Document and Entity Information
Document and Entity Information - shares | 6 Months Ended | |
Jun. 30, 2018 | Aug. 01, 2018 | |
Document And Entity Information [Abstract] | ||
Document Type | 10-Q | |
Amendment Flag | false | |
Document Period End Date | Jun. 30, 2018 | |
Document Fiscal Year Focus | 2,018 | |
Document Fiscal Period Focus (Q1,Q2,Q3,FY) | Q2 | |
Trading Symbol | MPC | |
Entity Registrant Name | Marathon Petroleum Corp | |
Entity Central Index Key | 1,510,295 | |
Current Fiscal Year End Date | --12-31 | |
Entity Filer Category | Large Accelerated Filer | |
Entity Common Stock, Shares Outstanding | 451,004,632 |
Consolidated Statements of Inco
Consolidated Statements of Income - USD ($) shares in Millions, $ in Millions | 3 Months Ended | 6 Months Ended | ||||
Jun. 30, 2018 | Jun. 30, 2017 | Jun. 30, 2018 | Jun. 30, 2017 | |||
Revenues and other income: | ||||||
Sales and other operating revenues, excluding consumer excise taxes | $ 22,118 | [1] | $ 40,812 | |||
Sales and other operating revenues, including consumer excise taxes | $ 18,033 | [1] | $ 34,167 | |||
Sales to related parties | 199 | 147 | 371 | 301 | ||
Income from equity method investments | 80 | 83 | 166 | 140 | ||
Net gain on disposal of assets | 3 | 7 | 5 | 12 | ||
Other income | 45 | 84 | 75 | 127 | ||
Total revenues and other income | 22,445 | 18,354 | 41,429 | 34,747 | ||
Costs and expenses: | ||||||
Cost of revenues (excludes items below) | 19,517 | [1] | 16,101 | [1] | 36,887 | 31,047 |
Purchases from related parties | 138 | 150 | 279 | 272 | ||
Depreciation and amortization | 533 | 521 | 1,061 | 1,057 | ||
Selling, general and administrative expenses | 424 | 485 | 826 | 875 | ||
Other taxes | 122 | 115 | 225 | 223 | ||
Total costs and expenses | 20,734 | 17,372 | 39,278 | 33,474 | ||
Income from operations | 1,711 | 982 | 2,151 | 1,273 | ||
Net interest and other financial costs | 195 | 158 | 378 | 307 | ||
Income before income taxes | 1,516 | 824 | 1,773 | 966 | ||
Provision for income taxes | 281 | 250 | 303 | 291 | ||
Net income | 1,235 | 574 | 1,470 | 675 | ||
Less net income attributable to: | ||||||
Redeemable noncontrolling interest | 20 | 17 | 36 | 33 | ||
Noncontrolling interests | 160 | 74 | 342 | 129 | ||
Net income attributable to MPC | $ 1,055 | $ 483 | $ 1,092 | $ 513 | ||
Basic: | ||||||
Net income attributable to MPC per share | $ 2.30 | $ 0.94 | $ 2.34 | $ 0.99 | ||
Weighted average shares outstanding (in shares) | 459 | 513 | 467 | 519 | ||
Diluted: | ||||||
Net income attributable to MPC per share | $ 2.27 | $ 0.93 | $ 2.31 | $ 0.98 | ||
Weighted average shares outstanding (in shares) | 464 | 517 | 472 | 523 | ||
Dividends paid (in USD per share) | $ 0.46 | $ 0.36 | $ 0.92 | $ 0.72 | ||
[1] | The 2018 period reflects an election to present certain taxes on a net basis. See Notes 2 and 3 for further information. |
Consolidated Statements of Comp
Consolidated Statements of Comprehensive Income - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2018 | Jun. 30, 2017 | Jun. 30, 2018 | Jun. 30, 2017 | |
Statement of Comprehensive Income [Abstract] | ||||
Net income | $ 1,235 | $ 574 | $ 1,470 | $ 675 |
Defined benefit postretirement and post-employment plans: | ||||
Actuarial changes, net of tax of $2, $4, $5 and $7, respectively | 7 | 7 | 14 | 11 |
Prior service costs, net of tax of ($2), ($4), ($4) and ($8), respectively | (7) | (6) | (14) | (13) |
Other, net of tax of $0, $0, ($1) and $0, respectively | 0 | 0 | (2) | 0 |
Other comprehensive income (loss) | 0 | 1 | (2) | (2) |
Comprehensive income | 1,235 | 575 | 1,468 | 673 |
Less comprehensive income attributable to: | ||||
Redeemable noncontrolling interest | 20 | 17 | 36 | 33 |
Noncontrolling interests | 160 | 74 | 342 | 129 |
Comprehensive income attributable to MPC | $ 1,055 | $ 484 | $ 1,090 | $ 511 |
Consolidated Statements of Com4
Consolidated Statements of Comprehensive Income (Parenthetical) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2018 | Jun. 30, 2017 | Jun. 30, 2018 | Jun. 30, 2017 | |
Statement of Comprehensive Income [Abstract] | ||||
Actuarial changes, tax | $ 2 | $ 4 | $ 5 | $ 7 |
Prior service costs, tax | (2) | (4) | (4) | (8) |
Other, tax | $ 0 | $ 0 | $ (1) | $ 0 |
Consolidated Balance Sheets
Consolidated Balance Sheets - USD ($) $ in Millions | Jun. 30, 2018 | Dec. 31, 2017 |
Current assets: | ||
Cash and cash equivalents (MPLX: $3 and $5, respectively) | $ 4,999 | $ 3,011 |
Receivables, less allowance for doubtful accounts of $10 and $11 (MPLX: $370 and $299, respectively) | 4,919 | 4,695 |
Inventories (MPLX: $73 and $65, respectively) | 5,485 | 5,550 |
Other current assets (MPLX: $36 and $29, respectively) | 145 | 145 |
Total current assets | 15,548 | 13,401 |
Equity method investments (MPLX: $4,042 and $4,010, respectively) | 4,838 | 4,787 |
Property, plant and equipment, net (MPLX: $13,642 and $12,187, respectively) | 26,931 | 26,443 |
Goodwill (MPLX: $2,460 and $2,245, respectively) | 3,586 | 3,586 |
Other noncurrent assets (MPLX: $472 and $479, respectively) | 833 | 830 |
Total assets | 51,736 | 49,047 |
Current liabilities: | ||
Accounts payable (MPLX: $728 and $621, respectively) | 8,113 | 8,297 |
Payroll and benefits payable (MPLX: $2 and $1, respectively) | 432 | 591 |
Accrued taxes (MPLX: $46 and $38, respectively) | 713 | 670 |
Debt due within one year (MPLX: $1 and $1, respectively) | 26 | 624 |
Other current liabilities (MPLX: $222 and $130, respectively) | 431 | 296 |
Total current liabilities | 9,715 | 10,478 |
Long-term debt (MPLX: $11,874 and $6,945, respectively) | 17,241 | 12,322 |
Deferred income taxes (MPLX: $11 and $5, respectively) | 3,144 | 2,654 |
Defined benefit postretirement plan obligations | 1,156 | 1,099 |
Deferred credits and other liabilities (MPLX: $246 and $230, respectively) | 659 | 666 |
Total liabilities | 31,915 | 27,219 |
Commitments and contingencies (see Note 22) | ||
Redeemable noncontrolling interest | 1,003 | 1,000 |
MPC stockholders’ equity: | ||
Preferred stock, no shares issued and outstanding (par value $0.01 per share, 30 million shares authorized) | 0 | 0 |
Common stock: | ||
Issued – 735 million and 734 million shares (par value $0.01 per share, 1 billion shares authorized) | 7 | 7 |
Held in treasury, at cost – 279 million and 248 million shares | (12,093) | (9,869) |
Additional paid-in capital | 13,688 | 11,262 |
Retained earnings | 13,589 | 12,864 |
Accumulated other comprehensive loss | (233) | (231) |
Total MPC stockholders’ equity | 14,958 | 14,033 |
Noncontrolling interests | 3,860 | 6,795 |
Total equity | 18,818 | 20,828 |
Total liabilities, redeemable noncontrolling interest and equity | $ 51,736 | $ 49,047 |
Consolidated Balance Sheets (Pa
Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions | Jun. 30, 2018 | Dec. 31, 2017 |
Statement of Financial Position [Abstract] | ||
Allowance for doubtful accounts | $ 10 | $ 11 |
Preferred stock: | ||
Shares issued | 0 | 0 |
Shares outstanding | 0 | 0 |
Par value | $ 0.01 | |
Shares authorized | 30,000,000 | |
Common stock: | ||
Shares issued | 735,000,000 | 734,000,000 |
Par value | $ 0.01 | |
Shares authorized | 1,000,000,000 | |
Treasury stock | (279,000,000) | (248,000,000) |
Consolidated Balance Sheets (MP
Consolidated Balance Sheets (MPLX Parenthetical) - USD ($) $ in Millions | Jun. 30, 2018 | Dec. 31, 2017 |
Assets | ||
Cash and cash equivalents | $ 4,999 | $ 3,011 |
Receivables, less allowance for doubtful accounts | 4,919 | 4,695 |
Inventories | 5,485 | 5,550 |
Other current assets | 145 | 145 |
Equity method investments | 4,838 | 4,787 |
Property, plant and equipment, net | 26,931 | 26,443 |
Goodwill | 3,586 | 3,586 |
Other noncurrent assets | 833 | 830 |
Liabilities | ||
Accounts payable | 8,113 | 8,297 |
Payroll and benefits payable | 432 | 591 |
Accrued taxes | 713 | 670 |
Debt due within one year | 26 | 624 |
Other current liabilities | 431 | 296 |
Total long-term debt due after one year | 17,241 | 12,322 |
Deferred income taxes (MPLX: $11 and $5, respectively) | 3,144 | 2,654 |
Defined benefit postretirement plan obligations | 1,156 | 1,099 |
Deferred credits and other liabilities | 659 | 666 |
MPLX LP | ||
Assets | ||
Cash and cash equivalents | 3 | 5 |
Receivables, less allowance for doubtful accounts | 370 | 299 |
Inventories | 73 | 65 |
Other current assets | 36 | 29 |
Equity method investments | 4,042 | 4,010 |
Property, plant and equipment, net | 13,642 | 12,187 |
Goodwill | 2,460 | 2,245 |
Other noncurrent assets | 472 | 479 |
Liabilities | ||
Accounts payable | 728 | 621 |
Payroll and benefits payable | 2 | 1 |
Accrued taxes | 46 | 38 |
Debt due within one year | 1 | 1 |
Other current liabilities | 222 | 130 |
Total long-term debt due after one year | 11,874 | 6,945 |
Deferred income taxes (MPLX: $11 and $5, respectively) | 11 | 5 |
Defined benefit postretirement plan obligations | 0 | 0 |
Deferred credits and other liabilities | $ 246 | $ 230 |
Consolidated Statements of Cash
Consolidated Statements of Cash Flows - USD ($) $ in Millions | 6 Months Ended | ||
Jun. 30, 2018 | Jun. 30, 2017 | ||
Operating activities: | |||
Net income | $ 1,470 | $ 675 | |
Adjustments to reconcile net income to net cash provided by operating activities: | |||
Amortization of deferred financing costs and debt discount | 35 | 30 | |
Depreciation and amortization | 1,061 | 1,057 | |
Pension and other postretirement benefits, net | 65 | (59) | |
Deferred income taxes | 2 | 23 | |
Net gain on disposal of assets | (5) | (12) | |
Income from equity method investments | (166) | (140) | |
Distributions from equity method investments | 217 | 136 | |
Changes in the fair value of derivative instruments | 1 | 59 | |
Changes in: | |||
Current receivables | (225) | 344 | |
Inventories | 66 | 107 | |
Current accounts payable and accrued liabilities | (231) | (208) | |
All other, net | (41) | (51) | |
Net cash provided by operating activities | 2,249 | 1,961 | |
Investing activities: | |||
Additions to property, plant and equipment | (1,466) | (1,265) | |
Acquisitions, net of cash acquired | 0 | (220) | |
Disposal of assets | 14 | 37 | |
Investments – acquisitions, loans and contributions | (118) | (677) | |
Investments - redemptions, repayments and return of capital | 15 | 24 | |
All other, net | 37 | 89 | |
Net cash used in investing activities | (1,518) | (2,012) | |
Financing activities: | |||
Commercial paper – issued | 0 | 300 | |
Commercial paper - repayments | 0 | (300) | |
Long-term debt – borrowings | 9,610 | 2,241 | |
Long-term debt – repayments | (5,270) | (213) | |
Debt issuance costs | (53) | (21) | |
Issuance of common stock | 21 | 20 | |
Common stock repurchased | (2,212) | (1,170) | |
Dividends paid | (430) | (376) | |
Issuance of MPLX LP common units | 0 | 434 | |
Distributions to noncontrolling interests | (394) | (324) | |
Contributions from noncontrolling interests | 5 | 128 | |
Contingent consideration payment | 0 | (89) | |
All other, net | (19) | (17) | |
Net cash provided by financing activities | 1,258 | 613 | |
Net increase in cash, cash equivalents and restricted cash | 1,989 | 562 | |
Cash, cash equivalents and restricted cash at beginning of period | 3,015 | [1] | 892 |
Cash, cash equivalents and restricted cash at end of period | $ 5,004 | [1] | $ 1,454 |
[1] | As a result of the adoption of ASU 2016-18, the consolidated statements of cash flows now explain the change during the period of both “Cash and cash equivalents” and “Restricted cash.” |
Consolidated Statements of Equi
Consolidated Statements of Equity - USD ($) $ in Millions | Total | Common Stock | Treasury Stock | Additional Paid-in Capital | Retained Earnings | Accumulated Other Comprehensive Loss | Non-controlling Interests |
Beginning balance at Dec. 31, 2016 | $ 20,203 | $ 7 | $ (7,482) | $ 11,060 | $ 10,206 | $ (234) | $ 6,646 |
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||
Net income | 642 | 513 | 129 | ||||
Dividends declared | (375) | (375) | |||||
Distributions to noncontrolling interests | (291) | (291) | |||||
Contributions from noncontrolling interests | 128 | 128 | |||||
Other comprehensive loss | (2) | (2) | |||||
Shares repurchased | (1,170) | (1,170) | |||||
Shares returned - stock based compensation | (12) | ||||||
Shares issued - stock based compensation | 47 | ||||||
Net shares issued - stock based compensation | 36 | 1 | |||||
Impact from equity transactions of MPLX LP | 393 | 78 | 315 | ||||
Ending balance at Jun. 30, 2017 | 19,564 | 7 | (8,664) | 11,185 | 10,344 | (236) | 6,928 |
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||
Cumulative effect of new accounting principle in period of adoption | 64 | 63 | 1 | ||||
Beginning balance at Dec. 31, 2017 | 20,828 | 7 | (9,869) | 11,262 | 12,864 | (231) | 6,795 |
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||
Net income | 1,434 | 1,092 | 342 | ||||
Dividends declared | (430) | (430) | |||||
Distributions to noncontrolling interests | (361) | (361) | |||||
Contributions from noncontrolling interests | 5 | 5 | |||||
Other comprehensive loss | (2) | (2) | |||||
Shares repurchased | (2,212) | (2,212) | |||||
Shares returned - stock based compensation | (12) | ||||||
Shares issued - stock based compensation | 45 | ||||||
Net shares issued - stock based compensation | 38 | 5 | |||||
Impact from equity transactions of MPLX LP | (546) | 2,381 | (2,927) | ||||
Ending balance at Jun. 30, 2018 | $ 18,818 | $ 7 | $ (12,093) | $ 13,688 | $ 13,589 | $ (233) | $ 3,860 |
Consolidated Statement of Equit
Consolidated Statement of Equity - Shares - shares shares in Millions | Total | Common Stock | Treasury Stock |
Number of common shares issued (beginning balance) at Dec. 31, 2016 | 731 | ||
Number of common shares issued - stock compensation | 1 | ||
Number of common shares issued (ending balance) at Jun. 30, 2017 | 732 | ||
Number of shares held in treasury (beginning balance) at Dec. 31, 2016 | (203) | ||
Number of shares repurchased | (23) | (23) | |
Number of shares returned - stock compensation | 0 | ||
Number of shares held in treasury (ending balance) at Jun. 30, 2017 | (226) | ||
Number of common shares issued (beginning balance) at Dec. 31, 2017 | 734 | 734 | |
Number of common shares issued - stock compensation | 1 | ||
Number of common shares issued (ending balance) at Jun. 30, 2018 | 735 | 735 | |
Number of shares held in treasury (beginning balance) at Dec. 31, 2017 | (248) | (248) | |
Number of shares repurchased | (31) | (31) | |
Number of shares returned - stock compensation | 0 | ||
Number of shares held in treasury (ending balance) at Jun. 30, 2018 | (279) | (279) |
Redeemable Noncontrolling Inter
Redeemable Noncontrolling Interest - USD ($) $ in Millions | 6 Months Ended | |
Jun. 30, 2018 | Jun. 30, 2017 | |
Temporary Equity [Abstract] | ||
Beginning balance | $ 1,000 | $ 1,000 |
Net income attributable to redeemable noncontrolling interest | 36 | 33 |
Distributions to noncontrolling interests | (33) | (33) |
Ending balance | $ 1,003 | $ 1,000 |
Description of the Business and
Description of the Business and Basis of Presentation | 6 Months Ended |
Jun. 30, 2018 | |
Accounting Policies [Abstract] | |
Description of the Business and Basis of Presentation | DESCRIPTION OF THE BUSINESS AND BASIS OF PRESENTATION Description of the Business Our business consists of refining and marketing, retail and midstream services conducted primarily in the Midwest, Gulf Coast, East Coast, Northeast and Southeast regions of the United States, through subsidiaries, including Marathon Petroleum Company LP (“MPC LP”), Speedway LLC and its subsidiaries (“Speedway”) and MPLX LP and its subsidiaries (“MPLX”). See Note 10 for additional information about our operations. Basis of Presentation All significant intercompany transactions and accounts have been eliminated. These interim consolidated financial statements are unaudited; however, in the opinion of our management, these statements reflect all adjustments necessary for a fair statement of the results for the periods reported. All such adjustments are of a normal, recurring nature unless otherwise disclosed. These interim consolidated financial statements, including the notes, have been prepared in accordance with the rules of the SEC applicable to interim period financial statements and do not include all of the information and disclosures required by GAAP for complete financial statements. These interim consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2017 . The results of operations for the three and six months ended June 30, 2018 are not necessarily indicative of the results to be expected for the full year. Certain prior period financial statement amounts have been reclassified to conform to current period presentation. |
Summary of Principal Accounting
Summary of Principal Accounting Policies | 6 Months Ended |
Jun. 30, 2018 | |
Accounting Policies [Abstract] | |
Summary of Principal Accounting Policies | SUMMARY OF PRINCIPAL ACCOUNTING POLICIES Revenue Recognition As described in Note 3 , we adopted ASU 2014-09, Revenue from Contracts with Customers (“ASC 606”) effective January 1, 2018. We recognize revenue based on consideration specified in contracts or agreements with customers when we satisfy our performance obligations by transferring control over products or services to a customer. Concurrent with our adoption of ASC 606, we made an accounting policy election that all taxes assessed by a governmental authority that are both imposed on and concurrent with a revenue-producing transaction and collected from our customers will be recognized on a net basis within “Sales and other operating revenues.” The adoption of ASC 606 did not materially change our revenue recognition patterns, which are described below by reportable segment: • Refining & Marketing - The vast majority of our Refining & Marketing contracts contain pricing that is based on the market price for the product at the time of delivery. Our obligations to deliver product volumes are typically satisfied and revenue is recognized when control of the product transfers to our customers. Concurrent with the transfer of control, we typically receive the right to payment for the delivered product, the customer accepts the product and the customer has significant risks and rewards of ownership of the product. Payment terms require customers to pay shortly after delivery and do not contain significant financing components. • Speedway - Revenue is recognized when our customers receive control of the transportation fuels or merchandise. Payments from customers are received at the time sales occur in cash or by credit or debit card. Speedway offers a loyalty rewards program to its customers. We defer a minor portion of revenue on sales to the loyalty program participants until the participants redeem their rewards. The related contract liability, as defined in the standard, is not material to our financial statements. • Midstream - Midstream revenue transactions typically are defined by contracts under which we sell a product or provide a service. Revenues from sales of product are recognized when control of the product transfers to the customer. Revenues from sales of services are recognized over time when the performance obligation is satisfied as services are provided in a series. We have elected to use the output measure of progress to recognize revenue based on the units delivered, processed or transported. The transaction price in our Midstream contracts often has both fixed components, related to minimum volume commitments, and variable components which are primarily dependent on volumes. Variable consideration will generally not be estimated at contract inception as the transaction price is specifically allocable to the services provided at each period end. Refer to Note 10 for disclosure of our revenue disaggregated by segment and product line, as well as a description of our reportable segment operations. |
Accounting Standards
Accounting Standards | 6 Months Ended |
Jun. 30, 2018 | |
New Accounting Pronouncements and Changes in Accounting Principles [Abstract] | |
Recently Adopted | ACCOUNTING STANDARDS Recently Adopted ASU 2014-09, Revenue - Revenue from Contracts with Customers (ASC 606) On January 1, 2018, we adopted the new revenue standard, applying the modified retrospective method, whereby a cumulative effect is recorded to opening retained earnings and ASC 606 is applied prospectively. We recorded a net increase of $1 million to our retained earnings balance as of January 1, 2018 due to the cumulative effect of applying the new revenue standard. Impact of Adoption The adoption of ASC 606 did not materially change our revenue recognition patterns. The most significant impacts of adopting ASC 606 for the period ended June 30, 2018 are as follows: • a reduction of “Sales and other operating revenues” of $1.36 billion for the three months ended June 30, 2018 and $2.61 billion for the six months ended June 30, 2018 due to our accounting policy election to present taxes incurred concurrently with revenue producing transactions and collected on behalf of our customers on a net basis. For the three and six months ended June 30, 2017 , taxes are reflected on a gross basis in “Sales and other operating revenues” and “Cost of revenues”, and include $1.27 billion and $2.47 billion , respectively, of taxes that are now subject to our net basis accounting policy election. • an increase to both “Sales and other operating revenues” and “Cost of revenues” of $124 million for the three months ended June 30, 2018 and $240 million for the six months ended June 30, 2018 related to certain Midstream contract provisions for third-party reimbursements, non-cash consideration and imbalances that require gross presentation under ASC 606. Comparative information continues to be reported under the accounting standards in effect for those periods. Practical Expedients We elected the completed contract practical expedient and only applied ASC 606 to contracts that were not completed as of January 1, 2018. We do not disclose information on the future performance obligations for any contract with expected duration of one year or less at inception. As of June 30, 2018 , we do not have future performance obligations that are material to future periods. Receivables On the accompanying consolidated balance sheets, “Receivables, less allowance for doubtful accounts” primarily consists of customer receivables. Significant, non-customer balances included in our receivables at June 30, 2018 include matching buy/sell receivables of $1.50 billion and income tax receivables of $117 million . ASU 2016-16, Income Taxes - Intra-Entity Transfers of Assets Other Than Inventory We adopted this accounting standards update in the first quarter of 2018 and recorded a $61 million cumulative-effect adjustment as an increase to retained earnings as of January 1, 2018 with the offset recorded as a reduction to “Deferred Income Taxes.” We also adopted the following standards during the first six months of 2018, none of which had a material impact to our financial statements or financial statement disclosures: ASU Effective Date 2017-09 Stock Compensation - Scope of Modification Accounting January 1, 2018 2017-07 Retirement Benefits - Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Cost January 1, 2018 2017-05 Gains and Losses from the Derecognition of Nonfinancial Assets - Clarifying the Scope of Asset Derecognition Guidance January 1, 2018 2017-01 Business Combinations - Clarifying the Definition of a Business January 1, 2018 2016-18 Statement of Cash Flows - Restricted Cash January 1, 2018 2016-15 Statement of Cash Flows - Classification of Certain Cash Receipts and Cash Payments January 1, 2018 2016-01 Financial Instruments - Recognition and Measurement of Financial Assets and Liabilities January 1, 2018 |
