Edgar Filing: Marathon Petroleum Corp

10-K

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K

ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

For the Fiscal Year Ended December 31, 2012

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, OH 45840-3229

(Address of principal executive offices)

(419) 422-2121

(Registrant’s telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act


Title of Each Class		Name of Each Exchange on Which Registered
Common Stock, par value $.01		New York Stock Exchange

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes þ No ¨

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes ¨ No þ

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 and (2) has been subject to such filing requirements for the past 90 days. Yes þ 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 þ No ¨

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. þ

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

Large accelerated filer þ Accelerated filer ¨ Non-accelerated filer ¨ Smaller reporting company ¨

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act). Yes ¨ No þ

The aggregate market value of Common Stock held by non-affiliates as of June 30, 2012 was approximately $15.3 billion. This amount is based on the closing price of the registrant’s Common Stock on the New York Stock Exchange on June 29, 2012. Shares of Common Stock held by executive officers and directors of the registrant are not included in the computation. The registrant, solely for the purpose of this required presentation, has deemed its directors and executive officers to be affiliates.

There were 331,433,926 shares of Marathon Petroleum Corporation Common Stock outstanding as of February 15, 2013.

Documents Incorporated By Reference

Portions of the registrant’s proxy statement relating to its 2013 Annual Meeting of Shareholders, to be filed with the Securities and Exchange Commission pursuant to Regulation 14A under the Securities Exchange Act of 1934, are incorporated by reference to the extent set forth in Part III, Items 10-14 of this report.

MARATHON PETROLEUM CORPORATION

Unless otherwise stated or the context otherwise indicates, all references in this Annual Report on Form 10-K to “MPC,” “us,” “our,” “we” or “the Company” mean Marathon Petroleum Corporation and its consolidated subsidiaries, and for periods prior to its spinoff from Marathon Oil Corporation, the Refining, Marketing & Transportation Business of Marathon Oil Corporation.

Table of Contents


			Page
PART I

	Item 1.	Business		3

	Item 1A.	Risk Factors		27

	Item 1B.	Unresolved Staff Comments		38

	Item 2.	Properties		38

	Item 3.	Legal Proceedings		38

	Item 4.	Mine Safety Disclosures		39

PART II

	Item 5.	Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities		40

	Item 6.	Selected Financial Data		41

	Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations		42

	Item 7A.	Quantitative and Qualitative Disclosures about Market Risk		73

	Item 8.	Financial Statements and Supplementary Data		76

	Item 9.	Changes in and Disagreements with Accountants on Accounting and Financial Disclosure		134

	Item 9A.	Controls and Procedures		134

	Item 9B.	Other Information		134

PART III

	Item 10.	Directors, Executive Officers and Corporate Governance		135

	Item 11.	Executive Compensation		135

	Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters		136

	Item 13.	Certain Relationships and Related Transactions, and Director Independence		136

	Item 14.	Principal Accounting Fees and Services		137

PART IV

	Item 15.	Exhibits and Financial Statement Schedules		138

		SIGNATURES		142

Disclosures Regarding Forward-Looking Statements

This Annual Report on Form 10-K, particularly Item 1. Business, Item 1A. Risk Factors, Item 3. Legal Proceedings, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations and Item 7A. Quantitative and Qualitative Disclosures about Market Risk, includes forward-looking statements. You can identify our forward-looking statements by words such as “anticipate,” “believe,” “estimate,” “expect,” “forecast,” “goal,” “intend,” “plan,” “predict,” “project,” “seek,” “target,” “could,” “may,” “should” or “would” or other similar expressions that convey the uncertainty of future events or outcomes. In accordance with “safe harbor” provisions of the Private Securities Litigation Reform Act of 1995, these statements are accompanied by cautionary language identifying important factors, though not necessarily all such factors, that could cause future outcomes to differ materially from those set forth in the forward-looking statements.

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

•

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

•

anticipated volumes of feedstock, throughput, sales or shipments of refined products;

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anticipated levels of regional, national and worldwide prices of crude oil and refined products;

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anticipated levels of crude oil and refined product inventories;

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

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

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expectations regarding the acquisition or divestiture of assets;

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our share repurchase program, including the timing and amounts of any common stock repurchases;

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the effect of restructuring or reorganization of business components;

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

•

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

We have based our forward-looking statements on our current expectations, estimates and projections about our industry and our company. We caution that these statements are not guarantees of future performance and you should not rely unduly on them, as they involve risks, uncertainties, and assumptions that we cannot predict. In addition, we have based many of these forward-looking statements on assumptions about future events that may prove to be inaccurate. While our management considers these assumptions to be reasonable, they are inherently subject to significant business, economic, competitive, regulatory and other risks, contingencies and uncertainties, most of which are difficult to predict and many of which are beyond our control. Accordingly, our actual results may differ materially from the future performance that we have expressed or forecast in our forward-looking statements. Differences between actual results and any future performance suggested in our forward-looking statements could result from a variety of factors, including the following:

•

changes in general economic, market or business conditions;

•

domestic and foreign supplies of crude oil and other feedstocks;

•

the ability of the members of the Organization of Petroleum Exporting Countries (“OPEC”) to agree on and to influence crude oil price and production controls;

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

•

foreign imports of refined products;

•

refining industry overcapacity or under capacity;

•

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

•

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

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fluctuations in consumer demand for refined products, including seasonal fluctuations;

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

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

•

changes in fuel and utility costs for our facilities;

•

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

•

the ability to successfully implement new assets and growth opportunities;

•

accidents or other unscheduled shutdowns affecting our refineries, machinery, pipelines or equipment, or those of our suppliers or customers;

•

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

•

acts of war, terrorism or civil unrest that could impair our ability to produce or transport refined products or receive feedstocks;

•

legislative or regulatory action, which may adversely affect our business or operations;

•

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

•

labor and material shortages;

•

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

•

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

•

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

•

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

•

the other factors described in Item 1A. Risk Factors.

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

PART I

Item 1. Business

Overview

Marathon Petroleum Corporation (“MPC”) was incorporated in Delaware on November 9, 2009 in connection with an internal restructuring of Marathon Oil Corporation (“Marathon Oil”). On May 25, 2011, the Marathon Oil board of directors approved the spinoff of its Refining, Marketing & Transportation Business (“RM&T Business”) into an independent, publicly traded company, MPC, through the distribution of MPC common stock to the stockholders of Marathon Oil common stock. In accordance with a separation and distribution agreement between Marathon Oil and MPC, the distribution of MPC common stock was made on June 30, 2011, with Marathon Oil stockholders receiving one share of MPC common stock for every two shares of Marathon Oil common stock held (the “Spinoff”). Following the Spinoff, Marathon Oil retained no ownership interest in MPC, and each company had separate public ownership, boards of directors and management. All subsidiaries and equity method investments not contributed by Marathon Oil to MPC remained with Marathon Oil and, together with Marathon Oil, are referred to as the “Marathon Oil Companies.” On July 1, 2011, our common stock began trading “regular-way” on the New York Stock Exchange (“NYSE”) under the ticker symbol “MPC”.

We are one of the largest independent petroleum product refiners, marketers and transporters in the United States. Our operations consist of three business segments:

•

Refining & Marketing—refines crude oil and other feedstocks at our seven refineries in the Gulf Coast and Midwest regions of the United States (including the recently acquired Galveston Bay refinery), 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 business segment and to dealers and jobbers who operate Marathon^® retail outlets;

•

Speedway—sells transportation fuels and convenience products in the retail market in the Midwest, primarily through Speedway^® convenience stores; and

•

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 LP and MPC’s retained pipeline assets and investments.

See Item 8. Financial Statements and Supplementary Data – Note 11 for operating segment and geographic financial information, which is incorporated herein by reference.

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, an allocation of BP’s Colonial Pipeline Company shipper history, four light product terminals, branded-jobber marketing contract assignments for the supply of approximately 1,200 branded sites and a 1,040 megawatt electric cogeneration facility. We refer to these assets as the “Galveston Bay Refinery and Related Assets”. The operating statistics included in this section do not include these assets. See Item 8. Financial Statements and Supplementary Data – Note 26 for additional information on the acquisition of these assets.

In 2012, we formed MPLX LP (“MPLX”), a master limited partnership, 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. On October 31, 2012, MPLX completed its initial public offering of 19,895,000 common units, which represented the sale by us of a 26.4 percent interest in MPLX. We own a 73.6

percent interest in MPLX, including the general partner interest, and we consolidate this entity for financial reporting purposes since we have a controlling financial interest. Headquartered in Findlay, Ohio, MPLX’s initial assets consist 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. We own the remaining 49 percent limited partner interest in Pipe Line Holdings. The operating statistics in this section include 100 percent of these assets for all time periods presented. See Item 8. Financial Statements and Supplementary Data – Note 4 for additional information on MPLX’s initial public offering.

On December 1, 2010, we completed the sale of most of our Minnesota assets. These assets included the 74,000 barrel per calendar day St. Paul Park refinery and associated terminals, 166 convenience stores primarily branded SuperAmerica^® (including six stores in Wisconsin) along with the SuperMom’s^® bakery (a baked goods and sandwich supply operation) and certain associated trademarks, SuperAmerica Franchising LLC, interests in pipeline assets in Minnesota and associated inventories. We refer to these assets as the “Minnesota Assets.” The operating statistics included in this section reflect the exclusion of these assets, except as otherwise indicated. See Item 8. Financial Statements and Supplementary Data – Note 7 for additional information on the disposition of these assets.

Our Competitive Strengths

High Quality Asset Base

We believe we are the largest crude oil refiner in the Midwest and the fourth largest in the United States based on crude oil refining capacity. We own a seven-plant refinery network, including our recently acquired Galveston Bay refinery, with approximately 1.7 million barrels per calendar day (“mmbpcd”) of crude oil throughput capacity. Our refineries process a wide range of crude oils, including heavy and sour crude oils, which can generally be purchased at a discount to sweet crude, and produce transportation fuels such as gasoline and distillates, specialty chemicals and other refined products.

Strategic Location

The geographic locations of our refineries and our extensive midstream distribution system provide us with strategic advantages. Located in Petroleum Administration for Defense District (“PADD”) II and PADD III, which consist of states in the Midwest and the Gulf Coast regions of the United States, our refineries have the ability to procure crude oil from a variety of supply sources, including domestic, Canadian and other foreign sources, which provides us with flexibility to optimize crude supply costs. For example, geographic proximity to Canadian crude oil supply sources allows our Midwest refineries to incur lower transportation costs than competitors transporting Canadian crude oil to the Gulf Coast for refining. Our refinery locations and midstream distribution system also allow us to access export markets and to serve a broad range of key end-user markets across the United States quickly and cost-effectively.

LOGO

*	As of December 31, 2012. Excludes the Galveston Bay Refinery and Related Assets.

Attractive Growth Opportunities through Internal Projects

We believe we have attractive growth opportunities through internal capital projects. In 2012, we completed a $2.2 billion (excluding capitalized interest) heavy oil upgrading and expansion project at our Detroit, Michigan refinery. The project enables the refinery to process additional heavy, sour crude oils, including Canadian bitumen blends, which have traded at a significant discount to light sweet crude oil, and increased the refinery’s total crude oil refining capacity by approximately 14 thousand barrels per calendar day (“mbpcd”) to 120 mbpcd.

We plan to evaluate projects that will extract additional value from this major investment at Detroit. At our Garyville, Louisiana refinery, we have initiated projects that we expect will increase our ultra-low-sulfur diesel (“ULSD”) production and expand our gasoline and distillates export capabilities. We also have projects underway at our Robinson, Illinois refinery to increase distillate yields and at our Catlettsburg, Kentucky refinery to improve gas oil recovery and reduce purchased feedstock volumes, thus reducing our feedstock costs. We are also increasing our capacity to process condensate from the Utica Shale region at our Canton, Ohio and Catlettsburg refineries.

Acquisition of Galveston Bay Refinery and Related Assets

Through our February 1, 2013 acquisition of the Galveston Bay Refinery and Related Assets, we added 451 mbpcd of crude oil refining capacity and have diversified and further balanced our network of refining assets. Our refining capacity is now balanced between three market areas, with 646 mbpcd of capacity in the Midwest, 531 mbpcd in Texas and 522 mbpcd in Louisiana. This acquisition provides us with the opportunity to capture synergies across our existing Gulf Coast operations, increases our refining capacity for specialty chemicals and is anticipated to enhance our ability to sell refined products into export markets.

Extensive Midstream Distribution Networks

We believe the relative scale of our transportation and distribution assets and operations distinguishes us from other refining and marketing companies. We currently own, lease or have ownership interests in approximately 8,300 miles of crude oil and products pipelines, including the approximate 100 miles of natural gas liquid pipelines recently acquired with the Galveston Bay Refinery and Related Assets. Through our ownership interests in MPLX and Pipe Line Holdings, we are one of the largest petroleum pipeline companies in the United States on the basis of total volume delivered. We also own one of the largest private domestic fleets of inland petroleum product barges and one of the largest terminal operations in the United States, as well as trucking and rail assets. We operate this system in coordination with our refining and marketing network, which enables us to optimize feedstock and raw material supplies and refined product distribution, and further allows for important economies of scale across our system.

General Partner and Sponsor of MPLX

Our investment in MPLX provides us an efficient vehicle to invest in organic projects and pursue acquisitions of midstream assets. MPLX’s strong liquidity and borrowing capacity provides us a strong foundation to execute our strategy for growing our midstream logistics business. Our role as the general partner allows us to maintain strategic control of the assets so we can continue to optimize our refinery feedstock and distribution networks.

Competitively Positioned Marketing Operations

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 our 1,464 Speedway^® convenience stores, which we operate through a wholly owned subsidiary, Speedway LLC, comprise the fourth largest chain of company-owned and operated retail gasoline and convenience stores in the United States. The Marathon brand is an established motor fuel brand in the Midwest and Southeast regions of the United States, and was available through approximately 5,000 retail outlets operated by jobbers and dealers in 17 states as of December 31, 2012. In addition, as part of the acquisition of the Galveston Bay Refinery and Related Assets, we were assigned retail marketing contracts for approximately 1,200 branded retail outlets that we are in the process of converting to the Marathon brand. We believe our distribution system allows us to maximize the sales value of our products and minimize cost.

Established Track Record of Profitability and Diversified Income Stream

We have demonstrated an ability to achieve positive financial results throughout all stages of the refining cycle. We believe our business mix and strategies position us well to continue to achieve competitive financial results. As shown in the following chart, income from operations attributable to the Speedway and Pipeline Transportation segments is less sensitive to business cycles while our Refining & Marketing segment enables us to generate significant income and cash flow when market conditions are more favorable.

Marathon Petroleum Corporation

Segment Income from Operations

LOGO

Strong Financial Position

As of December 31, 2012, we had $4.86 billion in cash and cash equivalents and $3.0 billion in unused committed credit facilities, excluding MPLX’s credit facility. We also had $3.36 billion of debt at year-end, which represented only 22 percent of our total capitalization. This combination of strong liquidity and manageable leverage allows us to fund our growth projects and to pursue our business strategies.

Our Business Strategies

Achieve Top-Tier Safety and Environmental Performance

We remain committed to operating our assets in a safe and reliable manner and targeting continuous improvement in our safety record across all of our operations. We have a history of safe and reliable operations, which was demonstrated with record employee and contractor safety performance across all our operations in 2012, including a world class safety record for the heavy oil upgrading and expansion project at our Detroit refinery. In addition, we remain committed to environmental stewardship by continuing to improve the efficiency of our operations while proactively meeting our regulatory requirements.

Grow Enterprise Value

We intend to grow our share price through a combination of earnings growth and return of capital to shareholders in the form of strong and growing dividends and sustained share repurchases. We have increased our quarterly dividend by 75 percent since becoming a stand-alone company in June 2011 and our board of directors has authorized share repurchases totaling $4.0 billion. We entered into two accelerated share repurchase (“ASR”) programs for a total of $1.35 billion, through which we repurchased approximately 8 percent of our outstanding common shares in 2012. After the effects of these ASR programs, $2.65 billion of the $4.0 billion total authorization is available for future repurchases.

Expand Midstream Business through MPLX

We expect there will be significant investment in infrastructure to connect growing North American crude oil production with existing refining assets and to move refined products to wholesale and retail marketing customers. We intend to aggressively participate in this infrastructure build out and MPLX will be the entity through which we expect to grow our midstream business. We intend to increase revenue on the MPLX network of pipeline systems through higher utilization of existing assets, by capitalizing on organic investment opportunities that may arise from the growth of MPC’s operations and from increased third-party activity in MPLX’s areas of operations. Through MPLX, we also plan to pursue acquisitions of midstream assets both within our existing geographic footprint and in new areas.

Deliver Top Quartile Refining Performance

Our refineries are well positioned to benefit from the growing crude oil and condensate production in North America, including the Bakken, Eagle Ford and Utica Shale regions, along with the Canadian oil sands. We are also well positioned to export distillates and other products as the demand continues to grow.

We intend to increase our earnings in the Refining & Marketing segment through organic investments and selective acquisitions, while maintaining financial discipline. For example, we recently completed a $2.2 billion investment (excluding capitalized interest) to upgrade and expand our Detroit refinery. This investment significantly expands our ability to process heavy crude oil at the Detroit refinery from about 20 mbpcd to 100 mbpcd. In February 2013, we closed on the 451 mbpcd Galveston Bay refinery. This acquisition increases our crude oil refining capacity by approximately 36 percent, diversifies the footprint of our refining assets, provides us with the opportunity to increase our export sales, and significantly increases our participation in the chemicals value chain. We will continue to evaluate opportunities to expand our existing asset base, with an emphasis on increasing distillates production and export capabilities.

Increase Assured Sales Volumes at our Marathon Brand and Speedway Locations

We consider assured sales as those sales we make to Marathon brand customers, our Speedway operations and to our wholesale customers with whom we have required minimum volume sales contracts. We believe having assured sales brings ratability to our distribution systems, provides a solid base to enhance our overall supply reliability and allows us to efficiently and effectively optimize our operations between our refineries, our pipelines and our terminals. The Marathon brand has been a consistent vehicle for sales volume growth in existing and contiguous markets. The acquisition of the Galveston Bay Refinery and Related Assets provides us with opportunities to further expand our market presence. Through the assignment of branded-jobber contracts representing approximately 1,200 retail outlets, we are in position to take advantage of opportunities with premier Southeast jobbers and to significantly expand our brand presence in the Southeast. We also intend to grow Speedway gasoline and distillates sales volumes through internal capital program growth projects and acquisitions that complement our existing store network.

Deliver Profitable Speedway Growth

We intend to grow Speedway’s sales and profitability by focusing on continuous improvement of existing operations, organic growth and strategic store acquisition opportunities. For example, the acquisition of 97 convenience stores in 2012 has increased Speedway’s presence in the Midwest. In addition, our industry-leading Speedy Rewards^® customer loyalty program, which has over three million members, provides us with a unique competitive advantage and opportunity to increase our Speedway customer base with existing and new Speedway locations.

Utilize and Expand our High Quality Employee Workforce

We plan to utilize our high quality employee workforce by continuing to leverage our commercial skills. In addition, we plan to expand our workforce through selective hiring practices and effective training programs on safety, environmental stewardship and other professional and technical skills.

The above discussion contains forward-looking statements with respect to our competitive strengths and business strategies, including our share repurchase program and pursuing potential acquisitions. There can be no assurance that we will be successful, in whole or in part, in pursuing our business strategies, including our share repurchase program or pursuing potential acquisitions. Factors that could affect the share repurchase program and its timing include, but are not limited to, business conditions, availability of liquidity and the market price of our common stock. Factors that could affect pursuing potential acquisitions include, but are not limited to, our ability to implement and realize the benefits and synergies of our strategic initiatives, availability of liquidity, actions taken by competitors, regulatory approvals and operating performance. These factors, among others, could cause actual results to differ materially from those set forth in the forward-looking statements. For additional information on forward-looking statements and risks that can affect our business, see “Disclosures Regarding Forward-Looking Statements” and Item 1A. Risk Factors in this Annual Report on Form 10-K.

Refining & Marketing

Refineries

As of December 31, 2012, we owned and operated six refineries in the Gulf Coast and Midwest regions of the United States with an aggregate crude oil refining capacity of approximately 1.25 mmbpcd. The acquisition of the Galveston Bay refinery on February 1, 2013 increased our crude oil refining capacity to approximately 1.7 mmbpcd. During 2012, our refineries processed 1,195 thousand barrels per day (“mbpd”) of crude oil and 168 mbpd of other charge and blendstocks. During 2011, our refineries processed 1,177 mbpd of crude oil and 181 mbpd of other charge and blendstocks. The table below sets forth the location, crude oil refining capacity, tank storage capacity and number of tanks for each of our refineries as of December 31, 2012.


Refinery	Crude Oil Refining Capacity (mbpcd)^(a)		Tank Shell Capacity (million barrels)		Number of Tanks

Garyville, Louisiana		522		16		75

Catlettsburg, Kentucky		240		6		112

Robinson, Illinois		206		6		103

Detroit, Michigan		120		6		86

Canton, Ohio		80		3		73

Texas City, Texas		80		5		60


Total		1,248		42		509

^(a)

Refining throughput can exceed crude oil capacity due to the processing of other feedstocks in addition to crude oil and the timing of planned turnaround and major maintenance activity.

Our refineries include crude oil atmospheric and vacuum distillation, fluid catalytic cracking, catalytic reforming, desulfurization and sulfur recovery units. The refineries process a wide variety of crude oils and produce numerous refined products, ranging from transportation fuels, such as reformulated gasolines, blend-grade gasolines intended for blending with fuel ethanol and ULSD fuel, to heavy fuel oil and asphalt. Additionally, we manufacture aromatics, propane, propylene, cumene and sulfur. Our refineries are integrated with each other via pipelines, terminals and barges to maximize operating efficiency. The transportation links that connect our refineries allow the movement of intermediate products between refineries to optimize operations, produce higher margin products and utilize our processing capacity efficiently. For example, naphtha may be moved from Texas City to Robinson where excess reforming capacity is available. Also, by shipping intermediate products between facilities during partial refinery shutdowns, we are able to utilize processing capacity that is not directly affected by the shutdown work.

Garyville, Louisiana Refinery. Our Garyville, Louisiana refinery is located along the Mississippi River in southeastern Louisiana between New Orleans and Baton Rouge. The Garyville refinery is configured to process almost any grade of crude oil into products such as gasoline, distillates, fuel-grade coke, asphalt, polymer grade propylene, propane, slurry, isobutane and sulfur. An expansion project was completed in 2009 that increased Garyville’s crude oil refining capacity, making it one of the largest refineries in the U.S. Our Garyville refinery has earned designation as a U.S. Occupational Safety and Health Administration (“OSHA”) Voluntary Protection Program (“VPP”) Star site.

Catlettsburg, Kentucky Refinery. Our Catlettsburg, Kentucky refinery is located in northeastern Kentucky on the western bank of the Big Sandy River, near the confluence with the Ohio River. The Catlettsburg refinery processes sweet and sour crude oils into products such as gasoline, distillates, asphalt, heavy fuel oil, cumene, propane, propylene and petrochemicals.

Robinson, Illinois Refinery. Our Robinson, Illinois refinery is located in southeastern Illinois. The Robinson refinery processes sweet and sour crude oils into products such as multiple grades of gasoline, distillates, propane, anode-grade coke and propylene. The Robinson refinery has earned designation as an OSHA VPP Star site.

