due 2044 and $400 million aggregate principal amount of our Senior Notes due 2054. The net proceeds from the offering of the Senior Notes were approximately $1.915 billion, after deducting underwriting discounts and estimated offering expenses. The proceeds were used to fund a portion of the purchase price for the acquisition of Hess' Retail Operations and Related Assets. Interest on each series of Senior Notes is payable semi-annually in arrears on March 15 and September 15 of each year, commencing on March 15, 2015.

The Senior Notes are unsecured and unsubordinated obligations of ours and rank equally with all our other existing and future unsecured and unsubordinated indebtedness.

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Debt Senior Notes (Details) (Senior Notes, USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2014	Sep. 05, 2014
Debt Instrument [Line Items]
Debt instrument, face amount		$ 1,950
Proceeds from (repayments of) debt	1,915
3.625% senior notes due September 15, 2024
Debt Instrument [Line Items]
Debt instrument, face amount		750
4.750% senior notes due September 15, 2044
Debt Instrument [Line Items]
Debt instrument, face amount		800
5.000% senior notes due September 15, 2054
Debt Instrument [Line Items]
Debt instrument, face amount		$ 400

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Defined Benefit Pension and Other Postretirement Plans (Tables)

9 Months Ended

Sep. 30, 2014

Compensation and Retirement Disclosure [Abstract]

Components of Net Periodic Benefit Costs

The following summarizes the components of net periodic benefit costs:

	Three Months Ended September 30,
	Pension Benefits						Other Benefits
(In millions)	2014			2013			2014			2013
Components of net periodic benefit cost:
Service cost	$	24		$	24		$	7		$	7
Interest cost	18			19			7			6
Expected return on plan assets	(27		)	(28		)	—			—
Amortization – prior service credit	(12		)	(12		)	(1		)	(1		)
– actuarial loss	12			14			1			1
– settlement loss	21			23			—			—
Net periodic benefit cost	$	36		$	40		$	14		$	13

	Nine Months Ended September 30,
	Pension Benefits						Other Benefits
(In millions)	2014			2013			2014			2013
Components of net periodic benefit cost:
Service cost	$	67		$	70		$	20		$	19
Interest cost	56			55			24			19
Expected return on plan assets	(81		)	(81		)	—			—
Amortization – prior service credit	(35		)	(34		)	(3		)	(3		)
– actuarial loss	38			53			2			2
– settlement loss	90			83			—			—
Net periodic benefit cost	$	135		$	146		$	43		$	37

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Commitments and Contingencies (Detail) (USD $) In Millions, unless otherwise specified	9 Months Ended		9 Months Ended					3 Months Ended		9 Months Ended
	Sep. 30, 2014	Dec. 31, 2013	Sep. 30, 2014 Galveston Bay Refinery and Related Assets	Sep. 30, 2014 North Dakota Pipeline	Sep. 30, 2014 Illinois Extension Pipeline Company LLC	Sep. 30, 2014 Indemnification Agreement Marathon Oil Companies	Sep. 30, 2014 Other Guarantees Equity method investees	Sep. 30, 2014 Guarantee of Indebtedness of Others Financial Guarantee LOOP and LOCAP LLC	Sep. 30, 2014 Master Shelf Agreement Financial Guarantee Centennial	Sep. 30, 2014 Standby Letters of Credit Financial Guarantee TAME	Sep. 30, 2014 Pending Litigation	Sep. 30, 2014 Pending Litigation Emergency Pricing And Consumer Protection Laws
Loss Contingencies [Line Items]
Loss contingency, inestimable loss											For matters for which we have not recorded an accrued liability, we are unable to estimate a range of possible loss because the issues involved have not been fully developed through pleadings and discovery.
Accrued liabilities for remediation	$ 182	$ 123
Receivables for recoverable costs	71	51
Alleged amount overcharged from customers												89
Loss contingency, period of occurrence												during September and October 2005
Plaintiff												Commonwealth of Kentucky
Line of credit facility, expiration date								Dec. 31, 2037	Dec. 31, 2024	Dec. 31, 2018
Maximum potential undiscounted payments							122	172	39	25
Percentage of credit agreement agreed to reimburse										50.00%
Guarantee obligation current carrying value						2
Guarantee obligations maximum exposure per event							50
Contractual commitments to acquire property, plant and equipment and advance funds to equity method investees	$ 1,800		$ 520	$ 751	$ 208