Not Yet Adopted | Not Yet Adopted ASU 2018-02, Reporting Comprehensive Income - Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income In February 2018, the FASB issued an accounting standards update allowing an entity the choice to reclassify to retained earnings the tax effects related to the TCJA that are stranded in accumulated other comprehensive income. We do not expect adoption of this standard to have a material impact on our financial statements. The amendment is effective beginning in 2019 with early adoption permitted. ASU 2017-12, Derivatives and Hedging - Targeted Improvements to Accounting for Hedging Activities In August 2017, the FASB issued an accounting standards update to amend the hedge accounting rules to simplify the application of hedge accounting guidance and better portray the economic results of risk management activities in the financial statements. The guidance expands the ability to hedge nonfinancial and financial risk components, reduces complexity in fair value hedges of interest rate risk, eliminates the requirement to separately measure and report hedge ineffectiveness and eases certain hedge effectiveness assessment requirements. The guidance is effective beginning in 2019 with early adoption permitted. We are currently evaluating the impact of this guidance, including transition elections and required disclosures, on our financial statements and the timing of adoption. However, since we have not historically designated our commodity derivatives as hedges, we do not expect the adoption of this accounting standards update to have a material impact on our consolidated financial statements. ASU 2017-04, Intangibles - Goodwill and Other - Simplifying the Test for Goodwill Impairment In January 2017, the FASB issued an accounting standards update which simplifies the subsequent measurement of goodwill by eliminating Step 2 from the goodwill impairment test. Under the new guidance, the recognition of an impairment charge is calculated based on the amount by which the carrying amount exceeds the reporting unit’s fair value, which could be different from the amount calculated under the current method using the implied fair value of the goodwill; however, the loss recognized should not exceed the total amount of goodwill allocated to that reporting unit. The guidance should be applied on a prospective basis, and is effective for annual or any interim goodwill impairment tests in fiscal years beginning after December 15, 2019. ASU 2016-13, Credit Losses - Measurement of Credit Losses on Financial Instruments In June 2016, the FASB issued an accounting standards update related to the accounting for credit losses on certain financial instruments. The guidance requires that for most financial assets, losses be based on an expected loss approach which includes estimates of losses over the life of exposure that considers historical, current and forecasted information. Expanded disclosures related to the methods used to estimate the losses as well as a specific disaggregation of balances for financial assets are also required. The change is effective for fiscal years beginning after December 15, 2019, and interim periods within those fiscal years, with early adoption permitted for fiscal years beginning after December 15, 2018, and interim periods within those fiscal years. We do not expect application of this accounting standards update to have a material impact on our consolidated financial statements. ASU 2016-02, Leases In February 2016, the FASB issued an accounting standards update requiring lessees to record virtually all leases on their balance sheets. The accounting standards update also requires expanded disclosures to help financial statement users better understand the amount, timing and uncertainty of cash flows arising from leases. For lessors, this amended guidance modifies the classification criteria and the accounting for sales-type and direct financing leases. The change will be effective on a modified retrospective basis for fiscal years beginning after December 15, 2018, and interim periods within those years, with early adoption permitted. We continue to evaluate the impact of this standard on our financial statements and disclosures, internal controls and accounting policies. This evaluation process includes reviewing all forms of leases, performing a completeness assessment over the lease population and analyzing the practical expedients in order to determine the best path of implementing changes to existing processes and controls. We are implementing a third-party supported lease accounting information system to account for our lease population in accordance with this new standard and establishing internal controls over the new system. We believe the adoption of the standard will have a material impact on our consolidated financial statements as virtually all leases will be recognized as a right of use asset and lease obligation. |
MPLX LP
MPLX LP | 6 Months Ended |
Jun. 30, 2018 | |
Noncontrolling Interest [Abstract] | |
MPLX LP | MPLX LP MPLX is a diversified, growth-oriented publicly traded master limited partnership formed by us to own, operate, develop and acquire midstream energy infrastructure assets. MPLX is engaged in the gathering, processing and transportation of natural gas; the gathering, transportation, fractionation, storage and marketing of NGLs; and the transportation, storage, distribution and marketing of crude oil and refined petroleum products. As of June 30, 2018 , we owned 63.6 percent of the outstanding MPLX common units and control MPLX through our ownership of the general partner interest in MPLX. MPLX is a VIE because the limited partners of MPLX do not have substantive kick-out or substantive participating rights over the general partner. We are the primary beneficiary of MPLX because in addition to our significant economic interest, we also have the power, through our 100 percent ownership of the general partner, to control the decisions that most significantly impact MPLX. We therefore consolidate MPLX and record a noncontrolling interest for the 36.4 percent interest owned by the public. We also record a redeemable noncontrolling interest related to MPLX’s preferred units. The creditors of MPLX do not have recourse to MPC’s general credit through guarantees or other financial arrangements. The assets of MPLX are the property of MPLX and cannot be used to satisfy the obligations of MPC. MPC has effectively guaranteed certain indebtedness of LOOP LLC (“LOOP”) and LOCAP LLC (“LOCAP”), in which MPLX holds an interest. See Note 22 for more information. Dropdowns to MPLX and GP/IDR Exchange On February 1, 2018, we contributed our refining logistics assets and fuels distribution services to MPLX in exchange for $4.1 billion in cash and approximately 112 million common units and 2 million general partner units from MPLX. MPLX financed the cash portion of the transaction with its $4.1 billion 364 -day term loan facility, which was entered into on January 2, 2018. We agreed to waive approximately one-third of the first quarter 2018 distributions on the common units issued in connection with this transaction. The contributions of these assets were accounted for as transactions between entities under common control and we did not record a gain or loss. Immediately following the February 1, 2018 dropdown to MPLX, our IDRs were cancelled and our economic general partner interest was converted into a non-economic general partner interest, all in exchange for 275 million newly issued MPLX common units (“GP/IDR Exchange”). As a result of this transaction, the general partner units and IDRs were eliminated, are no longer outstanding and no longer participate in distributions of cash from MPLX. On September 1, 2017, we contributed our joint-interest ownership in certain pipelines and storage facilities to MPLX in exchange for $420 million in cash and approximately 19 million common units and 378 thousand general partner units from MPLX. We also agreed to waive approximately two-thirds of the third quarter 2017 common unit distributions, IDRs and general partner distributions with respect to the common units issued in this transaction. The contributions of these assets were accounted for as transactions between entities under common control and we did not record a gain or loss. On March 1, 2017, we contributed certain terminal, pipeline and storage assets to MPLX in exchange for $1.5 billion in cash and approximately 13 million common units and 264 thousand general partner units from MPLX. We also agreed to waive two-thirds of the first quarter 2017 common unit distributions, IDRs and general partner distributions with respect to the common units issued in this transaction. The contributions of these assets were accounted for as transactions between entities under common control and we did not record a gain or loss. Noncontrolling Interest in MPLX As a result of equity transactions of MPLX, we are required to adjust non-controlling interest and additional paid-in capital. Changes in MPC’s additional paid-in capital resulting from changes in its ownership interests in MPLX were as follows: Six Months Ended (In millions) 2018 2017 Increase due to the issuance of MPLX LP common units to the public $ 5 $ 25 Increase due to the issuance of MPLX LP common units and general partner units to MPC 1,114 94 Increase due to GP/IDR Exchange 1,808 — Increase in MPC's additional paid-in capital 2,927 119 Tax impact (546 ) (41 ) Increase in MPC's additional paid-in capital, net of tax $ 2,381 $ 78 Agreements We have various long-term, fee-based commercial agreements with MPLX. Under these agreements, MPLX provides transportation, storage, distribution and marketing services to us. Under certain agreements, we commit to provide MPLX with minimum quarterly throughput and distribution volumes of crude oil and refined products and minimum storage volumes of crude oil, refined products and butane. Under certain other agreements, we commit to pay for 100 percent of available capacity for certain marine transportation and refining logistics assets. We also have agreements with MPLX that establish fees for operational and management services provided between us and MPLX and for executive management services and certain general and administrative services provided by us to MPLX. These transactions are eliminated in consolidation, but are reflected as intersegment transactions between our Refining & Marketing and Midstream segments. |
Acquisitions and Investments
Acquisitions and Investments | 6 Months Ended |
Jun. 30, 2018 | |
Business Combinations [Abstract] | |
Acquisitions and Investments | ACQUISITIONS AND INVESTMENTS Pending Merger with Andeavor On April 29, 2018 , MPC and Andeavor (“ANDV”) entered into a definitive merger agreement under which MPC has agreed to acquire all of ANDV’s outstanding shares. Under the terms of the agreement, ANDV shareholders will have the option to choose 1.87 shares of MPC stock or $152.27 in cash per share of ANDV common stock. The merger agreement includes election proration provisions that will result in approximately 22.9 million Andeavor shares being converted into cash consideration and the remaining Andeavor shares of approximately 128.2 million being converted into stock consideration. The aggregate cash consideration will be approximately $3.5 billion . The transaction was unanimously approved by the boards of directors of both companies , and MPC’s joint proxy statement/prospectus with ANDV has been declared effective by the Securities and Exchange Commission. The closing of the transaction remains subject to, among other things, customary closing conditions, including receipt of the approval of shareholders at the special meetings of both MPC and ANDV, which are scheduled for September 24, 2018. We recognized transaction costs related to the pending merger of $10 million , which are reflected in selling, general and administrative expenses for the three and six months ended June 30, 2018 . Acquisition of Ozark Pipeline On March 1, 2017, MPLX acquired the Ozark pipeline from Enbridge Pipelines (Ozark) LLC for approximately $219 million , including purchase price adjustments made in the second quarter of 2017. Based on the fair value of assets acquired and liabilities assumed at the acquisition date, the final purchase price was primarily allocated to property, plant and equipment. The Ozark pipeline is a 433 -mile, 22 -inch crude oil pipeline originating in Cushing, Oklahoma, and terminating in Wood River, Illinois, capable of transporting approximately 230 mbpd. We account for the Ozark pipeline within the Midstream segment. Assuming the acquisition of the Ozark pipeline had occurred on January 1, 2016, the consolidated pro forma results would not have been materially different from reported results. Investment in Pipeline Company On February 15, 2017, MPLX acquired a partial, indirect equity interest in the Dakota Access Pipeline (“DAPL”) and Energy Transfer Crude Oil Company Pipeline (“ETCOP”) projects, collectively referred to as the Bakken Pipeline system, through a joint venture with Enbridge Energy Partners L.P. (“Enbridge Energy Partners”). The Bakken Pipeline system is capable of transporting more than 520 mbpd of crude oil from the Bakken/Three Forks production area in North Dakota to the Midwest through Patoka, Illinois and ultimately to the Gulf Coast. MPLX contributed $500 million of the $2 billion purchase price paid by the joint venture, MarEn Bakken Company LLC (“MarEn Bakken”), to acquire a 36.75 percent indirect equity interest in the Bakken Pipeline system from Energy Transfer Partners, L.P. (“ETP”) and Sunoco Logistics Partners, L.P. (“SXL”). MPLX holds, through a subsidiary, a 25 percent interest in MarEn Bakken, which equates to an approximate 9.2 percent indirect equity interest in the Bakken Pipeline system. We account for the investment in MarEn Bakken as part of our Midstream segment using the equity method of accounting. Formation of Gathering and Processing Joint Venture Effective January 1, 2017, MPLX and Antero Midstream formed a joint venture, Sherwood Midstream LLC (“Sherwood Midstream”), to support the development of Antero Resources Corporation’s Marcellus Shale acreage in West Virginia. MPLX has a 50 percent ownership interest in Sherwood Midstream. In connection with this transaction, MPLX contributed assets then under construction at the Sherwood Complex with a fair value of approximately $134 million and cash of approximately $20 million . Antero Midstream made an initial capital contribution of approximately $154 million . Also effective January 1, 2017, MPLX converted all of its ownership interests in MarkWest Ohio Fractionation Company, L.L.C. (“Ohio Fractionation”), a previously wholly-owned subsidiary, to Class A Interests and amended its LLC Agreement to create Class B-3 Interests, which were sold to Sherwood Midstream for $126 million in cash. The Class B-3 Interests provide Sherwood Midstream with the right to fractionation revenue and the obligation to pay expenses related to 20 mbpd of capacity in the Hopedale 3 fractionator. Effective January 1, 2017, MPLX and Sherwood Midstream formed a joint venture, Sherwood Midstream Holdings LLC (“Sherwood Midstream Holdings”), for the purpose of owning, operating and maintaining all of the shared assets for the benefit of and use in the operation of the gas plants and other assets owned by Sherwood Midstream and the gas plants and deethanization facilities owned by MPLX. MPLX contributed certain real property, equipment and facilities with a fair value of approximately $209 million to Sherwood Midstream Holdings in exchange for a 79 percent initial ownership interest. Sherwood Midstream contributed cash of approximately $44 million to Sherwood Midstream Holdings in exchange for a 21 percent ownership interest. The net book value of the contributed assets was approximately $203 million . The contribution was determined to be an in-substance sale of real estate. During the six months ended June 30, 2018 , MPLX sold to Sherwood Midstream six percent of its equity ownership in Sherwood Midstream Holdings for $15 million . We account for our direct interests in Sherwood Midstream and Sherwood Midstream Holdings as part of our Midstream segment using the equity method of accounting. We continue to consolidate Ohio Fractionation and have recognized a noncontrolling interest for Sherwood Midstream’s interest in that entity. See Note 6 for additional information related to the investments in Sherwood Midstream, Ohio Fractionation and Sherwood Midstream Holdings. |
Variable Interest Entities
Variable Interest Entities | 6 Months Ended |
Jun. 30, 2018 | |
Variable Interest Entity, Not Primary Beneficiary, Disclosures [Abstract] | |
Variable Interest Entities | VARIABLE INTEREST ENTITIES In addition to MPLX, as described in Note 4 , the following entities are also VIEs. Crowley Coastal Partners In May 2016, Crowley Coastal Partners was formed to own an interest in both Crowley Ocean Partners and Crowley Blue Water Partners. We have determined that Crowley Coastal Partners is a VIE based on the terms of the existing financing arrangements for Crowley Blue Water Partners and Crowley Ocean Partners and the associated debt guarantees by MPC and Crowley. Our maximum exposure to loss at June 30, 2018 was $483 million , which includes our equity method investment in Crowley Coastal Partners and the debt guarantees provided to each of the lenders to Crowley Blue Water Partners and Crowley Ocean Partners. We are not the primary beneficiary of this VIE because we do not have the power to control the activities that significantly influence the economic outcomes of the entity and, therefore, do not consolidate the entity. MarkWest Utica EMG On January 1, 2012, MarkWest Utica Operating Company, LLC (“Utica Operating”), a wholly-owned and consolidated subsidiary of MarkWest, and EMG Utica, LLC ("EMG Utica") (together the "Members"), executed agreements to form a joint venture, MarkWest Utica EMG LLC (“MarkWest Utica EMG”), to develop significant natural gas gathering, processing and NGL fractionation, transportation and marketing infrastructure in eastern Ohio. As of June 30, 2018 , MarkWest had a 56 percent ownership interest in MarkWest Utica EMG. MarkWest Utica EMG's inability to fund its planned activities without subordinated financial support qualify it as a VIE. Utica Operating is not deemed to be the primary beneficiary due to EMG Utica’s voting rights on significant matters. We account for our ownership interest in MarkWest Utica EMG as an equity method investment. Our maximum exposure to loss as a result of our involvement with MarkWest Utica EMG includes our equity investment, any additional capital contribution commitments and any operating expenses incurred by the subsidiary operator in excess of compensation received for the performance of the operating services. Our equity investment in MarkWest Utica EMG at June 30, 2018 was $2.1 billion . Ohio Gathering Ohio Gathering Company, L.L.C. (“Ohio Gathering”) is a subsidiary of MarkWest Utica EMG and is engaged in providing natural gas gathering services in the Utica Shale in eastern Ohio. Ohio Gathering is a joint venture between MarkWest Utica EMG and Summit Midstream Partners, LLC. As of June 30, 2018 , we had a 34 percent indirect ownership interest in Ohio Gathering. As this entity is a subsidiary of MarkWest Utica EMG, which is accounted for as an equity method investment, MPLX reports its portion of Ohio Gathering’s net assets as a component of its investment in MarkWest Utica EMG. Sherwood Midstream As described in Note 5 , MPLX and Antero Midstream formed a joint venture, Sherwood Midstream, to support the development of Antero Resources Corporation’s Marcellus Shale acreage in West Virginia. As of June 30, 2018 , MPLX had a 50 percent ownership interest in Sherwood Midstream. Sherwood Midstream’s inability to fund its planned activities without additional subordinated financial support qualify it as a VIE. MPLX is not deemed to be the primary beneficiary, due to Antero Midstream’s voting rights on significant matters. We account for our ownership interest in Sherwood Midstream using the equity method of accounting. Our maximum exposure to loss as a result of our involvement with Sherwood Midstream includes our equity investment, any additional capital contribution commitments and any operating expenses incurred by the subsidiary operator in excess of compensation received for the performance of the operating services. Our equity investment in Sherwood Midstream at June 30, 2018 was $291 million . Ohio Fractionation As described in Note 5 , MPLX converted all of its ownership interests in Ohio Fractionation to Class A Interests and amended its LLC Agreement to create Class B-3 Interests, which were sold to Sherwood Midstream, providing it with the right to fractionation revenue and the obligation to pay expenses related to 20 mbpd of capacity in the Hopedale 3 fractionator. Ohio Fractionation’s inability to fund its operations without additional subordinated financial support qualify it as a VIE. MPLX has been deemed to be the primary beneficiary of Ohio Fractionation because it has control over decisions that could significantly impact its financial performance, and as a result, consolidates Ohio Fractionation. Sherwood Midstream Holdings As described in Note 5 , MPLX and Sherwood Midstream entered into a joint venture, Sherwood Midstream Holdings, for the purpose of owning, operating and maintaining all of the shared assets for the benefit of and use in the operation of the gas plants and other assets owned by Sherwood Midstream and the gas plants and deethanization facilities owned by MPLX. MPLX had an initial 79 percent direct ownership in Sherwood Midstream Holdings, in addition to a 10.5 percent indirect interest through its ownership in Sherwood Midstream. Sherwood Midstream Holdings’ inability to fund its operations without additional subordinated financial support qualify it as a VIE. We account for our ownership interest in Sherwood Midstream Holdings using the equity method of accounting as Sherwood Midstream is considered to be the general partner and controls all decisions related to Sherwood Midstream Holdings. Our maximum exposure to loss as a result of our involvement with Sherwood Midstream Holdings includes our equity investment, any additional capital contribution commitments and any operating expenses incurred by the subsidiary operator in excess of compensation received for the performance of the operating services. Our equity investment in Sherwood Midstream Holdings at June 30, 2018 was $155 million . |