Detroit, Michigan Refinery. Our Detroit, Michigan refinery is located in southwest Detroit. It is the only petroleum refinery currently operating in Michigan. The Detroit refinery processes light sweet and heavy sour crude oils, including Canadian crude oils, into products such as gasoline, distillates, asphalt, propylene, propane, slurry and fuel-grade coke. Our Detroit refinery earned designation as a Michigan VPP Star site in 2010. In the fourth quarter of 2012, we completed a heavy oil upgrading and expansion project that enables the refinery to process up to an additional 80 mbpd of heavy sour crude oils, including Canadian bitumen blends, and increased its total crude oil refining capacity by approximately 14 mbpcd, to 120 mbpcd.

Canton, Ohio Refinery. Our Canton, Ohio refinery is located approximately 60 miles south of Cleveland, Ohio. The Canton refinery processes sweet and sour crude oils into products such as gasoline, distillates, asphalt, roofing flux, propane and slurry.

Texas City, Texas Refinery. Our Texas City, Texas refinery is located on the Texas Gulf Coast approximately 30 miles southeast of Houston, Texas. The refinery processes light sweet crude oil into products such as gasoline, chemical grade propylene, propane, slurry and aromatics. Our Texas City refinery earned designation as an OSHA VPP Star site in 2012.

As of December 31, 2012, our refineries had 24 rail loading racks and 23 truck loading racks and three of our refineries had a total of seven owned and four non-owned docks. Total throughput in 2012 was 75 mbpd for the refinery loading racks and 499 mbpd for the refinery docks.

Planned maintenance activities, or turnarounds, requiring temporary shutdown of certain refinery operating units, are periodically performed at each refinery. See Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations for additional detail.

Refined Product Yields

The following table sets forth our refinery production (including the St. Paul Park refinery until December 1, 2010) by product group for each of the last three years.


Refined Product Yields (mbpd)	2012		2011		2010

Gasoline		738		739		726

Distillates		433		433		409

Propane		26		25		24

Feedstocks and special products		109		109		97

Heavy fuel oil		18		21		24

Asphalt		62		56		76

Total		1,386		1,383		1,356

Crude Oil Supply

We obtain the crude oil we refine through negotiated contracts and purchases or exchanges on the spot market. Our crude oil supply contracts are generally term contracts with market-related pricing provisions. The following table provides information on our sources of crude oil for each of the last three years (including the St. Paul Park refinery until December 1, 2010). The crude oil sourced outside of North America was acquired from various foreign national oil companies, production companies and trading companies.


Sources of Crude Oil Refined (mbpd)	2012		2011		2010

United States		649		668		720

Canada		195		177		115

Middle East and other international		351		332		338



Total		1,195		1,177		1,173

Average cost of crude oil throughput (dollars per barrel)		$ 102.53		$ 102.83		$ 78.57

Our refineries receive crude oil and other feedstocks and distribute our refined products through a variety of channels, including pipelines, trucks, railcars, ships and barges. During 2012, we began transporting crude oil by truck from the Utica Shale region to our Canton refinery. As of December 31, 2012, we owned four transport trucks and seven trailers for this purpose.

Refined Product Marketing

We believe we are one of the largest wholesale suppliers of gasoline and distillates to resellers and consumers within our 17-state market area in the Midwest, Gulf Coast and Southeast regions of the United States. Independent retailers, wholesale customers, our Marathon brand jobbers and Speedway brand convenience stores, airlines, transportation companies and utilities comprise the core of our customer base. In addition, we sell distillates, asphalt and gasoline for export to international customers, primarily out of our Garyville refinery. Sales destined for export comprised approximately 25 percent of our distillate sales and 13 percent of our asphalt sales in 2012.

The following table sets forth, as a percentage of total refined product sales volume, the sales of refined products to our different customer types for the past three years (including the Minnesota Assets until December 1, 2010).


Refined Product Sales by Customer Type	2012		2011		2010

Private-brand marketers, commercial and industrial customers, including spot market		72%		72%		70%

Marathon-branded dealers and jobbers		17%		17%		17%

Speedway^® convenience stores		11%		11%		13%

The following table sets forth the approximate number of retail outlets (by state) where dealers and jobbers maintain Marathon-branded retail outlets, as of December 31, 2012.


State	Approximate Number of Marathon^® Retail Outlets
Alabama		139

Florida		259

Georgia		256

Illinois		395

Indiana		647

Kentucky		576

Maryland		1

Michigan		778

Minnesota		84

North Carolina		311

Ohio		860

Pennsylvania		40

South Carolina		128

Tennessee		173

Virginia		136

West Virginia		111

Wisconsin		70

Total		4,964

The following table sets forth our refined products sales volumes by product group and our average sales price for each of the last three years (including the Minnesota Assets until December 1, 2010).


Refined Product Sales (mbpd)	2012		2011		2010
Gasoline		916		908		912

Distillates		463		459		434

Propane		27		25		24

Feedstocks and special products		112		111		103

Heavy fuel oil		19		19		23

Asphalt		62		59		77

Total		1,599		1,581		1,573


Average sales price, including consumer excise taxes (dollars per barrel)		$ 126.13		$ 123.14		$ 94.13

Gasoline and Distillates. We sell gasoline, gasoline blendstocks and distillates (including No. 1 and No. 2 fuel oils, kerosene, jet fuel and diesel fuel) to wholesale customers, Marathon-branded jobbers and dealers and our

Speedway^® convenience stores in the Midwest, Gulf Coast and Southeast regions of the United States and on the spot market. In addition, we sell diesel fuel for export to international customers. We sold 57 percent of our gasoline sales volumes and 89 percent of our distillates sales volumes on a wholesale or spot market basis in 2012. The demand for gasoline and distillates is seasonal in many of our markets, with demand typically at its highest levels during the summer months.

We have blended ethanol into gasoline for more than 20 years and began expanding our blending program in 2007, in part due to federal regulations that require us to use specified volumes of renewable fuels. Ethanol volumes sold in blended gasoline (including the Minnesota Assets until December 1, 2010) were 68 mbpd in 2012, 70 mbpd in 2011 and 68 mbpd in 2010. The future expansion or contraction of our ethanol blending program will be driven by the economics of the ethanol supply and by government regulations. We sell reformulated gasoline, which is also blended with ethanol, in parts of our marketing territory, including Kentucky, Illinois, Indiana, Wisconsin, Pennsylvania and Texas. We also sell biodiesel-blended diesel fuel in Kentucky, West Virginia, Illinois, Ohio, North Carolina, Florida, Virginia, Pennsylvania, Georgia, Minnesota and Tennessee.

We hold a 36 percent interest in an entity that owns and operates a 110-million-gallon-per-year ethanol production facility in Clymers, Indiana. We also own a 50 percent interest in an entity that owns a 110-million-gallon-per-year ethanol production facility in Greenville, Ohio. Both of these facilities are managed by a co-owner.

Propane. We produce propane at all of our refineries. Propane is primarily used for home heating and cooking, as a feedstock within the petrochemical industry, for grain drying and as a fuel for trucks and other vehicles. Our propane sales are typically split evenly between the home heating market and industrial consumers.

Feedstocks and Special Products. We are a producer and marketer of feedstocks and specialty products. Product availability varies by refinery and includes propylene, cumene, molten sulfur, toluene, benzene, xylene and dilute naphthalene oil. We market all products domestically to customers in the chemical, agricultural and fuel blending industries. In addition, we produce fuel-grade coke at our Garyville and Detroit refineries, which is used for power generation and in miscellaneous industrial applications, and anode-grade coke at our Robinson refinery, which is used to make carbon anodes for the aluminum smelting industry.

Heavy Fuel Oil. We produce and market heavy residual fuel oil or related components at all of our refineries. Heavy residual fuel oil is primarily used in the utility and ship bunkering (fuel) industries, though there are other more specialized uses of the product.

Asphalt. We have refinery-based asphalt production capacity of up to 98 mbpcd. We market asphalt through 31 owned or leased terminals throughout the Midwest and Southeast. We have a broad customer base, including asphalt-paving contractors, government entities (states, counties, cities and townships) and asphalt roofing shingle manufacturers. We sell asphalt in the domestic and export wholesale markets via rail, barge and vessel. We also produce asphalt cements, polymer modified asphalt, emulsified asphalt and industrial asphalts.

Refined Product Distribution

As of December 31, 2012, we owned and operated 61 light product and 21 asphalt terminals. The acquisition of the Galveston Bay Refinery and Related Assets on February 1, 2013 increased our number of owned and operated light product terminals to 65. Our light product and asphalt terminals averaged 1,278 mbpd and 31 mbpd of throughput in 2012, respectively. In addition, we distribute refined products through one leased light product terminal, two light product terminals in which we have partial ownership interests but do not operate and approximately 61 third-party light product and 10 third-party asphalt terminals in our market area. The following table sets forth additional details about our owned and operated terminals at December 31, 2012.


Owned and Operated Terminals	Number of Terminals		Tank Shell Capacity (thousand barrels)		Number of Tanks		Number of Loading Lanes
Light Product Terminals:
Alabama		2		404		20		4
Florida		3		1,942		54		17
Georgia		4		896		38		9
Illinois		4		1,165		45		14
Indiana		7		3,021		79		19
Kentucky		6		2,266		64		24
Louisiana		1		89		8		2
Michigan		9		2,191		85		28
North Carolina		2		451		17		6
Ohio		13		4,114		164		33
Pennsylvania		1		336		10		2
South Carolina		1		344		13		3
Tennessee		3		727		29		9
Virginia		1		276		12		2
West Virginia		2		149		10		2
Wisconsin		2		814		20		7

Subtotal light product terminals		61		19,185		668		181

Asphalt Terminals:
Florida		1		254		4		3
Illinois		2		100		9		6
Indiana		3		703		18		9
Kentucky		4		567		34		14
Louisiana		1		52		8		2
Michigan		1		12		2		8
New York		1		112		3		3
Ohio		4		1,919		46		10
Pennsylvania		1		469		14		8
Tennessee		3		951		34		12

Subtotal asphalt terminals		21		5,139		172		75

Total owned and operated terminals		82		24,324		840		256

As of December 31, 2012, our marine transportation operations included 15 towboats, as well as 177 owned and 14 leased barges that transport refined products on the Ohio, Mississippi and Illinois rivers and their tributaries and inter-coastal waterways. The following table sets forth additional details about our towboats and barges.


Class of Equipment	Number in Class		Capacity (thousand barrels)
Inland tank barges:^(a)
Less than 25,000 barrels		61		858
25,000 barrels and over		130		3,784

Total		191		4,642

Inland towboats:
Less than 2000 horsepower		2
2000 horsepower and over		13

Total		15

^(a)

All of our barges are double-hulled.

As of December 31, 2012, we owned 142 transport trucks and 150 trailers with an aggregate capacity of 1.4 million gallons for the movement of refined products. In addition, we had 1,944 leased and 27 owned railcars of various sizes and capacities for movement and storage of refined products. The following table sets forth additional details about our railcars.


	Number of Railcars
Class of Equipment	Owned		Leased		Total		Capacity per Railcar
General service tank cars		-		694		694		20,000-30,000 gallons
High pressure tank cars		-		1,041		1,041		33,500 gallons
Open-top hoppers		27		209		236		4,000 cubic feet

		27		1,944		1,971

Galveston Bay Refinery and Related Assets

Our Galveston Bay refinery, which we acquired on February 1, 2013, is located on the Texas Gulf Coast approximately 30 miles southeast of Houston, Texas. The refinery has a crude oil refining capacity of 451 mbpcd and storage tank shell capacity of approximately 16 million barrels. The refinery can process almost any grade of crude oil into products such as gasoline, distillates, fuel-grade coke, slurry, propylene, propane and aromatics. Our cogeneration facility, which supplies the Galveston Bay refinery, has 1,040 megawatts of electrical production capacity and can produce 4.6 million pounds of steam per hour.

The four light product terminals we acquired are located in Nashville, Tennessee; Charlotte, North Carolina; Selma, North Carolina and Jacksonville, Florida. The terminals have 42 storage tanks with aggregate shell capacity of 2.27 million barrels and 19 loading lanes.

The assignment of branded-jobber contracts represents approximately 1,200 retail outlets, primarily in Florida, Mississippi, Tennessee and Alabama.

Speedway

Our Speedway segment sells gasoline and merchandise through convenience stores that it owns and operates, primarily under the Speedway brand. Diesel fuel is also sold at the vast majority of these convenience stores. Speedway brand convenience stores offer a wide variety of merchandise, such as prepared foods, beverages and non-food items, including a number of private-label items. Speedy Rewards™, an industry-leading customer loyalty program, has achieved significant customer engagement over the years since its introduction in 2004. The average monthly active membership in 2012 was more than three million customers.

As of December 31, 2012, Speedway had 1,464 convenience stores in seven states. Revenues from sales of merchandise (including sales until December 1, 2010 from convenience stores we sold as part of the Minnesota Assets) totaled $3.06 billion in 2012, $2.92 billion in 2011 and $3.20 billion in 2010. The demand for gasoline is seasonal, with the highest demand usually occurring during the summer driving season. Margins from the sale of merchandise tend to be less volatile than margins from the retail sale of gasoline and diesel fuel.

As of December 31, 2012, the Speedway segment’s convenience stores were located in the following states:


State	Number of Convenience Stores
Illinois		107
Indiana		310
Kentucky		140
Michigan		301
Ohio		483
West Virginia		60
Wisconsin		63

Total		1,464

Harris Interactive’s annual Harris Poll EquiTrend^® brand equity study named Speedway the number one convenience store brand with consumers nationally for 2012 and the number one gasoline brand with consumers for each of the prior three years. For 2011, Speedway was presented with a Convenience Retailing Award from CSP Information Group, Inc., for consumer experience provided by the Speedy Rewards™ program.

Pipeline Transportation

As of December 31, 2012, we owned, leased or had ownership interests in approximately 8,200 miles of crude oil and products pipelines, of which approximately 2,900 miles are owned through our investments in MPLX and Pipe Line Holdings. The acquisition of approximately 100 miles of natural gas liquid pipelines on February 1, 2013 increased the total mile count to approximately 8,300 miles.

MPLX

In 2012, we formed MPLX, a master limited partnership, 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. On October 31, 2012, MPLX completed its initial public offering. We own a 73.6 percent interest in MPLX, including the general partner interest. MPLX’s assets consist of a 51 percent general partner interest in Pipe Line Holdings, which owns common carrier pipeline systems through Marathon Pipe Line LLC (“MPL”) and Ohio River Pipe Line LLC (“ORPL”), and a 100 percent interest in a one million barrel butane storage cavern in West Virginia. In addition, we own the remaining 49 percent limited partner interest in Pipe Line Holdings. As of December 31, 2012, Pipe Line Holdings, through MPL and ORPL, owned or leased and operated 1,004 miles of common carrier crude oil lines and 1,902 miles of common carrier products lines comprising 30 systems located in nine states and four tank farms in Illinois and Indiana with available storage capacity of 3.29 million barrels that is committed to MPC.

The table below sets forth additional detail regarding the pipeline systems and storage assets we own through Pipe Line Holdings and MPLX as of December 31, 2012.

Pipeline System or Storage Asset

Origin

Destination

Diameter
(inches)

Length
(miles)

Capacity^(a)

Associated MPC refinery

Crude oil pipeline systems (mbpd):

Patoka, IL to Lima, OH crude system

Patoka, IL

Lima, OH

20”-22”

302

290

Detroit, Canton

Catlettsburg, KY and Robinson, IL crude system

Patoka, IL

Catlettsburg, KY &
Robinson, IL

20”-24”

484

481

Catlettsburg, Robinson

Detroit, MI crude system^(b)

Samaria &
Romulus, MI

Detroit, MI

16”

320

Detroit

Wood River, IL to Patoka, IL crude system^(b)

Wood River &
Roxana, IL

Patoka, IL

12”-22”

115

307

All Midwest refineries

Inactive pipelines

N/A

Total

1,004

1,398

Products pipeline systems (mbpd):

Garyville, LA products system

Garyville, LA

Zachary, LA

20”-36”

389

Garyville

Texas City, TX products system

Texas City, TX

Pasadena, TX

16”-36”

215

Texas City

ORPL products system

Various

6”-14”

518

242

Catlettsburg, Canton

Robinson, IL products system^(b)

Various

10”-16”

1,173

545

Robinson

Louisville, KY Airport products system

Louisville, KY

6”-8”

Robinson

Inactive pipelines

N/A

Total

1,902

1,420

Wood River, IL barge dock (mbpd)

Garyville

Storage assets (thousand barrels):

Neal, WV butane cavern^(c)

1,000

Catlettsburg

Patoka, IL tank farm

1,386

All Midwest refineries

Wood River, IL tank farm

419

All Midwest refineries

Martinsville, IL tank farm

738

Detroit, Canton

Lebanon, IN tank farm

750

Detroit, Canton

Total

4,293

^(a)	All capacities reflect 100 percent of the pipeline systems’ and barge dock’s average capacity in thousands of barrels per day and 100 percent of the available storage capacity of our butane cavern and tank farms in thousand of barrels. Crude oil capacity is based on light crude oil barrels.

^(b)	Includes pipelines leased from third parties.

^(c)	The Neal, WV butane cavern is 100 percent owned by MPLX.

The Pipe Line Holdings common carrier pipeline network is one of the largest petroleum pipeline systems in the United States, based on total volume delivered. Third parties generated 14 percent of the crude oil and refined product shipments on these common carrier pipelines in 2012, excluding volumes shipped by MPC under joint tariffs with third parties. These common carrier pipelines transported the volumes shown in the following table for each of the last three years.


Pipeline Throughput (mbpd)^(a)(b)	2012		2011		2010
Crude oil pipelines		1,029		993		883
Refined products pipelines		980		1,031		968

Total		2,009		2,024		1,851

^(a)

MPLX volumes reported in MPLX’s prospectus related to its initial public offering included our undivided joint interest crude oil pipeline systems, which were not contributed to MPLX. The undivided joint interest volumes are not included above.

^(b)

Volumes represent 100 percent of the throughput through these pipelines.

MPC-Retained Assets and Investments

In addition to our 49% ownership interest in Pipe Line Holdings, we retained ownership interests in several crude oil and products pipeline systems and pipeline companies. As of December 31, 2012, we owned undivided joint interests in the following common carrier crude oil pipeline systems.

Pipeline System

Origin

Destination

Diameter
(inches)

Length
(miles)

Ownership
Interest

Operated
by MPL

Capline

St. James, LA

Patoka, IL

40”

635

Maumee

Lima, OH

Samaria, MI

22”

Total

730

MPC consolidated volumes transported through our common carrier pipelines, which include MPLX and our undivided joint interests, are shown in the following table for each of the last three years.


MPC Consolidated Pipeline Throughput (mbpd)	2012		2011		2010
Crude oil pipelines		1,190		1,184		1,204
Refined products pipelines		980		1,031		968

Total		2,170		2,215		2,172

As of December 31, 2012, we had partial ownership interests in the following pipeline companies.

Pipeline Company

Origin

Destination

Diameter
(inches)

Length
(miles)

Ownership
Interest

Operated
by MPL

Crude oil pipeline companies:

LOCAP LLC

Clovelly, LA

St. James, LA

48”

LOOP LLC

Offshore Gulf of Mexico

Clovelly, LA

48”

Total

105

Products pipeline companies:

Centennial Pipeline LLC^(a)

Beaumont, TX

Bourbon, IL

24”-26”

795

Yes

Explorer Pipeline Company

Lake Charles, LA

Hammond, IN

12”-28”

1,883

Muskegon Pipeline LLC

Griffith, IN

Muskegon, MI

10”

170

Yes

Wolverine Pipe Line Company

Chicago, IL

Bay City &
Ferrysburg, MI

6”-18”

743

Total

3,591

^(a)	Includes 48 miles of inactive pipeline.

We also own 183 miles of private crude oil pipelines and 658 miles of private refined products pipelines that are operated by MPL for the benefit of our Refining & Marketing segment on a cost recovery basis. The following table provides additional information on these assets.


Private Pipeline Systems	Diameter (inches)	Length (miles)		Capacity (mbpd)
Crude oil pipeline systems:
Lima, OH to Canton, OH	12”-16”		153		84
St. James, LA to Garyville, LA	30”		20		620
Other			2		15
Inactive pipelines			8		N/A

Total			183		719

Products pipeline systems:
Robinson, IL to Lima, OH	8”		250		18
Louisville, KY to Lexington, KY^(a)	8”		87		37
Woodhaven, MI to Detroit, MI	4”		26		11
Illinois pipeline systems	4”-8”		118		32
Ohio pipeline systems	4”-6”		61		39
Inactive pipelines			116		N/A

Total			658		137

^(a)

We own a 65 percent undivided joint interest in the Louisville, KY to Lexington, KY system.

As of December 31, 2012, we owned 60 private tanks with storage capacity of approximately 6.5 million barrels, which are located along MPLX pipelines.

Galveston Bay Refinery and Related Assets

As part of the February 1, 2013 acquisition of the Galveston Bay Refinery and Related Assets, we acquired approximately 100 miles of natural gas liquid pipelines consisting of three intrastate systems originating at the Galveston Bay refinery. The pipelines are each eight inches in diameter and have a total capacity of approximately 40 mbpd.

Competition, Market Conditions and Seasonality

The downstream petroleum business is highly competitive, particularly with regard to accessing crude oil and other feedstock supply and the marketing of refined products. We compete with a large number of other companies to acquire crude oil for refinery processing and in the distribution and marketing of a full array of petroleum products. Based upon the “The Oil & Gas Journal 2012 Worldwide Refinery Survey” and our acquisition of the Galveston Bay refinery on February 1, 2013, we ranked fourth among U.S. petroleum companies on the basis of U.S. crude oil refining capacity as of February 1, 2013. We compete in four distinct markets for the sale of refined products—wholesale, spot, branded and retail distribution. We believe we compete with about 60 companies in the sale of refined products to wholesale marketing customers, including private-brand marketers and large commercial and industrial consumers; about 80 companies in the sale of refined products in the spot market; 11 refiners or marketers in the supply of refined products to refiner-branded dealers and jobbers; and approximately 250 retailers in the retail sale of refined products. In addition, we compete with producers and marketers in other industries that supply alternative forms of energy and fuels to satisfy the requirements of our industrial, commercial and individual consumers. We do not produce any of the crude oil we refine.

We also face strong competition for sales of retail gasoline, diesel fuel and merchandise. Our competitors include service stations and convenience stores operated by fully integrated major oil companies and their dealers and jobbers and other well-recognized national or regional convenience stores and travel centers, often selling gasoline, diesel fuel and merchandise at aggressively competitive prices. Non-traditional retailers, such as supermarkets, club stores and mass merchants, have affected the convenience store industry with their entrance into the retail transportation fuel business. Energy Analysts International, Inc. estimates such retailers had 12.4 percent of the U.S. gasoline market in 2012.

Our pipeline transportation operations are highly regulated, which affects the rates that our common carrier pipelines can charge for transportation services and the return we obtain from such pipelines.