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Inventories (Tables)

9 Months Ended

Sep. 30, 2014

Inventory Disclosure [Abstract]

Summary Of Inventories

(In millions)	September 30, 2014		December 31, 2013
Crude oil and refinery feedstocks	$	2,405	$	1,797
Refined products	2,731		2,367
Materials and supplies	308		425
Merchandise	164		100
Total (at cost)	$	5,608	$	4,689

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Supplementary Statistics - Supplementary Statistics (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended				9 Months Ended
	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013
Supplementary Statistics [Line Items]
Income from operations	$ 1,062		$ 301		$ 2,792		$ 2,417
Capital expenditures and investments	3,278	[1],[2],[3]	411	[1],[2],[3]	4,012	[1],[2],[3]	2,268	[1],[2],[3]
Hess' Retail Operations and Related Assets
Supplementary Statistics [Line Items]
Capital expenditures and investments					2,680	[3]
Galveston Bay Refinery and Related Assets
Supplementary Statistics [Line Items]
Capital expenditures and investments							1,360	[2],[3]
Operating Segments
Supplementary Statistics [Line Items]
Income from operations	1,159	[4]	383	[4]	3,086	[4]	2,690	[4]
Capital expenditures and investments	3,249	[3],[5]	350	[3]	3,932	[3],[5]	2,147	[3],[6]
Operating Segments | Refining & Marketing
Supplementary Statistics [Line Items]
Income from operations	971		227		2,593		2,235
Capital expenditures and investments	318	[3],[5]	243	[3]	731	[3],[5]	1,797	[2],[3],[6]
Operating Segments | Refining & Marketing | Hess' Retail Operations and Related Assets
Supplementary Statistics [Line Items]
Capital expenditures and investments					54	[3]
Operating Segments | Refining & Marketing | Galveston Bay Refinery and Related Assets
Supplementary Statistics [Line Items]
Capital expenditures and investments							1,290	[2],[3]
Operating Segments | Speedway
Supplementary Statistics [Line Items]
Income from operations	119		102		271		292
Capital expenditures and investments	2,707	[3],[5]	65	[3]	2,783	[3],[5]	177	[3]
Operating Segments | Speedway | Hess' Retail Operations and Related Assets
Supplementary Statistics [Line Items]
Capital expenditures and investments					2,630	[3]
Operating Segments | Pipeline Transportation
Supplementary Statistics [Line Items]
Income from operations	69	[4]	54	[4]	222	[4]	163	[4]
Capital expenditures and investments	224	[3]	42	[3]	418	[3]	173	[2],[3],[6]
Operating Segments | Pipeline Transportation | Galveston Bay Refinery and Related Assets
Supplementary Statistics [Line Items]
Capital expenditures and investments							70	[2],[3]
Corporate and Other
Supplementary Statistics [Line Items]
Income from operations	(76)	[4],[7]	(59)	[4],[7]	(204)	[4],[7],[8]	(190)	[4],[7]
Capital expenditures and investments	29	[1],[3]	61	[1],[3]	80	[1],[3]	121	[1],[3]
Capitalized interest	7		7		20		15
Segment Reconciling Items
Supplementary Statistics [Line Items]
Pension settlement expenses	$ (21)	[9]	$ (23)	[9]	$ (90)	[9]	$ (83)	[9]

[1] Includes capitalized interest of $7 million for both the three months ended September 30, 2014 and 2013, and $20 million and $15 million for the nine months ended September 30, 2014 and 2013, respectively.

[2] The nine months ended September 30, 2013 includes $1.36 billion for the acquisition of the Galveston Bay Refinery and Related Assets. See Note 4 to the unaudited consolidated financial statements.