Related Party Transactions
Related Party Transactions | 6 Months Ended |
Jun. 30, 2018 | |
Related Party Transactions [Abstract] | |
Related Party Transactions | RELATED PARTY TRANSACTIONS Our related parties include: • Crowley Blue Water Partners, in which we have a 50 percent indirect noncontrolling interest. Crowley Blue Water Partners owns and operates three Jones Act ATB vessels. • Crowley Ocean Partners, in which we have a 50 percent indirect noncontrolling interest. Crowley Ocean Partners owns and operates Jones Act product tankers. • Illinois Extension Pipeline Company, L.L.C. (“Illinois Extension Pipeline”), in which we have a 35 percent noncontrolling interest. Illinois Extension Pipeline owns and operates the Southern Access Extension (“SAX”) crude oil pipeline. • LOCAP, in which we have a 59 percent noncontrolling interest. LOCAP owns and operates a crude oil pipeline. • LOOP, in which we have a 51 percent noncontrolling interest. LOOP owns and operates the only U.S. deepwater crude oil port. • MarkWest Utica EMG, in which we have a 56 percent noncontrolling interest. MarkWest Utica EMG is engaged in natural gas processing and NGL fractionation, transportation and marketing in Ohio. • Ohio Gathering, in which we have a 34 percent indirect noncontrolling interest. Ohio Gathering is a subsidiary of MarkWest Utica EMG providing natural gas gathering service in the Utica Shale region of eastern Ohio. • PFJ Southeast, in which we have a 29 percent noncontrolling interest. PFJ Southeast owns and operates travel plazas primarily in the Southeast region of the United States. • Sherwood Midstream, in which we have a 50 percent noncontrolling interest. Sherwood Midstream supports the development of Antero Resources Corporation’s Marcellus Shale acreage in West Virginia. • Sherwood Midstream Holdings, in which we have an 81 percent direct and indirect noncontrolling interest. Sherwood Midstream Holdings owns certain infrastructure at the Sherwood Complex that is shared by and supports the operation of both the Sherwood Midstream and MarkWest gas processing plants and deethanization facilities. • The Andersons Albion Ethanol LLC (“TAAE”), in which we have a 45 percent noncontrolling interest, The Andersons Clymers Ethanol LLC (“TACE”), in which we have a 61 percent noncontrolling interest and The Andersons Marathon Ethanol LLC (“TAME”), in which we have a 67 percent noncontrolling interest. These companies each own and operate an ethanol production facility. • Other equity method investees. We believe that transactions with related parties were conducted on terms comparable to those with unaffiliated parties. Sales to related parties were as follows: Three Months Ended Six Months Ended (In millions) 2018 2017 2018 2017 PFJ Southeast $ 196 $ 145 $ 365 $ 296 Other equity method investees 3 2 6 5 Total $ 199 $ 147 $ 371 $ 301 Sales to related parties consists primarily of sales of refined products. Other income from related parties, which is included in “Other income” on the accompanying consolidated statements of income, was as follows: Three Months Ended Six Months Ended (In millions) 2018 2017 2018 2017 MarkWest Utica EMG $ 4 $ 4 $ 8 $ 8 Ohio Gathering 4 4 8 8 Sherwood Midstream 2 3 5 4 Other equity method investees 4 4 6 6 Total $ 14 $ 15 $ 27 $ 26 Other income from related parties consists primarily of fees received for operating transportation assets for our related parties. Purchases from related parties were as follows: Three Months Ended Six Months Ended (In millions) 2018 2017 2018 2017 Crowley Blue Water Partners $ 14 $ 14 $ 30 $ 28 Crowley Ocean Partners 20 20 40 39 Illinois Extension Pipeline 23 24 47 49 LOCAP 3 6 7 11 LOOP 14 26 31 39 TAAE 22 23 41 31 TACE 10 9 18 25 TAME 25 21 45 38 Other equity method investees 7 7 20 12 Total $ 138 $ 150 $ 279 $ 272 Related party purchases from Crowley Blue Water Partners and Crowley Ocean Partners consist of leasing marine equipment primarily used to transport refined products. Related party purchases from Illinois Extension Pipeline, LOCAP, LOOP and other equity method investees consist primarily of crude oil transportation costs. Related party purchases from TAAE, TACE and TAME consist of ethanol purchases. Receivables from related parties, which are included in “Receivables, less allowance for doubtful accounts” on the accompanying consolidated balance sheets, were as follows: (In millions) June 30, December 31, PFJ Southeast $ 30 $ 28 Other equity method investees 8 8 Total $ 38 $ 36 Payables to related parties, which are included in “Accounts payable” on the accompanying consolidated balance sheets, were as follows: (In millions) June 30, December 31, Illinois Extension Pipeline $ 8 $ 8 LOOP 4 3 MarkWest Utica EMG 26 29 Ohio Gathering — 9 Sherwood Midstream 8 8 Other equity method investees 10 12 Total $ 56 $ 69 |
Income per Common Share
Income per Common Share | 6 Months Ended |
Jun. 30, 2018 | |
Earnings Per Share [Abstract] | |
Income per Common Share | INCOME PER COMMON SHARE We compute basic earnings per share by dividing net income attributable to MPC less income allocated to participating securities by the weighted average number of shares of common stock outstanding. Since MPC grants certain incentive compensation awards to employees and non-employee directors that are considered to be participating securities, we have calculated our earnings per share using the two-class method. Diluted income per share assumes exercise of certain stock-based compensation awards, provided the effect is not anti-dilutive. Three Months Ended Six Months Ended (In millions, except per share data) 2018 2017 2018 2017 Basic earnings per share: Allocation of earnings: Net income attributable to MPC $ 1,055 $ 483 $ 1,092 $ 513 Income allocated to participating securities 1 — 1 — Income available to common stockholders – basic $ 1,054 $ 483 $ 1,091 $ 513 Weighted average common shares outstanding 459 513 467 519 Basic earnings per share $ 2.30 $ 0.94 $ 2.34 $ 0.99 Diluted earnings per share: Allocation of earnings: Net income attributable to MPC $ 1,055 $ 483 $ 1,092 $ 513 Income allocated to participating securities 1 — 1 — Income available to common stockholders – diluted $ 1,054 $ 483 $ 1,091 $ 513 Weighted average common shares outstanding 459 513 467 519 Effect of dilutive securities 5 4 5 4 Weighted average common shares, including dilutive effect 464 517 472 523 Diluted earnings per share $ 2.27 $ 0.93 $ 2.31 $ 0.98 The following table summarizes the shares that were anti-dilutive and, therefore, were excluded from the diluted share calculation. Three Months Ended Six Months Ended (In millions) 2018 2017 2018 2017 Shares issued under stock-based compensation plans 1 — 1 2 |
Equity
Equity | 6 Months Ended |
Jun. 30, 2018 | |
Equity [Abstract] | |
Equity | EQUITY As of June 30, 2018 , we had $5.98 billion of share repurchase authorization remaining under authorizations from our board of directors. We may utilize various methods to effect the repurchases, which could include open market repurchases, negotiated block transactions, accelerated share repurchases or open market solicitations for shares, some of which may be effected through Rule 10b5-1 plans. The timing and amount of future repurchases, if any, will depend upon several factors, including market and business conditions, and such repurchases may be discontinued at any time. Total share repurchases were as follows: Three Months Ended Six Months Ended (In millions, except per share data) 2018 2017 2018 2017 Number of shares repurchased 12 14 31 23 Cash paid for shares repurchased $ 885 $ 750 $ 2,212 $ 1,170 Average cost per share $ 76.30 $ 52.35 $ 71.58 $ 51.53 As of June 30, 2018 , we had agreements to acquire 495,702 common shares for $35 million , which were settled in early July 2018. |
Segment Information
Segment Information | 6 Months Ended |
Jun. 30, 2018 | |
Segment Reporting [Abstract] | |
Segment Information | SEGMENT INFORMATION We have three reportable segments: Refining & Marketing; Speedway; and Midstream. Each of these segments is organized and managed based upon the nature of the products and services it offers. • Refining & Marketing – refines crude oil and other feedstocks at our six refineries in the Gulf Coast and Midwest regions of the United States, purchases refined products and ethanol for resale and distributes refined products through transportation, storage, distribution and marketing services provided by our Midstream segment. We sell refined products to wholesale marketing customers domestically and internationally, to buyers on the spot market, to our Speedway business segment and to independent entrepreneurs who operate Marathon ® retail outlets. • Speedway – sells transportation fuels and convenience merchandise in retail markets in the Midwest, East Coast, Southeast and Gulf Coast regions of the United States. • Midstream – gathers, processes and transports natural gas; gathers, transports, fractionates, stores and markets NGLs; and transports, stores, distributes and markets crude oil and refined products principally for the Refining & Marketing segment via refining logistics assets, pipelines, terminals, towboats and barges. The Midstream segment primarily reflects the results of MPLX, our sponsored master limited partnership. As discussed in Note 4 , on February 1, 2018, we contributed certain refining logistics assets and fuels distribution services to MPLX. The results of these new businesses are reported in the Midstream segment prospectively from February 1, 2018, resulting in a net reduction of $232 million and $413 million to Refining & Marketing segment results and a net increase to Midstream segment results of the same amount for the three and six months ended June 30, 2018 , respectively. No effect was given to prior periods as these entities were not considered businesses prior to February 1, 2018. Segment income represents income from operations attributable to the reportable segments. Corporate administrative expenses, except for those attributable to MPLX, and costs related to certain non-operating assets are not allocated to the reportable segments. In addition, certain items that affect comparability (as determined by the chief operating decision maker) are not allocated to the reportable segments. (In millions) Refining & Marketing Speedway Midstream Total Three Months Ended June 30, 2018 Revenues: Third party $ 16,105 $ 5,263 $ 750 $ 22,118 Intersegment 2,871 2 762 3,635 Related party 197 2 — 199 Segment revenues $ 19,173 $ 5,267 $ 1,512 $ 25,952 Segment income from operations $ 1,025 $ 159 $ 617 $ 1,801 Income from equity method investments (b) 4 19 56 79 Depreciation and amortization (b) 252 73 191 516 Capital expenditures and investments (c) 196 88 601 885 (In millions) Refining & Marketing Speedway Midstream Total Three Months Ended June 30, 2017 Revenues: Third party $ 12,691 $ 4,794 $ 548 $ 18,033 Intersegment (a) 2,808 1 363 3,172 Related party 145 2 — 147 Segment revenues $ 15,644 $ 4,797 $ 911 $ 21,352 Segment income from operations $ 562 $ 238 $ 332 $ 1,132 Income from equity method investments (b) 2 21 40 63 Depreciation and amortization (b) 272 65 168 505 Capital expenditures and investments (c) 180 78 494 752 (In millions) Refining & Marketing Speedway Midstream Total Six Months Ended June 30, 2018 Revenues: Third party $ 29,517 $ 9,832 $ 1,463 $ 40,812 Intersegment 5,250 3 1,393 6,646 Related party 367 4 — 371 Segment revenues $ 35,134 $ 9,839 $ 2,856 $ 47,829 Segment income from operations $ 892 $ 254 $ 1,184 $ 2,330 Income from equity method investments (b) 7 33 125 165 Depreciation and amortization (b) 504 152 372 1,028 Capital expenditures and investments (c) 387 127 1,083 1,597 (In millions) Refining & Marketing Speedway Midstream Total Six Months Ended June 30, 2017 Revenues: Third party $ 23,912 $ 9,175 $ 1,080 $ 34,167 Intersegment (a) 5,398 2 707 6,107 Related party 297 4 — 301 Segment revenues $ 29,607 $ 9,181 $ 1,787 $ 40,575 Segment income from operations $ 492 $ 373 $ 641 $ 1,506 Income from equity method investments (b) 4 34 82 120 Depreciation and amortization (b) 539 129 359 1,027 Capital expenditures and investments (c)(d) 372 113 1,564 2,049 (a) Management believes intersegment transactions were conducted under terms comparable to those with unaffiliated parties. (b) Differences between segment totals and MPC totals represent amounts related to corporate and other unallocated items and are included in “Items not allocated to segments” in the reconciliation below. (c) Capital expenditures include changes in capital accruals, acquisitions and investments in affiliates. See reconciliation from segment totals to MPC total capital expenditures below. (d) The Midstream segment includes $220 million for the acquisition of the Ozark pipeline and an investment of $500 million in MarEn Bakken related to the Bakken Pipeline system for the six months ended June 30, 2017 . The following reconciles segment income from operations to income before income taxes as reported in the consolidated statements of income: Three Months Ended Six Months Ended (In millions) 2018 2017 2018 2017 Segment income from operations $ 1,801 $ 1,132 $ 2,330 $ 1,506 Items not allocated to segments: Corporate and other unallocated items (a) (91 ) (83 ) (180 ) (166 ) Litigation — (86 ) — (86 ) Impairments (b) 1 19 1 19 Income from operations 1,711 982 2,151 1,273 Net interest and other financial costs 195 158 378 307 Income before income taxes $ 1,516 $ 824 $ 1,773 $ 966 (a) Corporate and other unallocated items consists primarily of MPC’s corporate administrative expenses and costs related to certain non-operating assets, except for corporate overhead expenses attributable to MPLX, which are included in the Midstream segment. Corporate overhead expenses are not allocated to the Refining & Marketing and Speedway segments. (b) Includes MPC’s share of gains from the sale of assets remaining from the canceled Sandpiper pipeline project. The following reconciles segment capital expenditures and investments to total capital expenditures: Three Months Ended Six Months Ended (In millions) 2018 2017 2018 2017 Segment capital expenditures and investments $ 885 $ 752 $ 1,597 $ 2,049 Less investments in equity method investees (a) 77 111 118 677 Plus items not allocated to segments: Corporate 17 18 35 34 Capitalized interest 16 14 34 26 Total capital expenditures (b) $ 841 $ 673 $ 1,548 $ 1,432 (a) The six months ended June 30, 2017 includes an investment of $500 million in MarEn Bakken related to the Bakken Pipeline system. (b) Capital expenditures include changes in capital accruals. See Note 18 for a reconciliation of total capital expenditures to additions to property, plant and equipment as reported in the consolidated statements of cash flows. Revenues by product line were as follows: Three Months Ended Six Months Ended (In millions) 2018 2017 2018 2017 Refined products $ 19,292 $ 15,439 $ 35,450 $ 29,315 Merchandise 1,286 1,343 2,416 2,535 Crude oil and refinery feedstocks 978 824 1,861 1,511 Midstream services, transportation and other 562 427 1,085 806 Sales and other operating revenues $ 22,118 $ 18,033 $ 40,812 $ 34,167 |
Other Items
Other Items | 6 Months Ended |
Jun. 30, 2018 | |
Other Income and Expenses [Abstract] | |
Other Items | OTHER ITEMS Net interest and other financial costs were as follows: Three Months Ended Six Months Ended (In millions) 2018 2017 2018 2017 Interest income $ (25 ) $ (4 ) $ (45 ) $ (9 ) Interest expense 229 173 442 336 Interest capitalized (16 ) (18 ) (34 ) (33 ) Loss on extinguishment of debt — — 4 — Other financial costs 7 7 11 13 Net interest and other financial costs $ 195 $ 158 $ 378 $ 307 |
Income Taxes
Income Taxes | 6 Months Ended |
Jun. 30, 2018 | |
Income Tax Disclosure [Abstract] | |
Income Taxes | INCOME TAXES The combined federal, state and foreign income tax rate was 19 percent and 30 percent for the three months ended June 30, 2018 and 2017 , respectively, and 17 percent and 30 percent for the six months ended June 30, 2018 and 2017 , respectively. The effective tax rate for the three and six months ended June 30, 2018 was less than the U.S. statutory rate of 21 percent primarily due to certain permanent tax differences related to net income attributable to noncontrolling interest and equity compensation offset by state and local tax expense. The effective tax rate for the three and six months ended June 30, 2017 was less than the then applicable U.S. statutory rate of 35 percent primarily due to certain permanent tax differences related to net income attributable to noncontrolling interest, the domestic manufacturing deduction and equity compensation offset by state and local tax expense. We are continuously undergoing examination of our income tax returns, which have been completed through the 2007 tax year for state returns and the 2009 tax year for our U.S. federal return. As of June 30, 2018 , we had $21 million of unrecognized tax benefits. Prior to its spin-off on June 30, 2011, Marathon Petroleum Corporation was included in the Marathon Oil Corporation (“Marathon Oil”) federal income tax returns for all applicable years. During the third quarter 2017, Marathon Oil received a notice of Final Partnership Administrative Adjustment (“FPAA”) from the IRS for taxable year 2010, relating to certain pre-spinoff transactions. Marathon Oil filed a U.S. Tax Court petition disputing these adjustments during the fourth quarter of 2017. We received an FPAA for taxable years 2011-2014 for items resulting from this matter and filed a U.S. Tax Court petition for tax years 2011-2014 to dispute these corollary adjustments in the fourth quarter of 2017. We continue to believe that the issue in dispute is more likely than not to be fully sustained and therefore, no liability has been accrued for this matter. Pursuant to our tax sharing agreement with Marathon Oil, the unrecognized tax benefits related to pre-spinoff operations for which Marathon Oil was the taxpayer remain the responsibility of Marathon Oil and we have indemnified Marathon Oil accordingly. See Note 22 for indemnification information. |
Inventories
Inventories | 6 Months Ended |
Jun. 30, 2018 | |
Inventory Disclosure [Abstract] | |
Inventories | INVENTORIES (In millions) June 30, December 31, Crude oil and refinery feedstocks $ 2,059 $ 2,056 Refined products 2,811 2,839 Materials and supplies 455 494 Merchandise 160 161 Total $ 5,485 $ 5,550 Inventories are carried at the lower of cost or market value. The cost of inventories of crude oil and refinery feedstocks, refined products and merchandise is determined primarily under the LIFO method. There were no material liquidations of LIFO inventories for the six months ended June 30, 2018 . |
Property, Plant and Equipment
Property, Plant and Equipment | 6 Months Ended |
Jun. 30, 2018 | |
Property, Plant and Equipment [Abstract] | |
Property, Plant and Equipment | PROPERTY, PLANT AND EQUIPMENT (In millions) June 30, December 31, Refining & Marketing (a) $ 18,314 $ 19,490 Speedway 5,433 5,358 Midstream (a) 17,411 14,898 Corporate and Other 827 792 Total 41,985 40,538 Less accumulated depreciation 15,054 14,095 Property, plant and equipment, net $ 26,931 $ 26,443 (a) On February 1, 2018, we contributed certain refining logistics assets and fuels distribution services to MPLX. In connection with this transaction, approximately $830 million of net property, plant and equipment was recorded to the Midstream segment with an offsetting reduction to the Refining & Marketing segment . We own a 33 percent undivided joint interest in the Capline Pipeline System (“Capline”), a crude oil pipeline that runs from St. James, LA to Patoka, IL. We account for this undivided joint interest by recognizing our proportionate share of Capline’s assets on our balance sheet, which are primarily classified as property, plant and equipment. Capline experienced a significant reduction in shipment volumes in the second quarter of 2018 primarily due to recently completed competing pipelines. The pipeline`s owners are proceeding with planning for the reversal of the pipeline to support southbound movements of crude oil as supported by shipper interest indicated during a non-binding open season conducted in 2017. Pending agreement among the owners, southbound service is estimated to commence by the second half of 2022. In the second quarter of 2018, we evaluated our share of Capline assets for impairment in accordance with ASC 360, and determined no impairment existed due to the probability of continuing future cash flows associated with a reversed Capline. As of June 30, 2018, our carrying value was $155 million . |