Market conditions in the oil and gas industry are cyclical and subject to global economic and political events and new and changing governmental regulations. Our operating results are affected by price changes in crude oil, natural gas and refined products, as well as changes in competitive conditions in the markets we serve. Price differentials between sweet and sour crude oil also affect our operating results.

Demand for gasoline, diesel fuel and asphalt is higher during the spring and summer months than during the winter months in most of our markets, primarily due to seasonal increases in highway traffic and construction. As a result, the operating results for each of our segments for the first and fourth quarters are generally lower than for those in the second and third quarters of each calendar year.

Environmental Matters

Our management is responsible for ensuring that our operating organizations maintain environmental compliance systems that support and foster our compliance with applicable laws and regulations, and for reviewing our overall performance associated with various environmental compliance programs. We also have a Corporate Emergency Response Team, composed primarily of senior management, which oversees our response to any major environmental or other emergency incident involving us or any of our facilities.

We believe it is likely that the scientific and political attention to issues concerning the extent and causes of climate change will continue, with the potential for further regulations that could affect our operations. Currently, various legislative and regulatory measures to address greenhouse gases are in various phases of review, discussion or implementation. The cost to comply with these laws and regulations cannot be estimated at this time, but could be significant. For additional information, see Item 1A. Risk Factors. We estimate and publicly report greenhouse gas emissions from our operations and products we produce. Additionally, we continuously strive to improve operational and energy efficiencies through resource and energy conservation where practicable and cost effective.

Our operations are also subject to numerous other laws and regulations relating to the protection of the environment. These environmental laws and regulations include, among others, the Clean Air Act with respect to air emissions, the Clean Water Act with respect to water discharges, the Resource Conservation and Recovery Act (“RCRA”) with respect to solid and hazardous waste treatment, storage and disposal, the Comprehensive Environmental Response, Compensation, and Liability Act (“CERCLA”) with respect to releases and remediation of hazardous substances and the Oil Pollution Act of 1990 (“OPA-90”) with respect to oil pollution and response. In addition, many states where we operate have similar laws. New laws are being enacted and regulations are being adopted by various regulatory agencies on a continuing basis, and the costs of compliance with any new laws and regulations are very difficult to estimate at this time.

For a discussion of environmental capital expenditures and costs of compliance for air, water, solid waste and remediation, see Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations—Environmental Matters and Compliance Costs.

Air

We are subject to substantial requirements in connection with air emissions from our operations. The U.S. Environmental Protection Agency (“EPA”) issued an “endangerment finding” in 2009 that greenhouse gas emissions contribute to air pollution that endangers public health and welfare. Related to this endangerment finding, in April 2010, the EPA finalized a greenhouse gas emissions standard for mobile sources (cars and light duty vehicles). The endangerment finding along with the mobile source standard and the EPA’s determination that greenhouse gases are subject to regulation under the Clean Air Act, and the EPA’s so-called “tailoring rule” led to permitting of larger stationary sources of greenhouse gas emissions, including refineries. Legal challenges filed against these EPA actions were overruled by the D.C. Circuit Court of Appeals, but several parties will seek further review by the U.S. Supreme Court. We also expect refinery-specific New Source Performance Standards will be proposed in 2013. Congress may again consider legislation on greenhouse gas emissions or a carbon tax. Private parties have sued utilities and other emitters of greenhouse gas emissions, but we have not been named in any of those lawsuits. Private-party litigation is also pending against federal and certain state governmental entities seeking additional greenhouse gas emission reductions beyond those currently being undertaken. Although there may be an adverse financial impact (including compliance costs, potential permitting delays and potential reduced demand for certain refined products made from crude oil) associated with any legislation, regulation, litigation or other action, the extent and magnitude of that impact cannot be reasonably estimated due to the uncertainty regarding the additional measures and how they will be implemented.

Of particular significance to our refining operations were EPA Mobile Source Air Toxics II (“MSAT II”) regulations that require reduced benzene levels in refined products. We spent approximately $620 million over a four-year period to complete all MSAT II projects, and all units were in operation as of December 31, 2011.

The EPA has reviewed and has revised or will propose to revise the National Ambient Air Quality Standards (“NAAQS”) for criteria air pollutants. The NAAQS are subject to multiple court challenges, making final compliance plans uncertain. The EPA promulgated a revised ozone standard in March 2008 and commenced a multi-year process to develop the implementing rules required by the Clean Air Act. In 2013, the EPA is expected to propose a stricter ozone standard as part of EPA’s periodic review of that standard. Also, in 2010, the EPA adopted new short-term standards for nitrogen dioxide and sulfur dioxide, and in December 2012 issued a more stringent fine particulate matter (PM 2.5) standard. We cannot reasonably estimate the final financial impact of these proposed and revised NAAQS standards until the standards are finalized, individual state implementing rules are established and judicial challenges are resolved.

In December 2012, the EPA signed final reconsideration amendments to the Boiler and Process Heater Maximum Achievable Control Technology (“Boiler MACT”) rule. This rule had been finalized in March 2011 with work practice standards that are applicable to refinery and natural gas fired equipment. While EPA retained the work practice standards for most refinery equipment, we are currently evaluating the financial impact of the Boiler MACT rule as a result of the reconsideration amendments. Further changes to the rule may occur because of potential litigation.

In 2013, the EPA is expected to propose a Refinery Sector Rule. This rule may require various refinery unit modifications, additional controls, lower emission standards and ambient air monitoring. We cannot reasonably estimate the financial impact of this rule until it is proposed and finalized.

Water

We maintain numerous discharge permits as required under the National Pollutant Discharge Elimination System program of the Clean Water Act and have implemented systems to oversee our compliance efforts. In addition, we are regulated under OPA-90, which among other requirements, requires the owner or operator of a tank vessel or a facility to maintain an emergency plan to respond to releases of oil or hazardous substances. Also, in case of any such release, OPA-90 requires the responsible company to pay resulting removal costs and damages. OPA-90 also

provides for civil penalties and imposes criminal sanctions for violations of its provisions. We have implemented emergency oil response plans for all of our components and facilities covered by OPA-90 and we have established Spill Prevention, Control and Countermeasures plans for all facilities subject to such requirements.

Additionally, OPA-90 requires that new tank vessels entering or operating in U.S. waters be double-hulled and that existing tank vessels that are not double-hulled be retrofitted or removed from U.S. service, according to a phase-out schedule. All of the barges used for river transport of our raw materials and refined products meet the double-hulled requirements of OPA-90. We operate facilities at which spills of oil and hazardous substances could occur. Some coastal states in which we operate have passed state laws similar to OPA-90, but with expanded liability provisions, including provisions for cargo owner responsibility as well as ship owner and operator responsibility.

Solid Waste

We continue to seek methods to minimize the generation of hazardous wastes in our operations. RCRA establishes standards for the management of solid and hazardous wastes. Besides affecting waste disposal practices, RCRA also addresses the environmental effects of certain past waste disposal operations, the recycling of wastes and the regulation of underground storage tanks (“USTs”) containing regulated substances. We have ongoing RCRA treatment and disposal operations at one of our facilities and primarily utilize offsite third-party treatment and disposal facilities. Ongoing RCRA-related costs, however, are not expected to be material to our results of operations or cash flows.

Remediation

We own or operate, or have owned or operated, certain retail outlets where, during the normal course of operations, releases of refined products from USTs have occurred. Federal and state laws require that contamination caused by such releases at these sites be assessed and remediated to meet applicable standards. The enforcement of the UST regulations under RCRA has been delegated to the states, which administer their own UST programs. Our obligation to remediate such contamination varies, depending on the extent of the releases and the stringency of the laws and regulations of the states in which we operate. A portion of these remediation costs may be recoverable from the appropriate state UST reimbursement funds once the applicable deductibles have been satisfied. We also have ongoing remediation projects at a number of our current and former refinery, terminal and pipeline locations. Penalties or other sanctions may be imposed for noncompliance.

Claims under CERCLA and similar state acts have been raised with respect to the clean-up of various waste disposal and other sites. CERCLA is intended to facilitate the clean-up of hazardous substances without regard to fault. Potentially responsible parties for each site include present and former owners and operators of, transporters to and generators of the hazardous substances at the site. Liability is strict and can be joint and several. Because of various factors including the difficulty of identifying the responsible parties for any particular site, the complexity of determining the relative liability among them, the uncertainty as to the most desirable remediation techniques and the amount of damages and clean-up costs and the time period during which such costs may be incurred, we are unable to reasonably estimate our ultimate cost of compliance with CERCLA; however, we do not believe such costs will be material to our business, financial condition, results of operations or cash flows.

Mileage Standards, Renewable Fuels and Other Fuels Requirements

In 2007, the U.S. Congress passed the Energy Independence and Security Act (“EISA”), which, among other things, set a target of 35 miles per gallon for the combined fleet of cars and light trucks in the United States by model year 2020, and contains a second Renewable Fuel Standard (the “RFS2”). In August 2012, the EPA and the National Highway Traffic Safety Administration jointly adopted regulations that establish average industry

fleet fuel economy standards for passenger cars and light trucks of up to 41 miles per gallon by model year 2021 and average fleet fuel economy standards of up to 49.7 miles per gallon by model year 2025 (the standards from 2022 to 2025 are the government’s current estimate but will require further rulemaking).

The RFS2 requires 16.55 billion gallons of renewable fuel usage in 2013, increasing to 36.0 billion gallons by 2022. In the near term, the RFS2 will be satisfied primarily with fuel ethanol blended into gasoline. The RFS2 presents production and logistic challenges for both the renewable fuels and petroleum refining and marketing industries. The RFS2 has required, and may in the future continue to require, additional capital expenditures or expenses by us to accommodate increased renewable fuels use.

Within the overall 36.0 billion gallon RFS2, EISA established an advanced biofuel RFS2 volume of 2.0 billion gallons in 2012 increasing to 21.0 billion gallons in 2022. Subsets within the advanced biofuel RFS2 include biomass-based diesel, which was set at 1.0 billion gallons in 2012 and at least 1.0 billion gallons in 2013 through 2022 (to be determined by the EPA through future rulemaking), and cellulosic biofuel, which was set at 0.5 billion gallons in 2012, 1.0 billion gallons in 2013, increasing to 16.0 billion gallons by 2022. The EPA established the 2013 biomass-based diesel requirement at 1.28 billion gallons. The EPA determined that 0.5 billion gallons of cellulosic biofuel would not be produced in 2012, and lowered the requirement to 8.65 million gallons. The American Petroleum Institute challenged the EPA 2012 cellulosic biofuel requirement and the D.C. Circuit Court of Appeals vacated the requirement finding that it was unlawfully determined and remanded it for further determination.

The advanced biofuels programs will present specific challenges in that we may have to enter into arrangements with other parties or purchase credits from the EPA to meet our obligations to use advanced biofuels, including biomass-based diesel and cellulosic biofuel, with potentially uncertain supplies of these new fuels. The advanced requirement for 2012 required a substantial level of Brazilian sugarcane ethanol imports since other sources of advanced renewable fuels were not available. In 2012, the EPA also discovered that 140 million biodiesel Renewable Identification Numbers (“RINs”) used to meet the annual requirement for that fuel had been fraudulently created and sold to unsuspecting third parties, including us.

We made investments in infrastructure capable of expanding biodiesel blending capability to help comply with the biodiesel RFS2 requirement by buying and blending biodiesel into our refined diesel product, and by buying needed biodiesel RINs in the EPA-created biodiesel RINs market.

On October 13, 2010, the EPA issued a partial waiver decision under the Clean Air Act to allow for an increase in the amount of ethanol permitted to be blended into gasoline from 10 percent (“E10”) to 15 percent (“E15”) for 2007 and newer light-duty motor vehicles. On January 21, 2011, the EPA issued a second waiver for the use of E15 in vehicles model year 2001-2006. There are numerous issues, including state and federal regulatory issues, which need to be addressed before E15 can be marketed for use in traditional gasoline engines.

There will be compliance costs and uncertainties regarding how we will comply with the various requirements contained in EISA and related regulations. We may experience a decrease in demand for refined petroleum products due to an increase in combined fleet mileage or due to refined petroleum products being replaced by renewable fuels.

The EPA Tier 3 gasoline rulemaking could potentially lower the allowable sulfur level in gasoline but it may also lower the Reid vapor pressure, and the allowable benzene, aromatics and olefins content of gasoline, while possibly increasing octane requirements. We anticipate a proposed rule will be issued in 2013 and plan to participate in the public comment process.

Trademarks, Patents and Licenses

Our Marathon trademark is material to the conduct of our refining and marketing operations, and our Speedway trademark is material to the conduct of our retail marketing operations. We currently hold a number of U.S. and

foreign patents and have various pending patent applications. Although in the aggregate our patents and licenses are important to us, we do not regard any single patent or license or group of related patents or licenses as critical or essential to our business as a whole. In general, we depend on our technological capabilities and the application of know-how rather than patents and licenses in the conduct of our operations.

Employees

We had approximately 25,985 regular employees as of December 31, 2012, which includes approximately 18,490 employees of Speedway. Approximately 2,025 employees were added in February 2013 associated with the Galveston Bay Refinery and Related Assets.

Certain hourly employees at our Catlettsburg, Canton, Galveston Bay and Texas City refineries are represented by the United Steel, Paper and Forestry, Rubber, Manufacturing, Energy, Allied Industrial and Service Workers Union under labor agreements that are due to expire in 2015. The International Brotherhood of Teamsters represents certain hourly employees at our Detroit refinery under a labor agreement that is scheduled to expire in January 2014.

Executive Officers of the Registrant

The executive officers of MPC and their ages as of February 1, 2013, are as follows:


Name	Age	Position with MPC
Gary R. Heminger	59	President and Chief Executive Officer

Pamela K.M. Beall	56	Vice President, Investor Relations and Government & Public Affairs

Richard D. Bedell	58	Senior Vice President, Refining

Michael G. Braddock	55	Vice President and Controller

Timothy T. Griffith	43	Vice President of Finance and Treasurer

Thomas M. Kelley	53	Senior Vice President, Marketing

Anthony R. Kenney	59	President, Speedway LLC

Rodney P. Nichols	60	Senior Vice President, Human Resources and Administrative Services

C. Michael Palmer	59	Senior Vice President, Supply, Distribution and Planning

Garry L. Peiffer	61	Executive Vice President, Corporate Planning and Investor & Government Relations

George P. Shaffner	53	Senior Vice President, Transportation and Logistics

John S. Swearingen	53	Vice President, Health, Environmental, Safety & Security

Donald C. Templin	49	Senior Vice President and Chief Financial Officer

Donald W. Wehrly	53	Vice President and Chief Information Officer

J. Michael Wilder	60	Vice President, General Counsel and Secretary

With the exception of Mr. Griffith and Mr. Templin, all of the executive officers have held responsible management or professional positions with MPC, its affiliates or prior to the Spinoff with Marathon Oil or its affiliates, for more than five years.

Mr. Heminger was appointed president and chief executive officer effective June 30, 2011. Prior to this appointment, Mr. Heminger was president of Marathon Petroleum Company LP (formerly known as Marathon Ashland Petroleum LLC and Marathon Petroleum Company LLC), currently a wholly owned subsidiary of MPC and prior to the Spinoff, a wholly owned subsidiary of Marathon Oil. He assumed responsibility as president of Marathon Petroleum Company LP in September 2001.

Ms. Beall was appointed vice president, Investor Relations and Government & Public Affairs effective June 30, 2011. Prior to this appointment, Ms. Beall was vice president, Products Supply and Optimization of Marathon Petroleum Company LP beginning in June 2010. She served as vice president of Global Procurement for Marathon Oil Company between 2007 and 2010 and prior to that as organizational vice president, Business Development—Downstream.

Mr. Bedell was appointed senior vice president, Refining effective June 30, 2011. Prior to this appointment, Mr. Bedell served in the same capacity for Marathon Petroleum Company LP beginning in June 2010 and as manager, Louisiana Refining Division beginning in 2001.

Mr. Braddock was appointed vice president and controller effective June 30, 2011. Prior to this appointment, Mr. Braddock was controller of Marathon Petroleum Company LP beginning in 2008 and manager, Internal Audit between 2005 and 2008.

Mr. Griffith was appointed vice president of Finance and treasurer effective August 1, 2011. Prior to this appointment, Mr. Griffith was vice president Investor Relations and treasurer of Smurfit-Stone Container Corporation, a packaging manufacturer, in St. Louis, Missouri, and prior to that was vice president and treasurer of Cooper-Standard Automotive, a global automotive supplier, in Novi, Michigan, from 2006 to 2008.

Mr. Kelley was appointed senior vice president, Marketing effective June 30, 2011. Prior to this appointment, Mr. Kelley served in the same capacity for Marathon Petroleum Company LP beginning in January 2010. Previously, he served as director of Crude Supply and Logistics for Marathon Petroleum Company LP from January 2008, and as a Brand Marketing manager for eight years prior to that.

Mr. Kenney has served as president of Speedway LLC since August 2005.

Mr. Nichols was appointed senior vice president, Human Resources and Administrative Services effective March 2012. Prior to this appointment, Mr. Nichols served as vice president, Human Resources and Administrative Services beginning on June 30, 2011 and served in the same capacity for Marathon Petroleum Company LP beginning in April 1998.

Mr. Palmer was appointed senior vice president, Supply Distribution and Planning effective June 30, 2011. Prior to this appointment, Mr. Palmer served as vice president, Supply Distribution & Planning for Marathon Petroleum Company LP beginning in June 2010. He served as Crude Supply and Logistics director for Marathon Petroleum Company LP beginning in February 2010, and as senior vice president, Oil Sands Operations and Commercial Activities for Marathon Oil Canada Corporation beginning in 2007.

Mr. Peiffer was appointed executive vice president of Corporate Planning and Investor & Government Relations effective June 30, 2011. Prior to this appointment, Mr. Peiffer was senior vice president of Finance and Commercial Services for Marathon Petroleum Company LP beginning in 1998.

Mr. Shaffner was appointed senior vice president, Transportation and Logistics effective June 30, 2011. Prior to this appointment, Mr. Shaffner served in the same capacity for Marathon Petroleum Company LP beginning in June 2010. Previously, Mr. Shaffner served as Michigan Refining Division manager beginning in October 2006.

Mr. Swearingen was appointed vice president of Health, Environmental, Safety & Security effective June 30, 2011. Prior to this appointment, Mr. Swearingen was president of Marathon Pipe Line LLC beginning in 2009 and the Illinois Refining Division manager beginning in November 2001.

Mr. Templin was appointed senior vice president and chief financial officer effective June 30, 2011. Prior to this appointment, Mr. Templin was a partner at PricewaterhouseCoopers LLP, an audit, tax and advisory services provider, with various audit and management responsibilities beginning in 1996.

Mr. Wehrly was appointed vice president and chief information officer effective June 30, 2011. Prior to this appointment, Mr. Wehrly was the manager of Information Technology Services for Marathon Petroleum Company LP beginning in 2003.

Mr. Wilder was appointed vice president, general counsel and secretary effective June 30, 2011. Prior to this appointment, Mr. Wilder was associate general counsel of Marathon Oil Company beginning in 2010 and general counsel and secretary of Marathon Petroleum Company LP beginning in 1997.

Available Information

General information about MPC, including Corporate Governance Principles and Charters for the Audit Committee, Compensation Committee and Corporate Governance and Nominating Committee, can be found at http://ir.marathonpetroleum.com. In addition, our Code of Business Conduct and Code of Ethics for Senior Financial Officers are also available in this same location.

MPC uses its website, www.marathonpetroleum.com, as a channel for routine distribution of important information, including news releases, analyst presentations, financial information and market data. Our Annual Report on Form 10-K, Quarterly Reports on Form 10-Q and Current Reports on Form 8-K, as well as any amendments and exhibits to those reports, are available free of charge through our website as soon as reasonably practicable after the reports are filed or furnished with the Securities and Exchange Commission. These documents are also available in hard copy, free of charge, by contacting our Investor Relations office. In addition, our website allows investors and other interested persons to sign up to automatically receive email alerts when we post news releases and financial information on our website. Information contained on our website is not incorporated into this Annual Report on Form 10-K or other securities filings.

Item 1A. Risk Factors

You should carefully consider each of the following risks and all of the other information contained in this Annual Report on Form 10-K in evaluating us and our common stock. Some of these risks relate principally to our business and the industry in which we operate, while others relate principally to our Spinoff from Marathon Oil, the ownership of our common stock and securities markets generally.

Our business, financial condition, results of operations or cash flows could be materially and adversely affected by any of these risks, and, as a result, the trading price of our common stock could decline.

Risks Relating to Our Industry and Our Business

Failure to identify and manage risks inherent in our industry could adversely impact our business.

Our business requires us to identify and manage the risks inherent to the refining, marketing and transportation business in which we operate. Our operations are subject to business interruption due to scheduled refinery turnarounds and to unplanned maintenance or events such as explosions, fires, refinery or pipeline releases or other incidents, severe weather and labor disputes. Such incidents may result in personal injury, loss of life, environmental damage, legal liability and loss of revenue. Failure to identify and manage these risks could result in explosions, fires, refinery or pipeline releases or other incidents resulting in personal injury, loss of life, environmental damage, property damage, legal liability, loss of revenue and substantial fines by governmental authorities.

A substantial or extended decline in refining and marketing gross margins would reduce our operating results and cash flows and could materially and adversely impact our future rate of growth and the carrying value of our assets.

Our operating results, cash flows, future rate of growth and the carrying value of our assets are highly dependent on the margins we realize on our refined products. The measure of the difference between market prices for refined products and crude oil, or crack spread, is commonly used by the industry as a proxy for refining and marketing gross margins. Historically, refining and marketing gross margins have been volatile and we believe they will continue to be volatile in the future. Our margins and cost of producing gasoline and other refined products are influenced by a number of conditions, including the price of crude oil. We do not produce crude oil and must purchase all of the crude oil we refine. The price of crude oil and the price at which we can sell our refined products may fluctuate independently due to a variety of regional and global market conditions. The overall change in crack spreads will impact our refining and marketing gross margins. Many of the factors influencing the change in crack spreads and refining and marketing gross margins are beyond our control. These factors include:

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worldwide and domestic supplies of and demand for crude oil and refined products;

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the cost of crude oil to be manufactured into refined products;

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the prices realized for refined products;

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utilization rates of refineries;

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natural gas and electricity supply costs incurred by refineries;

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the ability of the members of the OPEC to agree to and maintain production controls;

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political instability or armed conflict in oil and natural gas producing regions;

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local weather conditions;

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seasonality of demand in our marketing area due to increased highway traffic in the spring and summer months;

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natural disasters such as hurricanes and tornados;

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the price and availability of alternative and competing forms of energy;

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domestic and foreign governmental regulations and taxes; and

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local, regional, national and worldwide economic conditions.

Some of these factors can vary by region and may change quickly, adding to market volatility, while others may have longer-term effects. The longer-term effects of these and other factors on refining and marketing gross margins are uncertain. We purchase our crude oil and other refinery feedstocks weeks before refining them and selling the refined products. Price level changes during the period between purchasing feedstocks and selling the refined products from these feedstocks could have a significant effect on our financial results. We also purchase refined products manufactured by others for resale to our customers. Price changes during the periods between purchasing and reselling those refined products also could have a material adverse effect on our business, financial condition, results of operations and cash flows.

Lower refining and marketing gross margins may reduce the amount of refined product we produce, which may reduce our revenues, operating income and cash flows. Significant reductions in refining and marketing gross margins could require us to reduce our capital expenditures or impair the carrying value of our assets.