[3] Capital expenditures include changes in capital accruals, acquisitions and investments in affiliates.

[4] Corporate overhead expenses attributable to MPLX are included in the Pipeline Transportation segment. Corporate overhead expenses are not allocated to the Refining & Marketing and Speedway segments.

[5] The Speedway and Refining & Marketing segments include $2.63 billion and $54 million, respectively, for the acquisition of Hess' Retail Operations and Related Assets. See Note 4.

[6] The Refining & Marketing and Pipeline Transportation segments include $1.29 billion and $70 million, respectively, for the acquisition of the Galveston Bay Refinery and Related Assets. See Note 4.

[7] Corporate and other unallocated items consists primarily of MPC’s corporate administrative expenses and costs related to certain non-operating assets.

[8] Management believes intersegment transactions were conducted under terms comparable to those with unaffiliated parties

[9] See Note 20.

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Consolidated Balance Sheets (USD $) In Millions, unless otherwise specified	Sep. 30, 2014	Dec. 31, 2013
Current assets:
Cash and cash equivalents	$ 1,854	$ 2,292
Receivables, less allowance for doubtful accounts of $10 and $9	5,271	5,559
Inventories	5,608	4,689
Other current assets	154	197
Total current assets	12,887	12,737
Equity method investments	862	463
Property, plant and equipment, net	15,999	13,921
Goodwill	1,537	938
Other noncurrent assets	420	326
Total assets	31,705	28,385
Current liabilities:
Accounts payable	8,726	8,234
Payroll and benefits payable	345	406
Consumer excise taxes payable	365	373
Accrued taxes	586	513
Long-term debt due within one year	26	23
Other current liabilities	324	275
Total current liabilities	10,372	9,824
Long-term debt	6,238	3,373
Deferred income taxes	2,165	2,304
Defined benefit postretirement plan obligations	937	771
Deferred credits and other liabilities	727	781
Total liabilities	20,439	17,053
Commitments and contingencies (see Note 22)
MPC stockholders’ equity:
Preferred stock, no shares issued and outstanding (par value $0.01 per share, 30 million shares authorized)	0	0
Common stock:
Issued - 363 million and 362 million shares (par value $0.01 per share, 1 billion shares authorized)	4	4
Held in treasury, at cost - 82 million and 65 million shares	(5,616)	(4,155)
Additional paid-in capital	9,833	9,768
Retained earnings	6,856	5,507
Accumulated other comprehensive loss	(228)	(204)
Total MPC stockholders’ equity	10,849	10,920
Noncontrolling interests	417	412
Total equity	11,266	11,332
Total liabilities and equity	$ 31,705	$ 28,385

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Fair Value Measurements - Financial Instruments at Fair Value, Excluding Derivative Financial Instruments and Contingent Consideration (Detail) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014		Dec. 31, 2013
Fair Value
Financial assets:
Investments	$ 23		$ 336
Other assets	31		31
Total financial assets	54		367
Financial liabilities:
Long-term debt	6,224	[1]	3,306	[1]
Deferred credits and other liabilities	20		21
Total financial liabilities	6,244		3,327
Carrying Value
Financial assets:
Investments	2		14
Other assets	29		30
Total financial assets	31		44
Financial liabilities:
Long-term debt	5,886	[1]	3,001	[1]
Deferred credits and other liabilities	20		21
Total financial liabilities	$ 5,906		$ 3,022

[1] Excludes capital leases

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Description of the Business and Basis of Presentation

9 Months Ended

Sep. 30, 2014

Accounting Policies [Abstract]

Description of the Business and Basis of Presentation

Description of the Business and Basis of Presentation

Description of the Business—As used in this report, the terms “MPC,” “we,” “us,” “the Company” or “our” may refer to Marathon Petroleum Corporation, one or more of its consolidated subsidiaries or all of them taken as a whole.