Fair Value Measurements
Fair Value Measurements | 6 Months Ended |
Jun. 30, 2018 | |
Fair Value Disclosures [Abstract] | |
Fair Value Measurements | FAIR VALUE MEASUREMENTS Fair Values—Recurring The following tables present assets and liabilities accounted for at fair value on a recurring basis as of June 30, 2018 and December 31, 2017 by fair value hierarchy level. We have elected to offset the fair value amounts recognized for multiple derivative contracts executed with the same counterparty, including any related cash collateral as shown below; however, fair value amounts by hierarchy level are presented on a gross basis in the following tables. June 30, 2018 Fair Value Hierarchy (In millions) Level 1 Level 2 Level 3 Netting and Collateral (a) Net Carrying Value on Balance Sheet (b) Collateral Pledged Not Offset Commodity derivative instruments, assets $ 134 $ — $ — $ (134 ) $ — $ 16 Other assets 3 — — N/A 3 — Total assets at fair value $ 137 $ — $ — $ (134 ) $ 3 $ 16 Commodity derivative instruments, liabilities $ 171 $ — $ 2 $ (171 ) $ 2 $ — Embedded derivatives in commodity contracts (c) — — 66 — 66 — Total liabilities at fair value $ 171 $ — $ 68 $ (171 ) $ 68 $ — December 31, 2017 Fair Value Hierarchy (In millions) Level 1 Level 2 Level 3 Netting and Collateral (a) Net Carrying Value on Balance Sheet (b) Collateral Pledged Not Offset Commodity derivative instruments, assets $ 127 $ — $ — $ (118 ) $ 9 $ 8 Other assets 3 — — N/A 3 — Total assets at fair value $ 130 $ — $ — $ (118 ) $ 12 $ 8 Commodity derivative instruments, liabilities $ 126 $ — $ 2 $ (126 ) $ 2 $ — Embedded derivatives in commodity contracts (c) — — 64 — 64 — Total liabilities at fair value $ 126 $ — $ 66 $ (126 ) $ 66 $ — (a) Represents the impact of netting assets, liabilities and cash collateral when a legal right of offset exists. As of June 30, 2018 , cash collateral of $37 million was netted with the mark-to-market derivative liabilities. As of December 31, 2017 , $8 million was netted with mark-to-market derivative liabilities. (b) We have no derivative contracts that are subject to master netting arrangements reflected gross on the balance sheet. (c) Level 3 includes $12 million classified as current at both June 30, 2018 and December 31, 2017 . Commodity derivatives in Level 1 are exchange-traded contracts for crude oil and refined products measured at fair value with a market approach using the close-of-day settlement prices for the market. Commodity derivatives are covered under master netting agreements with an unconditional right to offset. Collateral deposits in futures commission merchant accounts covered by master netting agreements related to Level 1 commodity derivatives are classified as Level 1 in the fair value hierarchy. Level 3 instruments are OTC NGL contracts and embedded derivatives in commodity contracts. The embedded derivative liability relates to a natural gas purchase agreement embedded in a keep‑whole processing agreement. The fair value calculation for these Level 3 instruments used significant unobservable inputs including: (1) NGL prices interpolated and extrapolated due to inactive markets ranging from $0.70 to $1.58 per gallon and (2) the probability of renewal of 65 percent for the first five -year term and 84 percent for the second five -year term of the natural gas purchase agreement and the related keep-whole processing agreement. For these contracts, increases in forward NGL prices result in a decrease in the fair value of the derivative assets and an increase in the fair value of the derivative liabilities. The forward prices for the individual NGL products generally increase or decrease in a positive correlation with one another. Increases or decreases in forward NGL prices result in an increase or decrease in the fair value of the embedded derivative liability. An increase in the probability of renewal would result in an increase in the fair value of the related embedded derivative liability. The following is a reconciliation of the beginning and ending balances recorded for liabilities classified as Level 3 in the fair value hierarchy. Three Months Ended Six Months Ended (In millions) 2018 2017 2018 2017 Beginning balance $ 60 $ 175 $ 66 $ 190 Contingent consideration payment — (131 ) — (131 ) Unrealized and realized (gains) losses included in net income 12 (2 ) 9 (14 ) Settlements of derivative instruments (4 ) (1 ) (7 ) (4 ) Ending balance $ 68 $ 41 $ 68 $ 41 The amount of total losses for the period included in earnings attributable to the change in unrealized losses relating to assets still held at the end of period: Derivative instruments $ 11 $ (1 ) $ 5 $ (12 ) Contingent consideration agreement — — — 1 Total $ 11 $ (1 ) $ 5 $ (11 ) Fair Values – Reported The following table summarizes financial instruments on the basis of their nature, characteristics and risk at June 30, 2018 and December 31, 2017 , excluding the derivative financial instruments and contingent consideration reported above. June 30, 2018 December 31, 2017 (In millions) Fair Value Carrying Value Fair Value Carrying Value Financial assets: Environmental receivables and misc. deposits 30 30 17 17 Total financial assets $ 30 $ 30 $ 17 $ 17 Financial liabilities: Long-term debt (a) $ 17,321 $ 17,023 $ 13,893 $ 12,642 Deferred credits and other liabilities 116 107 122 109 Total financial liabilities $ 17,437 $ 17,130 $ 14,015 $ 12,751 (a) Excludes capital leases and debt issuance costs; includes amount classified as debt due within one year. Our current assets and liabilities include financial instruments, the most significant of which are trade accounts receivable and payables. Fair values of our financial assets and of our financial liabilities included in deferred credits and other liabilities are measured primarily using an income approach and most inputs are internally generated, which results in a Level 3 classification. Estimated future cash flows are discounted using a rate deemed appropriate to obtain the fair value. Deferred credits and other liabilities primarily consist of a liability resulting from a financing arrangement for the construction of MPLX’s steam methane reformer at the Javelina gas processing and fractionation complex in Corpus Christi, Texas, insurance liabilities and environmental remediation liabilities. Fair value of fixed-rate long-term debt is measured using Level 3 inputs. Fair value of variable-rate long-term debt approximates the carrying value. |
Derivatives
Derivatives | 6 Months Ended |
Jun. 30, 2018 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
Derivatives | DERIVATIVES For further information regarding the fair value measurement of derivative instruments, including any effect of master netting agreements or collateral, see Note 15 . We do not designate any of our commodity derivative instruments as hedges for accounting purposes. Derivatives that are not designated as accounting hedges may include commodity derivatives used to hedge price risk on (1) inventories, (2) fixed price sales of refined products, (3) the acquisition of foreign-sourced crude oil, (4) the acquisition of ethanol for blending with refined products, (5) the sale of NGLs and (6) the purchase of natural gas. The following table presents the gross fair values of derivative instruments, excluding cash collateral, and where they appear on the consolidated balance sheets as of June 30, 2018 and December 31, 2017 : (In millions) June 30, 2018 Balance Sheet Location Asset Liability Commodity derivatives Other current assets $ 134 $ 171 Other current liabilities (a) — 14 Deferred credits and other liabilities (a) — 54 (In millions) December 31, 2017 Balance Sheet Location Asset Liability Commodity derivatives Other current assets $ 127 $ 126 Other current liabilities (a) — 14 Deferred credits and other liabilities (a) — 52 (a) Includes embedded derivatives. The tables below summarize open commodity derivative contracts for crude oil and refined products as of June 30, 2018 . Position Total Barrels (In thousands) Crude Oil (a) Exchange-traded Long 31,732 Exchange-traded Short (33,530 ) (a ) 98.6 percent of the exchange-traded contracts expire in the third quarter of 2018 . Position Total Gallons (In thousands) Refined Products (a) Exchange-traded Long 111,762 Exchange-traded Short (228,396 ) (a ) 92.5 percent of the exchange-traded contracts expire in the third quarter of 2018 . The following table summarizes the effect of all commodity derivative instruments in our consolidated statements of income: Gain (Loss) Gain (Loss) (In millions) Three Months Ended June 30, Six Months Ended June 30, Income Statement Location 2018 2017 2018 2017 Sales and other operating revenues $ (1 ) $ 2 $ (2 ) $ 18 Cost of revenues (56 ) (7 ) (83 ) (31 ) Total $ (57 ) $ (5 ) $ (85 ) $ (13 ) |
Debt
Debt | 6 Months Ended |
Jun. 30, 2018 | |
Debt Disclosure [Abstract] | |
Debt | DEBT Our outstanding borrowings at June 30, 2018 and December 31, 2017 consisted of the following: (In millions) June 30, December 31, Marathon Petroleum Corporation: Commercial paper $ — $ — 364-day bank revolving credit facility due July 2018 (a) — — Trade receivables securitization facility due July 2019 — — Bank revolving credit facility due 2022 — — Senior notes, 2.700% due December 2018 — 600 Senior notes, 3.400% due December 2020 650 650 Senior notes, 5.125% due March 2021 1,000 1,000 Senior notes, 3.625%, due September 2024 750 750 Senior notes, 6.500%, due March 2041 1,250 1,250 Senior notes, 4.750%, due September 2044 800 800 Senior notes, 5.850% due December 2045 250 250 Senior notes, 5.000%, due September 2054 400 400 Capital lease obligations due 2018-2033 344 356 MPLX LP: MPLX bank revolving credit facility due 2022 — 505 MPLX senior notes, 5.500%, due February 2023 710 710 MPLX senior notes, 3.375%, due March 2023 500 — MPLX senior notes, 4.500%, due July 2023 989 989 MPLX senior notes, 4.875%, due December 2024 1,149 1,149 MPLX senior notes, 4.000%, due February 2025 500 500 MPLX senior notes, 4.875%, due June 2025 1,189 1,189 MarkWest senior notes, 4.500% - 5.500%, due 2023 - 2025 63 63 MPLX senior notes, 4.125%, due March 2027 1,250 1,250 MPLX senior notes, 4.000%, due March 2028 1,250 — MPLX senior notes, 4.500%, due April 2038 1,750 — MPLX senior notes, 5.200%, due March 2047 1,000 1,000 MPLX senior notes, 4.700%, due April 2048 1,500 — MPLX senior notes, 4.900%, due April 2058 500 — MPLX capital lease obligations due 2020 7 7 Total 17,801 13,418 Unamortized debt issuance costs (107 ) (59 ) Unamortized discount (b) (427 ) (413 ) Amounts due within one year (26 ) (624 ) Total long-term debt due after one year $ 17,241 $ 12,322 (a) The 364-day facility expired on July 20, 2018. (b) Includes $349 million and $374 million of unamortized discount as of June 30, 2018 and December 31, 2017 , respectively, related to the difference between the fair value and the principal amount of assumed MarkWest debt. Commercial Paper During the six months ended June 30, 2018 , we had no borrowings or repayments under the commercial paper program. At June 30, 2018 , we had no amounts outstanding under the commercial paper program. Trade Receivables Securitization Facility At June 30, 2018 , we had no amounts outstanding under our trade receivables securitization facility. MPC Bank Revolving Credit Facilities There were no borrowings or letters of credit outstanding under the MPC bank revolving credit facility at June 30, 2018 . MPC Senior Notes On March 15, 2018, we redeemed all of the $600 million outstanding aggregate principal amount of our 2.700 percent senior notes due December 2018. The 2018 senior notes were redeemed at a price equal to par plus a make whole premium, plus accrued and unpaid interest. The make whole premium of $2.5 million was calculated based on the market yield of the applicable treasury issue as of the redemption date as determined in accordance with the indenture governing the 2018 senior notes. MPLX Credit Agreement During the six months ended June 30, 2018 , MPLX borrowed $50 million under the MPLX bank revolving credit facility, at an average interest rate of 3.0 percent , and repaid $555 million . At June 30, 2018 , MPLX had no outstanding borrowings and $3 million letters of credit outstanding under the MPLX bank revolving credit facility, resulting in total availability of approximately $2.25 billion . MPLX 364-Day Term Loan On January 2, 2018, MPLX entered into a term loan agreement with a syndicate of lenders providing for a $4.1 billion , 364 -day term loan facility. MPLX drew the entire amount of the term loan facility in a single borrowing to fund the cash portion of the consideration for the February 1, 2018 dropdown. On February 8, 2018, MPLX used $4.1 billion of the net proceeds from the issuance of MPLX senior notes to repay the 364 -day term-loan facility. MPLX Senior Notes On February 8, 2018, MPLX issued $5.5 billion in aggregate principal amount of senior notes in a public offering, consisting of $500 million aggregate principal amount of 3.375 percent unsecured senior notes due March 2023, $1.25 billion aggregate principal amount of 4.000 percent unsecured senior notes due March 2028, $1.75 billion aggregate principal amount of 4.500 percent unsecured senior notes due April 2038, $1.5 billion aggregate principal amount of 4.700 percent unsecured senior notes due April 2048, and $500 million aggregate principal amount of 4.900 percent unsecured senior notes due April 2058. MPLX used $4.1 billion of the net proceeds of the offering to repay the 364-day term-loan facility. The remaining proceeds were used to repay outstanding borrowings under MPLX’s revolving credit facility and intercompany loan agreement with us and for general partnership purposes. |
Supplemental Cash Flow Informat
Supplemental Cash Flow Information | 6 Months Ended |
Jun. 30, 2018 | |
Supplemental Cash Flow Elements [Abstract] | |
Supplemental Cash Flow Information | SUPPLEMENTAL CASH FLOW INFORMATION Six Months Ended (In millions) 2018 2017 Net cash provided by operating activities included: Interest paid (net of amounts capitalized) $ 279 $ 231 Income taxes paid to taxing authorities 40 198 Non-cash investing and financing activities: Contribution of assets to joint venture (a) — 337 (a) MarkWest’s contribution of assets to Sherwood Midstream and Sherwood Midstream Holdings. See Note 5 . (In millions) June 30, December 31, Cash and cash equivalents $ 4,999 $ 3,011 Restricted cash (a) 5 4 Cash, cash equivalents and restricted cash (b) $ 5,004 $ 3,015 (a) The restricted cash balance is included within “Other current assets” on the consolidated balance sheets. (b) As a result of the adoption of ASU 2016-18, the consolidated statements of cash flows now explain the change during the period of both “Cash and cash equivalents” and “Restricted cash.” The consolidated statements of cash flows exclude changes to the consolidated balance sheets that did not affect cash. The following is a reconciliation of additions to property, plant and equipment per the consolidated statements of cash flows to total capital expenditures: Six Months Ended (In millions) 2018 2017 Additions to property, plant and equipment per the consolidated statements of cash flows $ 1,466 $ 1,265 Asset retirement expenditures 5 1 Increase (decrease) in capital accruals 77 (54 ) Total capital expenditures before acquisitions 1,548 1,212 Acquisitions (a) — 220 Total capital expenditures $ 1,548 $ 1,432 (a) The six months ended June 30, 2017 reflects the acquisition of the Ozark pipeline. |
Accumulated Other Comprehensive
Accumulated Other Comprehensive Loss | 6 Months Ended |
Jun. 30, 2018 | |
Equity [Abstract] | |
Accumulated Other Comprehensive Loss | ACCUMULATED OTHER COMPREHENSIVE LOSS The following table shows the changes in accumulated other comprehensive loss by component. Amounts in parentheses indicate debits. (In millions) Pension Benefits Other Benefits Gain on Cash Flow Hedge Workers Compensation Total Balance as of December 31, 2016 $ (233 ) $ (7 ) $ 4 $ 2 $ (234 ) Other comprehensive income before reclassifications 1 — — — 1 Amounts reclassified from accumulated other comprehensive loss: Amortization – prior service credit (a) (19 ) (2 ) — — (21 ) – actuarial loss/(gain) (a) 18 (1 ) — — 17 – settlement loss (a) 1 — — — 1 Other (b) — — — (1 ) (1 ) Tax effect (1 ) 2 — — 1 Other comprehensive loss — (1 ) — (1 ) (2 ) Balance as of June 30, 2017 $ (233 ) $ (8 ) $ 4 $ 1 $ (236 ) (In millions) Pension Benefits Other Benefits Gain on Cash Flow Hedge Workers Compensation Total Balance as of December 31, 2017 $ (190 ) $ (48 ) $ 4 $ 3 $ (231 ) Other comprehensive income (loss) before reclassifications 2 (1 ) (2 ) — (1 ) Amounts reclassified from accumulated other comprehensive loss: Amortization – prior service credit (a) (16 ) (2 ) — — (18 ) – actuarial loss (a) 17 — — — 17 – settlement loss (a) 2 — — — 2 Other (b) — — — (2 ) (2 ) Tax effect (1 ) 1 — — — Other comprehensive income (loss) 4 (2 ) (2 ) (2 ) (2 ) Balance as of June 30, 2018 $ (186 ) $ (50 ) $ 2 $ 1 $ (233 ) (a) These accumulated other comprehensive loss components are included in the computation of net periodic benefit cost. See Note 20 . (b) This amount was reclassified out of accumulated other comprehensive loss and is included in selling, general and administrative on the consolidated statements of income. |
Defined Benefit Pension and Oth
Defined Benefit Pension and Other Postretirement Plans | 6 Months Ended |
Jun. 30, 2018 | |
Retirement Benefits [Abstract] | |
Defined Benefit Pension and Other Postretirement Plans | DEFINED BENEFIT PENSION AND OTHER POSTRETIREMENT PLANS The following summarizes the components of net periodic benefit costs: Three Months Ended June 30, Pension Benefits Other Benefits (In millions) 2018 2017 2018 2017 Components of net periodic benefit cost: Service cost $ 35 $ 35 $ 8 $ 6 Interest cost 18 18 8 7 Expected return on plan assets (24 ) (24 ) — — Amortization – prior service credit (8 ) (9 ) (1 ) (1 ) – actuarial loss (gain) 8 9 — (1 ) – settlement loss 1 1 — — Net periodic benefit cost $ 30 $ 30 $ 15 $ 11 Six Months Ended June 30, Pension Benefits Other Benefits (In millions) 2018 2017 2018 2017 Components of net periodic benefit cost: Service cost $ 71 $ 66 $ 15 $ 13 Interest cost 36 37 15 15 Expected return on plan assets (50 ) (50 ) — — Amortization – prior service credit (16 ) (19 ) (2 ) (2 ) – actuarial loss (gain) 17 18 — (1 ) – settlement loss 2 1 — — Net periodic benefit cost $ 60 $ 53 $ 28 $ 25 The components of net periodic benefit cost other than the service cost component are included in the line item “Net interest and other financial costs” in the income statement. During the six months ended June 30, 2018 , we made no contributions to our funded pension plans. Benefit payments related to unfunded pension and other postretirement benefit plans were $7 million and $16 million , respectively, during the six months ended June 30, 2018 . |
Stock-Based Compensation Plans
Stock-Based Compensation Plans | 6 Months Ended |
Jun. 30, 2018 | |
Disclosure of Compensation Related Costs, Share-based Payments [Abstract] | |
Stock-Based Compensation Plans | STOCK-BASED COMPENSATION PLANS Stock Option Awards The following table presents a summary of our stock option award activity for the six months ended June 30, 2018 : Number of Shares Weighted Average Exercise Price Outstanding at December 31, 2017 8,465,398 $ 33.74 Granted 903,797 67.71 Exercised (796,571 ) 25.89 Forfeited or expired (11,219 ) 51.67 Outstanding at June 30, 2018 8,561,405 38.03 The grant date fair value of stock option awards granted during the six months ended June 30, 2018 was $17.21 per share. The fair value of stock options granted to our employees is estimated on the date of the grant using the Black Scholes option-pricing model, which employs various assumptions. Restricted Stock Awards The following table presents a summary of restricted stock award activity for the six months ended June 30, 2018 : Shares of Restricted Stock (“RS”) Restricted Stock Units (“RSU”) Number of Shares Weighted Average Grant Date Fair Value Number of Units Weighted Average Grant Date Fair Value Outstanding at December 31, 2017 1,188,662 $ 45.07 285,164 $ 29.95 Granted 432,792 70.31 14,019 70.54 RS Vested/RSUs Issued (544,900 ) 44.83 (1,829 ) 43.28 Forfeited (31,280 ) 47.13 — — Outstanding at June 30, 2018 1,045,274 55.58 297,354 31.78 Performance Unit Awards The following table presents a summary of the activity for performance unit awards to be settled in shares for the six months ended June 30, 2018 : Number of Units Weighted Average Grant Date Fair Value Outstanding at December 31, 2017 6,851,542 $ 0.81 Granted 3,830,000 0.83 Vested (2,052,959 ) 0.95 Forfeited (10,000 ) 0.92 Outstanding at June 30, 2018 8,618,583 0.79 The performance unit awards granted during the six months ended June 30, 2018 have a grant date fair value of $0.83 per unit, as calculated using a Monte Carlo valuation model. MPLX Awards During the six months ended June 30, 2018 , MPLX granted equity-based compensation awards under the MPLX LP 2018 and MPLX LP 2012 Incentive Compensation Plans. The compensation expense for these awards is not material to our consolidated financial statements. |
Commitments and Contingencies
Commitments and Contingencies | 6 Months Ended |
Jun. 30, 2018 | |
Commitments and Contingencies Disclosure [Abstract] | |