The availability of crude oil and increases in crude oil prices may reduce profitability and refining and marketing gross margins.

The profitability of our operations depends largely on the difference between the cost of crude oil and other feedstocks we refine and the selling prices we obtain for refined products. A portion of our crude oil is purchased from various foreign national oil companies, producing companies and trading companies, including suppliers from Canada, the Middle East and various other international locations. We are, therefore, subject to the political, geographic and economic risks attendant to doing business with suppliers located in, and supplies originating from, those areas. If one or more of our major supply sources were eliminated, or if political events disrupted our traditional crude oil supply, we believe adequate alternative supplies of crude oil would be available, but it is possible we would be unable to find alternative sources of supply. If we are unable to obtain adequate crude oil volumes or are able to obtain such volumes only at unfavorable prices, our operations, sales of refined products and refining and marketing margins could be adversely affected, materially and adversely impacting our business, financial condition, results of operations and cash flows.

Worldwide political and economic developments could materially and adversely impact our business, financial condition, results of operations and cash flows.

In addition to impacting crude oil and other feedstock supplies, political and economic factors in global markets could have a material adverse effect on us in other ways. Hostilities in the Middle East or the occurrence or threat of future terrorist attacks could adversely affect the economies of the United States (the “U.S.”) and other developed countries. A lower level of economic activity could result in a decline in energy consumption, which could cause our revenues and margins to decline and limit our future growth prospects. These risks could lead to increased volatility in prices for refined products. Additionally, these risks could increase instability in the

financial and insurance markets and make it more difficult or costly for us to access capital and to obtain the insurance coverage that we consider adequate. Additionally, tax policy, legislative or regulatory action and commercial restrictions could reduce our operating profitability. The U.S. government could prevent or restrict exports of refined products or the conduct of business with certain foreign countries.

Changes in environmental or other laws or regulations may reduce our refining and marketing gross margin and may result in substantial capital expenditures and operating costs that could materially and adversely affect our business, financial condition, results of operations and cash flows.

Various laws and regulations are expected to impose increasingly stringent and costly requirements on our operations, which may reduce our refining and marketing gross margin. Laws and regulations relating to the emission or discharge of materials into the environment, solid and hazardous waste management, pollution prevention, greenhouse gas emissions and characteristics and composition of gasoline and diesel fuels, as well as those relating to public and employee safety and health and to facility security, in particular, are expected to become more stringent. The specific impact of laws and regulations on us and our competitors may vary depending on a number of factors, including the age and location of operating facilities, marketing areas, crude oil and feedstock sources and production processes. We may be required to make expenditures to modify operations, install pollution control equipment, perform site cleanups or curtail operations that could materially and adversely affect our business, financial condition, results of operations and cash flows.

We believe the issue of climate change will likely continue to receive scientific and political attention, with the potential for further laws and regulations that could affect our operations. The U.S. pledge in 2009, as part of the Copenhagen Accord, to reduce greenhouse gas emissions 17% below 2005 levels by 2020, remains in effect. Meetings of the United Nations Climate Change Conference, however, have produced no legally binding emission reduction requirements on the U.S. Also in 2009, the EPA issued a finding that greenhouse gas emissions contribute to air pollution that endangers public health and welfare. Related to the endangerment finding, in April 2010, the EPA finalized a greenhouse gas emission standard for mobile sources (cars and other light duty vehicles). The endangerment finding, the mobile source standard and the EPA’s determination that greenhouse gases are subject to regulation under the Clean Air Act and the EPA’s so-called “tailoring rule” led to permitting of larger stationary sources of greenhouse gas emissions, including refineries. We also expect refinery-specific New Source Performance Standards will be proposed in 2013. Legal challenges were filed against these EPA actions. The D.C. Circuit Court of Appeals overruled these challenges but several parties will seek further review by the U.S. Supreme Court.

In the future, Congress may again consider legislation on greenhouse gas emissions or a carbon tax. Other measures to address greenhouse gas emissions are in various phases of review or implementation in the U.S. These measures include state actions to develop statewide or regional programs to impose emission reductions. Private party litigation is pending against federal and certain state governmental entities seeking additional greenhouse gas emission reductions beyond those currently being undertaken. These actions could result in increased costs to operate and maintain our facilities, capital expenditures to install new emission controls and costs to administer any carbon trading or tax programs implemented. Although uncertain, these developments could increase our costs, reduce the demand for the products we sell and create delays in our obtaining air pollution permits for new or modified facilities.

The EISA, among other things, sets a target of 35 miles per gallon for the combined fleet of cars and light trucks in the U.S. by model year 2020 and contains a second Renewable Fuel Standard commonly referred to as RFS2. In August 2012, the EPA and the National Highway Traffic Safety Administration jointly adopted regulations that establish average industry fleet fuel economy standards for passenger cars and light trucks of up to 41 miles per gallon by model year 2021 and of up to 49.7 miles per gallon by model year 2025 (the standards from 2022 to 2025 are the government’s current estimate but will require further rulemaking). Increases in fuel mileage standards and the increased use of renewable fuels (including ethanol and advanced biofuels) may reduce demand for refined products.

The RFS2 required the total volume of renewable transportation fuels sold or introduced annually in the U.S. to reach 15.2 billion gallons in 2012 and increases to 36.0 billion gallons by 2022. The RFS2 presents production and logistics challenges for both the renewable fuels and petroleum refining industries, and may continue to require additional capital expenditures or expenses by us to accommodate increased renewable fuels use. The advanced biofuels program, a subset of the RFS2 requirements, creates uncertainties and presents challenges of supply, and may require that we and other refiners and other obligated parties purchase credits from the EPA to meet our obligations.

Tax incentives and other subsidies have also made renewable fuels more competitive with refined products than they otherwise would have been, which may further reduce refined product margins.

The EPA Tier 3 gasoline rulemaking could potentially lower the allowable sulfur level in gasoline, but it may also lower the Reid vapor pressure, and the allowable benzene, aromatics and olefins content of gasoline, while possibly increasing octane requirements. We anticipate a proposed rule will be issued in 2013 and plan to participate in the public comment process.

We have in the past owned or operated, and currently own and operate, convenience stores and other locations with USTs in various states. The operation of USTs poses risks, including soil and groundwater contamination, at our previously or currently operated locations. Such contamination could result in substantial cleanup costs, fines or civil liabilities.

We have in the past and will continue to dispose of various wastes at lawful disposal sites. Environmental laws, including CERCLA, and similar state laws can impose liability for the entire cost of cleanup on any responsible party, without regard to negligence or fault, and impose liability on us for the conduct of others or conditions others have caused, or for our acts that complied with all applicable requirements when performed.

Any failure by us to comply with existing or future laws or regulations could result in the imposition of administrative, civil or criminal penalties, injunctions limiting our operations, investigatory or remedial liabilities or impediments to construction of additional facilities or equipment.

Compliance with and changes in tax laws could materially and adversely impact our financial performance.

We are subject to extensive tax liabilities, including federal and state income taxes and transactional taxes such as excise, sales and use, payroll, franchise, withholding and property taxes. New tax laws and regulations and changes in existing tax laws and regulations could result in increased expenditures by us for tax liabilities in the future and could materially and adversely impact our financial performance. Additionally, many tax liabilities are subject to periodic audits by taxing authorities, and such audits could subject us to interest and penalties.

Competitors that produce their own supply of feedstocks, have more extensive retail outlets or have greater financial resources may have a competitive advantage.

We do not produce any of our crude oil supply. Some of our competitors, however, obtain a significant portion of their crude oil from their own exploration and production activities. Competitors that have their own exploration and production activities may at times be able to offset losses from downstream operations with profits from upstream operations, and may be better positioned to withstand periods of depressed refined product margins or feedstock shortages.

Some of our competitors also have significantly greater financial and other resources than we have. Those competitors may have a greater ability to respond to volatile industry or market conditions, such as shortages of crude oil or other feedstocks or intense price fluctuations.

The retail market is diverse and highly competitive, and severe competition could adversely impact our business.

We also face strong competition in the market for the sale of retail gasoline, diesel and merchandise. Our competitors include outlets owned or operated by fully integrated major oil companies or their dealers or jobbers, and other well-recognized national or regional retail outlets, often selling gasoline or merchandise at very competitive prices. Several non-traditional retailers such as supermarkets, club stores and mass merchants are in the retail business. These non-traditional gasoline retailers have obtained a significant share of the transportation fuels market and we expect their market share to grow. Because of their diversity, integration of operations, experienced management and greater resources, these companies may be better able to withstand volatile market conditions or levels of low or no profitability in the retail segment of the market. In addition, these retailers may use promotional pricing or discounts, both at the pump and in the store, to encourage in-store merchandise sales. These activities by our competitors could pressure us to offer similar discounts, adversely affecting our profit margins. Additionally, the loss of market share by our convenience stores to these and other retailers relating to either gasoline or merchandise could have a material adverse effect on our business, financial condition, results of operations and cash flows.

Our operations are subject to business interruptions and casualty losses. We do not insure against all such potential losses, and, therefore, our business, financial condition, results of operations and cash flows could be adversely affected by unexpected liabilities and increased costs.

Our operations are subject to business interruption due to scheduled refinery turnarounds and to unplanned events such as explosions, fires, refinery or pipeline releases or other incidents or unplanned maintenance, severe weather and labor disputes. For example, our pipelines provide a nearly-exclusive form of transportation of crude oil to, or refined products from, some of our refineries. In such instances, a prolonged interruption in service of such a pipeline could materially and adversely affect the operations, profitability and cash flows of the connected refinery.

Our operations could result in serious personal injury or loss of human life, significant damage to property and equipment, environmental pollution, impairment of operations and substantial losses to us. Damages resulting from a catastrophic occurrence involving us or any of our assets or operations may result in our being named as a defendant in one or more lawsuits asserting potentially substantial claims or in our being assessed potentially substantial fines by governmental authorities. In addition, our information technology systems and network infrastructure are subject to unauthorized access or attack, which could result in the loss of sensitive business information, systems interruptions or the disruption of our business operations. To protect against such attempts of unauthorized access or attack, we have implemented infrastructure protection technologies and disaster recovery plans. The level of protection and disaster recovery capability varies from site to site, and there can be no guarantee such plans, to the extent they are in place, will be totally effective.

We maintain insurance coverage in amounts we believe to be prudent against many, but not all, potential liabilities arising from operating hazards. Uninsured liabilities arising from operating hazards could reduce the funds available to us for capital and investment spending and could have a material adverse effect on our business, financial condition, results of operations and cash flows. Historically, we also have maintained insurance coverage for physical damage and resulting business interruption to our major facilities, with significant self-insured retentions. In the future, we may not be able to maintain or obtain insurance of the types and amounts we desire at reasonable rates.

As a result of market conditions, premiums and deductibles for certain of our insurance coverage have increased substantially and could escalate further. Certain insurance coverage could become unavailable or available only for reduced amounts of coverage. For example, due to hurricane activity in recent years, the availability of insurance coverage for our facilities for windstorms in the Gulf of Mexico region has been reduced.

We are subject to interruptions of supply and increased costs as a result of our reliance on third-party transportation of crude oil and refined products.

We utilize the services of third parties to transport crude oil and refined products to and from our refineries. In addition to our own operational risks discussed above, we could experience interruptions of supply or increases in costs to deliver refined products to market if the ability of the pipelines or vessels to transport crude oil or refined products is disrupted because of weather events, accidents, governmental regulations or third-party actions. A prolonged disruption of the ability of a pipeline or vessels to transport crude oil or refined product to or from one or more of our refineries could have a material adverse effect on our business, financial condition, results of operations and cash flows.

If foreign ownership of our stock exceeds certain levels, we could be prohibited from operating inland river vessels, which could materially and adversely affect our business, financial condition, results of operations and cash flows.

The Shipping Act of 1916 and Merchant Marine Act of 1920, which we refer to collectively as the Maritime Laws, generally require that vessels engaged in U.S. coastwise trade be owned by U.S. citizens. Among other requirements to establish citizenship, corporations that own such vessels must be owned at least 75% by U.S. citizens. If we fail to maintain compliance with the Maritime Laws, we would be prohibited from operating vessels in the U.S. inland waters. Such a prohibition could materially and adversely affect our business, financial condition, results of operations and cash flows.

We may incur losses to our business as a result of our forward-contract activities and derivative transactions.

We currently use commodity derivative instruments and we expect to enter into these types of transactions in the future. A failure of a futures commission merchant or counterparty to perform would affect these transactions. To the extent the instruments we utilize to manage these exposures are not effective, we may incur losses related to the ineffective portion of the derivative transaction or costs related to moving the derivative positions to another futures commission merchant or counterparty once a failure has occurred.

We have substantial debt obligations, therefore our business, financial condition, results of operations and cash flows could be harmed by a deterioration of our credit profile, a decrease in debt capacity or unsecured commercial credit available to us, or by factors adversely affecting credit markets generally.

On February 1, 2011, we completed the offering of senior notes aggregating $3.0 billion in principal amount. At December 31, 2012, our total debt obligations for borrowed money and capital lease obligations was $3.36 billion. We may incur substantial additional debt obligations in the future.

Our indebtedness may impose various restrictions and covenants on us that could have material adverse consequences, including:

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increasing our vulnerability to changing economic, regulatory and industry conditions;

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limiting our ability to compete and our flexibility in planning for, or reacting to, changes in our business and the industry;

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limiting our ability to pay dividends to our stockholders;

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limiting our ability to borrow additional funds; and

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requiring us to dedicate a substantial portion of our cash flow from operations to payments on our debt, thereby reducing funds available for working capital, capital expenditures, acquisitions and other purposes.

A decrease in our debt and commercial credit capacity, including unsecured credit extended by third-party suppliers, or a deterioration in our credit profile could increase our costs of borrowing money and/or limit our access to the capital markets and commercial credit, which could materially and adversely affect our business, financial condition, results of operations and cash flows.

Historic or current operations could subject us to significant legal liability or restrict our ability to operate.

We currently are defending litigation and anticipate we will be required to defend new litigation in the future. Our operations and those of our predecessors could expose us to litigation and civil claims by private plaintiffs for alleged damages related to contamination of the environment or personal injuries caused by releases of hazardous substances from our facilities, products liability, consumer credit or privacy laws, product pricing or antitrust laws or any other laws or regulations that apply to our operations. While an adverse outcome in most litigation matters would not be expected to be material to us, in class-action litigation large classes of plaintiffs may allege damages relating to extended periods of time or other alleged facts and circumstances that could increase the amount of potential damages. Attorneys general and other government officials may pursue litigation in which they seek to recover civil damages from companies on behalf of a state or its citizens for a variety of claims, including violation of consumer protection and product pricing laws or natural resources damages. We are defending litigation of that type and anticipate that we will be required to defend new litigation of that type in the future. If we are not able to successfully defend such litigation, it may result in liability to our company that could materially and adversely affect our business, financial condition, results of operations and cash flows. We do not have insurance covering all of these potential liabilities. In addition to substantial liability, plaintiffs in litigation may also seek injunctive relief which, if imposed, could have a material adverse effect on our future business, financial condition, results of operations and cash flows.

A portion of our workforce is unionized, and we may face labor disruptions that could materially and adversely affect our business, financial condition, results of operations and cash flows.

Approximately 38 percent of our refining employees are covered by collective bargaining agreements. The contracts for the hourly refinery workers at our Detroit and Texas City refineries are scheduled to expire in January 2014 and March 2015, respectively. The contracts for the hourly refinery workers at our Canton, Catlettsburg and Galveston Bay refineries are each scheduled to expire in January 2015. These contracts may be renewed at an increased cost to us or we may experience work stoppages as a result of labor disagreements.

One of our subsidiaries acts as the general partner of a publicly traded master limited partnership, MPLX, which may involve a greater exposure to legal liability than our historic business operations.

One of our subsidiaries acts as the general partner of MPLX, a publicly traded master limited partnership. Our control of the general partner of MPLX may increase the possibility of claims of breach of fiduciary duties including claims of conflicts of interest related to MPLX. Any liability resulting from such claims could have a material adverse effect on our future business, financial condition, results of operations and cash flows.

Significant transactions, including the Galveston Bay Refinery and Related Assets acquisition, are subject to substantial risks that could adversely affect our business, financial conditions, results of operations and cash flows.

Any significant transaction, including the Galveston Bay Refinery and Related Assets acquisition, involves potential risks, including, among other things:

•

the validity of our assumptions about future synergies, revenues, capital expenditures and operating costs;

•

an inability to successfully integrate any asset or businesses we acquire;

•

a decrease in our liquidity by using a portion of our available cash or borrowing capacity under our revolving credit agreement to finance transactions;

•

a significant increase in our interest expense or financial leverage if we incur additional debt to finance transactions;

•

the assumption of unknown environmental and other liabilities, losses or costs for which we are not indemnified or for which our indemnity is inadequate;

•

the diversion of management’s attention from other business concerns; and

•

the incurrence of other significant charges, such as impairment of goodwill or other intangible assets, asset devaluation or restructuring charges.

Risks Relating to our Spinoff from Marathon Oil

We are subject to certain continuing contingent liabilities of Marathon Oil relating to taxes and other matters and to potential liabilities and temporary limitations pursuant to the tax sharing agreement we entered into with Marathon Oil that could materially and adversely affect our business, financial condition, results of operations and cash flows.

Although the Spinoff occurred in mid 2011, certain liabilities of Marathon Oil could become our obligations. For example, under the Internal Revenue Code of 1986 (the “Code”) and related rules and regulations, each corporation that was a member of the Marathon Oil consolidated tax reporting group during any taxable period or portion of any taxable period ending on or before the effective time of the Spinoff is jointly and severally liable for the federal income tax liability of the entire Marathon Oil consolidated tax reporting group for that taxable period. In connection with the Spinoff, we entered into a tax sharing agreement with Marathon Oil that allocates the responsibility for prior period taxes of the Marathon Oil consolidated tax reporting group between us and Marathon Oil. However, if Marathon Oil is unable to pay any prior period taxes for which it is responsible, we could be required to pay the entire amount of such taxes. Other provisions of federal law establish similar liability for other matters, including laws governing tax-qualified pension plans as well as other contingent liabilities.

Also pursuant to the tax sharing agreement, following the Spinoff we are responsible generally for all taxes attributable to us or any of our subsidiaries, whether accruing before, on or after the Spinoff. We also agreed to be responsible for, and indemnify Marathon Oil with respect to, all taxes arising as a result of the Spinoff (or certain internal restructuring transactions) failing to qualify as transactions under Sections 368(a) and 355 of the Code for U.S. federal income tax purposes to the extent such tax liability arises as a result of any breach of any representation, warranty, covenant or other obligation by us or certain affiliates made in connection with the issuance of the private letter ruling relating to the Spinoff or in the tax sharing agreement. In addition, we agreed to indemnify Marathon Oil for specified tax-related liabilities associated with our 2005 acquisition of the minority interest in our refining joint venture from Ashland Inc. Our indemnification obligations to Marathon Oil and its subsidiaries, officers and directors are not limited or subject to any cap. If we are required to indemnify Marathon Oil and its subsidiaries and their respective officers and directors under the tax sharing agreement, we may be subject to substantial liabilities. At this time, we cannot precisely quantify the amount of these liabilities that have been assumed pursuant to the tax sharing agreement and there can be no assurances as to their final amounts. The tax liabilities described in this paragraph could have a material adverse effect on our company.

Under the tax sharing agreement we could be limited for a period of time in our ability to pursue certain strategic or capital raising transactions. In addition, under some circumstances, we could be liable for any adverse tax consequences resulting from engaging in such transactions. Even if the Spinoff’s status as a tax-free distribution under Section 355 of the Code remains intact, the Spinoff may result in significant U.S. federal income tax

liabilities to Marathon Oil under applicable provisions of the Code if 50 percent or more of Marathon Oil’s stock or our stock is treated as having been acquired, directly or indirectly, by one or more persons as part of a plan that includes the Spinoff. Under those provisions, any acquisitions of Marathon Oil stock or our stock (or similar acquisitions), or any understanding, arrangement or substantial negotiations regarding an acquisition of Marathon Oil stock or our stock (or similar acquisitions), within two years before or after the Spinoff are subject to special scrutiny. The process for determining whether an acquisition triggering those provisions has occurred is complex, inherently factual and subject to interpretation of the facts and circumstances of a particular case. If a direct or indirect acquisition of Marathon Oil stock or our stock resulted in a change in control as contemplated by those provisions, Marathon Oil (but not its stockholders) would recognize a taxable gain.

Under the tax sharing agreement, there are also restrictions on our ability to take actions that could cause the separation to fail to qualify as a tax-free distribution, and we are required to indemnify Marathon Oil against any such tax liabilities attributable to actions taken by or with respect to us or any of our affiliates, or any person that, after the Spinoff, is our affiliate. We may be similarly liable if we breach certain other representations or covenants set forth in the tax sharing agreement. We are also subject to restrictions on our ability to issue shares of our stock without satisfying certain conditions within the tax sharing agreement. As a result of the foregoing, we may be unable to engage in strategic or capital raising transactions that our stockholders might consider favorable, or to structure potential transactions in the manner most favorable to us, without adverse tax consequences, if at all.

The Spinoff could be determined not to qualify as a tax-free transaction, and Marathon Oil and its stockholders could be subject to material amounts of taxes and, in certain circumstances, we could be required to indemnify Marathon Oil for material taxes pursuant to indemnification obligations under the tax sharing agreement.

Marathon Oil received a private letter ruling from the Internal Revenue Service (the “IRS”), to the effect that, among other things, the distribution of shares of MPC common stock in the Spinoff qualifies as tax-free to Marathon Oil, us and Marathon Oil stockholders for U.S. federal income tax purposes under Sections 355 and 368(a) and related provisions of the Code. If the factual assumptions or representations made in the private letter ruling request are inaccurate or incomplete in any material respect, then Marathon Oil would not be able to continue to rely on the ruling. We are not aware of any facts or circumstances that would cause the assumptions or representations that were relied on in the private letter ruling to be inaccurate or incomplete in any material respect. If, notwithstanding receipt of the private letter ruling, the Spinoff were determined not to qualify under Section 355 of the Code, Marathon Oil would be subject to tax as if it had sold its shares of common stock of our company in a taxable sale for their fair market value and would recognize a taxable gain in an amount equal to the excess of the fair market value of such shares over its tax basis in such shares.

With respect to taxes and other liabilities that could be imposed on Marathon Oil in connection with the Spinoff (and certain related transactions) as a result of a final determination that is inconsistent with the anticipated tax consequences as set forth in the private letter ruling, we would be liable to Marathon Oil under the tax sharing agreement for any such taxes or liabilities attributable to actions taken by or with respect to us, any of our affiliates, or any person that, after the Spinoff, is our affiliate. We may be similarly liable if we breach specified representations or covenants set forth in the tax sharing agreement. If we are required to indemnify Marathon Oil for taxes incurred as a result of the Spinoff (or certain related transactions) being taxable to Marathon Oil, it would have a material adverse effect on our business, financial condition, results of operations and cash flows.

We have potential liabilities pursuant to the separation and distribution agreement we entered into with Marathon Oil in connection with the Spinoff that could materially and adversely affect our business, financial condition, results of operations and cash flows.