Our business consists of refining and marketing, retail marketing and pipeline transportation operations conducted primarily in the Midwest, Gulf Coast, East Coast and Southeast regions of the United States, through subsidiaries, including Marathon Petroleum Company LP, Speedway LLC 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 Securities and Exchange Commission applicable to interim period financial statements and do not include all of the information and disclosures required by United States generally accepted accounting principles (“U.S. 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, 2013. The results of operations for the three and nine months ended September 30, 2014 are not necessarily indicative of the results to be expected for the full year.

During the first quarter of 2014, we recorded an out-of-period adjustment for additional expenses related to the prior year's bonus programs of $29 million, included in total costs and expenses on the consolidated statements of income. The impact to our consolidated results of operations for the nine months ended September 30, 2014 and for the year ended December 31, 2013 was immaterial. We do not expect this adjustment to have a material impact to our results of operations for the year ended December 31, 2014.

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Acquisitions and Investments (Acquisitions of Convenience Stores) (Details) (USD $) In Millions, unless otherwise specified	9 Months Ended		12 Months Ended
	Sep. 30, 2014		Dec. 31, 2013 Store
Business Acquisition [Line Items]
Goodwill acquired during period	$ 600
Speedway
Business Acquisition [Line Items]
Number of convenience stores acquired			9
Goodwill acquired during period	$ 600	[1]	$ 8

[1] See Note 4 for information on the acquisitions.

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Property, Plant And Equipment - Summary Of Property, Plant And Equipment (Detail) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014	Dec. 31, 2013
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 24,712	$ 21,793
Less accumulated depreciation	8,713	7,872
Net property, plant and equipment	15,999	13,921
Operating Segments | Refining & Marketing
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	17,646	16,982
Operating Segments | Speedway
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	4,477	2,344
Operating Segments | Pipeline Transportation
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	1,995	1,921
Corporate and Other
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 594	$ 546

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Subsequent Event Sale of remaining interest in Pipe Line Holdings (Details) (MPLX Pipe Line Holdings LP)	Mar. 01, 2014	May 01, 2013	Oct. 29, 2014 Scenario, Forecast Subsequent Event
Subsequent Event [Line Items]
Additional interest sold	13.00%	5.00%	31.00%

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Income Per Common Share - Anti-dilutive Shares (Details) (Stock Compensation Plan) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Stock Compensation Plan
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares issued under stock-based compensation plans	0	1	0	1

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Supplemental Cash Flow Information

9 Months Ended

Sep. 30, 2014

Supplemental Cash Flow Elements [Abstract]

Supplemental Cash Flow Information

Supplemental Cash Flow Information

	Nine Months Ended   September 30,
(In millions)	2014		2013
Net cash provided by operating activities included:
Interest paid (net of amounts capitalized)	$	162	$	166
Net income taxes paid to taxing authorities	969		1,027
Non-cash investing and financing activities:
Capital lease obligations increase	$	—	$	61
Property, plant and equipment sold	4		43
Property, plant and equipment acquired	4		—
Acquisition:
Contingent consideration(a)	—		600
Payable to seller(a)	—		6

^(a)  Acquisition-date fair value of non-cash consideration associated with the Galveston Bay Refinery and Related Assets acquisition.

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)	2014		2013
Additions to property, plant and equipment per consolidated statements of cash flows	$	952	$	733
Non-cash additions to property, plant and equipment	4		—
Acquisitions(a)	2,714		1,386
Asset retirement expenditures	1		—
Increase in capital accruals	—		63
Total capital expenditures	$	3,671	$	2,182

^(a)  The 2014 acquisition includes the acquisition of Hess' Retail Operations and Related Assets. The 2013 acquisition includes the acquisition of the Galveston Bay Refinery and Related Assets. The acquisition numbers above include property, plant and equipment and intangibles. See Note 4.