Commitments and Contingencies | COMMITMENTS AND CONTINGENCIES We are the subject of, or a party to, a number of pending or threatened legal actions, contingencies and commitments involving a variety of matters, including laws and regulations relating to the environment. Some of these matters are discussed below. For matters for which we have not recorded a liability, we are unable to estimate a range of possible loss because the issues involved have not been fully developed through pleadings, discovery or court proceedings. However, the ultimate resolution of some of these contingencies could, individually or in the aggregate, be material. Environmental Matters We are subject to federal, state, local and foreign laws and regulations relating to the environment. These laws generally provide for control of pollutants released into the environment and require responsible parties to undertake remediation of hazardous waste disposal sites and certain other locations including presently or formerly owned or operated retail marketing sites. Penalties may be imposed for noncompliance. At June 30, 2018 and December 31, 2017 , accrued liabilities for remediation totaled $108 million and $114 million , respectively. It is not presently possible to estimate the ultimate amount of all remediation costs that might be incurred or the penalties if any that may be imposed. Receivables for recoverable costs from certain states, under programs to assist companies in clean-up efforts related to underground storage tanks at presently or formerly owned or operated retail marketing sites, were $48 million and $45 million at June 30, 2018 and December 31, 2017 , respectively. We are involved in a number of environmental enforcement matters arising in the ordinary course of business. While the outcome and impact on us cannot be predicted with certainty, management believes the resolution of these environmental matters will not, individually or collectively, have a material adverse effect on our consolidated results of operations, financial position or cash flows. MarkWest Environmental Proceeding MarkWest Liberty Midstream & Resources, L.L.C., a wholly owned subsidiary of MPLX (“MarkWest Liberty Midstream”), and its affiliates agreed in principle to pay a cash penalty of approximately $0.6 million and to undertake certain supplemental environmental projects with an estimated cost of approximately $2.4 million , related to civil enforcement allegations associated with permitting and other regulatory obligations for launcher/receiver and compressor station facilities in southeastern Ohio and western Pennsylvania. On April 24, 2018, MarkWest Liberty Midstream and its affiliates entered into a Consent Decree with the EPA and the Pennsylvania Department of Environmental Protection (“PADEP”) resolving these issues, pursuant to which MarkWest Liberty Midstream will pay a penalty of $0.6 million and undertake certain supplemental environmental projects with an estimated cost of approximately $2.4 million , in addition to other related projects that are substantially complete. The Consent Decree was approved by the court on July 9, 2018 and the penalty has been paid. Litigation Relating to the Pending Merger with Andeavor Between June 20 and July 11, 2018, six putative class actions were filed against some or all of Andeavor, the directors of Andeavor, and MPC Mahi Inc. (“Merger Sub 1”) and Mahi LLC (“Merger Sub 2” and, together with MPC and Merger Sub 1, the “MPC Defendants”), relating to the merger. Two complaints, Malka Raul v. Andeavor, et al., and Stephen Bushansky v. Andeavor, et al., were filed in the U.S. District Court for the Western District of Texas. Four complaints, captioned The Vladimir Gusinsky Rev. Trust v. Andeavor, et al., Lawrence Zucker v. Andeavor, et al., Mel Gross v. Andeavor, et al., and Hudson v. Andeavor, et al. were filed in the U.S. District Court for the District of Delaware. The complaints generally allege that Andeavor, the directors of Andeavor and the MPC Defendants disseminated a false or misleading registration statement regarding the proposed merger in violation of Section 14(a) of the Exchange Act and Rule 14a-9 promulgated thereunder. Specifically, the complaints allege that the registration statement filed by MPC misstated or omitted material information regarding the parties’ financial projections and the analyses performed by Andeavor’s and MPC’s respective financial advisors, and that disclosure of material information is necessary in light of preclusive deal protection provisions in the merger agreement, the financial interests of Andeavor’s officers and directors in completing the deal, and the financial interests of Andeavor’s and MPC’s respective financial advisors. The complaints further allege that the directors of Andeavor and/or the MPC Defendants are liable for these violations as “controlling persons” of Andeavor under Section 20(a) of the Exchange Act. The complaints seek injunctive relief, including to enjoin and/or rescind the merger, damages in the event the merger is consummated, and an award of attorneys’ fees, in addition to other relief. Additional lawsuits arising out of the proposed merger may be filed in the future. We believe that the lawsuits are without merit and intend to defend vigorously against them and any other lawsuits challenging the merger. Therefore, at this time, we do not believe the ultimate resolution of these lawsuits will have a material adverse effect. Other Lawsuits MPLX, MarkWest, MarkWest Liberty Midstream, MarkWest Liberty Bluestone, L.L.C., Ohio Fractionation and MarkWest Utica EMG (collectively, the “MPLX Parties”) are parties to various lawsuits with Bilfinger Westcon, Inc. (“Westcon”) that were instituted in 2016 and 2017 in the Court of Common Pleas in Butler County, Pennsylvania, the Circuit Court in Wetzel County, West Virginia, and the Court of Common Pleas in Harrison County, Ohio. The lawsuits relate to disputes regarding construction work performed by Westcon at the Bluestone, Mobley and Cadiz processing complexes in Pennsylvania, West Virginia and Ohio, respectively, and the Hopedale fractionation complex in Ohio. With respect to work performed by Westcon at the Mobley and Bluestone processing complexes, one or more of the MPLX Parties have asserted breach of contract, fraud, and with respect to work performed at the Mobley processing complex, MarkWest Liberty Midstream has also asserted negligent misrepresentation claims against Westcon. Westcon has also asserted claims against one or more of the MPLX Parties regarding these construction projects for breach of contract, unjust enrichment, promissory estoppel, fraud and constructive fraud, tortious interference with contractual relations, and civil conspiracy. Collectively, in the several cases, the MPLX Parties seek in excess of $10 million , plus an unspecified amount of punitive damages. Collectively, in the several cases, Westcon seeks in excess of $40 million , plus an unspecified amount of punitive damages. While the ultimate outcome and impact cannot be predicted with certainty, and management is not able to estimate a reasonably possible loss (or range of loss), if any, for these matters, we believe the resolution of these claims will not have a material adverse effect on our consolidated financial position, results of operations, or cash flows. In May 2015, the Kentucky attorney general filed a lawsuit against our wholly-owned subsidiary, MPC LP, in the United States District Court for the Western District of Kentucky asserting claims under federal and state antitrust statutes, the Kentucky Consumer Protection Act, and state common law. The complaint, as amended in July 2015, alleges that MPC LP used deed restrictions, supply agreements with customers and exchange agreements with competitors to unreasonably restrain trade in areas within Kentucky and seeks declaratory relief, unspecified damages, civil penalties, restitution and disgorgement of profits. At this stage, the ultimate outcome of this litigation remains uncertain, and neither the likelihood of an unfavorable outcome nor the ultimate liability, if any, can be determined, and we are unable to estimate a reasonably possible loss (or range of loss) for this matter. We intend to vigorously defend ourselves in this matter. In May 2007, the Kentucky attorney general filed a lawsuit against us and Marathon Oil in state court in Franklin County, Kentucky for alleged violations of Kentucky’s emergency pricing and consumer protection laws following Hurricanes Katrina and Rita in 2005. The lawsuit alleges that we overcharged customers by $89 million during September and October 2005 . The complaint seeks disgorgement of these sums, as well as penalties, under Kentucky’s emergency pricing and consumer protection laws. We are vigorously defending this litigation. We believe that this is the first lawsuit for damages and injunctive relief under the Kentucky emergency pricing laws to progress this far and it contains many novel issues. In May 2011, the Kentucky attorney general amended his complaint to include a request for immediate injunctive relief as well as unspecified damages and penalties related to our wholesale gasoline pricing in April and May 2011 under statewide price controls that were activated by the Kentucky governor on April 26, 2011 and which have since expired. The court denied the attorney general’s request for immediate injunctive relief, and the remainder of the 2011 claims likely will be resolved along with those dating from 2005. If the lawsuit is resolved unfavorably in its entirety, it could materially impact our consolidated results of operations, financial position or cash flows. However, management does not believe the ultimate resolution of this litigation will have a material adverse effect on our consolidated financial position, results of operations, or cash flows. We are also a party to a number of other lawsuits and other proceedings arising in the ordinary course of business. While the ultimate outcome and impact to us cannot be predicted with certainty, we believe that the resolution of these other lawsuits and proceedings will not have a material adverse effect on our consolidated financial position, results of operations or cash flows. Guarantees We have provided certain guarantees, direct and indirect, of the indebtedness of other companies. Under the terms of most of these guarantee arrangements, we would be required to perform should the guaranteed party fail to fulfill its obligations under the specified arrangements. In addition to these financial guarantees, we also have various performance guarantees related to specific agreements. Guarantees related to indebtedness of equity method investees —MPC and MPLX hold interests in an offshore oil port, LOOP, and MPLX holds an interest in a crude oil pipeline system, LOCAP. Both LOOP and LOCAP have secured various project financings with throughput and deficiency agreements. Under the agreements, MPC, as a shipper, is required to advance funds if the investees are unable to service their debt. Any such advances are considered prepayments of future transportation charges. The duration of the agreements vary but tend to follow the terms of the underlying debt, which extend through 2037 . Our maximum potential undiscounted payments under these agreements for the debt principal totaled $160 million as of June 30, 2018 . We hold an interest in a refined products pipeline through our investment in Centennial, and have guaranteed our portion of the payment of Centennial’s principal, interest and prepayment costs, if applicable, under a Master Shelf Agreement, which is scheduled to expire in 2024 . The guarantee arose in order for Centennial to obtain adequate financing. Our maximum potential undiscounted payments under this agreement for debt principal totaled $23 million as of June 30, 2018 . In connection with our 50 percent indirect interest in Crowley Ocean Partners, we have agreed to conditionally guarantee our portion of the obligations of the joint venture and its subsidiaries under a senior secured term loan agreement. The term loan agreement provides for loans of up to $325 million to finance the acquisition of four product tankers. MPC’s liability under the guarantee for each vessel is conditioned upon the occurrence of certain events, including if we cease to maintain an investment grade credit rating or the charter for the relevant product tanker ceases to be in effect and is not replaced by a charter with an investment grade company on certain defined commercial terms. As of June 30, 2018 , our maximum potential undiscounted payments under this agreement for debt principal totaled $163 million . In connection with our 50 percent indirect interest in Crowley Blue Water Partners, we have agreed to provide a conditional guarantee of up to 50 percent of its outstanding debt balance in the event there is no charter agreement in place with an investment grade customer for the entity’s three vessels as well as other financial support in certain circumstances. The maximum exposure under these arrangements is 50 percent of the amount of the debt, which was $132 million as of June 30, 2018 . Marathon Oil indemnifications — In conjunction with our spinoff from Marathon Oil, we have entered into arrangements with Marathon Oil providing indemnities and guarantees with recorded values of $2 million as of June 30, 2018 , which consist of unrecognized tax benefits related to MPC, its consolidated subsidiaries and the refining, marketing and transportation business operations prior to our spinoff which are not already reflected in the unrecognized tax benefits described in Note 12 , and other contingent liabilities Marathon Oil may incur related to taxes. Furthermore, the separation and distribution agreement and other agreements with Marathon Oil to effect our spinoff provide for cross-indemnities between Marathon Oil and us. In general, Marathon Oil is required to indemnify us for any liabilities relating to Marathon Oil’s historical oil and gas exploration and production operations, oil sands mining operations and integrated gas operations, and we are required to indemnify Marathon Oil for any liabilities relating to Marathon Oil’s historical refining, marketing and transportation operations. The terms of these indemnifications are indefinite and the amounts are not capped. Other guarantees —We have entered into other guarantees with maximum potential undiscounted payments totaling $92 million as of June 30, 2018 , which primarily consist of a commitment to contribute cash to an equity method investee for certain catastrophic events, up to $50 million per event, in lieu of procuring insurance coverage, a commitment to fund a share of the bonds issued by a government entity for construction of public utilities in the event that other industrial users of the facility default on their utility payments and leases of assets containing general lease indemnities and guaranteed residual values. General guarantees associated with dispositions —Over the years, we have sold various assets in the normal course of our business. Certain of the related agreements contain performance and general guarantees, including guarantees regarding inaccuracies in representations, warranties, covenants and agreements, and environmental and general indemnifications that require us to perform upon the occurrence of a triggering event or condition. These guarantees and indemnifications are part of the normal course of selling assets. We are typically not able to calculate the maximum potential amount of future payments that could be made under such contractual provisions because of the variability inherent in the guarantees and indemnities. Most often, the nature of the guarantees and indemnities is such that there is no appropriate method for quantifying the exposure because the underlying triggering event has little or no past experience upon which a reasonable prediction of the outcome can be based. Contractual Commitments and Contingencies At June 30, 2018 , our contractual commitments to acquire property, plant and equipment and advance funds to equity method investees totaled $901 million . Certain natural gas processing and gathering arrangements require us to construct natural gas processing plants, natural gas gathering pipelines and NGL pipelines and contain certain fees and charges if specified construction milestones are not achieved for reasons other than force majeure. In certain cases, certain producer customers may have the right to cancel the processing arrangements with us if there are significant delays that are not due to force majeure. |
Supplementary Statistics
Supplementary Statistics | 6 Months Ended |
Jun. 30, 2018 | |
Text Block [Abstract] | |
Supplementary Statistics | Three Months Ended Six Months Ended (In millions) 2018 2017 2018 2017 Income from Operations by Segment Refining & Marketing (a) $ 1,025 $ 562 $ 892 $ 492 Speedway 159 238 254 373 Midstream (a) 617 332 1,184 641 Items not allocated to segments: Corporate and other unallocated items (91 ) (83 ) (180 ) (166 ) Litigation — (86 ) — (86 ) Impairments (b) 1 19 1 19 Income from operations $ 1,711 $ 982 $ 2,151 $ 1,273 Capital Expenditures and Investments (c) Refining & Marketing $ 196 $ 180 $ 387 $ 372 Speedway 88 78 127 113 Midstream (d) 601 494 1,083 1,564 Corporate and Other (e) 33 32 69 60 Total capital expenditures and investments $ 918 $ 784 $ 1,666 $ 2,109 (a) On February 1, 2018, we contributed certain refining logistics assets and fuels distributions services to MPLX. The results of these new businesses are reported in the Midstream segment prospectively from February 1, resulting in a net reduction of $232 million and $413 million to Refining & Marketing segment results and a net increase to Midstream segment results of the same amount for the three and six months ended June 30, 2018 , respectively . No effect was given to prior periods as these entities were not considered businesses prior to February 1, 2018. (b) Includes MPC’s share of gains from the sales of assets remaining from the canceled Sandpiper pipeline project. (c) Capital expenditures include changes in capital accruals, acquisitions and investments in affiliates. (d) The six months ended June 30, 2017 includes $220 million for the acquisition of the Ozark pipeline and an investment of $500 million in MarEn Bakken related to the Bakken Pipeline system. (e) Includes capitalized interest of $16 million and $14 million for the three months ended June 30, 2018 and 2017 , respectively, and $34 million and $26 million for the six months ended June 30, 2018 and 2017 , respectively. SUPPLEMENTARY STATISTICS (UNAUDITED) Three Months Ended Six Months Ended 2018 2017 2018 2017 MPC Consolidated Refined Product Sales Volumes (mbpd) (a) 2,404 2,370 2,340 2,228 Refining & Marketing Operating Statistics Refining & Marketing refined product sales volume (mbpd) (b) 2,392 2,358 2,327 2,215 Export sales volume (mbpd) (c) 311 313 292 271 Refining & Marketing margin (dollars per barrel) (d) $ 15.40 $ 11.32 $ 13.08 $ 11.47 Crude oil capacity utilization percent (e) 99.9 102.6 96.3 92.9 Refinery throughputs (mbpd): (f) Crude oil refined 1,878 1,864 1,812 1,688 Other charge and blendstocks 160 159 160 179 Total 2,038 2,023 1,972 1,867 Sour crude oil throughput percent 55 62 53 64 WTI-priced crude oil throughput percent 28 20 27 18 Refined product yields (mbpd): (f) Gasoline 970 922 943 895 Distillates 691 665 651 605 Propane 40 38 35 33 Feedstocks and special products 278 331 283 277 Heavy fuel oil 27 34 31 32 Asphalt 72 70 65 63 Total 2,078 2,060 2,008 1,905 Refinery direct operating costs (dollars per barrel): (g) Planned turnaround and major maintenance $ 0.98 $ 1.01 $ 1.58 $ 1.96 Depreciation and amortization 1.27 1.39 1.32 1.50 Other manufacturing (h) 3.54 3.84 3.80 4.24 Total $ 5.79 $ 6.24 $ 6.70 $ 7.70 Refining & Marketing Operating Statistics By Region - Gulf Coast Refinery throughputs (mbpd): (i) Crude oil refined 1,156 1,147 1,106 999 Other charge and blendstocks 190 218 179 220 Total 1,346 1,365 1,285 1,219 Sour crude oil throughput percent 65 74 63 78 WTI-priced crude oil throughput percent 16 12 15 8 Refined product yields (mbpd): (i) Gasoline 570 537 552 518 Distillates 458 432 410 371 Propane 26 27 22 24 Feedstocks and special products 290 360 294 302 Heavy fuel oil 16 23 20 20 Asphalt 23 19 20 17 Total 1,383 1,398 1,318 1,252 Three Months Ended Six Months Ended 2018 2017 2018 2017 Refinery direct operating costs (dollars per barrel): (g) Planned turnaround and major maintenance $ 0.56 $ 0.91 $ 1.65 $ 2.40 Depreciation and amortization 0.99 1.10 1.04 1.21 Other manufacturing (h) 3.21 3.45 3.54 3.96 Total $ 4.76 $ 5.46 $ 6.23 $ 7.57 Refining & Marketing Operating Statistics By Region – Midwest Refinery throughputs (mbpd): (i) Crude oil refined 722 717 706 689 Other charge and blendstocks 34 28 34 30 Total 756 745 740 719 Sour crude oil throughput percent 39 42 38 43 WTI-priced crude oil throughput percent 49 34 48 32 Refined product yields (mbpd): (i) Gasoline 400 385 391 377 Distillates 233 233 241 234 Propane 14 12 13 10 Feedstocks and special products 52 56 42 45 Heavy fuel oil 11 12 11 12 Asphalt 49 51 45 46 Total 759 749 743 724 Refinery direct operating costs (dollars per barrel): (g) Planned turnaround and major maintenance $ 1.65 $ 1.06 $ 1.33 $ 1.02 Depreciation and amortization 1.66 1.76 1.71 1.84 Other manufacturing (h) 3.81 4.13 3.98 4.31 Total $ 7.12 $ 6.95 $ 7.02 $ 7.17 Speedway Operating Statistics Convenience stores at period-end 2,744 2,729 Gasoline and distillate sales (millions of gallons) 1,450 1,475 2,843 2,868 Gasoline and distillate margin (dollars per gallon) (j) $ 0.1645 $ 0.1835 $ 0.1604 $ 0.1704 Merchandise sales (in millions) $ 1,285 $ 1,271 $ 2,414 $ 2,398 Merchandise margin (in millions) $ 366 $ 371 $ 685 $ 691 Merchandise margin percent 28.5 % 29.2 % 28.4 % 28.8 % Same store gasoline sales volume (period over period) (k) (2.6 %) (0.5 %) (2.1 %) (0.8 %) Same store merchandise sales (period over period) (k)(l) 2.9 % 2.1 % 2.6 % 2.1 % Midstream Operating Statistics Crude oil and refined product pipeline throughputs (mbpd) (m) 3,789 3,439 3,625 3,165 Terminal throughput (mbpd) 1,485 1,489 1,465 1,456 Gathering system throughput (MMcf/d) (n) 4,295 3,326 4,233 3,255 Natural gas processed (MMcf/d) (n) 6,850 6,292 6,740 6,212 C2 (ethane) + NGLs (natural gas liquids) fractionated (mbpd) (n) 439 387 432 377 (a) Total average daily volumes of refined product sales to wholesale, branded and retail customers. (b) Includes intersegment sales. (c) Represents fully loaded export cargoes for each time period. These sales volumes are included in the total sales volume amounts. (d) Sales revenue less cost of refinery inputs and purchased products, divided by total refinery throughputs. (e) Based on calendar-day capacity, which is an annual average that includes down time for planned maintenance and other normal operating activities. (f) Excludes inter-refinery volumes of 64 mbpd and 87 mbpd for the three months ended June 30, 2018 and 2017 , respectively, and 53 mbpd and 71 mbpd for the six months ended June 30, 2018 and 2017 , respectively. (g) Per barrel of total refinery throughputs. Effective with the February 1, 2018 dropdown, direct operating costs related to certain refining logistics assets are now reported in the Midstream segment. No effect was given to prior periods as this entity was not considered a business prior to February 1, 2018. (h) Includes utilities, labor, routine maintenance and other operating costs. (i) Includes inter-refinery transfer volumes. (j) The price paid by consumers less the cost of refined products, including transportation, consumer excise taxes and bank card processing fees, divided by gasoline and distillate sales volume. (k) Same store comparison includes only locations owned at least 13 months. (l) Excludes cigarettes. (m) Includes common-carrier pipelines and private pipelines owned or operated by MPLX, excluding equity method investments. (n) Includes amounts related to unconsolidated equity method investments on a 100 percent basis. |