In connection with the Spinoff, we entered into a separation and distribution agreement with Marathon Oil that provides for, among other things, the principal corporate transactions that were required to affect the Spinoff, certain conditions to the Spinoff and provisions governing the relationship between our company and Marathon

Oil with respect to and resulting from the Spinoff. Among other things, the separation and distribution agreement provides for indemnification obligations designed to make us financially responsible for substantially all liabilities that may exist relating to our downstream business activities, whether incurred prior to or after the Spinoff, as well as certain obligations of Marathon Oil assumed by us. Our obligations to indemnify Marathon Oil under the circumstances set forth in the separation and distribution agreement could subject us to substantial liabilities. Marathon Oil also agreed to indemnify us for certain liabilities. However, third parties could seek to hold us responsible for any of the liabilities retained by Marathon Oil and there can be no assurance that the indemnity from Marathon Oil will be sufficient to protect us against the full amount of such liabilities, that Marathon Oil will be able to fully satisfy its indemnification obligations or that Marathon Oil’s insurers will cover us for liabilities associated with occurrences prior to the Spinoff. Moreover, even if we ultimately succeed in recovering from Marathon Oil or it insurers any amounts for which we are held liable, we may be temporarily required to bear these losses ourselves. If Marathon Oil is unable to satisfy its indemnification obligations, the underlying liabilities could have a material adverse effect on our business, financial condition, results of operations and cash flows.

Risks Relating to Ownership of Our Common Stock

Provisions in our corporate governance documents could operate to delay or prevent a change in control of our company, dilute the voting power or reduce the value of our capital stock or affect its liquidity.

The existence of some provisions within our restated certificate of incorporation and amended and restated bylaws could discourage, delay or prevent a change in control of us that a stockholder may consider favorable. These include provisions:

•

providing that our board of directors fixes the number of members of the board;

•

providing for the division of our board of directors into three classes with staggered terms;

•

providing that only our board of directors may fill board vacancies;

•

limiting who may call special meetings of stockholders;

•

prohibiting stockholder action by written consent, thereby requiring stockholder action to be taken at a meeting of the stockholders;

•

establishing advance notice requirements for nominations of candidates for election to our board of directors or for proposing matters that can be acted on by stockholders at stockholder meetings;

•

establishing supermajority vote requirements for certain amendments to our restated certificate of incorporation and stockholder proposals for amendments to our amended and restated bylaws;

•

providing that our directors may only be removed for cause;

•

authorizing a large number of shares of common stock that are not yet issued, which would allow our board of directors to issue shares to persons friendly to current management, thereby protecting the continuity of our management, or which could be used to dilute the stock ownership of persons seeking to obtain control of us; and

•

authorizing the issuance of “blank check” preferred stock, which could be issued by our board of directors to increase the number of outstanding shares and thwart a takeover attempt.

We believe these provisions protect our stockholders from coercive or otherwise unfair takeover tactics by requiring potential acquirers to negotiate with our board of directors and by providing our board of directors time

to assess any acquisition proposal, and are not intended to make us immune from takeovers. However, these provisions apply even if the offer may be considered beneficial by some stockholders and could delay or prevent an acquisition that our board of directors determines is not in the best interests of us and our stockholders.

Our restated certificate of incorporation also authorizes us to issue, without the approval of our stockholders, one or more classes or series of preferred stock having such designation, powers, preferences and relative, participating, optional and other special rights, including preferences over our common stock respecting dividends and distributions, as our board of directors generally may determine. The terms of one or more classes or series of preferred stock could dilute the voting power or reduce the value of our common stock. For example, we could grant holders of preferred stock the right to elect some number of our board of directors in all events or on the happening of specified events or the right to veto specified transactions. Similarly, the repurchase or redemption rights or liquidation preferences we could assign to holders of preferred stock could affect the residual value of our common stock.

Finally, to facilitate compliance with the Maritime Laws, our restated certificate of incorporation limits the aggregate percentage ownership by non-U.S. citizens of our common stock or any other class of our capital stock to 23 percent of the outstanding shares. We may prohibit transfers that would cause ownership of our common stock or any other class of our capital stock by non-U.S. citizens to exceed 23 percent. Our restated certificate of incorporation also authorizes us to effect any and all measures necessary or desirable to monitor and limit foreign ownership of our common stock or any other class of our capital stock. These limitations could have an adverse impact on the liquidity of the market for our common stock if holders are unable to transfer shares to non-U.S. citizens due to the limitations on ownership by non-U.S. citizens. Any such limitation on the liquidity of the market for our common stock could adversely impact the market price of our common stock.

Item 1B. Unresolved Staff Comments

None.

Item 2. Properties

The location and general character of our refineries, convenience stores, pipeline systems and other important physical properties have been described by segment under Item 1. Business and are incorporated herein by reference. The plants and facilities have been constructed or acquired over a period of years and vary in age and operating efficiency. In addition, we believe that our properties and facilities are adequate for our operations and that our facilities are adequately maintained. As of December 31, 2012, we were the lessee under a number of cancellable and noncancellable leases for certain properties, including land and building space, office equipment, storage facilities and transportation equipment. See Item 8. Financial Statements and Supplementary Data – Note 24 for additional information regarding our leases.

Item 3. 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. Some of these matters are discussed below.

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.

Kentucky Emergency Pricing Litigation

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

Environmental Proceedings

During 2001, we entered into a New Source Review consent decree and settlement of alleged Clean Air Act and other violations with the EPA covering our refineries. The settlement committed us to specific control technologies and implementation schedules for environmental expenditures and improvements to our refineries, which are now complete. We are working with the EPA to terminate the New Source Review consent decree.

In January 2011, the EPA notified us of 18 alleged violations of various statutory and regulatory provisions related to motor fuels, some of which we had previously self-reported to the EPA. No formal enforcement action has been commenced and no demand for penalties has been asserted by the EPA in connection with these alleged violations. However, it is possible that the EPA could seek penalties in excess of $100,000 in connection with one or more of the alleged violations.

We have been subject to a pending enforcement matter with the Illinois Environmental Protection Agency (“IEPA”) and the Illinois attorney general’s office since 2002 concerning self-reporting of possible emission exceedences and permitting issues related to storage tanks at the Robinson, Illinois refinery. It is possible the IEPA could seek penalties in excess of $100,000 in connection with this matter.

On January 3, 2013, the Louisiana Department of Environmental Quality (“LDEQ”) issued a consolidated compliance order and notice of potential penalty alleging violations related to self-reported air emission events occurring at our Garyville, Louisiana refinery between the years of 2005 and 2011. It is possible the LDEQ could seek penalties in excess of $100,000 in connection with this matter.

In January 2013, the EPA notified our subsidiary, Marathon Pipe Line LLC, of alleged Clean Air Act violations pertaining to a 2011 audit of our Woodhaven, Michigan facility. The resolution of this matter may result in a penalty in excess of $100,000.

We are involved in a number of other environmental enforcement matters 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 each of these other matters is not likely to result in a penalty in excess of $100,000 and that collectively, the environmental proceedings described above and these other environmental enforcement matters will not have a material adverse effect on our consolidated results of operations, financial position or cash flows.

Item 4. Mine Safety Disclosures

Not applicable.

PART II

Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities

Our common stock is listed on the NYSE and traded under the symbol “MPC”. As of February 15, 2013, there were 41,830 registered holders of our common stock.

The following table reflects intraday high and low sales prices of and dividends declared on our common stock by quarter since July 1, 2011, the date on which our stock began trading “regular-way” on the NYSE:


	2012						2011
Dollars per share	High Price		Low Price		Dividends		High Price		Low Price		Dividends
Quarter 1	$	45.42	$	30.24	$	0.25	$	-	$	-	$	-
Quarter 2		45.35		33.66		0.25		-		-		-
Quarter 3		56.22		42.60		0.35		47.43		26.35		0.20
Quarter 4		63.44		52.36		0.35		39.55		26.61		0.25
Year		63.44		30.24		1.20

Dividends

Our board of directors intends to declare and pay dividends on our common stock based on our financial condition and consolidated results of operations. On January 30, 2013, our board of directors approved a 35 cents per share dividend, payable March 11, 2013 to stockholders of record at the close of business on February 20, 2013.

Dividends on our common stock are limited to our legally available funds.

Issuer Purchases of Equity Securities

The following table sets forth a summary of our purchases during the quarter ended December 31, 2012, 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)
10/01/12 - 10/31/12		199	$	55.07		-	$	1,150,000,000
11/01/12 - 11/30/12		7,404,073	$	53.89		7,403,294		650,000,000
12/01/12 - 12/31/12		1,155	$	58.69		-		650,000,000

Total		7,405,427	$	56.60		7,403,294

^(a)

The amounts in this column include 199, 779 and 1,155 shares of our common stock delivered by employees to MPC, upon vesting of restricted stock, to satisfy tax withholding requirements in October, November and December, respectively.

^(b)

“Average Price Paid per Share” reflects the weighted average price paid for shares tendered to us in satisfaction of employee tax withholding obligations upon the vesting of restricted stock granted under our stock plans. See footnote (c) below for details on the average price paid per share under our accelerated share repurchase, or ASR, program.

^(c)

On February 1, 2012, we announced that our board of directors authorized a share repurchase plan, enabling us to purchase up to $2.0 billion of our common stock over a two-year period to expire on January 31, 2014. On February 3, 2012, we entered into an ASR program and paid $850 million to purchase our common stock. We received 20,357,380 shares of our common stock under this program and concluded the program on July 25, 2012. On November 5, 2012, we entered into a second ASR program, representing a second tranche of share repurchases under the share repurchase authorization, and paid $500 million to purchase our common stock. Pursuant to the second ASR program, we received 7,403,294 shares of our common stock on November 5, 2012. On February 5, 2013, an additional 870,947 shares of our common stock were delivered to us, for a total of 8,274,241 repurchased shares, which concluded the second ASR program. Upon final settlement, the average per share cost for all shares purchased under the second ASR program was $60.43. The total value of share repurchases pursuant to the two ASR programs implemented by MPC in 2012 is $1.35 billion, with $650 million remaining under the initial authorization. On January 30, 2013, our board of directors extended the existing $650 million repurchase authorization and approved a new $2.0 billion repurchase authorization, both to expire on December 31, 2014. Consequently, as of January 30, 2013, we had a total outstanding share repurchase authorization of $2.65 billion through December 2014.

Item 6. Selected Financial Data


	Year Ended December 31,
(In millions, except per share data)	2012			2011			2010 ^(a)			2009 ^(a)			2008 ^(a)
Statements of Income Data
Revenues	$	82,243		$	78,638		$	62,487		$	45,530		$	64,939
Income from operations		5,347			3,745			1,011			654			1,855
Net income		3,393			2,389			623			449			1,215
Net income attributable to MPC		3,389			2,389			623			449			1,215

Per Share Data^(b)
Basic:
Net income attributable to MPC per share	$	9.95		$	6.70		$	1.75		$	1.26		$	3.41
Diluted:
Net income attributable to MPC per share	$	9.89		$	6.67		$	1.74		$	1.25		$	3.39

Dividends per share	$	1.20		$	0.45			-			-			-

Statements of Cash Flows Data
Net cash provided by operating activities	$	4,492		$	3,309		$	2,217		$	2,455		$	684
Additions to property, plant and equipment		(1,369	)		(1,185	)		(1,217	)		(2,891	)		(2,787	)
Dividends paid		(407	)		(160	)		-			-			-

	December 31,
(In millions)	2012			2011			2010			2009			2008
Balance Sheets Data
Total assets	$	27,223		$	25,745		$	23,232		$	21,254		$	18,177
Long-term debt, including capitalized leases^(c)		3,361			3,307			279			254			182
Long-term debt payable to Marathon Oil and subsidiaries^(d)		-			-			3,618			2,358			2,343

^(a)

On December 1, 2010, we disposed of our Minnesota Assets. All periods prior to the disposition include amounts for those operations.

^(b)

The number of weighted average shares for 2012 reflects the impact of shares repurchased under our share repurchase plan. For comparative purposes and to provide a more meaningful calculation, for basic weighted average shares we assumed the 356 million shares distributed to Marathon Oil stockholders in conjunction with the Spinoff were outstanding as of the beginning of each period prior to the Spinoff. In addition, for dilutive weighted average share calculations, we assumed the 358 million dilutive securities outstanding at June 30, 2011 were also outstanding for each period prior to the Spinoff.

^(c)

Includes amounts due within one year. During 2011, we issued $3.0 billion in senior notes, which replaced a portion of the debt payable to Marathon Oil and subsidiaries.

^(d)

Includes amounts due within one year owed to Marathon Oil and subsidiaries, which were repaid prior to the Spinoff.

Item 7:

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 information included under Item 1. Business, Item 1A. Risk Factors, Item 6. Selected Financial Data and Item 8. Financial Statements and Supplementary Data.

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,” “expect,” “forecast,” “goal,” “intend,” “plan,” “predict,” “project,” “seek,” “target,” “could,” “may,” “should” or “would” or other similar expressions that convey the uncertainty of future events or outcomes. In accordance with “safe harbor” provisions of the Private Securities Litigation Reform Act of 1995, these statements are accompanied by cautionary language identifying important factors, though not necessarily all such factors, which could cause future outcomes to differ materially from those set forth in forward-looking statements.

The Spinoff and Basis of Presentation

On May 25, 2011, the Marathon Oil board of directors approved the spinoff of its RM&T Business into an independent, publicly traded company, MPC, through the distribution of MPC common stock to the stockholders of Marathon Oil common stock. In accordance with a separation and distribution agreement between Marathon Oil and MPC, the distribution of MPC common stock was made on June 30, 2011, with Marathon Oil stockholders receiving one share of MPC common stock for every two shares of Marathon Oil common stock held. Following the Spinoff, Marathon Oil retained no ownership interest in MPC, and each company had separate public ownership, boards of directors and management. On July 1, 2011, our common stock began trading “regular-way” on the NYSE under the ticker symbol “MPC”.

Prior to the Spinoff on June 30, 2011, our results of operations and cash flows consisted of the RM&T Business, which represented a combined reporting entity. Subsequent to the Spinoff, our results of operations and cash flows consist of consolidated MPC activities. All significant intercompany transactions and accounts have been eliminated. The consolidated statements of income for periods prior to the Spinoff include expense allocations for certain corporate functions historically performed by the Marathon Oil Companies, including allocations of general corporate expenses related to executive oversight, accounting, treasury, tax, legal, procurement and information technology. Those allocations were based primarily on specific identification, headcount or computer utilization. Our management believes the assumptions underlying the consolidated financial statements, including the assumptions regarding allocating general corporate expenses from the Marathon Oil Companies, are reasonable. However, the consolidated financial statements do not include all of the actual expenses that would have been incurred had we been a stand-alone company during those periods presented prior to the Spinoff and may not reflect our consolidated results of operations and cash flows had we been a stand-alone company during the periods presented. Actual costs that would have been incurred if we had been a stand-alone company would depend on multiple factors, including organizational structure and strategic decisions made in various areas, including information technology and infrastructure. Subsequent to the Spinoff, we are performing these functions using internal resources or services provided by third parties, certain of which were provided by the Marathon Oil Companies during a transition period pursuant to a transition services agreement, which terminated June 30, 2012.

Corporate Overview

We are an independent petroleum refining, marketing and transportation company. As of December 31, 2012, we owned and operated six refineries, all located in the United States, with an aggregate crude oil refining capacity of approximately 1.25 mmbpcd. The acquisition of the Galveston Bay refinery on February 1, 2013 increased our crude oil refining capacity to approximately 1.7 mmbpcd. Our refineries supply refined products to resellers and

consumers within our market areas, including the Midwest, Gulf 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. As of December 31, 2012, we owned, leased or had ownership interests in approximately 8,200 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. The acquisition of approximately 100 miles of natural gas liquid pipelines on February 1, 2013 increased our pipeline mileage to approximately 8,300 miles. 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 they offer. See Item 1. Business for additional information on our segments.

•

Speedway—sells transportation fuels and convenience products in the retail market in the Midwest, primarily through Speedway^® convenience stores; and

•

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.

Net income attributable to MPC was $3.39 billion, or $9.89 per diluted share, in 2012 compared to $2.39 billion, or $6.67 per diluted share, in 2011. The increase was primarily due to our Refining & Marketing segment operations, which generated income from operations of $5.10 billion in 2012 compared to $3.59 billion in 2011. The increase in Refining & Marketing segment income from operations was due to an improved refining and marketing gross margin, which was primarily a result of larger Light Louisiana Sweet crude oil (“LLS”) 6-3-2-1 crack spreads and wider sweet/sour differentials.

In 2012, we completed a $2.2 billion (excluding capitalized interest) heavy oil upgrading and expansion project at our Detroit refinery. This project increased the refinery’s heavy crude oil refining capacity from 20 mbpcd to 100 mbpcd, allowing it to process more heavy, sour crude oils, including Canadian bitumen blends, which have traded at a significant discount to light sweet crude oil. In addition, the project increased the refinery’s total crude oil refining capacity by approximately 14 mbpcd to 120 mbpcd. We also continued to optimize our other refineries in 2012, which includes increasing our Garyville refinery crude oil refining capacity from 490 mbpcd to 522 mbpcd as of December 31, 2012.

Our Speedway segment generated income from operations of $310 million for 2012 compared to $271 million for 2011. The increase in 2012 was primarily due to increases in our merchandise gross margin and our gasoline and distillates gross margin, partially offset by higher expenses associated with an increase in the number of convenience stores.

In 2012, Speedway LLC acquired 10 convenience stores located in the northern Kentucky and southwestern Ohio regions from Road Ranger LLC in exchange for cash and a truck stop location in the Chicago metropolitan area and 87 convenience stores situated throughout Indiana and Ohio from GasAmerica Services, Inc. These acquisitions support our strategic initiative to increase Speedway segment sales and complement our existing network of assets.

Our Pipeline Transportation segment generated income from operations of $216 million for 2012 compared to $199 million for 2011. The increase primarily reflects higher transportation tariffs, partially offset by higher mechanical integrity expenses and a reduction in income from a pipeline affiliate.

On February 1, 2013, we acquired from BP the 451,000 barrel per calendar day Texas City, Texas refinery, three intrastate natural gas liquid pipelines originating at the refinery, an allocation of BP’s Colonial Pipeline Company shipper history, four light product terminals, branded-jobber marketing contract assignments for the supply of approximately 1,200 branded sites and a 1,040 megawatt electric cogeneration facility. We refer to these assets as the “Galveston Bay Refinery and Related Assets”. The financial results and operating statistics included in this section do not include these assets. See Item 8. Financial Statements and Supplementary Data – Note 26 for additional information on the acquisition of these assets.

In 2012, we formed MPLX, a master limited partnership, 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. On October 31, 2012, MPLX completed its initial public offering of 19,895,000 common units, which represented the sale by us of a 26.4 percent interest in MPLX. We own a 73.6 percent interest in MPLX, including the general partner interest, and we consolidate this entity for financial reporting purposes since we have a controlling financial interest. Headquartered in Findlay, Ohio, MPLX’s initial assets consist of a 51 percent general partner interest in 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. We own the remaining 49 percent limited partner interest in Pipe Line Holdings. The financial results and operating statistics in this section include 100 percent of these assets for all time periods presented. See Item 8. Financial Statements and Supplementary Data – Note 4 for additional information on MPLX’s initial public offering.

In 2012, we signed a letter of intent with Harvest Pipeline Company, agreeing to jointly develop infrastructure that will facilitate transportation of hydrocarbon liquids production from the Utica Shale in eastern Ohio and western Pennsylvania. The proposed project is expected to result in up to 24,000 barrels per day of truck unloading capacity and a terminal capable of loading up to 50,000 barrels per day onto barges on the Ohio River at our Wellsville, Ohio asphalt terminal.

In 2012, to increase access to Bakken and Canadian crude oil, we agreed to be the anchor shipper on Enbridge Inc.’s proposed Southern Access Extension pipeline with an option to acquire a 25 percent equity interest in the pipeline. This line will originate in Flanagan, Illinois near Chicago and terminate in Patoka, Illinois, a critical crude storage and blending hub and the origination point for crude supply to our four Midwest refineries.

On February 1, 2012, we announced that our board of directors authorized a share repurchase plan, enabling us to purchase up to $2.0 billion of MPC common stock over a two-year period. We entered into two ASR programs in 2012 to repurchase shares of MPC common stock totaling $1.35 billion. We received 27,760,674 shares under these programs in 2012 and 870,947 shares in February 2013. On January 30, 2013, we announced that our board of directors approved an additional $2.0 billion share repurchase authorization. The board also extended the remaining $650 million share repurchase authorization announced on February 1, 2012, for a total outstanding authorization of $2.65 billion through December 2014.

In 2012, we entered into a five-year revolving credit agreement with an initial borrowing capacity of $2.0 billion and terminated our previous four-year revolving credit agreement. We subsequently amended this agreement to increase the borrowing capacity to $2.5 billion, which became effective in February 2013 in conjunction with the acquisition of the Galveston Bay Refinery and Related Assets. Also in 2012, MPLX Operations LLC, an affiliate of MPC and wholly-owned subsidiary of MPLX, entered into a five-year senior unsecured revolving credit agreement with an initial borrowing loan capacity of $500 million that became effective at the time of MPLX’s initial public offering. The agreement provides MPLX with an independent source of liquidity.

As of December 31, 2012, we had cash and cash equivalents of $4.86 billion and no borrowings or letters of credit outstanding under MPC’s revolving credit agreement or trade receivables securitization facility or MPLX’s revolving credit agreement.

On December 1, 2010, we completed the sale of the Minnesota Assets. These assets included the 74,000 barrel per calendar day St. Paul Park refinery and associated terminals, 166 convenience stores primarily branded SuperAmerica^® (including six stores in Wisconsin) along with the SuperMom’s bakery and commissary (a baked goods and sandwich supply operation) and certain associated trademarks, SuperAmerica Franchising LLC, interests in pipeline assets in Minnesota and associated inventories. Our financial results and operating statistics for all periods prior to the disposition include amounts for the Minnesota Assets.

The above discussion includes forward-looking statements that relate to our expectations with respect to the proposed project with Harvest Pipeline Company and the share repurchase plan. Factors that could affect the proposed project with Harvest Pipeline Company include, but are not limited to, our ability to reach a definitive agreement with Harvest Pipeline Company and the timing and extent of hydrocarbon liquids production and demand from the Utica Shale. Factors that could affect the share repurchase plan and its timing 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 and marketing gross margin and refinery throughputs.

Our refining and 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, the costs of purchased products and manufacturing expenses, including depreciation and amortization. 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 U.S. Gulf Coast (“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 3 percent sulfur residual fuel) are used for these crack-spread calculations.

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

Historically, WTI has traded at prices similar to LLS. During 2012 and 2011, WTI traded at prices significantly less than LLS, which favorably impacted our refining and marketing gross margin. The logistical constraints in the U.S. mid-continent markets have prevented the price of WTI from rising with the prices of crude oil produced in other regions. Future differentials will be dependent on changes made to the logistical infrastructure.

The following table provides sensitivities showing the estimated change in annual net income, including the impact of the Galveston Bay refinery, 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)	$	425

Sweet/sour differential sensitivity^(b) (per $1.00/barrel change)		225

LLS-WTI spread sensitivity^(c) (per $1.00/barrel change)		75

Natural gas price sensitivity (per $1.00/million British thermal unit change)		140

^(a)

Weighted 38% Chicago and 62% 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% of crude oil throughput volumes are WTI-based domestic crude oil.