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Segment Information - Reconciliation Of Segment Income From Operations To Income Before Income Taxes (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended				9 Months Ended
	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Income from operations	$ 1,062		$ 301		$ 2,792		$ 2,417
Net interest and other financial income (costs)	(50)		(47)		(144)		(140)
Income before income taxes	1,012		254		2,648		2,277
Operating Segments
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Income from operations	1,159	[1]	383	[1]	3,086	[1]	2,690	[1]
Corporate and Other
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Income from operations	(76)	[1],[2]	(59)	[1],[2]	(204)	[1],[2],[3]	(190)	[1],[2]
Segment Reconciling Items
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Pension settlement expenses	$ (21)	[4]	$ (23)	[4]	$ (90)	[4]	$ (83)	[4]

[1] Corporate overhead expenses attributable to MPLX are included in the Pipeline Transportation segment. Corporate overhead expenses are not allocated to the Refining & Marketing and Speedway segments.

[2] Corporate and other unallocated items consists primarily of MPC’s corporate administrative expenses and costs related to certain non-operating assets.

[3] Management believes intersegment transactions were conducted under terms comparable to those with unaffiliated parties

[4] See Note 20.

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Equity (Tables)

9 Months Ended

Sep. 30, 2014

Equity [Abstract]

Share Repurchases Transacted Through ASR Programs and Open Market Transactions

Total share repurchases were as follows for the three and nine months ended September 30, 2014 and 2013:

	Three Months Ended   September 30,				Nine Months Ended   September 30,
(In millions, except per share data)	2014		2013		2014		2013
Number of shares repurchased(a)	4		14		17		31
Cash paid for shares repurchased	$	301	$	1,028	$	1,449	$	2,341
Effective average cost per delivered share	$	85.15	$	70.73	$	87.25	$	76.01

^(a)  The nine months ended September 30, 2013 includes one million shares received under the November 2012 accelerated share repurchase program, which were paid for in 2012.

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Income Taxes

9 Months Ended

Sep. 30, 2014

Income Tax Disclosure [Abstract]

Income Taxes

Income Taxes

The combined federal, state and foreign income tax rate was 33 percent and 32 percent for the three months ended September 30, 2014 and 2013, respectively, and 34 percent for both the nine months ended September 30, 2014 and 2013. The effective tax rate for the three and nine months ended September 30, 2014 and 2013 is slightly less than the U.S. statutory rate of 35 percent primarily due to certain permanent benefit differences, including the domestic manufacturing deduction, partially offset by state and local tax expense.

Prior to the June 30, 2011 spinoff transaction from Marathon Oil Corporation (“Marathon Oil”), we were included in Marathon Oil’s income tax returns for all applicable years. During 2011, we anticipated a future settlement between Marathon Oil and us upon the filing of Marathon Oil’s consolidated U.S. federal and state income tax returns for the period prior to June 30, 2011. During the second quarter of 2013, we settled with Marathon Oil for the 2011 period based on filed tax returns, resulting in a $39 million increase to additional paid-in capital.

We are continuously undergoing examination of our income tax returns, which have been completed for our U.S. federal and state income tax returns through the 2009 and 2003 tax years, respectively. We had $16 million of unrecognized tax benefits as of September 30, 2014. Pursuant to our tax sharing agreement with Marathon Oil, the unrecognized tax benefits related to pre-spinoff operations for which Marathon Oil was the taxpayer remain the responsibility of Marathon Oil and we have indemnified Marathon Oil accordingly. See Note 22 for indemnification information.

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Stock-Based Compensation Plans - Summary of Stock Option Award Activity (Detail) (Stock Options, USD $)	9 Months Ended
	Sep. 30, 2014
Stock Options
Number of Shares
Outstanding, beginning balance	5,147,837	[1]
Granted	446,310	[1]
Exercised	(696,159)	[1]
Forfeited, canceled or expired	(20,761)	[1]
Outstanding, ending balance	4,877,227	[1]
Weighted Average Exercise Price
Outstanding, beginning balance (in USD per share)	$ 40.08
Granted (in USD per share)	$ 85.02
Exercised (in USD per share)	$ 32.12
Forfeited, canceled or expired (in USD per share)	$ 49.67
Outstanding, ending balance (in USD per share)	$ 45.28

[1] Includes an immaterial number of stock appreciation rights.