Summary of Principal Accountin
Summary of Principal Accounting Policies (Policies) | 6 Months Ended |
Jun. 30, 2018 | |
Accounting Policies [Abstract] | |
Use of estimates | These interim consolidated financial statements are unaudited; however, in the opinion of our management, these statements reflect all adjustments necessary for a fair statement of the results for the periods reported. All such adjustments are of a normal, recurring nature unless otherwise disclosed. These interim consolidated financial statements, including the notes, have been prepared in accordance with the rules of the SEC applicable to interim period financial statements and do not include all of the information and disclosures required by GAAP for complete financial statements. |
Revenue recognition | Revenue Recognition As described in Note 3 , we adopted ASU 2014-09, Revenue from Contracts with Customers (“ASC 606”) effective January 1, 2018. We recognize revenue based on consideration specified in contracts or agreements with customers when we satisfy our performance obligations by transferring control over products or services to a customer. Concurrent with our adoption of ASC 606, we made an accounting policy election that all taxes assessed by a governmental authority that are both imposed on and concurrent with a revenue-producing transaction and collected from our customers will be recognized on a net basis within “Sales and other operating revenues.” The adoption of ASC 606 did not materially change our revenue recognition patterns, which are described below by reportable segment: • Refining & Marketing - The vast majority of our Refining & Marketing contracts contain pricing that is based on the market price for the product at the time of delivery. Our obligations to deliver product volumes are typically satisfied and revenue is recognized when control of the product transfers to our customers. Concurrent with the transfer of control, we typically receive the right to payment for the delivered product, the customer accepts the product and the customer has significant risks and rewards of ownership of the product. Payment terms require customers to pay shortly after delivery and do not contain significant financing components. • Speedway - Revenue is recognized when our customers receive control of the transportation fuels or merchandise. Payments from customers are received at the time sales occur in cash or by credit or debit card. Speedway offers a loyalty rewards program to its customers. We defer a minor portion of revenue on sales to the loyalty program participants until the participants redeem their rewards. The related contract liability, as defined in the standard, is not material to our financial statements. • Midstream - Midstream revenue transactions typically are defined by contracts under which we sell a product or provide a service. Revenues from sales of product are recognized when control of the product transfers to the customer. Revenues from sales of services are recognized over time when the performance obligation is satisfied as services are provided in a series. We have elected to use the output measure of progress to recognize revenue based on the units delivered, processed or transported. The transaction price in our Midstream contracts often has both fixed components, related to minimum volume commitments, and variable components which are primarily dependent on volumes. Variable consideration will generally not be estimated at contract inception as the transaction price is specifically allocable to the services provided at each period end. Refer to Note 10 for disclosure of our revenue disaggregated by segment and product line, as well as a description of our reportable segment operations. |
Inventories | Inventories are carried at the lower of cost or market value. The cost of inventories of crude oil and refinery feedstocks, refined products and merchandise is determined primarily under the LIFO method. |
Derivative instruments | Derivatives that are not designated as accounting hedges may include commodity derivatives used to hedge price risk on (1) inventories, (2) fixed price sales of refined products, (3) the acquisition of foreign-sourced crude oil, (4) the acquisition of ethanol for blending with refined products, (5) the sale of NGLs and (6) the purchase of natural gas. |
Stock-based compensation arrangements | The fair value of stock options granted to our employees is estimated on the date of the grant using the Black Scholes option-pricing model, which employs various assumptions. |
MPLX LP (Tables)
MPLX LP (Tables) | 6 Months Ended |
Jun. 30, 2018 | |
Noncontrolling Interest [Abstract] | |
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net | As a result of equity transactions of MPLX, we are required to adjust non-controlling interest and additional paid-in capital. Changes in MPC’s additional paid-in capital resulting from changes in its ownership interests in MPLX were as follows: Six Months Ended (In millions) 2018 2017 Increase due to the issuance of MPLX LP common units to the public $ 5 $ 25 Increase due to the issuance of MPLX LP common units and general partner units to MPC 1,114 94 Increase due to GP/IDR Exchange 1,808 — Increase in MPC's additional paid-in capital 2,927 119 Tax impact (546 ) (41 ) Increase in MPC's additional paid-in capital, net of tax $ 2,381 $ 78 |
Related Party Transactions (Tab
Related Party Transactions (Tables) | 6 Months Ended |
Jun. 30, 2018 | |
Related Party Transactions [Abstract] | |
Sales to Related Parties | Sales to related parties were as follows: Three Months Ended Six Months Ended (In millions) 2018 2017 2018 2017 PFJ Southeast $ 196 $ 145 $ 365 $ 296 Other equity method investees 3 2 6 5 Total $ 199 $ 147 $ 371 $ 301 |
Other Income From Related Parties | Other income from related parties, which is included in “Other income” on the accompanying consolidated statements of income, was as follows: Three Months Ended Six Months Ended (In millions) 2018 2017 2018 2017 MarkWest Utica EMG $ 4 $ 4 $ 8 $ 8 Ohio Gathering 4 4 8 8 Sherwood Midstream 2 3 5 4 Other equity method investees 4 4 6 6 Total $ 14 $ 15 $ 27 $ 26 |
Purchases From Related Parties | Purchases from related parties were as follows: Three Months Ended Six Months Ended (In millions) 2018 2017 2018 2017 Crowley Blue Water Partners $ 14 $ 14 $ 30 $ 28 Crowley Ocean Partners 20 20 40 39 Illinois Extension Pipeline 23 24 47 49 LOCAP 3 6 7 11 LOOP 14 26 31 39 TAAE 22 23 41 31 TACE 10 9 18 25 TAME 25 21 45 38 Other equity method investees 7 7 20 12 Total $ 138 $ 150 $ 279 $ 272 |
Receivables From Related Parties | Receivables from related parties, which are included in “Receivables, less allowance for doubtful accounts” on the accompanying consolidated balance sheets, were as follows: (In millions) June 30, December 31, PFJ Southeast $ 30 $ 28 Other equity method investees 8 8 Total $ 38 $ 36 |
Payables To Related Parties | Payables to related parties, which are included in “Accounts payable” on the accompanying consolidated balance sheets, were as follows: (In millions) June 30, December 31, Illinois Extension Pipeline $ 8 $ 8 LOOP 4 3 MarkWest Utica EMG 26 29 Ohio Gathering — 9 Sherwood Midstream 8 8 Other equity method investees 10 12 Total $ 56 $ 69 |
Income per Common Share (Tables
Income per Common Share (Tables) | 6 Months Ended |
Jun. 30, 2018 | |
Earnings Per Share [Abstract] | |
Summary of Earnings Per Common Share | We compute basic earnings per share by dividing net income attributable to MPC less income allocated to participating securities by the weighted average number of shares of common stock outstanding. Since MPC grants certain incentive compensation awards to employees and non-employee directors that are considered to be participating securities, we have calculated our earnings per share using the two-class method. Diluted income per share assumes exercise of certain stock-based compensation awards, provided the effect is not anti-dilutive. Three Months Ended Six Months Ended (In millions, except per share data) 2018 2017 2018 2017 Basic earnings per share: Allocation of earnings: Net income attributable to MPC $ 1,055 $ 483 $ 1,092 $ 513 Income allocated to participating securities 1 — 1 — Income available to common stockholders – basic $ 1,054 $ 483 $ 1,091 $ 513 Weighted average common shares outstanding 459 513 467 519 Basic earnings per share $ 2.30 $ 0.94 $ 2.34 $ 0.99 Diluted earnings per share: Allocation of earnings: Net income attributable to MPC $ 1,055 $ 483 $ 1,092 $ 513 Income allocated to participating securities 1 — 1 — Income available to common stockholders – diluted $ 1,054 $ 483 $ 1,091 $ 513 Weighted average common shares outstanding 459 513 467 519 Effect of dilutive securities 5 4 5 4 Weighted average common shares, including dilutive effect 464 517 472 523 Diluted earnings per share $ 2.27 $ 0.93 $ 2.31 $ 0.98 |
Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share | The following table summarizes the shares that were anti-dilutive and, therefore, were excluded from the diluted share calculation. Three Months Ended Six Months Ended (In millions) 2018 2017 2018 2017 Shares issued under stock-based compensation plans 1 — 1 2 |
Equity (Tables)
Equity (Tables) | 6 Months Ended |
Jun. 30, 2018 | |
Equity [Abstract] | |
Share Repurchases | Total share repurchases were as follows: Three Months Ended Six Months Ended (In millions, except per share data) 2018 2017 2018 2017 Number of shares repurchased 12 14 31 23 Cash paid for shares repurchased $ 885 $ 750 $ 2,212 $ 1,170 Average cost per share $ 76.30 $ 52.35 $ 71.58 $ 51.53 |
Segment Information (Tables)
Segment Information (Tables) | 6 Months Ended |
Jun. 30, 2018 | |
Segment Reporting [Abstract] | |
Income From Operations Attributable To Operating Segments | Segment income represents income from operations attributable to the reportable segments. Corporate administrative expenses, except for those attributable to MPLX, and costs related to certain non-operating assets are not allocated to the reportable segments. In addition, certain items that affect comparability (as determined by the chief operating decision maker) are not allocated to the reportable segments. (In millions) Refining & Marketing Speedway Midstream Total Three Months Ended June 30, 2018 Revenues: Third party $ 16,105 $ 5,263 $ 750 $ 22,118 Intersegment 2,871 2 762 3,635 Related party 197 2 — 199 Segment revenues $ 19,173 $ 5,267 $ 1,512 $ 25,952 Segment income from operations $ 1,025 $ 159 $ 617 $ 1,801 Income from equity method investments (b) 4 19 56 79 Depreciation and amortization (b) 252 73 191 516 Capital expenditures and investments (c) 196 88 601 885 (In millions) Refining & Marketing Speedway Midstream Total Three Months Ended June 30, 2017 Revenues: Third party $ 12,691 $ 4,794 $ 548 $ 18,033 Intersegment (a) 2,808 1 363 3,172 Related party 145 2 — 147 Segment revenues $ 15,644 $ 4,797 $ 911 $ 21,352 Segment income from operations $ 562 $ 238 $ 332 $ 1,132 Income from equity method investments (b) 2 21 40 63 Depreciation and amortization (b) 272 65 168 505 Capital expenditures and investments (c) 180 78 494 752 (In millions) Refining & Marketing Speedway Midstream Total Six Months Ended June 30, 2018 Revenues: Third party $ 29,517 $ 9,832 $ 1,463 $ 40,812 Intersegment 5,250 3 1,393 6,646 Related party 367 4 — 371 Segment revenues $ 35,134 $ 9,839 $ 2,856 $ 47,829 Segment income from operations $ 892 $ 254 $ 1,184 $ 2,330 Income from equity method investments (b) 7 33 125 165 Depreciation and amortization (b) 504 152 372 1,028 Capital expenditures and investments (c) 387 127 1,083 1,597 (In millions) Refining & Marketing Speedway Midstream Total Six Months Ended June 30, 2017 Revenues: Third party $ 23,912 $ 9,175 $ 1,080 $ 34,167 Intersegment (a) 5,398 2 707 6,107 Related party 297 4 — 301 Segment revenues $ 29,607 $ 9,181 $ 1,787 $ 40,575 Segment income from operations $ 492 $ 373 $ 641 $ 1,506 Income from equity method investments (b) 4 34 82 120 Depreciation and amortization (b) 539 129 359 1,027 Capital expenditures and investments (c)(d) 372 113 1,564 2,049 (a) Management believes intersegment transactions were conducted under terms comparable to those with unaffiliated parties. (b) Differences between segment totals and MPC totals represent amounts related to corporate and other unallocated items and are included in “Items not allocated to segments” in the reconciliation below. (c) Capital expenditures include changes in capital accruals, acquisitions and investments in affiliates. See reconciliation from segment totals to MPC total capital expenditures below. (d) The Midstream segment includes $220 million for the acquisition of the Ozark pipeline and an investment of $500 million in MarEn Bakken related to the Bakken Pipeline system for the six months ended June 30, 2017 . |
Reconciliation Of Segment Income From Operations To Income Before Income Taxes | The following reconciles segment income from operations to income before income taxes as reported in the consolidated statements of income: Three Months Ended Six Months Ended (In millions) 2018 2017 2018 2017 Segment income from operations $ 1,801 $ 1,132 $ 2,330 $ 1,506 Items not allocated to segments: Corporate and other unallocated items (a) (91 ) (83 ) (180 ) (166 ) Litigation — (86 ) — (86 ) Impairments (b) 1 19 1 19 Income from operations 1,711 982 2,151 1,273 Net interest and other financial costs 195 158 378 307 Income before income taxes $ 1,516 $ 824 $ 1,773 $ 966 (a) Corporate and other unallocated items consists primarily of MPC’s corporate administrative expenses and costs related to certain non-operating assets, except for corporate overhead expenses attributable to MPLX, which are included in the Midstream segment. Corporate overhead expenses are not allocated to the Refining & Marketing and Speedway segments. (b) Includes MPC’s share of gains from the sale of assets remaining from the canceled Sandpiper pipeline project. |
Reconciliation Of Segment Capital Expenditures And Investments To Total Capital Expenditures | The following reconciles segment capital expenditures and investments to total capital expenditures: Three Months Ended Six Months Ended (In millions) 2018 2017 2018 2017 Segment capital expenditures and investments $ 885 $ 752 $ 1,597 $ 2,049 Less investments in equity method investees (a) 77 111 118 677 Plus items not allocated to segments: Corporate 17 18 35 34 Capitalized interest 16 14 34 26 Total capital expenditures (b) $ 841 $ 673 $ 1,548 $ 1,432 (a) The six months ended June 30, 2017 includes an investment of $500 million in MarEn Bakken related to the Bakken Pipeline system. (b) Capital expenditures include changes in capital accruals. See Note 18 for a reconciliation of total capital expenditures to additions to property, plant and equipment as reported in the consolidated statements of cash flows. |
Revenue from External Customers by Products and Services | Revenues by product line were as follows: Three Months Ended Six Months Ended (In millions) 2018 2017 2018 2017 Refined products $ 19,292 $ 15,439 $ 35,450 $ 29,315 Merchandise 1,286 1,343 2,416 2,535 Crude oil and refinery feedstocks 978 824 1,861 1,511 Midstream services, transportation and other 562 427 1,085 806 Sales and other operating revenues $ 22,118 $ 18,033 $ 40,812 $ 34,167 |
Other Items (Tables)
Other Items (Tables) | 6 Months Ended |
Jun. 30, 2018 | |
Other Income and Expenses [Abstract] | |
Net Interest And Other Financial Income (Costs) | Net interest and other financial costs were as follows: Three Months Ended Six Months Ended (In millions) 2018 2017 2018 2017 Interest income $ (25 ) $ (4 ) $ (45 ) $ (9 ) Interest expense 229 173 442 336 Interest capitalized (16 ) (18 ) (34 ) (33 ) Loss on extinguishment of debt — — 4 — Other financial costs 7 7 11 13 Net interest and other financial costs $ 195 $ 158 $ 378 $ 307 |
Inventories (Tables)
Inventories (Tables) | 6 Months Ended |
Jun. 30, 2018 | |
Inventory Disclosure [Abstract] | |
Summary Of Inventories | (In millions) June 30, December 31, Crude oil and refinery feedstocks $ 2,059 $ 2,056 Refined products 2,811 2,839 Materials and supplies 455 494 Merchandise 160 161 Total $ 5,485 $ 5,550 |
Property, Plant and Equipment (
Property, Plant and Equipment (Tables) | 6 Months Ended |
Jun. 30, 2018 | |
Property, Plant and Equipment [Abstract] | |
Summary Of Property, Plant And Equipment | (In millions) June 30, December 31, Refining & Marketing (a) $ 18,314 $ 19,490 Speedway 5,433 5,358 Midstream (a) 17,411 14,898 Corporate and Other 827 792 Total 41,985 40,538 Less accumulated depreciation 15,054 14,095 Property, plant and equipment, net $ 26,931 $ 26,443 (a) On February 1, 2018, we contributed certain refining logistics assets and fuels distribution services to MPLX. In connection with this transaction, approximately $830 million of net property, plant and equipment was recorded to the Midstream segment with an offsetting reduction to the Refining & Marketing segment . |
Fair Value Measurements (Tables
Fair Value Measurements (Tables) | 6 Months Ended |
Jun. 30, 2018 | |
Fair Value Disclosures [Abstract] | |
Assets and Liabilities Accounted for at Fair Value on Recurring Basis | The following tables present assets and liabilities accounted for at fair value on a recurring basis as of June 30, 2018 and December 31, 2017 by fair value hierarchy level. We have elected to offset the fair value amounts recognized for multiple derivative contracts executed with the same counterparty, including any related cash collateral as shown below; however, fair value amounts by hierarchy level are presented on a gross basis in the following tables. June 30, 2018 Fair Value Hierarchy (In millions) Level 1 Level 2 Level 3 Netting and Collateral (a) Net Carrying Value on Balance Sheet (b) Collateral Pledged Not Offset Commodity derivative instruments, assets $ 134 $ — $ — $ (134 ) $ — $ 16 Other assets 3 — — N/A 3 — Total assets at fair value $ 137 $ — $ — $ (134 ) $ 3 $ 16 Commodity derivative instruments, liabilities $ 171 $ — $ 2 $ (171 ) $ 2 $ — Embedded derivatives in commodity contracts (c) — — 66 — 66 — Total liabilities at fair value $ 171 $ — $ 68 $ (171 ) $ 68 $ — December 31, 2017 Fair Value Hierarchy (In millions) Level 1 Level 2 Level 3 Netting and Collateral (a) Net Carrying Value on Balance Sheet (b) Collateral Pledged Not Offset Commodity derivative instruments, assets $ 127 $ — $ — $ (118 ) $ 9 $ 8 Other assets 3 — — N/A 3 — Total assets at fair value $ 130 $ — $ — $ (118 ) $ 12 $ 8 Commodity derivative instruments, liabilities $ 126 $ — $ 2 $ (126 ) $ 2 $ — Embedded derivatives in commodity contracts (c) — — 64 — 64 — Total liabilities at fair value $ 126 $ — $ 66 $ (126 ) $ 66 $ — (a) Represents the impact of netting assets, liabilities and cash collateral when a legal right of offset exists. As of June 30, 2018 , cash collateral of $37 million was netted with the mark-to-market derivative liabilities. As of December 31, 2017 , $8 million was netted with mark-to-market derivative liabilities. (b) We have no derivative contracts that are subject to master netting arrangements reflected gross on the balance sheet. (c) Level 3 includes $12 million classified as current at both June 30, 2018 and December 31, 2017 . |
Reconciliation of Net Beginning and Ending Balances Recorded for Net Assets and Liabilities Classified as Level 3 | The following is a reconciliation of the beginning and ending balances recorded for liabilities classified as Level 3 in the fair value hierarchy. Three Months Ended Six Months Ended (In millions) 2018 2017 2018 2017 Beginning balance $ 60 $ 175 $ 66 $ 190 Contingent consideration payment — (131 ) — (131 ) Unrealized and realized (gains) losses included in net income 12 (2 ) 9 (14 ) Settlements of derivative instruments (4 ) (1 ) (7 ) (4 ) Ending balance $ 68 $ 41 $ 68 $ 41 The amount of total losses for the period included in earnings attributable to the change in unrealized losses relating to assets still held at the end of period: Derivative instruments $ 11 $ (1 ) $ 5 $ (12 ) Contingent consideration agreement — — — 1 Total $ 11 $ (1 ) $ 5 $ (11 ) |
Financial Instruments at Fair Value, Excluding Derivative Financial Instruments and Contingent Consideration | The following table summarizes financial instruments on the basis of their nature, characteristics and risk at June 30, 2018 and December 31, 2017 , excluding the derivative financial instruments and contingent consideration reported above. June 30, 2018 December 31, 2017 (In millions) Fair Value Carrying Value Fair Value Carrying Value Financial assets: Environmental receivables and misc. deposits 30 30 17 17 Total financial assets $ 30 $ 30 $ 17 $ 17 Financial liabilities: Long-term debt (a) $ 17,321 $ 17,023 $ 13,893 $ 12,642 Deferred credits and other liabilities 116 107 122 109 Total financial liabilities $ 17,437 $ 17,130 $ 14,015 $ 12,751 (a) Excludes capital leases and debt issuance costs; includes amount classified as debt due within one year. |