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

•

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

•

the selling prices realized for refined products;

•

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

•

the cost of products purchased for resale; and

•

changes in manufacturing costs, which include depreciation and amortization.

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. The following table lists the refineries that had significant planned turnaround and major maintenance activities for each of the last three years.


Year		Refinery

2012		Catlettsburg, Detroit, Garyville and Robinson

2011		Canton and Catlettsburg

2010		Catlettsburg, Detroit, Garyville, Robinson and Texas City

The table below sets forth the location and daily crude oil refining capacity of each of our refineries at December 31 of each year. The acquisition of the Galveston Bay refinery (not shown below) on February 1, 2013 increased our crude oil refining capacity to approximately 1.7 mmbpcd.


	Crude Oil Refining Capacity (mbpcd)
Refinery	2012		2011		2010

Garyville, Louisiana		522		490		464

Catlettsburg, Kentucky		240		233		212

Robinson, Illinois		206		206		206

Detroit, Michigan		120		106		106

Canton, Ohio		80		78		78

Texas City, Texas		80		80		76


Total		1,248		1,193		1,142

Speedway

Our retail marketing gross margin for gasoline and distillates, 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 distillates demand throughout the year, including local competition, seasonal demand fluctuations, the available wholesale supply, the level of economic activity in our marketing areas and weather conditions. The demand for gasoline in the Midwest region is estimated to have declined by less than half a percent in 2012 after decreasing by more than two percent in 2011. Stronger economic growth supported demand, but was offset by slightly higher prices and increasing vehicle efficiency. Unseasonably warm winter weather early in 2012 contributed to an estimated one percent decline in Midwest distillate demand in 2012, which followed a slight decrease in demand in 2011. Market demand increases for gasoline and distillates generally increase the product margin we can realize. The gross margin on merchandise sold at convenience stores historically has been less volatile. Approximately two-thirds of Speedway’s gross margin was derived from merchandise sales in 2012.

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. In 2012, new transportation services agreements were entered into between MPC and MPLX, which resulted in higher tariff rates. 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 distillates peaks during the summer driving season, which extends from May through September of each year, and declines during the fall and winter months. As with crude oil, other transportation alternatives and system maintenance levels influence refined product movements.

Results of Operations

Years Ended December 31, 2012 and December 31, 2011

Consolidated Results of Operations


(In millions)	2012		2011		Variance
Revenues and other income:
Sales and other operating revenues (including consumer excise taxes)	$	82,235	$	78,583	$	3,652
Sales to related parties		8		55		(47)
Income from equity method investments		26		50		(24)
Net gain on disposal of assets		177		12		165
Other income		46		59		(13)

Total revenues and other income		82,492		78,759		3,733

Costs and expenses:
Cost of revenues (excludes items below)		68,668		65,795		2,873
Purchases from related parties		280		1,916		(1,636)
Consumer excise taxes		5,709		5,114		595
Depreciation and amortization		995		891		104
Selling, general and administrative expenses		1,223		1,059		164
Other taxes		270		239		31

Total costs and expenses		77,145		75,014		2,131

Income from operations		5,347		3,745		1,602
Related party net interest and other financial income		1		35		(34)
Net interest and other financial income (costs)		(110)		(61)		(49)

Income before income taxes		5,238		3,719		1,519
Provision for income taxes		1,845		1,330		515

Net income		3,393		2,389		1,004
Less net income attributable to noncontrolling interests		4		-		4

Net income attributable to MPC	$	3,389	$	2,389	$	1,000

Net income attributable to MPC was $1.00 billion higher in 2012 compared to 2011, primarily due to a higher refining and marketing gross margin, which increased to $10.45 per barrel in 2012 from $7.75 per barrel in 2011.

Sales and other operating revenues (including consumer excise taxes) increased $3.65 billion in 2012 compared to 2011, primarily due to increases in refined product selling prices and sales volumes, crude oil and refinery feedstock sales volumes and consumer excise taxes.

Sales to related parties decreased $47 million in 2012 compared to 2011. The decrease resulted from lower refined product volumes sold to Centennial Pipeline LLC (“Centennial”) and sales to Marathon Oil after the Spinoff no longer being classified as related party.

Income from equity method investments decreased $24 million in 2012 compared to 2011. The decrease resulted from an $18 million decrease in income from our ethanol investments and an $8 million decrease in income from our investment in LOOP LLC (“LOOP”). Our ethanol investments experienced lower product margins in 2012, primarily due to lower demand for corn ethanol and higher corn prices, and LOOP experienced higher expenses in 2012 compared to 2011. Additionally, Centennial experienced a significant reduction in shipment volumes in the second half of 2011 that continued in 2012. At December 31, 2012, Centennial was not shipping product. As a result, we continued to evaluate the carrying value of our equity investment in Centennial and concluded that no impairment was required given our assessment of its fair value based on various uses for Centennial’s assets.

Other income decreased $13 million in 2012 compared to 2011, primarily due to a decrease in income from transition services provided to the buyer of our Minnesota Assets and to Marathon Oil and a decrease in sales of Renewable Identification Numbers. These decreases were partially offset by $12 million of dividend income recognized in 2012 from our preferred equity interest in the buyer of our Minnesota Assets, which was paid in connection with our settlement agreement with the buyer. See Item 8. Financial Statements and Supplementary Data—Note 7 for additional information on the Minnesota Assets sale and subsequent settlement with the buyer.

Cost of revenues increased $2.87 billion in 2012 compared to 2011. The increase was primarily due to higher acquisition costs of crude oil and refined products in the Refining & Marketing segment, which resulted from increased volumes, partially offset by decreased prices. The increase in crude oil volumes was partially due to purchases from Marathon Oil not being classified as related party purchases in periods subsequent to the Spinoff. These impacts were partially offset by decreased acquisition costs of other charge and blendstocks, due to decreased volumes and prices. Crude oil volumes were up 6 percent and refined product volumes were up 8 percent, while other charge and blendstocks volumes were down 7 percent. Crude oil acquisition prices were down 1 percent, charge and blendstock prices were down 6 percent and purchased refined product prices were down 4 percent.

Purchases from related parties decreased $1.64 billion in 2012 compared to 2011. The decrease was primarily due to purchases of crude oil from Marathon Oil after the Spinoff not being classified as related party transactions.

Consumer excise taxes increased $595 million in 2012 compared to 2011, primarily due to the expiration of a federal excise tax credit for blending ethanol and increased excise tax in select states.

Depreciation and amortization increased $104 million in 2012 compared to 2011, primarily due to the completion of the heavy oil upgrading and expansion project at our Detroit refinery and Speedway’s acquisition of 97 convenience stores in 2012.

Selling, general and administrative expenses increased $164 million in 2012 compared to 2011. Employee compensation and benefit expenses comprised $141 million of the increase, which was primarily due to $117 million of higher pension settlement expenses in 2012 and an increase in the number of administrative employees associated with being a stand-alone company for a full year in 2012 compared to half of the year in 2011, partially offset by a decrease in pension expenses associated with a pension plan amendment. See Item 8. Financial Statements and Supplementary Data—Note 22 for additional information on the pension settlements and the pension plan amendment. Contract service expenses increased $52 million primarily due to higher information technology costs, higher refinery-related contract services and contract services associated with the acquisition of the Galveston Bay Refinery and Related Assets. These impacts were partially offset by having no allocations from Marathon Oil subsequent to the Spinoff.

Other taxes increased $31 million in 2012 compared to 2011, primarily due to increases in operating taxes of $11 million, personal property taxes of $8 million, real estate taxes of $7 million and franchise taxes of $6 million. These increases were attributable to a number of factors including the completion of the heavy oil upgrading and expansion project at our Detroit refinery, Speedway’s acquisition of 97 convenience stores and higher feedstock inventory values.

Related party net interest and other financial income decreased $34 million in 2012 compared to 2011, primarily due to our short-term investments in preferred stock of MOC Portfolio Delaware, Inc. (“PFD”), a subsidiary of Marathon Oil, being redeemed prior to the Spinoff. The agreement with PFD was terminated on June 30, 2011. See Item 8. Financial Statements and Supplementary Data—Note 5 for further discussion of the PFD preferred stock.

Net interest and other financial costs increased $49 million in 2012 compared to 2011, primarily reflecting an increase in interest expense associated with the $3.0 billion senior notes issued in February 2011, a decrease in foreign currency gains and an increase in bank service and other fees. We capitalized third-party interest of $101 million in 2012 compared to $104 million in 2011. The capitalized interest was primarily associated with the Detroit refinery heavy oil upgrading and expansion project.

Provision for income taxes increased $515 million 2012 compared to 2011, primarily due to the $1.52 billion increase in income before income taxes. The effective income tax rate decreased from 36 percent in 2011 to 35 percent in 2012. The 2012 effective income tax rate was favorably impacted by a decrease in adverse tax impacts from state legislation and other permanent benefit differences. For years 2012 and 2011, adverse tax impacts of state legislation were $9 million and $19 million, respectively. The provision for income taxes for periods prior to the Spinoff has been computed as if we were a stand-alone company. See Item 8. Financial Statements and Supplementary Data—Note 13 for further details.

Segment Results

Revenues are summarized by segment in the following table.


(In millions)	2012		2011
Refining & Marketing	$	76,710	$	73,381
Speedway		14,243		13,490
Pipeline Transportation		459		403

Segment revenues		91,412		87,274

Elimination of intersegment revenues		(9,167)		(8,636)

Total revenues	$	82,245	$	78,638


Items included in both revenues and costs:
Consumer excise taxes	$	5,709	$	5,114

Refining & Marketing segment revenues increased $3.33 billion in 2012 from 2011, primarily due to increased refined product selling prices and sales volumes. Our average refined product selling prices were $3.00 per gallon in 2012 compared to $2.93 per gallon in 2011. The table below shows the average refined product benchmark prices for our marketing areas.


(Dollars per gallon)	2012		2011
Chicago spot unleaded regular gasoline	$	2.84	$	2.79

Chicago spot ultra-low sulfur diesel		3.01		2.98

USGC spot unleaded regular gasoline		2.81		2.75

USGC spot ultra-low sulfur diesel		3.05		2.97

Refining & Marketing intersegment sales to our Speedway segment were $8.78 billion in 2012 compared to $8.30 billion in 2011. Intersegment refined product sales volumes were 2.73 billion gallons in 2012 compared to 2.66 billion gallons in 2011, with the increased volumes primarily due to Speedway’s acquisition of 97 convenience stores in 2012.

Speedway segment revenues increased $753 million in 2012 compared to 2011, primarily due to higher gasoline and distillates sales volumes and selling prices, which averaged $3.54 per gallon in 2012 compared to $3.44 per gallon in 2011. The Speedway segment also had higher merchandise sales excluding cigarettes. The increases in gasoline and distillates sales volumes and merchandise sales were primarily due to the acquisition of 97 convenience stores in 2012.

Pipeline Transportation segment revenue increased $56 million in 2012 compared to 2011, primarily due to higher transportation tariffs resulting from increased tariff rates in 2012 and the startup of a new crude oil pipeline in 2012.

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


(In millions)	2012		2011
Income from operations by segment:

Refining & Marketing	$	5,098	$	3,591

Speedway		310		271

Pipeline Transportation^(a)		216		199

Items not allocated to segments:

Corporate and other unallocated items^(a)(b)		(336)		(316)

Minnesota Assets sale settlement gain^(c)		183		—

Pension settlement expenses^(a)(d)		(124)		—

Income from operations		5,347		3,745

Net interest and other financial income (costs)^(e)		(109)		(26)


Income before income taxes	$	5,238	$	3,719

^(a)

Corporate overhead allocations and pension settlement expenses attributable to MPLX were included in the Pipeline Transportation segment subsequent to MPLX’s October 31, 2012 initial public offering.

^(b)

Corporate and other unallocated items consists primarily of MPC’s corporate administrative expenses, including allocations from Marathon Oil for periods prior to the Spinoff, and costs related to certain non-operating assets.

^(c)

See Item 8. Financial Statements and Supplementary Data - Note 7.

^(d)

See Item 8. Financial Statements and Supplementary Data - Note 22.

^(e)

Includes related party net interest and other financial income.

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


(Dollars per barrel)	2012		2011
Chicago LLS 6-3-2-1^(a)(b)	$	6.74	$	3.81

USGC LLS 6-3-2-1^(a)		6.67		2.84

Blended 6-3-2-1^(a)(c)		6.71		3.35

LLS		111.67		112.37

WTI		94.15		95.11

LLS - WTI differential^(a)		17.52		17.26

Sweet/Sour differential^(a)(d)		12.47		9.11

^(a)

All spreads and differentials are measured against prompt LLS.

^(b)

Calculation utilizes USGC 3% Bunker value as a proxy for Chicago residual fuel price.

^(c)

Blended Chicago/USGC crack spread is 52%/48% in 2012 and 53%/47% in 2011 based on MPC’s refining capacity by region in each period.

^(d)

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

Refining & Marketing segment income from operations increased $1.51 billion in 2012 from 2011, primarily due to a higher refining and marketing gross margin per barrel, which averaged $10.45 per barrel in 2012 compared to $7.75 per barrel in 2011. Our realized Refining & Marketing gross margin for 2012 benefited from increases in the Chicago and USGC LLS 6-3-2-1 blended crack spread of $3.36 per barrel and the sweet/sour differential of $3.36 per barrel in 2012, and we estimate these had positive impacts on our Refining & Marketing gross margin of $1.68 billion and $870 million, respectively. These favorable impacts on our Refining & Marketing gross margin for 2012 compared to 2011 were partially offset by higher cost realizations of the actual mix of crude oils we processed compared to market indicators and higher direct operating costs associated with higher planned turnaround and major maintenance expenses and depreciation and amortization expenses.

The following table summarizes our refinery throughputs for 2012 and 2011.


(mbpd)	2012		2011
Refinery Throughputs:

Crude oil refined		1,195		1,177

Other charge and blendstocks		168		181


Total		1,363		1,358

The increase in crude oil throughput in 2012 compared to 2011 was primarily due to the increased crude oil refining capacities of the Garyville and Catlettsburg refineries and the impacts of the planned turnarounds in 2012 and 2011. The decrease in other charge and blendstocks throughput in 2012 compared to 2011 was primarily due to the planned turnarounds in 2012 and a combination of increased crude oil throughput and feedstock economics at our Garyville refinery in 2012.

Within our refining system, sour crude accounted for 53 percent and 52 percent of our crude oil processed in 2012 and 2011, respectively.

The following table includes certain key operating statistics for the Refining & Marketing segment for 2012 and 2011.


	2012		2011
Refining & Marketing gross margin (Dollars per barrel)^(a)	$	10.45	$	7.75

Direct operating costs in Refining & Marketing gross margin (Dollars per barrel):^(b)

Planned turnaround and major maintenance	$	1.00	$	0.78

Depreciation and amortization		1.44		1.29

Other manufacturing^(c)		3.15		3.16


Total	$	5.59	$	5.23


Refined products sales volumes (mbpd)^(d)		1,599		1,581

^(a)

Sales revenue less cost of refinery inputs, purchased products and manufacturing expenses, including depreciation and amortization, divided by Refining & Marketing segment refined product sales volumes.

^(b)

Per barrel of total refinery throughputs.

^(c)

Includes utilities, labor, routine maintenance and other operating costs.

^(d)

Includes intersegment sales.

Speedway segment income from operations increased $39 million in 2012 compared to 2011, primarily due to increases in our merchandise gross margin and our gasoline and distillates gross margin, partially offset by higher expenses attributable to an increase in the number of convenience stores. The increase in the merchandise gross margin was primarily due to margin expansion resulting from higher merchandise and food sales along with an increase in the number of convenience stores.

The following table includes certain key operating statistics for the Speedway segment for 2012 and 2011.


	2012		2011
Convenience stores at period-end		1,464		1,371

Gasoline & distillates sales (millions of gallons)		3,027		2,938

Gasoline & distillates gross margin (dollars per gallon)^(a)	$	0.1318	$	0.1308

Merchandise sales (in millions)	$	3,058	$	2,924

Merchandise gross margin (in millions)	$	795	$	719

^(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 distillates sales volume.

Same-store gasoline sales volume decreased 0.8 percent in 2012 compared to 2011, while same-store merchandise sales excluding cigarettes increased 7.0 percent for the same period. The primary factor affecting lower same store gasoline sales volume was lower gasoline demand in our market area.

Pipeline Transportation segment income from operations increased $17 million in 2012 from 2011. The increase primarily reflects higher transportation tariffs, partially offset by higher mechanical integrity expenses and a reduction in income from LOOP.

Corporate and other unallocated expenses increased $20 million in 2012 compared to 2011. The increase was primarily due to our administrative units realizing the impact of being a stand-alone company in 2012 compared to expenses incurred prior to the June 30, 2011 Spinoff, partially offset by lower pension expenses associated with a pension plan amendment in the second quarter of 2012.

We recognized a gain of $183 million in 2012 associated with the settlement agreement with the buyer of our Minnesota Assets, which included $86 million of the deferred gain that was recorded when the sale transaction was originally closed. See Item 8. Financial Statements and Supplementary Data - Note 7 for additional information on the Minnesota Assets sale and subsequent settlement with the buyer.

We recorded pretax pension settlement expenses of $124 million in 2012 resulting from the level of employee lump sum retirement distributions that occurred in 2012. See Item 8. Financial Statements and Supplementary Data—Note 22 for additional information on the pension plan amendments.

Years Ended December 31, 2011 and December 31, 2010

Consolidated Results of Operations


(In millions)	2011		2010		Variance
Revenues and other income:

Sales and other operating revenues (including consumer excise taxes)	$	78,583	$	62,387	$	16,196

Sales to related parties		55		100		(45)

Income from equity method investments		50		70		(20)

Net gain on disposal of assets		12		11		1

Other income		59		37		22


Total revenues and other income		78,759		62,605		16,154

Costs and expenses:

Cost of revenues (excludes items below)		65,795		51,731		14,064

Purchases from related parties		1,916		2,593		(677)

Consumer excise taxes		5,114		5,208		(94)

Depreciation and amortization		891		941		(50)

Selling, general and administrative expenses		1,059		874		185

Other taxes		239		247		(8)


Total costs and expenses		75,014		61,594		13,420


Income from operations		3,745		1,011		2,734

Related party net interest and other financial income		35		24		11

Net interest and other financial income (costs)		(61)		(12)		(49)

Income before income taxes		3,719		1,023		2,696

Provision for income taxes		1,330		400		930


Net income	$	2,389	$	623	$	1,766

Consolidated net income was $1.77 billion higher in 2011 compared to 2010, primarily due to a higher refining and marketing gross margin, which increased to $7.75 per barrel in 2011 from $2.81 per barrel in 2010.

Sales and other operating revenues (including consumer excise taxes) increased $16.20 billion in 2011 compared to 2010, primarily due to higher refined product selling prices.

Sales to related parties decreased $45 million in 2011 compared to 2010. The decrease resulted from sales to Marathon Oil after the Spinoff no longer being classified as related party and lower refined product volumes sold to Centennial, partially offset by higher refined product selling prices.

Income from equity method investments decreased $20 million from 2010 to 2011, primarily due to $12 million of increased losses from our investment in Centennial. Centennial experienced a significant reduction in shipment volumes in the second half of 2011 compared to the corresponding period of 2010. Also, 2010 included $4 million of income from an investment in a pipeline company that was included in the Minnesota Assets disposition.

Other income increased $22 million in 2011 compared with 2010, due primarily to income from transition services provided to the purchaser of the Minnesota Assets and to Marathon Oil.

Cost of revenues increased $14.06 billion in 2011 from 2010. The increase was primarily the result of higher acquisition costs of crude oil, refinery charge and blendstocks and refined products in the Refining & Marketing segment, largely due to higher market prices. Crude oil acquisition prices were up 31 percent, charge and blendstock prices were up 28 percent and purchased refined product prices were up 40 percent.

Purchases from related parties decreased $677 million in 2011 compared to 2010. The decrease was primarily due to purchases of crude oil from Marathon Oil after the Spinoff not being classified as related party transactions.

Selling, general and administrative expenses increased $185 million in 2011 compared with 2010. Employee compensation and benefits expenses comprised $81 million of the increase, which is partially due to an increase in the number of administrative employees associated with being a stand-alone public company, higher incentive compensation accruals related to 2011 performance and increased pension and postretirement benefit costs. Contract services expenses increased $62 million, primarily due to higher information technology costs associated with being a separate stand-alone company. In addition, bankcard processing fees related to Marathon brand sales increased $41 million, primarily due to higher transportation fuel selling prices. Following the Spinoff, we no longer receive allocated corporate overhead costs from Marathon Oil.

Related party net interest and other financial income increased $11 million in 2011 compared to 2010, primarily reflecting higher average balances of our short-term investments in PFD preferred stock. The agreement with PFD was terminated on June 30, 2011. See Item 8. Financial Statements and Supplementary Data - Note 5 for further discussion of the PFD preferred stock.

Net interest and other financial costs increased $49 million in 2011 compared with 2010, primarily reflecting increased interest expense associated with the $3.0 billion of long-term debt we issued in February 2011. We capitalized third-party interest of $104 million in 2011 compared to $17 million in 2010. See Item 8. Financial Statements and Supplementary Data - Note 20 for further details relating to our debt.

Provision for income taxes increased $930 million from 2010 to 2011, primarily due to the $2.70 billion increase in income before income taxes. The effective income tax rate decreased from 39 percent in 2010 to 36 percent in 2011. The 2011 effective income tax rate was favorably impacted by an increase in income qualifying for the domestic manufacturing deduction and a decrease in the effective tax rate for state taxes. The year 2011 included a $19 million adverse tax impact of state legislative changes, primarily in Michigan, and 2010 included a $26 million adverse tax impact of federal legislative changes. The provision for income taxes for periods prior to the Spinoff has been computed as if we were a stand-alone company. See Item 8. Financial Statements and Supplementary Data - Note 13 for further details.

Segment Results

Revenues are summarized by segment in the following table.


(In millions)	2011		2010
Refining & Marketing	$	73,381	$	57,333
Speedway		13,490		12,494
Pipeline Transportation		403		401

Segment revenues		87,274		70,228
Elimination of intersegment revenues		(8,636)		(7,741)

Total revenues	$	78,638	$	62,487


Items included in both revenues and costs:
Consumer excise taxes	$	5,114	$	5,208

Refining & Marketing segment revenues increased $16.05 billion in 2011 from 2010, primarily due to increased refined product selling prices. Our average refined product selling prices were $2.93 per gallon in 2011 compared to $2.24 per gallon in 2010. The table below shows the average refined product benchmark prices for our marketing areas.


(Dollars per gallon)	2011		2010
Chicago spot unleaded regular gasoline	$	2.79	$	2.09
Chicago spot ultra-low sulfur diesel		2.98		2.17
USGC spot unleaded regular gasoline		2.75		2.05
USGC spot ultra-low sulfur diesel		2.97		2.16

Refining & Marketing intersegment sales to our Speedway segment were $8.30 billion in 2011 compared to $7.39 billion in 2010. Intersegment refined product sales volumes were 2.66 billion gallons in 2011 compared to 3.11 billion gallons in 2010, with the decreased volumes primarily due to the Minnesota Assets disposition.

Speedway segment revenues increased $996 million from 2010 to 2011, mainly due to higher gasoline and distillates selling prices, which averaged $3.44 per gallon in 2011 compared to $2.70 per gallon in 2010. These impacts were partially offset by decreased gasoline and distillates sales volumes and lower merchandise sales primarily due to the Minnesota Assets disposition in December 2010.

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


(In millions)	2011		2010
Income from operations by segment:
Refining & Marketing	$	3,591	$	800
Speedway		271		293
Pipeline Transportation		199		183
Items not allocated to segments:
Corporate and other unallocated items^(a)		(316)		(236)
Impairments^(b)		-		(29)

Income from operations		3,745		1,011
Net interest and other financial income (costs)^(c)		(26)		12

Income before income taxes	$	3,719	$	1,023

^(a)

^(b)

The impairment in 2010 was related to a maleic anhydride plant.

^(c)

Includes related party net interest and other financial income.

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


(Dollars per barrel)	2011		2010
Chicago LLS 6-3-2-1^(a)(b)	$	3.81	$	3.02
USGC LLS 6-3-2-1^(a)		2.84		2.13
Blended 6-3-2-1^(a)(c)		3.35		2.64
LLS		112.37		82.83
WTI		95.11		79.61
LLS - WTI differential^(a)		17.26		3.22
Sweet/Sour differential^(a)(d)		9.11		7.57

^(a)

All spreads and differentials are measured against prompt LLS.

^(b)

Calculation utilizes USGC 3% Bunker value as a proxy for Chicago residual fuel price.

^(c)

Blended Chicago/USGC crack spread is 53%/47% in 2011 and 57%/43% in 2010 based on MPC’s refining capacity by region in each period.

^(d)

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

Refining & Marketing segment income from operations increased $2.79 billion in 2011 from 2010, primarily due to a higher refining and marketing gross margin per barrel, which averaged $7.75 per barrel in 2011 compared to $2.81 per barrel in 2010. Our realized refining and marketing gross margin for 2011 improved from 2010 primarily due to wider differentials between WTI and other light sweet crudes such as LLS, larger LLS 6-3-2-1 crack spreads, and wider sweet/sour differentials. The discount of WTI to LLS increased $14.04 per barrel as a result of logistical constraints in the U.S. mid-continent markets, which prevented the price of WTI from rising with the prices of crudes produced in other regions. We estimate this had a $1.69 billion positive impact on our refining and marketing gross margin. The Chicago and USGC LLS 6-3-2-1 crack spreads increased $0.79 per barrel and $0.71 per barrel, respectively, and we estimate this had a $349 million positive impact on our refining and marketing gross margin. The sweet/sour differential widened $1.54 per barrel and we estimate this had a $277 million positive impact on our refining and marketing gross margin. Within our refining system, sour crude accounted for 52 percent and 54 percent of our crude oil processed in 2011 and 2010, respectively. Direct operating costs declined $248 million from 2010 to 2011, primarily due to a $188 million reduction in planned turnaround and major maintenance costs, which also contributed to the increase in gross margin.

The following table summarizes our refinery throughputs for 2011 and 2010.


(mbpd)	2011		2010

Refinery Throughputs:

Crude oil refined		1,177		1,173

Other charge and blendstocks		181		162


Total		1,358		1,335

Our total refinery throughputs were two percent higher in 2011 compared to 2010, primarily due to improved refinery utilization and decreased turnaround activity in 2011 compared to 2010, primarily at our Garyville refinery, partially offset by the sale of the St. Paul Park refinery in December 2010. Crude oil refined was essentially flat in 2011 compared to 2010, while other charge and blendstock throughputs increased 12 percent over the same period.

The following table includes certain key operating statistics for the Refining & Marketing segment for 2011 and 2010.


	2011		2010
Refining & Marketing gross margin (Dollars per barrel)^(a)	$	7.75	$	2.81
Direct operating costs in Refining & Marketing gross margin (Dollars per barrel):^(b)
Planned turnaround and major maintenance	$	0.78	$	1.19
Depreciation and amortization		1.29		1.32
Other manufacturing^(c)		3.16		3.32

Total	$	5.23	$	5.83

Refined products sales volumes (mbpd)^(d)		1,581		1,573

^(a)

^(b)

Per barrel of total refinery throughputs.

^(c)

Includes utilities, labor, routine maintenance and other operating costs.

^(d)

Includes intersegment sales.

Speedway segment income from operations decreased $22 million from 2010 to 2011, with $45 million attributable to the sale of 166 convenience stores that were part of the Minnesota Assets disposition in December 2010 and $33 million attributable to increased operating expenses partially due to higher employee costs. These decreases were partially offset by a $30 million increase associated with a higher gasoline and distillates gross margin and a $26 million increase associated with a higher merchandise gross margin. Speedway’s gasoline and distillates gross margin per gallon averaged 13.08 cents in 2011, compared with 12.07 cents in 2010. Gasoline and distillates sales volumes declined in 2011 primarily reflecting the sale of the Minnesota Assets. Merchandise gross margin was $719 million in 2011 compared to $789 million in 2010, also reflecting the Minnesota Assets disposition.

Same-store gasoline sales volume decreased 1.7 percent in 2011 compared to 2010, while same-store merchandise sales excluding cigarettes increased 6.7 percent for the same period. The primary factor affecting same store gasoline sales volume was the higher average retail price of gasoline.

Pipeline Transportation segment income from operations increased $16 million in 2011 from 2010. The increase primarily reflects the absence of non-routine maintenance and impairment expenses incurred in 2010, partially offset by a reduction in income from pipeline equity method investments. Refined product throughput volumes increased seven percent in 2011 compared to 2010, while crude oil throughput volumes decreased two percent in the same period.

Corporate and other unallocated items increased $80 million in 2011 compared to 2010 due to higher information technology, employee benefits and other administrative expenses, partially resulting from costs associated with being a stand-alone company. Following the Spinoff, we no longer receive allocated corporate overhead costs from Marathon Oil.

Impairment expense in 2010 was a $29 million property impairment related to a maleic anhydride plant, which was operated by our Refining & Marketing segment.

Liquidity and Capital Resources

Cash Flows

Our cash and cash equivalents balance was $4.86 billion at December 31, 2012 compared to $3.08 billion at December 31, 2011. Net cash provided by (used in) operating activities, investing activities and financing activities for the past three years is presented in the following table.


(In millions)	2012		2011		2010
Net cash provided by (used in):
Operating activities	$	4,492	$	3,309	$	2,217
Investing activities		(1,452)		1,295		(2,145)
Financing activities		(1,259)		(1,643)		(82)

Total	$	1,781	$	2,961	$	(10)

Net cash provided from operating activities increased $1.18 billion in 2012 compared to 2011, primarily due to higher net income and noncash income adjustments in 2012, partially offset by changes in working capital. Net cash provided from operating activities increased $1.09 billion in 2011 compared to 2010, primarily due to higher net income in 2011, partially offset by changes in working capital and lower deferred income taxes.

Changes in working capital were a net $428 million use of cash in 2012, primarily due to a decrease in accounts payable and accrued liabilities resulting primarily from reductions in crude oil prices and payable volumes, partially offset by a decrease in accounts receivable resulting primarily from reductions in crude oil prices and receivable volumes. Changes in working capital were a net $13 million source of cash in 2011, primarily due to an increase in accounts payable and accrued liabilities resulting primarily from increases in crude oil prices and payable volumes, partially offset by an increase in accounts receivable resulting primarily from increases in crude oil prices and receivable volumes and refined product prices. Changes in working capital were a net $318 million source of cash in 2010, primarily due to an increase in accounts payable and accrued liabilities resulting primarily from increases in crude oil prices and payable volumes, partially offset by an increase in accounts receivable resulting primarily from increases in crude oil and refined product prices and crude oil receivable volumes.

Cash flows from investing activities decreased $2.75 billion in 2012 compared to 2011 and increased $3.44 billion in 2011 compared to 2010. The investing activity is further discussed below.

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 for each of the last three years.


(In millions)	2012			2011		2010
Additions to property, plant and equipment	$	1,369		$	1,185	$	1,217
Acquisitions^(a)		180			74		-
Increase (decrease) in capital accruals		(117	)		53		(51	)

Total capital expenditures		1,432			1,312		1,166
Investments in equity method investees		28			11		7

Total capital expenditures and investments	$	1,460		$	1,323	$	1,173

^(a)

Excludes inventory acquired and liability assumed in 2012.

Capital expenditures and investments for each of the last three years are summarized by segment below.


(In millions)	2012		2011		2010
Refining & Marketing	$	705	$	900	$	961
Speedway^(a)		340		164		84
Pipeline Transportation		211		121		24
Corporate and Other^(b)		204		138		104

Total	$	1,460	$	1,323	$	1,173

^(a)

Includes acquisitions of 97 convenience stores in 2012 and 23 convenience stores in 2011. See Item 8. Financial Statements and Supplementary Data - Note 6.

^(b)

Includes capitalized interest of $101 million, $114 million and $103 million in 2012, 2011 and 2010, respectively.

The Detroit refinery heavy oil upgrading and expansion project, which we completed in 2012, comprised 46 percent, 59 percent and 50 percent (excluding capitalized interest associated with this project) of our Refining & Marketing segment capital spending in 2012, 2011 and 2010, respectively.

Cash used in acquisitions, as presented on the consolidated statements of cash flows, totaled $190 million in 2012 and $74 million in 2011, which relates to the 97 convenience stores Speedway acquired in 2012 and the 23 convenience stores Speedway acquired in 2011.

Cash provided by disposal of assets totaled $53 million, $144 million and $763 million in 2012, 2011 and 2010, respectively. The $53 million of cash from asset disposals in 2012 primarily included proceeds from a settlement

agreement with the buyer of our Minnesota Assets. The $144 million of cash from asset disposals in 2011 primarily included the collection of a receivable associated with the sale of the Minnesota Assets. In 2010, disposal of assets primarily included proceeds from the original sale of the Minnesota Assets.

Net investments in related party debt securities was a source of cash of $2.40 billion in 2011 and a use of cash of $1.69 billion in 2010. All such activity reflected the net cash flow from redemptions and purchases of PFD preferred stock. Prior to the Spinoff, all investments in PFD preferred stock were redeemed, and the agreement with PFD was terminated. See Item 8. Financial Statements and Supplementary Data - Note 5 for further discussion of our investments in PFD preferred stock.

Net cash used in financing activities totaled $1.26 billion in 2012, $1.64 billion in 2011 and $82 million in 2010. The net use of cash in 2012 was primarily due to the common stock repurchases under our ASR programs and dividend payments, partially offset by proceeds from the issuance of MPLX common units. The use of cash in 2011 was primarily due to the net repayment of debt payable to Marathon Oil and its subsidiaries and net distributions to Marathon Oil, partially offset by cash provided from the issuance of long-term debt. These 2011 activities were undertaken to effect the Spinoff. The year 2011 also included a use of cash of $60 million for debt issuance costs associated with the $3.0 billion of senior notes, our $2.0 billion revolving credit agreement and our $1.0 billion trade receivables securitization facility. See Item 8. Financial Statements and Supplementary Data - Note 20 for additional information on our long-term debt. The net use of cash in 2010 was primarily due to distributions to Marathon Oil, partially offset by net borrowings of debt payable to Marathon Oil.

Cash used in common stock repurchases totaled $1.35 billion in 2012 associated with the share repurchase plan authorized by our board of directors. We entered into an $850 million ASR program on February 3, 2012, under which we repurchased 20,357,380 shares at an average cost of $41.75 per share, and a $500 million ASR program on November 5, 2012, under which we received 7,403,294 shares as of December 31, 2012 and 870,947 shares in February 2013. See Item 8. Financial Statements and Supplementary Data - Note 10 for further discussion of the share repurchase plan.

Cash used in dividend payments increased $247 million in 2012 compared to 2011, primarily due to having a full year of dividend payments in 2012 and a 75 percent increase in our base dividend since July 2011, partially offset by a decrease in the number of outstanding shares of our common stock attributable to the ASR programs. Our quarterly dividend began at 20 cents per common share in July 2011 and has increased to 35 cents per common share as of December 31, 2012.

Cash proceeds from the issuance of MPLX common units was $407 million in 2012, of which $203 million was distributed by MPLX to MPC, in partial consideration of assets we contributed to MPLX and to reimburse us for certain capital expenditures incurred with respect to those assets. The initial public offering represented the sale of a 26.4 percent interest in MPLX. See Item 8. Financial Statements and Supplementary Data - Note 4 for further discussion of MPLX and its initial public offering.

Net borrowings and repayments under our long-term debt payable to Marathon Oil and its subsidiaries was a use of cash of $3.62 billion in 2011 compared with a source of cash of $1.26 billion in 2010. The agreements with Marathon Oil and its subsidiaries were terminated in 2011. See Item 8. Financial Statements and Supplementary Data - Note 5 for further discussion of these financing agreements.

Net distributions to Marathon Oil totaled $783 million in 2011 and $1.33 billion in 2010. The net distribution in 2011 was primarily related to $1.47 billion in net cash distributions paid to Marathon Oil, partially offset by income taxes it incurred on our behalf. The net distribution in 2010 was primarily related to $1.48 billion in cash distributions paid to Marathon Oil.

Derivative Instruments

See Item 7A. Quantitative and Qualitative Disclosures about Market Risk for a discussion of derivative instruments and associated market risk.

Capital Resources

Our intention is to maintain an investment grade credit profile. As of December 31, 2012, our liquidity totaled $7.86 billion consisting of:


(In millions)	December 31, 2012
Cash and cash equivalents	$	4,860
Revolving credit agreement^(a)		2,000
Trade receivables securitization facility		1,000

Total	$	7,860

^(a)

Excludes MPLX’s revolving credit agreement and does not give effect to subsequent increase in capacity to $2.5 billion.

As of December 31, 2012, we had no borrowings or letters of credit outstanding under our revolving credit agreement or our trade receivables securitization facility.

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 September 14, 2012, we entered into a five-year revolving credit agreement (the “Credit Agreement”) with a syndicate of lenders and terminated our previous four-year revolving credit agreement. The Credit Agreement was amended on December 20, 2012 to increase the borrowing capacity by $500 million to a total of $2.5 billion. The commitment increase became effective on February 1, 2013 in conjunction with the acquisition of the Galveston Bay Refinery and Related Assets. The Credit Agreement includes letter of credit issuing capacity of up to $2.0 billion and swingline loan capacity of up to $100 million. We may increase the borrowing capacity under the Credit Agreement by up to an additional $500 million, subject to certain conditions including the consent of the lenders whose commitments would be increased. In addition, we may request that the term of the Credit Agreement, which expires on September 14, 2017, be extended for up to two additional one-year periods. Each such extension would be subject to the approval of lenders holding greater than 50 percent of the commitments then outstanding, and the commitment of any lender that does not consent to an extension of the maturity date will be terminated on the then-effective maturity date.

The Credit Agreement contains representations and warranties, affirmative and negative covenants and events of default that we consider usual and customary for an agreement of this type. The financial covenant included in the Credit Agreement requires us to maintain, as of the last day of each fiscal quarter, a ratio of Consolidated Net Debt (as defined in the Credit Agreement) to Total Capitalization (as defined in the Credit Agreement) of no greater than 0.65 to 1.00. As of December 31, 2012, we were in compliance with this debt covenant with a ratio of Consolidated Net Debt to Total Capitalization of -0.1 to 1.00, as well as the other covenants contained in the Credit Agreement. In addition, the Credit Agreement includes limitations on the indebtedness of our subsidiaries, other than subsidiaries that guarantee our obligations under the Credit Agreement and our ability, and the ability of our subsidiaries, to incur liens on property or assets or enter into certain transactions with affiliates.

Borrowings of revolving loans under the Credit Agreement bear interest at either (i) the sum of the Adjusted LIBO Rate (as defined in the Credit Agreement) and a margin ranging between 1.00 percent to 2.00 percent, depending on our credit ratings, or (ii) the sum of the Alternate Base Rate (as defined in the Credit Agreement) and a margin ranging between zero percent to 1.00 percent, depending on our credit ratings. The Credit Agreement also provides for customary fees, including administrative agent fees, annual commitment fees ranging from 0.10 percent to 0.35 percent, depending on our credit ratings, on the unused portion, fees in respect to letters of credit and other fees.

On September 14, 2012, MPLX Operations LLC, an affiliate of MPC and wholly-owned subsidiary of MPLX, as the borrower, and MPLX, as the parent guarantor, entered into a five-year revolving credit agreement (“MPLX Credit Agreement”) with a syndicate of lenders. The MPLX Credit Agreement became effective following MPLX’s initial public offering and has an initial borrowing capacity of $500 million. MPLX may increase the borrowing capacity under the MPLX Credit Agreement by up to an additional $300 million, subject to certain conditions, including the consent of the lenders whose commitments would be increased. The MPLX Credit Agreement includes letter of credit issuing capacity of up to $250 million and swingline loan capacity of up to $50 million. MPLX may, subject to certain conditions, request that the term of the MPLX Credit Agreement, which expires on October 31, 2017, be extended for up to two additional one-year periods. Each such extension would be subject to the approval of lenders holding greater than 50 percent of the commitments then outstanding, and the commitment of any lender that does not consent to an extension of the maturity date will be terminated on the then-effective maturity date. At December 31, 2012, MPLX had no borrowings or letters of credit outstanding under this agreement.

The MPLX Credit Agreement contains representations and warranties, affirmative and negative covenants and events of default that we consider usual and customary for an agreement of that type. 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 December 31, 2012, MPLX was in compliance with this debt covenant with a ratio of Consolidated Total Debt to Consolidated EBITDA of 0.1 to 1.0, as well as the other covenants contained in the MPLX Credit Agreement.

Borrowings of revolving loans under the MPLX Credit Agreement bear interest at either (i) the sum of the Adjusted LIBO Rate (as defined in the MPLX Credit Agreement) and a margin ranging from 1.00 percent to 2.00 percent or (ii) the sum of the Alternate Base Rate (as defined in the MPLX Credit Agreement) and a margin ranging from zero percent to 1.00 percent. Prior to MPLX receiving a rating from Standard & Poor’s Rating Group or Moody’s Investor Service, Inc. for its Index Debt (as defined in the MPLX Credit Agreement), the margin that is added to the applicable interest rate is based on MPLX’s ratio of Consolidated Total Debt as of the end of each fiscal quarter to Consolidated EBITDA for the prior four fiscal quarters. Once MPLX receives a rating, the margin added to the applicable interest rate will be based on MPLX’s credit ratings. The MPLX Credit Agreement also provides for customary fees, including administrative agent fees, commitment fees ranging from 0.10 percent to 0.35 percent of the unused portion, depending on MPLX’s ratio of Consolidated Total Debt to Consolidated EBITDA for the prior four fiscal quarters prior to the rating date, or MPLX’s credit ratings subsequent to the rating date, fronting and issuance fees in respect to letters of credit and other fees.

As of December 31, 2012, 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 our 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 to below investment grade ratings would increase the applicable interest rates, yields and other fees payable under our

Credit Agreement, the MPLX Credit Agreement and 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 and could potentially impact our ability to purchase crude oil on an unsecured basis.

Debt-to-Total-Capital Ratio

Our debt-to-total capital ratio (total debt to total debt-plus-equity) was 22 percent and 26 percent at December 31, 2012 and 2011, respectively.


	December 31,
(In millions)	2012		2011
Long-term debt due within one year	$	19	$	15
Long-term debt		3,342		3,292

Total debt	$	3,361	$	3,307


Calculation of debt-to-total capital ratio:
Total debt	$	3,361	$	3,307
Plus equity		12,105		9,505

Total debt plus equity	$	15,466	$	12,812

Debt-to-total capital ratio		22%		26%

Capital Requirements

We have a capital and investment budget for 2013 of $1.62 billion, excluding capitalized interest and the purchase price for the Galveston Bay Refinery and Related Assets. Additional details related to the 2013 capital and investment budget are discussed in the Outlook section below.

On February 1, 2013, we acquired the Galveston Bay Refinery and Related Assets for approximately $598 million plus approximately $900 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. This acquisition was paid for with cash on hand.

We plan to make contributions of approximately $160 million to our funded pension plans in 2013.

On January 30, 2013, our board of directors approved a 35 cents per share dividend, payable March 11, 2013 to stockholders of record at the close of business on February 20, 2013.

On February 1, 2012, we announced that our board of directors authorized a share repurchase plan, enabling us to purchase up to $2.0 billion of our common stock. On January 30, 2013, our board of directors approved an additional $2.0 billion share repurchase authorization and extended the unused amounts remaining on the February 1, 2012 authorization, with both authorizations ending December 2014. After the effects of the ASR programs described below, $2.65 billion of the $4.0 billion total share repurchase authorization is available. We may utilize various methods to effect the repurchases, which could include open market purchases, negotiated block transactions, ASRs or open market solicitations for shares, some of which may be effected through Rule 10b5-1 plans. The timing of future repurchases, if any, will depend upon several factors, including market and business conditions, and such repurchases may be discontinued at any time.

On February 3, 2012, we entered into an $850 million ASR program with a major financial institution as part of this authorization. Under this ASR program, we received 20,357,380 shares of our common stock in 2012, resulting in an average per share cost for these shares of $41.75.

On November 5, 2012, we entered into a second ASR program for $500 million. Under this ASR program, we received 7,403,294 shares of our common stock in 2012 and 870,947 shares in February 2013, for a total of 8,274,241 repurchased shares, which concluded this ASR program. Upon final settlement, the average per share cost for all shares purchased under this ASR program was $60.43.

These ASR programs are accounted for as treasury stock purchase transactions, reducing the weighted average number of basic and diluted common shares outstanding by the repurchased shares, and as forward contracts indexed to our common stock.

The above discussion of the share repurchase authorization includes forward-looking statements. Factors that could affect the share repurchase plan and its timing 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

The table below provides aggregated information on our consolidated obligations to make future payments under existing contracts as of December 31, 2012. The contractual obligations detailed below do not include our contractual obligations to MPLX under various fee-based commercial agreements as these transactions are eliminated in the consolidated financial statements. The contractual obligations detailed below include amounts paid at closing for the Galveston Bay Refinery and Related Assets, but do not include obligations assumed upon closing.


(In millions)	Total		2013		2014-2015		2016-2017		Later Years
Long-term debt^(a)	$	5,878	$	169	$	332	$	1,039	$	4,338
Capital lease obligations		546		44		89		87		326
Operating lease obligations		612		151		254		129		78
Purchase obligations:^(b)
Crude oil, feedstock, refined product and renewable fuel contracts^(c)(d)		11,545		10,302		765		395		83
Transportation and related contracts		1,700		144		267		315		974
Contracts to acquire property, plant and equipment^(e)(f)		1,391		834		410		147		-
Service and materials contracts^(g)		1,315		355		339		216		405

Total purchase obligations		15,951		11,635		1,781		1,073		1,462
Other long-term liabilities reported in the consolidated balance sheet^(h)		1,101		247		274		144		436

Total contractual cash obligations	$	24,088	$	12,246	$	2,730	$	2,472	$	6,640

^(a)

Includes interest payments for our senior notes and commitment and administrative fees for our Credit Agreement, the MPLX Credit Agreement and our trade receivables securitization facility.