Derivatives (Tables)
Derivatives (Tables) | 6 Months Ended |
Jun. 30, 2018 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
Classification of Fair Values of Derivative Instruments, Excluding Cash Collateral | The following table presents the gross fair values of derivative instruments, excluding cash collateral, and where they appear on the consolidated balance sheets as of June 30, 2018 and December 31, 2017 : (In millions) June 30, 2018 Balance Sheet Location Asset Liability Commodity derivatives Other current assets $ 134 $ 171 Other current liabilities (a) — 14 Deferred credits and other liabilities (a) — 54 (In millions) December 31, 2017 Balance Sheet Location Asset Liability Commodity derivatives Other current assets $ 127 $ 126 Other current liabilities (a) — 14 Deferred credits and other liabilities (a) — 52 (a) Includes embedded derivatives. |
Open Commodity Derivative Contracts | The tables below summarize open commodity derivative contracts for crude oil and refined products as of June 30, 2018 . Position Total Barrels (In thousands) Crude Oil (a) Exchange-traded Long 31,732 Exchange-traded Short (33,530 ) (a ) 98.6 percent of the exchange-traded contracts expire in the third quarter of 2018 . Position Total Gallons (In thousands) Refined Products (a) Exchange-traded Long 111,762 Exchange-traded Short (228,396 ) (a ) 92.5 percent of the exchange-traded contracts expire in the third quarter of 2018 . |
Effect of Commodity Derivative Instruments in Statements of Income | The following table summarizes the effect of all commodity derivative instruments in our consolidated statements of income: Gain (Loss) Gain (Loss) (In millions) Three Months Ended June 30, Six Months Ended June 30, Income Statement Location 2018 2017 2018 2017 Sales and other operating revenues $ (1 ) $ 2 $ (2 ) $ 18 Cost of revenues (56 ) (7 ) (83 ) (31 ) Total $ (57 ) $ (5 ) $ (85 ) $ (13 ) |
Debt (Tables)
Debt (Tables) | 6 Months Ended |
Jun. 30, 2018 | |
Debt Disclosure [Abstract] | |
Outstanding Borrowings | Our outstanding borrowings at June 30, 2018 and December 31, 2017 consisted of the following: (In millions) June 30, December 31, Marathon Petroleum Corporation: Commercial paper $ — $ — 364-day bank revolving credit facility due July 2018 (a) — — Trade receivables securitization facility due July 2019 — — Bank revolving credit facility due 2022 — — Senior notes, 2.700% due December 2018 — 600 Senior notes, 3.400% due December 2020 650 650 Senior notes, 5.125% due March 2021 1,000 1,000 Senior notes, 3.625%, due September 2024 750 750 Senior notes, 6.500%, due March 2041 1,250 1,250 Senior notes, 4.750%, due September 2044 800 800 Senior notes, 5.850% due December 2045 250 250 Senior notes, 5.000%, due September 2054 400 400 Capital lease obligations due 2018-2033 344 356 MPLX LP: MPLX bank revolving credit facility due 2022 — 505 MPLX senior notes, 5.500%, due February 2023 710 710 MPLX senior notes, 3.375%, due March 2023 500 — MPLX senior notes, 4.500%, due July 2023 989 989 MPLX senior notes, 4.875%, due December 2024 1,149 1,149 MPLX senior notes, 4.000%, due February 2025 500 500 MPLX senior notes, 4.875%, due June 2025 1,189 1,189 MarkWest senior notes, 4.500% - 5.500%, due 2023 - 2025 63 63 MPLX senior notes, 4.125%, due March 2027 1,250 1,250 MPLX senior notes, 4.000%, due March 2028 1,250 — MPLX senior notes, 4.500%, due April 2038 1,750 — MPLX senior notes, 5.200%, due March 2047 1,000 1,000 MPLX senior notes, 4.700%, due April 2048 1,500 — MPLX senior notes, 4.900%, due April 2058 500 — MPLX capital lease obligations due 2020 7 7 Total 17,801 13,418 Unamortized debt issuance costs (107 ) (59 ) Unamortized discount (b) (427 ) (413 ) Amounts due within one year (26 ) (624 ) Total long-term debt due after one year $ 17,241 $ 12,322 (a) The 364-day facility expired on July 20, 2018. (b) Includes $349 million and $374 million of unamortized discount as of June 30, 2018 and December 31, 2017 , respectively, related to the difference between the fair value and the principal amount of assumed MarkWest debt. |
Supplemental Cash Flow Inform47
Supplemental Cash Flow Information (Tables) | 6 Months Ended |
Jun. 30, 2018 | |
Supplemental Cash Flow Elements [Abstract] | |
Summary of Supplemental Cash Flow Information | Six Months Ended (In millions) 2018 2017 Net cash provided by operating activities included: Interest paid (net of amounts capitalized) $ 279 $ 231 Income taxes paid to taxing authorities 40 198 Non-cash investing and financing activities: Contribution of assets to joint venture (a) — 337 (a) MarkWest’s contribution of assets to Sherwood Midstream and Sherwood Midstream Holdings. See Note 5 . |
Schedule of Cash and Cash Equivalents | (In millions) June 30, December 31, Cash and cash equivalents $ 4,999 $ 3,011 Restricted cash (a) 5 4 Cash, cash equivalents and restricted cash (b) $ 5,004 $ 3,015 (a) The restricted cash balance is included within “Other current assets” on the consolidated balance sheets. (b) As a result of the adoption of ASU 2016-18, the consolidated statements of cash flows now explain the change during the period of both “Cash and cash equivalents” and “Restricted cash.” |
Reconciliation of Additions to Property, Plant and Equipment to Total Capital Expenditures | The consolidated statements of cash flows exclude changes to the consolidated balance sheets that did not affect cash. The following is a reconciliation of additions to property, plant and equipment per the consolidated statements of cash flows to total capital expenditures: Six Months Ended (In millions) 2018 2017 Additions to property, plant and equipment per the consolidated statements of cash flows $ 1,466 $ 1,265 Asset retirement expenditures 5 1 Increase (decrease) in capital accruals 77 (54 ) Total capital expenditures before acquisitions 1,548 1,212 Acquisitions (a) — 220 Total capital expenditures $ 1,548 $ 1,432 (a) The six months ended June 30, 2017 reflects the acquisition of the Ozark pipeline. |
Accumulated Other Comprehensi48
Accumulated Other Comprehensive Loss (Tables) | 6 Months Ended |
Jun. 30, 2018 | |
Equity [Abstract] | |
Changes in Accumulated Other Comprehensive Loss by Component | The following table shows the changes in accumulated other comprehensive loss by component. Amounts in parentheses indicate debits. (In millions) Pension Benefits Other Benefits Gain on Cash Flow Hedge Workers Compensation Total Balance as of December 31, 2016 $ (233 ) $ (7 ) $ 4 $ 2 $ (234 ) Other comprehensive income before reclassifications 1 — — — 1 Amounts reclassified from accumulated other comprehensive loss: Amortization – prior service credit (a) (19 ) (2 ) — — (21 ) – actuarial loss/(gain) (a) 18 (1 ) — — 17 – settlement loss (a) 1 — — — 1 Other (b) — — — (1 ) (1 ) Tax effect (1 ) 2 — — 1 Other comprehensive loss — (1 ) — (1 ) (2 ) Balance as of June 30, 2017 $ (233 ) $ (8 ) $ 4 $ 1 $ (236 ) (In millions) Pension Benefits Other Benefits Gain on Cash Flow Hedge Workers Compensation Total Balance as of December 31, 2017 $ (190 ) $ (48 ) $ 4 $ 3 $ (231 ) Other comprehensive income (loss) before reclassifications 2 (1 ) (2 ) — (1 ) Amounts reclassified from accumulated other comprehensive loss: Amortization – prior service credit (a) (16 ) (2 ) — — (18 ) – actuarial loss (a) 17 — — — 17 – settlement loss (a) 2 — — — 2 Other (b) — — — (2 ) (2 ) Tax effect (1 ) 1 — — — Other comprehensive income (loss) 4 (2 ) (2 ) (2 ) (2 ) Balance as of June 30, 2018 $ (186 ) $ (50 ) $ 2 $ 1 $ (233 ) (a) These accumulated other comprehensive loss components are included in the computation of net periodic benefit cost. See Note 20 . (b) This amount was reclassified out of accumulated other comprehensive loss and is included in selling, general and administrative on the consolidated statements of income. |
Defined Benefit Pension and O49
Defined Benefit Pension and Other Postretirement Plans (Tables) | 6 Months Ended |
Jun. 30, 2018 | |
Retirement Benefits [Abstract] | |
Components of Net Periodic Benefit Costs | The following summarizes the components of net periodic benefit costs: Three Months Ended June 30, Pension Benefits Other Benefits (In millions) 2018 2017 2018 2017 Components of net periodic benefit cost: Service cost $ 35 $ 35 $ 8 $ 6 Interest cost 18 18 8 7 Expected return on plan assets (24 ) (24 ) — — Amortization – prior service credit (8 ) (9 ) (1 ) (1 ) – actuarial loss (gain) 8 9 — (1 ) – settlement loss 1 1 — — Net periodic benefit cost $ 30 $ 30 $ 15 $ 11 Six Months Ended June 30, Pension Benefits Other Benefits (In millions) 2018 2017 2018 2017 Components of net periodic benefit cost: Service cost $ 71 $ 66 $ 15 $ 13 Interest cost 36 37 15 15 Expected return on plan assets (50 ) (50 ) — — Amortization – prior service credit (16 ) (19 ) (2 ) (2 ) – actuarial loss (gain) 17 18 — (1 ) – settlement loss 2 1 — — Net periodic benefit cost $ 60 $ 53 $ 28 $ 25 |
Stock-Based Compensation Plans
Stock-Based Compensation Plans (Tables) | 6 Months Ended |
Jun. 30, 2018 | |
Disclosure of Compensation Related Costs, Share-based Payments [Abstract] | |
Summary of Stock Option Award Activity | The following table presents a summary of our stock option award activity for the six months ended June 30, 2018 : Number of Shares Weighted Average Exercise Price Outstanding at December 31, 2017 8,465,398 $ 33.74 Granted 903,797 67.71 Exercised (796,571 ) 25.89 Forfeited or expired (11,219 ) 51.67 Outstanding at June 30, 2018 8,561,405 38.03 |
Summary of Restricted Stock Award Activity | The following table presents a summary of restricted stock award activity for the six months ended June 30, 2018 : Shares of Restricted Stock (“RS”) Restricted Stock Units (“RSU”) Number of Shares Weighted Average Grant Date Fair Value Number of Units Weighted Average Grant Date Fair Value Outstanding at December 31, 2017 1,188,662 $ 45.07 285,164 $ 29.95 Granted 432,792 70.31 14,019 70.54 RS Vested/RSUs Issued (544,900 ) 44.83 (1,829 ) 43.28 Forfeited (31,280 ) 47.13 — — Outstanding at June 30, 2018 1,045,274 55.58 297,354 31.78 |
Schedule of Performance Unit Awards | The following table presents a summary of the activity for performance unit awards to be settled in shares for the six months ended June 30, 2018 : Number of Units Weighted Average Grant Date Fair Value Outstanding at December 31, 2017 6,851,542 $ 0.81 Granted 3,830,000 0.83 Vested (2,052,959 ) 0.95 Forfeited (10,000 ) 0.92 Outstanding at June 30, 2018 8,618,583 0.79 |
Supplementary Statistics (Table
Supplementary Statistics (Tables) | 6 Months Ended |
Jun. 30, 2018 | |
Text Block [Abstract] | |
Supplementary Statistics | Three Months Ended Six Months Ended (In millions) 2018 2017 2018 2017 Income from Operations by Segment Refining & Marketing (a) $ 1,025 $ 562 $ 892 $ 492 Speedway 159 238 254 373 Midstream (a) 617 332 1,184 641 Items not allocated to segments: Corporate and other unallocated items (91 ) (83 ) (180 ) (166 ) Litigation — (86 ) — (86 ) Impairments (b) 1 19 1 19 Income from operations $ 1,711 $ 982 $ 2,151 $ 1,273 Capital Expenditures and Investments (c) Refining & Marketing $ 196 $ 180 $ 387 $ 372 Speedway 88 78 127 113 Midstream (d) 601 494 1,083 1,564 Corporate and Other (e) 33 32 69 60 Total capital expenditures and investments $ 918 $ 784 $ 1,666 $ 2,109 (a) On February 1, 2018, we contributed certain refining logistics assets and fuels distributions services to MPLX. The results of these new businesses are reported in the Midstream segment prospectively from February 1, resulting in a net reduction of $232 million and $413 million to Refining & Marketing segment results and a net increase to Midstream segment results of the same amount for the three and six months ended June 30, 2018 , respectively . No effect was given to prior periods as these entities were not considered businesses prior to February 1, 2018. (b) Includes MPC’s share of gains from the sales of assets remaining from the canceled Sandpiper pipeline project. (c) Capital expenditures include changes in capital accruals, acquisitions and investments in affiliates. (d) The six months ended June 30, 2017 includes $220 million for the acquisition of the Ozark pipeline and an investment of $500 million in MarEn Bakken related to the Bakken Pipeline system. (e) Includes capitalized interest of $16 million and $14 million for the three months ended June 30, 2018 and 2017 , respectively, and $34 million and $26 million for the six months ended June 30, 2018 and 2017 , respectively. |
Operating Statistics | Three Months Ended Six Months Ended 2018 2017 2018 2017 MPC Consolidated Refined Product Sales Volumes (mbpd) (a) 2,404 2,370 2,340 2,228 Refining & Marketing Operating Statistics Refining & Marketing refined product sales volume (mbpd) (b) 2,392 2,358 2,327 2,215 Export sales volume (mbpd) (c) 311 313 292 271 Refining & Marketing margin (dollars per barrel) (d) $ 15.40 $ 11.32 $ 13.08 $ 11.47 Crude oil capacity utilization percent (e) 99.9 102.6 96.3 92.9 Refinery throughputs (mbpd): (f) Crude oil refined 1,878 1,864 1,812 1,688 Other charge and blendstocks 160 159 160 179 Total 2,038 2,023 1,972 1,867 Sour crude oil throughput percent 55 62 53 64 WTI-priced crude oil throughput percent 28 20 27 18 Refined product yields (mbpd): (f) Gasoline 970 922 943 895 Distillates 691 665 651 605 Propane 40 38 35 33 Feedstocks and special products 278 331 283 277 Heavy fuel oil 27 34 31 32 Asphalt 72 70 65 63 Total 2,078 2,060 2,008 1,905 Refinery direct operating costs (dollars per barrel): (g) Planned turnaround and major maintenance $ 0.98 $ 1.01 $ 1.58 $ 1.96 Depreciation and amortization 1.27 1.39 1.32 1.50 Other manufacturing (h) 3.54 3.84 3.80 4.24 Total $ 5.79 $ 6.24 $ 6.70 $ 7.70 Refining & Marketing Operating Statistics By Region - Gulf Coast Refinery throughputs (mbpd): (i) Crude oil refined 1,156 1,147 1,106 999 Other charge and blendstocks 190 218 179 220 Total 1,346 1,365 1,285 1,219 Sour crude oil throughput percent 65 74 63 78 WTI-priced crude oil throughput percent 16 12 15 8 Refined product yields (mbpd): (i) Gasoline 570 537 552 518 Distillates 458 432 410 371 Propane 26 27 22 24 Feedstocks and special products 290 360 294 302 Heavy fuel oil 16 23 20 20 Asphalt 23 19 20 17 Total 1,383 1,398 1,318 1,252 Three Months Ended Six Months Ended 2018 2017 2018 2017 Refinery direct operating costs (dollars per barrel): (g) Planned turnaround and major maintenance $ 0.56 $ 0.91 $ 1.65 $ 2.40 Depreciation and amortization 0.99 1.10 1.04 1.21 Other manufacturing (h) 3.21 3.45 3.54 3.96 Total $ 4.76 $ 5.46 $ 6.23 $ 7.57 Refining & Marketing Operating Statistics By Region – Midwest Refinery throughputs (mbpd): (i) Crude oil refined 722 717 706 689 Other charge and blendstocks 34 28 34 30 Total 756 745 740 719 Sour crude oil throughput percent 39 42 38 43 WTI-priced crude oil throughput percent 49 34 48 32 Refined product yields (mbpd): (i) Gasoline 400 385 391 377 Distillates 233 233 241 234 Propane 14 12 13 10 Feedstocks and special products 52 56 42 45 Heavy fuel oil 11 12 11 12 Asphalt 49 51 45 46 Total 759 749 743 724 Refinery direct operating costs (dollars per barrel): (g) Planned turnaround and major maintenance $ 1.65 $ 1.06 $ 1.33 $ 1.02 Depreciation and amortization 1.66 1.76 1.71 1.84 Other manufacturing (h) 3.81 4.13 3.98 4.31 Total $ 7.12 $ 6.95 $ 7.02 $ 7.17 Speedway Operating Statistics Convenience stores at period-end 2,744 2,729 Gasoline and distillate sales (millions of gallons) 1,450 1,475 2,843 2,868 Gasoline and distillate margin (dollars per gallon) (j) $ 0.1645 $ 0.1835 $ 0.1604 $ 0.1704 Merchandise sales (in millions) $ 1,285 $ 1,271 $ 2,414 $ 2,398 Merchandise margin (in millions) $ 366 $ 371 $ 685 $ 691 Merchandise margin percent 28.5 % 29.2 % 28.4 % 28.8 % Same store gasoline sales volume (period over period) (k) (2.6 %) (0.5 %) (2.1 %) (0.8 %) Same store merchandise sales (period over period) (k)(l) 2.9 % 2.1 % 2.6 % 2.1 % Midstream Operating Statistics Crude oil and refined product pipeline throughputs (mbpd) (m) 3,789 3,439 3,625 3,165 Terminal throughput (mbpd) 1,485 1,489 1,465 1,456 Gathering system throughput (MMcf/d) (n) 4,295 3,326 4,233 3,255 Natural gas processed (MMcf/d) (n) 6,850 6,292 6,740 6,212 C2 (ethane) + NGLs (natural gas liquids) fractionated (mbpd) (n) 439 387 432 377 (a) Total average daily volumes of refined product sales to wholesale, branded and retail customers. (b) Includes intersegment sales. (c) Represents fully loaded export cargoes for each time period. These sales volumes are included in the total sales volume amounts. (d) Sales revenue less cost of refinery inputs and purchased products, divided by total refinery throughputs. (e) Based on calendar-day capacity, which is an annual average that includes down time for planned maintenance and other normal operating activities. (f) Excludes inter-refinery volumes of 64 mbpd and 87 mbpd for the three months ended June 30, 2018 and 2017 , respectively, and 53 mbpd and 71 mbpd for the six months ended June 30, 2018 and 2017 , respectively. (g) Per barrel of total refinery throughputs. Effective with the February 1, 2018 dropdown, direct operating costs related to certain refining logistics assets are now reported in the Midstream segment. No effect was given to prior periods as this entity was not considered a business prior to February 1, 2018. (h) Includes utilities, labor, routine maintenance and other operating costs. (i) Includes inter-refinery transfer volumes. (j) The price paid by consumers less the cost of refined products, including transportation, consumer excise taxes and bank card processing fees, divided by gasoline and distillate sales volume. (k) Same store comparison includes only locations owned at least 13 months. (l) Excludes cigarettes. (m) Includes common-carrier pipelines and private pipelines owned or operated by MPLX, excluding equity method investments. (n) Includes amounts related to unconsolidated equity method investments on a 100 percent basis. |
ASU 2014-09, Revenue - Revenue
ASU 2014-09, Revenue - Revenue from Contracts with Customers (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | |||||
Jun. 30, 2018 | Jun. 30, 2017 | Jun. 30, 2018 | Jun. 30, 2017 | Dec. 31, 2017 | |||
New Accounting Pronouncements or Change in Accounting Principle [Line Items] | |||||||
Cumulative effect of new accounting principle in period of adoption | $ 64 | ||||||
Sales and other operating revenues, excluding consumer excise taxes | $ 22,118 | [1] | $ 40,812 | ||||
Cost of revenues | 19,517 | [1] | $ 16,101 | [1] | 36,887 | $ 31,047 | |
Matching buy/sell receivables | 1,500 | 1,500 | |||||
Income taxes receivables | 117 | 117 | |||||
Accounting Standards Update 2014-09 | |||||||
New Accounting Pronouncements or Change in Accounting Principle [Line Items] | |||||||
Cumulative effect of new accounting principle in period of adoption | $ 1 | ||||||
Consumer Excise Tax | Accounting Standards Update 2014-09 | |||||||
New Accounting Pronouncements or Change in Accounting Principle [Line Items] | |||||||
Sales and other operating revenues, excluding consumer excise taxes | 1,360 | 2,610 | |||||
Cost of revenues | 1,360 | 2,610 | |||||
Third Party Reimbursements, Noncash Consideration and Imbalances | Accounting Standards Update 2014-09 | |||||||
New Accounting Pronouncements or Change in Accounting Principle [Line Items] | |||||||
Sales and other operating revenues, excluding consumer excise taxes | 124 | 240 | |||||
Cost of revenues | $ 124 | $ 240 | |||||
Revenue from Contract with Customer | Accounting Standards Update 2014-09 | |||||||
New Accounting Pronouncements or Change in Accounting Principle [Line Items] | |||||||
Excise and sales taxes | 1,270 | 2,470 | |||||
Cost of Goods, Total | Accounting Standards Update 2014-09 | |||||||
New Accounting Pronouncements or Change in Accounting Principle [Line Items] | |||||||
Excise and sales taxes | $ 1,270 | $ 2,470 | |||||
[1] | The 2018 period reflects an election to present certain taxes on a net basis. See Notes 2 and 3 for further information. |
ASU 2016-16, Income Taxes - Int
ASU 2016-16, Income Taxes - Intra-Entity Transfers of Assets Other Than Inventory (Details) $ in Millions | Dec. 31, 2017USD ($) |
Cumulative effect of new accounting principle in period of adoption | $ 64 |
Accounting Standards Update 2016-16 | |
Cumulative effect of new accounting principle in period of adoption | $ 61 |
MPLX LP (Detail)
MPLX LP (Detail) - MPLX LP | Jun. 30, 2018 |
Noncontrolling Interest [Line Items] | |
MPC's partnership interest in MPLX (in percentage) | 63.60% |
Ownership percentage of general partner interest | 100.00% |
Public's ownership interest in MPLX (in percentage) | 36.40% |
MPLX LP - Dropdowns to MPLX and
MPLX LP - Dropdowns to MPLX and GP/IDR Exchange(Details) - MPLX LP - USD ($) shares in Thousands, $ in Millions | Feb. 01, 2018 | Jan. 02, 2018 | Sep. 01, 2017 | Mar. 01, 2017 |
MPLX 364-day term loan | ||||
Noncontrolling Interest [Line Items] | ||||
Maximum borrowing capacity | $ 4,100 | $ 4,100 | ||
Debt instrument, term | 364 days | 364 days | ||
Cash and Cash Equivalents | ||||
Noncontrolling Interest [Line Items] | ||||
Payments to acquire business, gross | $ 4,100 | $ 420 | $ 1,500 | |
Limited Partner | ||||
Noncontrolling Interest [Line Items] | ||||
Units issued, number of units | 112,000 | 19,000 | 13,000 | |
Conversion of stock, shares issued | 275,000 | |||
General Partner | ||||
Noncontrolling Interest [Line Items] | ||||
Units issued, number of units | 2,000 | 378 | 264 |
MPLX LP - Noncontrolling Intere
MPLX LP - Noncontrolling Interest in MPLX (Details) - USD ($) $ in Millions | 6 Months Ended | |
Jun. 30, 2018 | Jun. 30, 2017 | |
Increase in MPC's additional paid-in capital, net of tax | $ (546) | $ 393 |
Additional Paid-in Capital | ||
Increase due to the issuance of MPLX LP common units to the public | 5 | 25 |
Increase due to the issuance of MPLX LP common units and general partner units to MPC | 1,114 | 94 |
Increase due to GP/IDR Exchange | 1,808 | 0 |
Increase in MPC's additional paid-in capital | 2,927 | 119 |
Tax impact | (546) | (41) |
Increase in MPC's additional paid-in capital, net of tax | $ 2,381 | $ 78 |
Acquisitions and Investments -