^(b)

Includes both short- and long-term purchases obligations.

^(c)

These contracts include variable price arrangements with estimated prices to be paid primarily based on current market conditions. We are in the process of implementing systems that will allow us to estimate prices based on futures curves, which as of December 31, 2012, has been implemented for contracts with purchase obligations of $1.78 billion.

^(d)

Includes the approximate value of inventories included in the purchase of the Galveston Bay Refinery and Related Assets, which was completed on February 1, 2013. See Item 8. Financial Statements and Supplementary Data - Note 26.

^(e)

Includes approximately $598 million in 2013 for the purchase of the Galveston Bay Refinery and Related Assets and $700 million for the contingent earnout provision. The acquisition was completed on February 1, 2013. See Item 8. Financial Statements and Supplementary Data - Note 26.

^(f)

Includes obligations to advance funds to equity method investees.

^(g)

Includes contracts to purchase services such as utilities, supplies and various other maintenance and operating services.

^(h)

Primarily includes obligations for pension and other postretirement benefits including medical and life insurance, which we have estimated through 2022. See Item 8. Financial Statements and Supplementary Data - Note 22.

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. Although off-balance sheet arrangements serve a variety of our business purposes, we are not dependent on these arrangements 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 the Spinoff, we entered into various indemnities and guarantees to Marathon Oil. These arrangements are described in Item 8. Financial Statements and Supplementary Data - Note 25.

Outlook

We have a capital and investment budget for 2013 of $1.62 billion, excluding capitalized interest and the purchase price for the Galveston Bay Refinery and Related Assets. This represents a 19 percent increase from our 2012 spending, which is primarily due to increases in the Refining & Marketing segment. The budget includes spending on refining, retail marketing, transportation, logistics and brand marketing projects as well as amounts designated for corporate activities. We continuously evaluate our capital budget and make changes as conditions warrant.

Refining & Marketing

The 2013 capital budget includes $1.02 billion for our Refining & Marketing segment. The Refining & Marketing capital budget includes approximately $400 million for our Galveston Bay Refinery and Related Assets for synergy capital and the continuation of infrastructure investments and other programs begun by the prior owner.

At our Garyville refinery, we have projects underway to optimize diesel and gasoline yields through modifications to the older crude unit, hydrocracker and the distillate hydrotreaters. Total capital spending is estimated at $225 million with projected capital spending of $117 million in 2013. The hydrocracker revamp is expected to be completed in 2014 and the completion of the final phase of the program is expected in 2015.

At our Robinson refinery, we have a $75 million project to revamp our distillate hydrocracker to improve margins by processing more feedstock at a lower conversion and shifting approximately 10 mbpd of other products to diesel production. The amount of capital spending budgeted for this project in 2013 is $15 million. The project is expected to be completed in 2015.

At our Catlettsburg refinery, we have a $25 million project underway to recover additional volumes of gas oil from the refinery’s residual oil production to be processed in the fluidized catalytic cracker, thus increasing the production of higher valued gasoline and diesel. The amount of capital spending budgeted for this project in 2013 is $9 million. This project is expected to be completed in 2014.

Our Refining & Marketing and Pipeline Transportation segments have approximately $300 million of capital projects that will allow us to process and handle crude oil and condensate from the Utica Shale region, of which approximately $110 million have been budgeted for in 2013. We have projects to invest in condensate splitters at our Canton and Catlettsburg refineries to allow the refineries to process up to 60 mbpd of condensate from the Utica Shale region. In addition, we have a truck-to-barge crude system project at our Wellsville asphalt terminal and expect to purchase new barges to allow Utica production to be transported from our Wellsville terminal to our Catlettsburg refinery.

The remaining budget is primarily allocated to maintaining facilities and meeting regulatory requirements at our refineries.

Speedway

The 2013 capital budget includes $255 million for our Speedway segment, relating to new construction and acquisitions to expand our markets and remodeling and rebuilding projects for existing convenience stores to upgrade and enhance our existing facilities. Also included in the capital budget are expenditures for dispenser, equipment and technology upgrades.

Pipeline Transportation

The 2013 capital budget includes $184 million for our Pipeline Transportation segment, primarily for upgrades to replace or enhance our existing facilities, including our Patoka to Catlettsburg crude oil pipeline upgrade, and new infrastructure.

Corporate and Other

The remaining 2013 capital budget includes $160 million, primarily related to upgrades to information technology systems.

In addition, we expect to record $43 million in capitalized interest, which is 57 percent less than 2012 primarily due to the completion of the Detroit refinery heavy oil upgrading and expansion project.

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, costs for projects under construction, project completion dates and expectations or projections about strategies and goals for growth, upgrades and expansion. 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

Following completion of the Spinoff on June 30, 2011, Marathon Oil retained no ownership interest in us and is no longer a related party.

Purchases of crude oil and natural gas from Marathon Oil accounted for five percent or less of our total cost of revenues and purchases from related parties for the periods prior to the Spinoff. Related party purchases of crude oil and natural gas from Marathon Oil were at market-based contract prices. The crude oil prices were based on indices that represented market value for time and place of delivery and that were also used in third-party contracts. The natural gas prices equaled the price at which Marathon Oil purchased the natural gas from third parties plus the cost of transportation.

We believe that transactions with related parties, other than certain transactions with Marathon Oil to effect the Spinoff and related to the provision of administrative services, were conducted under terms comparable to those with unrelated parties.

On May 25, 2011, we entered into a separation and distribution agreement and several other agreements with Marathon Oil to effect the Spinoff and to provide a framework for our relationship with Marathon Oil. Because the terms of our separation from Marathon Oil and these agreements were entered into in the context of a related-party transaction, the terms may not be comparable to terms that would be obtained in a transaction between unaffiliated parties. See Item 8. Financial Statements and Supplementary Data—Note 5 for further discussion of activity with related 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.

Legislation and regulations pertaining to fuel specifications, climate change and greenhouse gas emissions have the potential to materially adversely impact our business, financial condition, results of operations and cash flows, including costs of compliance and permitting delays. The extent and magnitude of these adverse impacts cannot be reliably or accurately estimated at this time because specific regulatory and legislative requirements have not been finalized and uncertainty exists with respect to the measures being considered, the costs and the time frames for compliance, and our ability to pass compliance costs on to our customers. For additional information see Item 1A. Risk Factors.

Our environmental expenditures, based on the American Petroleum Institute’s definition of environmental expenditures, for each of the last three years were:


(In millions)	2012		2011		2010
Capital	$	115	$	167	$	223
Compliance:
Operating and maintenance		318		354		403
Remediation^(a)		24		27		20

Total	$	457	$	548	$	646

^(a)

These amounts include spending charged against remediation reserves, where permissible, but exclude non-cash provisions recorded for environmental remediation.

We accrue for environmental remediation activities when the responsibility to remediate is probable and the amount of associated costs can be reasonably estimated. As environmental remediation matters proceed toward ultimate resolution or as additional remediation obligations arise, charges in excess of those previously accrued may be required.

New or expanded environmental requirements, which could increase our environmental costs, may arise in the future. We believe we comply with all legal requirements regarding the environment, but since not all of them are fixed or presently determinable (even under existing legislation) and may be affected by future legislation or regulations, it is not possible to predict all of the ultimate costs of compliance, including remediation costs that may be incurred and penalties that may be imposed.

Our environmental capital expenditures accounted for 8 percent, 13 percent and 19 percent of capital expenditures in 2012, 2011 and 2010, respectively. Our environmental capital expenditures are expected to approximate $41 million, or three percent, of total capital expenditures in 2013. Predictions beyond 2013 can only be broad-based estimates, which have varied, and will continue to vary, due to the ongoing evolution of specific regulatory requirements, the possible imposition of more stringent requirements and the availability of new technologies, among other matters. Based on currently identified projects, we anticipate that environmental capital expenditures will be approximately $86 million in 2014; however, actual expenditures may vary as the number and scope of environmental projects are revised as a result of improved technology or changes in regulatory requirements and could increase if additional projects are identified or additional requirements are imposed.

We spent $620 million from 2008 through 2011 to comply with MSAT II regulations relating to benzene content in refined products. All MSAT II compliance units were in operation in 2011.

For more information on environmental regulations that impact us, or could impact us, see Item 1. Business—Environmental Matters, Item 1A. Risk Factors and Item 3. Legal Proceedings.

Critical Accounting Estimates

The preparation of financial statements in accordance with accounting principles generally accepted in the United States (“US GAAP”) requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities as of the date of the consolidated financial statements and the reported amounts of revenues and expenses during the respective reporting periods. Accounting estimates are considered to be critical if (1) the nature of the estimates and assumptions is material due to the levels of subjectivity and judgment necessary to account for highly uncertain matters or the susceptibility of such matters to change; and (2) the impact of the estimates and assumptions on financial condition or operating performance is material. Actual results could differ from the estimates and assumptions used.

Fair Value Estimates

Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. There are three approaches for measuring the fair value of assets and liabilities: the market approach, the income approach and the cost approach, each of which includes multiple valuation techniques. The market approach uses prices and other relevant information generated by market transactions involving identical or comparable assets or liabilities. The income approach uses valuation techniques to measure fair value by converting future amounts, such as cash flows or earnings, into a single present value amount using current market expectations about those future amounts. The cost approach is based on the amount that would currently be required to replace the service capacity of an asset. This is often referred to as current replacement cost. The cost approach assumes that the fair value would not exceed what it would cost a market participant to acquire or construct a substitute asset of comparable utility, adjusted for obsolescence.

The fair value accounting standards do not prescribe which valuation technique should be used when measuring fair value and does not prioritize among the techniques. These standards establish a fair value hierarchy that prioritizes the inputs used in applying the various valuation techniques. Inputs broadly refer to the assumptions that market participants use to make pricing decisions, including assumptions about risk. Level 1 inputs are given the highest priority in the fair value hierarchy while Level 3 inputs are given the lowest priority. The three levels of the fair value hierarchy are as follows:

•

Level 1 – Observable inputs that reflect unadjusted quoted prices for identical assets or liabilities in active markets as of the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.

•

Level 2 – Observable market-based inputs or unobservable inputs that are corroborated by market data. These are inputs other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the measurement date.

•

Level 3 – Unobservable inputs that are not corroborated by market data and may be used with internally developed methodologies that result in management’s best estimate of fair value.

Valuation techniques that maximize the use of observable inputs are favored. Assets and liabilities are classified in their entirety based on the lowest priority level of input that is significant to the fair value measurement. The assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the placement of assets and liabilities within the levels of the fair value hierarchy. We use a market or income approach for recurring fair value measurements and endeavor to use the best information available. See Item 8. Financial Statements and Supplementary Data—Note 18 for disclosures regarding our fair value measurements.

Significant uses of fair value measurements include:

•

assessment of impairment of long-lived assets;

•

assessment of impairment of goodwill;

•

assessment of impairment of equity method investments;

•

recorded value of derivative instruments; and

•

recorded value of investments in debt and equity securities.

Impairment Assessments of Long-Lived Assets, Goodwill and Equity Method Investments

Fair value calculated for the purpose of testing our long-lived assets, goodwill and equity method investments for impairment is estimated using the expected present value of future cash flows method and comparative market prices when appropriate. Significant judgment is involved in performing these fair value estimates since the results are based on forecasted assumptions. Significant assumptions include:

•

Future margins on products produced and sold. Our estimates of future product margins are based on our analysis of various supply and demand factors, which include, among other things, industry-wide capacity, our planned utilization rate, end-user demand, capital expenditures and economic conditions. Such estimates are consistent with those used in our planning and capital investment reviews.

•

Future volumes. Our estimates of future pipeline throughput volumes are based on internal forecasts prepared by our Pipeline Transportation segment operations personnel.

•

Discount rate commensurate with the risks involved. We apply a discount rate to our cash flows based on a variety of factors, including market and economic conditions, operational risk, regulatory risk and political risk. This discount rate is also compared to recent observable market transactions, if possible. A higher discount rate decreases the net present value of cash flows.

•

Future capital requirements. These are based on authorized spending and internal forecasts.

We base our fair value estimates on projected financial information which we believe to be reasonable. However, actual results may differ from these projections.

The need to test for impairment can be based on several indicators, including a significant reduction in prices of or demand for products produced, a poor outlook for profitability, a significant reduction in pipeline throughput volumes, significant reduction in refining margins, other changes to contracts or changes in the regulatory environment in which the asset or equity method investment is located.

Long-lived assets used in operations are assessed for impairment whenever changes in facts and circumstances indicate that the carrying value of the assets may not be recoverable. For purposes of impairment evaluation, long-lived assets must be grouped at the lowest level for which independent cash flows can be identified, which generally is the refinery and associated distribution system level for Refining & Marketing segment assets, site level for Speedway segment convenience stores or the pipeline system level for Pipeline Transportation segment assets. If the sum of the undiscounted estimated pretax cash flows is less than the carrying value of an asset group, fair value is calculated, and the carrying value is written down if greater than the calculated fair value.

Unlike long-lived assets, goodwill must be tested for impairment at least annually, or between annual tests if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting unit below its carrying amount. Goodwill is tested for impairment at the reporting unit level. At December 31, 2012, we had a total of $930 million of goodwill recorded on our consolidated balance sheet. The fair value of our reporting units exceeded book value appreciably for each of our reporting units in 2012.

Equity method investments are assessed for impairment whenever factors indicate an other than temporary loss in value. Factors providing evidence of such a loss include the fair value of an investment that is less than its carrying value, absence of an ability to recover the carrying value or the investee’s inability to generate income sufficient to justify our carrying value. At December 31, 2012, we had $321 million of investments in equity method investments recorded in our consolidated balance sheet.

An estimate of the sensitivity to net income resulting from impairment calculations is not practicable, given the numerous assumptions (e.g., pricing, volumes and discount rates) that can materially affect our estimates. That is, unfavorable adjustments to some of the above listed assumptions may be offset by favorable adjustments in other assumptions.

Derivatives

We record all derivative instruments at fair value. A large volume of our commodity derivatives are exchange-traded and require few assumptions in arriving at fair value. Fair value estimation for all our derivative instruments is discussed in Item 8. Financial Statements and Supplementary Data - Note 18. Additional information about derivatives and their valuation may be found in Item 7A. Quantitative and Qualitative Disclosures about Market Risk.

Pension and Other Postretirement Benefit Obligations

Accounting for pension and other postretirement benefit obligations involves numerous assumptions, the most significant of which relate to the following:

•

the discount rate for measuring the present value of future plan obligations;

•

the expected long-term return on plan assets;

•

the rate of future increases in compensation levels; and

•

health care cost projections.

We develop our demographics and utilize the work of third-party actuaries to assist in the measurement of these obligations. We have selected different discount rates for our funded pension plans and our unfunded retiree health care plans due to the different projected benefit payment patterns. The selected rates are compared to various similar bond indexes for reasonableness. In determining the assumed discount rates, we use our third-party actuary’s discount rate model. This model calculates an equivalent single discount rate for the projected benefit plan cash flows using a yield curve derived from Aa bond yields. The yield curve represents a series of annualized individual spot discount rates from 0.5 to 99 years. The bonds used are rated Aa or higher by a recognized rating agency and only non-callable bonds are included. Outlier bonds that have a yield to maturity that deviate significantly from the average yield within each maturity grouping are not included. Each issue is required to have at least $250 million par value outstanding.

Of the assumptions used to measure the year-end obligations and estimated annual net periodic benefit cost, the discount rate has the most significant effect on the periodic benefit cost reported for the plans. Decreasing the discount rates of 3.45 percent for our pension plans and 4.05 percent for our other postretirement benefit plans by 0.25 percent would increase pension obligations and other postretirement benefit plan obligations by $85 million and $21 million, respectively, and would increase defined benefit pension expense and other postretirement benefit plan expense by $6 million and $2 million, respectively.

The long-term asset rate of return assumption considers the asset mix of the plans (currently targeted at approximately 75 percent equity securities and 25 percent fixed income securities for the funded pension plans), past performance and other factors. Certain components of the asset mix are modeled with various assumptions regarding inflation and returns. In addition, our long-term asset rate of return assumption is compared to those of other companies and to historical returns for reasonableness. After evaluating activity in the capital markets, we reduced the asset rate of return from 8.50 percent to 7.50 percent effective for 2012. We have also used the 7.50 percent long-term rate of return to determine our 2013 defined benefit pension expense. Decreasing the 7.50 percent asset rate of return assumption by 0.25 percent would increase our defined benefit pension expense by $4 million.

Compensation change assumptions are based on historical experience, anticipated future management actions and demographics of the benefit plans.

Health care cost trend assumptions are developed based on historical cost data, the near-term outlook and an assessment of likely long-term trends.

Item 8. Financial Statements and Supplementary Data - Note 22 includes detailed information about the assumptions used to calculate the components of our annual defined benefit pension and other postretirement plan expense, as well as the obligations and accumulated other comprehensive loss reported on the year-end balance sheets.

Contingent Liabilities

We accrue contingent liabilities for legal actions, claims, litigation, environmental remediation, tax deficiencies related to operating taxes and third-party indemnities for specified tax matters when such contingencies are both probable and estimable. We regularly assess these estimates in consultation with legal counsel to consider resolved and new matters, material developments in court proceedings or settlement discussions, new information obtained as a result of ongoing discovery and past experience in defending and settling similar matters. Actual costs can differ from estimates for many reasons. For instance, settlement costs for claims and litigation can vary from estimates based on differing interpretations of laws, opinions on degree of responsibility and assessments of the amount of damages. Similarly, liabilities for environmental remediation may vary from estimates because of changes in laws, regulations and their interpretation, additional information on the extent and nature of site contamination and improvements in technology.

We generally record losses related to these types of contingencies as cost of revenues or selling, general and administrative expenses in the consolidated statements of income, except for tax deficiencies unrelated to income taxes, which are recorded as other taxes. For additional information on contingent liabilities, see Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations - Environmental Matters and Compliance Costs.

An estimate of the sensitivity to net income if other assumptions had been used in recording these liabilities is not practical because of the number of contingencies that must be assessed, the number of underlying assumptions and the wide range of reasonably possible outcomes, in terms of both the probability of loss and the estimates of such loss.

Accounting Standards Not Yet Adopted

In February 2013, the Financial Accounting Standards Board (“FASB”) issued an accounting standards update that requires an entity to provide information about the amounts reclassified out of accumulated other comprehensive income by component. If the amount reclassified is required under US GAAP to be reclassified to net income in its entirety in the same reporting period, an entity is required to present, either on the face of the financial statements or in the notes, significant amounts reclassified out of accumulated other comprehensive income by the respective line items of net income. For other amounts not required to be reclassed in their entirety to net income, an entity is required to cross-reference to other disclosures that provide additional detail about those amounts. The accounting standards update is effective prospectively for annual periods beginning after December 15, 2012, and interim periods within those annual periods. Adoption of this accounting standards update in the first quarter of 2013 is not expected to have an impact on our consolidated results of operations, financial position or cash flows.

In July 2012, the FASB issued an accounting standards update that gives an entity the option to first assess qualitatively whether it is more likely than not that an indefinite-lived intangible asset is impaired. If, through the qualitative assessment, an entity determines that it is more likely than not that the intangible asset is impaired, the quantitative impairment test must then be performed. The accounting standards update is effective for annual and interim impairment tests performed in fiscal years beginning after September 15, 2012. Early adoption is permitted. Adoption of this accounting standards update in the first quarter of 2013 is not expected to have an impact on our consolidated results of operations, financial position or cash flows.

In December 2011, the FASB issued an accounting standards update which was amended in January 2013 that requires disclosure of additional information related to recognized derivative instruments, repurchase agreements and reverse repurchase agreements, and securities borrowing and securities lending transactions that are offset or are not offset but are subject to an enforceable netting agreement. The purpose of the requirement is to help users evaluate the effect or potential effect of offsetting and related netting arrangements on an entity’s financial position. The update is to be applied retrospectively and is effective for annual periods that begin on or after January 1, 2013 and interim periods within those annual periods. Adoption of this update is not expected to have an impact on our consolidated results of operations, financial position or cash flows.

Item 7A. Quantitative and Qualitative Disclosures about Market Risk

General

We are exposed to market risks related to the volatility of crude oil and refined product prices. We employ various strategies, including the use of commodity derivative instruments, to hedge the risks related to these price fluctuations. We are also exposed to market risks related to changes in interest rates and foreign currency exchange rates. As of December 31, 2012, we did not have any financial derivative instruments to hedge the risks related to interest rate fluctuations; however, we have used them in the past and we continually monitor the market and our exposure and may enter into these agreements again in the future. We are at risk for changes in fair value of all of our derivative instruments; however, such risk should be mitigated by price or rate changes related to the underlying commodity or financial transaction.

We believe that our use of derivative instruments, along with our risk assessment procedures and internal controls, does not expose us to material adverse consequences. While the use of derivative instruments could materially affect our results of operations in particular quarterly or annual periods, we believe that the use of these instruments will not have a material adverse effect on our financial position or liquidity.

See Item 8. Financial Statements and Supplementary Data - Notes 18 and 19 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.

Commodity Price Risk

Our strategy is to obtain competitive prices for our products and allow operating results to reflect market price movements dictated by supply and demand. We use a variety of commodity derivative instruments, including futures, forwards, swaps and combinations of options, as part of an overall program to hedge commodity price risk. We also authorize the use of the market knowledge gained from these activities to do a limited amount of trading not directly related to our physical transactions.

We use commodity derivative instruments on crude oil and refined product inventories to hedge price risk associated with inventories above or below last-in, first-out inventory targets. We also use derivative instruments related to the acquisition of foreign-sourced crude oil and ethanol blended with refined petroleum products to hedge price risk associated with market volatility between the time we purchase the product and when we use it in the refinery production process or it is blended. In addition, we may use commodity derivative instruments on fixed price contracts for the sale of refined products to hedge risk by converting the refined product sales to market-based prices. The majority of these derivatives are exchange-traded contracts for crude oil, refined products and ethanol.

We closely monitor and hedge our exposure to market risk on a daily basis in accordance with policies approved by our board of directors. Our positions are monitored daily by a risk control group to ensure compliance with our stated risk management policy.

Open Derivative Positions and Sensitivity Analysis

The table below sets forth information relating to our significant open commodity derivative contracts as of December 31, 2012.

December 31, 2012

Position

Total Barrels
(In thousands)

Weighted Average Price
(Per barrel)

Benchmark

Crude Oil ^(a)

Exchange-traded

Long

15,643

97.45

CME and ICE Crude^(b)(c)

Exchange-traded

Short

(26,191

)

99.41

CME and ICE Crude^(b)(c)

Position

Total Barrels
(In thousands)

Weighted Average Price
(Per gallon)

Benchmark

Refined Products ^(a)

Exchange-traded

Long

2,720

2.86

CME Heating Oil and RBOB^(b)(d)

Exchange-traded

Short

(3,429

)

2.89

CME Heating Oil and RBOB^(b)(d)

^(a)

100 percent of these contracts expire in the first quarter of 2013.

^(b)

Chicago Mercantile Exchange (“CME”).

^(c)

Intercontinental Exchange (“ICE”)

^(d)

Reformulated Gasoline Blendstock for Oxygenate Blending (“RBOB”).

Sensitivity analysis of the incremental 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 December 31, 2012 is provided in the following table.