Acquisitions and Investments - Pending Merger with Andeavor (Details) - Andeavor - USD ($) $ / shares in Units, $ in Millions | Apr. 29, 2018 | Sep. 30, 2018 | Jun. 30, 2018 |
Business Acquisition [Line Items] | |||
Date of merger agreement | Apr. 29, 2018 | ||
Share conversion rate | 1.87 | ||
Cash consideration to unitholders | $ 152.27 | ||
Transaction costs | $ 10 | ||
Scenario, Forecast | |||
Business Acquisition [Line Items] | |||
Shares converted to cash | 22,900,000 | ||
Shares converted | 128,200,000 | ||
Cash consideration | $ 3,500 |
Acquisitions and Investments 58
Acquisitions and Investments - Acquisition of Ozark Pipeline (Details) - Ozark Pipeline bbl / d in Thousands, $ in Millions | Mar. 01, 2017USD ($)bbl / dinmi |
Business Acquisition [Line Items] | |
Pipeline length | mi | 433 |
Pipeline diameter | in | 22 |
Crude oil throughput | bbl / d | 230 |
MPLX LP | |
Business Acquisition [Line Items] | |
Payments to acquire business, gross | $ | $ 219 |
Acquisitions and Investments 59
Acquisitions and Investments - Investment in Pipeline Company (Details) bbl / d in Thousands, $ in Millions | Feb. 15, 2017USD ($) | Jun. 30, 2017USD ($) | Jun. 30, 2018bbl / d | Jun. 30, 2017USD ($) |
Bakken Pipeline System | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Crude oil throughput | bbl / d | 520 | |||
MarEn Bakken | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Cash paid to acquire equity method investments | $ 500 | $ 500 | ||
MPLX LP | Bakken Pipeline System | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Equity method investments, ownership percentage | 9.20% | |||
MPLX LP | MarEn Bakken | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Cash paid to acquire equity method investments | $ 500 | |||
Equity method investments, ownership percentage | 25.00% | |||
MPC & Enbridge Energy Partners | Bakken Pipeline System | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Percentage of ownership interest in joint venture acquired | 36.75% | |||
MPC & Enbridge Energy Partners | MarEn Bakken | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Cash paid to acquire equity method investments | $ 2,000 |
Acquisitions and Investments 60
Acquisitions and Investments - Formation of Gathering and Processing Joint Venture (Details) bbl / d in Thousands, $ in Millions | Jan. 01, 2017USD ($)bbl / d | Jun. 30, 2018USD ($) | Jun. 30, 2017USD ($) | [1] |
Schedule of Equity Method Investments [Line Items] | ||||
Contribution of assets to joint venture | $ 0 | $ 337 | ||
Sherwood Midstream | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Equity method investments, ownership percentage | 50.00% | |||
Sherwood Midstream | MPLX LP | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Contribution of assets to joint venture | $ 134 | |||
Payments to acquire interest in joint venture | 20 | |||
Sherwood Midstream | Antero Midstream Partners L.P. | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Payments to acquire interest in joint venture | $ 154 | |||
Ohio Fractionation | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Capacity | bbl / d | 20 | |||
Ohio Fractionation | Sherwood Midstream | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Payments to acquire interest in joint venture | $ 126 | |||
Sherwood Midstream Holdings | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Equity method investments, ownership percentage | 81.00% | |||
Ownership interest In assets sold by company in affiliate | 6.00% | |||
Proceeds from sale of ownership interest in assets sold by company in affiliate | $ 15 | |||
Sherwood Midstream Holdings | Direct Ownership Interest | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Equity method investments, ownership percentage | 79.00% | |||
Sherwood Midstream Holdings | MPLX LP | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Contribution of assets to joint venture | $ 203 | |||
Fair value of assets contributed | $ 209 | |||
Sherwood Midstream Holdings | Sherwood Midstream | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Equity method investments, ownership percentage | 21.00% | |||
Payments to acquire interest in joint venture | $ 44 | |||
[1] | MarkWest’s contribution of assets to Sherwood Midstream and Sherwood Midstream Holdings. See Note 5. |
Variable Interest Entities (Det
Variable Interest Entities (Details) bbl / d in Thousands, $ in Millions | Jun. 30, 2018USD ($) | Dec. 31, 2017USD ($) | Jan. 01, 2017bbl / d |
Variable Interest Entity [Line Items] | |||
Equity method investments | $ 4,838 | $ 4,787 | |
Crowley Coastal Partners | |||
Variable Interest Entity [Line Items] | |||
VIE, maximum loss exposure, amount | $ 483 | ||
MarkWest Utica EMG | |||
Variable Interest Entity [Line Items] | |||
Equity method investments, ownership percentage | 56.00% | ||
Equity method investments | $ 2,100 | ||
Ohio Gathering | |||
Variable Interest Entity [Line Items] | |||
Equity method investments, ownership percentage | 34.00% | ||
Sherwood Midstream | |||
Variable Interest Entity [Line Items] | |||
Equity method investments, ownership percentage | 50.00% | ||
Equity method investments | $ 291 | ||
Ohio Fractionation | |||
Variable Interest Entity [Line Items] | |||
Capacity | bbl / d | 20 | ||
Sherwood Midstream Holdings | |||
Variable Interest Entity [Line Items] | |||
Equity method investments, ownership percentage | 81.00% | ||
Equity method investments | $ 155 | ||
Sherwood Midstream Holdings | Direct Ownership Interest | |||
Variable Interest Entity [Line Items] | |||
Equity method investments, ownership percentage | 79.00% | ||
Sherwood Midstream Holdings | Indirect Ownership Interest | |||
Variable Interest Entity [Line Items] | |||
Equity method investments, ownership percentage | 10.50% |
Related Party Transactions - Ad
Related Party Transactions - Additional Information (Detail) | Jun. 30, 2018 |
Crowley Blue Water Partners | |
Related Party Transaction [Line Items] | |
Equity method investments, ownership percentage | 50.00% |
Crowley Ocean Partners | |
Related Party Transaction [Line Items] | |
Equity method investments, ownership percentage | 50.00% |
Illinois Extension Pipeline | |
Related Party Transaction [Line Items] | |
Equity method investments, ownership percentage | 35.00% |
LOCAP | |
Related Party Transaction [Line Items] | |
Equity method investments, ownership percentage | 59.00% |
LOOP | |
Related Party Transaction [Line Items] | |
Equity method investments, ownership percentage | 51.00% |
MarkWest Utica EMG | |
Related Party Transaction [Line Items] | |
Equity method investments, ownership percentage | 56.00% |
Ohio Gathering | |
Related Party Transaction [Line Items] | |
Equity method investments, ownership percentage | 34.00% |
PFJ Southeast | |
Related Party Transaction [Line Items] | |
Equity method investments, ownership percentage | 29.00% |
Sherwood Midstream | |
Related Party Transaction [Line Items] | |
Equity method investments, ownership percentage | 50.00% |
Sherwood Midstream Holdings | |
Related Party Transaction [Line Items] | |
Equity method investments, ownership percentage | 81.00% |
TAAE | |
Related Party Transaction [Line Items] | |
Equity method investments, ownership percentage | 45.00% |
TACE | |
Related Party Transaction [Line Items] | |
Equity method investments, ownership percentage | 61.00% |
TAME | |
Related Party Transaction [Line Items] | |
Equity method investments, ownership percentage | 67.00% |
Related Party Transactions - Sa
Related Party Transactions - Sales to Related Parties (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2018 | Jun. 30, 2017 | Jun. 30, 2018 | Jun. 30, 2017 | |
Related Party Transaction [Line Items] | ||||
Sales to related parties | $ 199 | $ 147 | $ 371 | $ 301 |
PFJ Southeast | ||||
Related Party Transaction [Line Items] | ||||
Sales to related parties | 196 | 145 | 365 | 296 |
Other equity method investees | ||||
Related Party Transaction [Line Items] | ||||
Sales to related parties | $ 3 | $ 2 | $ 6 | $ 5 |
Related Party Transactions - Ot
Related Party Transactions - Other Income From Related Parties (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2018 | Jun. 30, 2017 | Jun. 30, 2018 | Jun. 30, 2017 | |
Related Party Transaction [Line Items] | ||||
Other income from related parties | $ 14 | $ 15 | $ 27 | $ 26 |
MarkWest Utica EMG | ||||
Related Party Transaction [Line Items] | ||||
Other income from related parties | 4 | 4 | 8 | 8 |
Ohio Gathering | ||||
Related Party Transaction [Line Items] | ||||
Other income from related parties | 4 | 4 | 8 | 8 |
Sherwood Midstream | ||||
Related Party Transaction [Line Items] | ||||
Other income from related parties | 2 | 3 | 5 | 4 |
Other equity method investees | ||||
Related Party Transaction [Line Items] | ||||
Other income from related parties | $ 4 | $ 4 | $ 6 | $ 6 |
Related Party Transactions - Pu
Related Party Transactions - Purchases from Related Parties (Detail) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2018 | Jun. 30, 2017 | Jun. 30, 2018 | Jun. 30, 2017 | |
Related Party Transaction [Line Items] | ||||
Purchases from related parties | $ 138 | $ 150 | $ 279 | $ 272 |
Crowley Blue Water Partners | ||||
Related Party Transaction [Line Items] | ||||
Purchases from related parties | 14 | 14 | 30 | 28 |
Crowley Ocean Partners | ||||
Related Party Transaction [Line Items] | ||||
Purchases from related parties | 20 | 20 | 40 | 39 |
Illinois Extension Pipeline | ||||
Related Party Transaction [Line Items] | ||||
Purchases from related parties | 23 | 24 | 47 | 49 |
LOCAP | ||||
Related Party Transaction [Line Items] | ||||
Purchases from related parties | 3 | 6 | 7 | 11 |
LOOP | ||||
Related Party Transaction [Line Items] | ||||
Purchases from related parties | 14 | 26 | 31 | 39 |
TAAE | ||||
Related Party Transaction [Line Items] | ||||
Purchases from related parties | 22 | 23 | 41 | 31 |
TACE | ||||
Related Party Transaction [Line Items] | ||||
Purchases from related parties | 10 | 9 | 18 | 25 |
TAME | ||||
Related Party Transaction [Line Items] | ||||
Purchases from related parties | 25 | 21 | 45 | 38 |
Other equity method investees | ||||
Related Party Transaction [Line Items] | ||||
Purchases from related parties | $ 7 | $ 7 | $ 20 | $ 12 |
Related Party Transactions - Re
Related Party Transactions - Receivables From Related Parties (Details) - USD ($) $ in Millions | Jun. 30, 2018 | Dec. 31, 2017 |
Related Party Transaction [Line Items] | ||
Current receivables from related parties | $ 38 | $ 36 |
PFJ Southeast | ||
Related Party Transaction [Line Items] | ||
Current receivables from related parties | 30 | 28 |
Other equity method investees | ||
Related Party Transaction [Line Items] | ||
Current receivables from related parties | $ 8 | $ 8 |
Related Party Transactions - Pa
Related Party Transactions - Payables To Related Parties (Detail) - USD ($) $ in Millions | Jun. 30, 2018 | Dec. 31, 2017 |
Related Party Transaction [Line Items] | ||
Payables to related parties | $ 56 | $ 69 |
Illinois Extension Pipeline | ||
Related Party Transaction [Line Items] | ||
Payables to related parties | 8 | 8 |
LOOP | ||
Related Party Transaction [Line Items] | ||
Payables to related parties | 4 | 3 |
MarkWest Utica EMG | ||
Related Party Transaction [Line Items] | ||
Payables to related parties | 26 | 29 |
Ohio Gathering | ||
Related Party Transaction [Line Items] | ||
Payables to related parties | 0 | 9 |
Sherwood Midstream | ||
Related Party Transaction [Line Items] | ||
Payables to related parties | 8 | 8 |
Other equity method investees | ||
Related Party Transaction [Line Items] | ||
Payables to related parties | $ 10 | $ 12 |
Income Per Common Share - Summa
Income Per Common Share - Summary of Earnings Per Common Share (Detail) - USD ($) $ / shares in Units, shares in Millions, $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2018 | Jun. 30, 2017 | Jun. 30, 2018 | Jun. 30, 2017 | |
Basic earnings per share: | ||||
Net income attributable to MPC | $ 1,055 | $ 483 | $ 1,092 | $ 513 |
Income allocated to participating securities | 1 | 0 | 1 | 0 |
Income available to common stockholders – basic | $ 1,054 | $ 483 | $ 1,091 | $ 513 |
Weighted average common shares outstanding (in shares) | 459 | 513 | 467 | 519 |
Basic (in USD per share) | $ 2.30 | $ 0.94 | $ 2.34 | $ 0.99 |
Diluted earnings per share: | ||||
Net income attributable to MPC | $ 1,055 | $ 483 | $ 1,092 | $ 513 |
Income allocated to participating securities | 1 | 0 | 1 | 0 |
Income available to common stockholders – diluted | $ 1,054 | $ 483 | $ 1,091 | $ 513 |
Weighted average common shares outstanding (in shares) | 459 | 513 | 467 | 519 |
Effect of dilutive securities (in shares) | 5 | 4 | 5 | 4 |
Weighted average common shares, including dilutive effect (in shares) | 464 | 517 | 472 | 523 |
Diluted (in USD per share) | $ 2.27 | $ 0.93 | $ 2.31 | $ 0.98 |
Income Per Common Share - Anti-
Income Per Common Share - Anti-dilutive Shares (Details) - shares shares in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2018 | Jun. 30, 2017 | Jun. 30, 2018 | Jun. 30, 2017 | |
Stock Based Compensation Expense [Member] | ||||
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items] | ||||
Shares issued under stock-based compensation plans | 1 | 0 | 1 | 2 |
Equity - Additional Information
Equity - Additional Information (Detail) - USD ($) $ in Millions | 1 Months Ended | 3 Months Ended | 6 Months Ended | ||
Jul. 31, 2018 | Jun. 30, 2018 | Jun. 30, 2017 | Jun. 30, 2018 | Jun. 30, 2017 | |
Stock repurchase program, remaining authorized repurchase amount | $ 5,980 | $ 5,980 | |||
Number of shares repurchased | 12,000,000 | 14,000,000 | 31,000,000 | 23,000,000 | |
Cash paid for shares repurchased | $ 885 | $ 750 | $ 2,212 | $ 1,170 | |
Scenario, Forecast | |||||
Number of shares repurchased | 495,702 | ||||
Cash paid for shares repurchased | $ 35 |
Equity - Share Repurchases (Det
Equity - Share Repurchases (Detail) - USD ($) $ / shares in Units, shares in Millions, $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2018 | Jun. 30, 2017 | Jun. 30, 2018 | Jun. 30, 2017 | |
Equity [Abstract] | ||||
Number of shares repurchased | 12 | 14 | 31 | 23 |
Cash paid for shares repurchased | $ 885 | $ 750 | $ 2,212 | $ 1,170 |
Average cost per share | $ 76.30 | $ 52.35 | $ 71.58 | $ 51.53 |
Segment Information - Additiona
Segment Information - Additional Information (Detail) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2018USD ($) | Jun. 30, 2017USD ($) | Jun. 30, 2018USD ($)Segmentrefinery | Jun. 30, 2017USD ($) | |
Segment Reporting Information [Line Items] | ||||
Number of reportable segments | Segment | 3 | |||
Number of refineries | refinery | 6 | |||
Income from operations | $ 1,711 | $ 982 | $ 2,151 | $ 1,273 |
Refining Logistics & Fuels Distribution [Member] | Midstream | ||||
Segment Reporting Information [Line Items] | ||||
Income from operations | 232 | 413 | ||
Refining Logistics & Fuels Distribution [Member] | Refining & Marketing | ||||
Segment Reporting Information [Line Items] | ||||
Income from operations | $ (232) | $ (413) |
Segment Information - Income Fr
Segment Information - Income From Operations Attributable To Operating Segments (Detail) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | |||||||
Jun. 30, 2018 | Jun. 30, 2017 | Jun. 30, 2018 | Jun. 30, 2017 | ||||||
Segment Reporting Information [Line Items] | |||||||||
Sales and other operating revenues, excluding consumer excise taxes | $ 22,118 | [1] | $ 40,812 | ||||||
Sales and other operating revenues, including consumer excise taxes | $ 18,033 | [1] | $ 34,167 | ||||||
Sales to related parties | 199 | 147 | 371 | 301 | |||||
Income from operations | 1,711 | 982 | 2,151 | 1,273 | |||||
Income from equity method investments | 80 | 83 | 166 | 140 | |||||
Depreciation and amortization | 533 | 521 | 1,061 | 1,057 | |||||
Capital expenditures and investments | [2] | 918 | 784 | 1,666 | 2,109 | ||||
MarEn Bakken | |||||||||
Segment Reporting Information [Line Items] | |||||||||
Cash paid to acquire equity method investments | 500 | 500 | |||||||
Intersegment Eliminations | |||||||||
Segment Reporting Information [Line Items] | |||||||||
Sales and other operating revenues, excluding consumer excise taxes | 3,635 | 6,646 | |||||||
Sales and other operating revenues, including consumer excise taxes | [3] | 3,172 | 6,107 | ||||||
Operating Segments | |||||||||
Segment Reporting Information [Line Items] | |||||||||
Sales and other operating revenues, excluding consumer excise taxes | 25,952 | 47,829 | |||||||
Sales and other operating revenues, including consumer excise taxes | 21,352 | 40,575 | |||||||
Income from operations | 1,801 | 1,132 | 2,330 | 1,506 | |||||
Income from equity method investments | [4] | 79 | 63 | 165 | 120 | ||||
Depreciation and amortization | [4] | 516 | 505 | 1,028 | 1,027 | ||||
Capital expenditures and investments | [5] | 885 | 752 | 1,597 | 2,049 | ||||
Cash paid to acquire equity method investments | 77 | 111 | [6] | 118 | 677 | [6] | |||
Refining & Marketing | |||||||||
Segment Reporting Information [Line Items] | |||||||||
Sales and other operating revenues, excluding consumer excise taxes | 16,105 | 29,517 | |||||||
Sales and other operating revenues, including consumer excise taxes | 12,691 | 23,912 | |||||||
Sales to related parties | 197 | 145 | 367 | 297 | |||||
Refining & Marketing | Intersegment Eliminations | |||||||||
Segment Reporting Information [Line Items] | |||||||||
Sales and other operating revenues, excluding consumer excise taxes | 2,871 | 5,250 | |||||||
Sales and other operating revenues, including consumer excise taxes | 2,808 | 5,398 | |||||||
Refining & Marketing | Operating Segments | |||||||||
Segment Reporting Information [Line Items] | |||||||||
Sales and other operating revenues, excluding consumer excise taxes | 19,173 | 35,134 | |||||||
Sales and other operating revenues, including consumer excise taxes | 15,644 | 29,607 | |||||||
Income from operations | 1,025 | [7] | 562 | 892 | [7] | 492 | |||
Income from equity method investments | 4 | 2 | 7 | 4 | |||||
Depreciation and amortization | 252 | 272 | 504 | 539 | |||||
Capital expenditures and investments | 196 | 180 | 387 | 372 | |||||
Speedway | |||||||||
Segment Reporting Information [Line Items] | |||||||||
Sales and other operating revenues, excluding consumer excise taxes | 5,263 | 9,832 | |||||||
Sales and other operating revenues, including consumer excise taxes | 4,794 | 9,175 | |||||||
Sales to related parties | 2 | 2 | 4 | 4 | |||||
Speedway | Intersegment Eliminations | |||||||||
Segment Reporting Information [Line Items] | |||||||||
Sales and other operating revenues, excluding consumer excise taxes | 2 | 3 | |||||||
Sales and other operating revenues, including consumer excise taxes | 1 | 2 | |||||||
Speedway | Operating Segments | |||||||||
Segment Reporting Information [Line Items] | |||||||||
Sales and other operating revenues, excluding consumer excise taxes | 5,267 | 9,839 | |||||||
Sales and other operating revenues, including consumer excise taxes | 4,797 | 9,181 | |||||||
Income from operations | 159 | 238 | 254 | 373 | |||||
Income from equity method investments | 19 | 21 | 33 | 34 | |||||
Depreciation and amortization | 73 | 65 | 152 | 129 | |||||
Capital expenditures and investments | 88 | 78 | 127 | 113 | |||||
Midstream | |||||||||
Segment Reporting Information [Line Items] | |||||||||
Sales and other operating revenues, excluding consumer excise taxes | 750 | 1,463 | |||||||
Sales and other operating revenues, including consumer excise taxes | 548 | 1,080 | |||||||
Sales to related parties | 0 | 0 | 0 | 0 | |||||
Midstream | Ozark Pipeline | |||||||||
Segment Reporting Information [Line Items] | |||||||||
Capital expenditures and investments | 220 | 220 | |||||||
Midstream | Intersegment Eliminations | |||||||||
Segment Reporting Information [Line Items] | |||||||||
Sales and other operating revenues, excluding consumer excise taxes | 762 | 1,393 | |||||||
Sales and other operating revenues, including consumer excise taxes | 363 | 707 | |||||||
Midstream | Operating Segments | |||||||||
Segment Reporting Information [Line Items] | |||||||||
Sales and other operating revenues, excluding consumer excise taxes | 1,512 | 2,856 | |||||||
Sales and other operating revenues, including consumer excise taxes | 911 | 1,787 | |||||||
Income from operations | 617 | [7] | 332 | 1,184 | [7] | 641 | |||
Income from equity method investments | 56 | 40 | 125 | 82 | |||||
Depreciation and amortization | 191 | 168 | 372 | 359 | |||||
Capital expenditures and investments | 601 | 494 | 1,083 | 1,564 | [8] | ||||
Reportable Segment | |||||||||
Segment Reporting Information [Line Items] | |||||||||
Sales and other operating revenues, excluding consumer excise taxes | $ 22,118 | $ 40,812 | |||||||
Sales and other operating revenues, including consumer excise taxes | $ 18,033 | $ 34,167 | |||||||
[1] | The 2018 period reflects an election to present certain taxes on a net basis. See Notes 2 and 3 for further information. | ||||||||
[2] | Capital expenditures include changes in capital accruals, acquisitions and investments in affiliates. | ||||||||
[3] | Management believes intersegment transactions were conducted under terms comparable to those with unaffiliated parties | ||||||||
[4] | Differences between segment totals and MPC totals represent amounts related to corporate and other unallocated items and are included in “Items not allocated to segments” in the reconciliation below. | ||||||||
[5] | Capital expenditures include changes in capital accruals, acquisitions and investments in affiliates. See reconciliation from segment totals to MPC total capital expenditures below. | ||||||||
[6] | The six months ended June 30, 2017 includes an investment of $500 million in MarEn Bakken related to the Bakken Pipeline system. | ||||||||
[7] | On February 1, 2018, we contributed certain refining logistics assets and fuels distributions services to MPLX. The results of these new businesses are reported in the Midstream segment prospectively from February 1, resulting in a net reduction of $232 million and $413 million to Refining & Marketing segment results and a net increase to Midstream segment results of the same amount for the three and six months ended June 30, 2018, respectively. No effect was given to prior periods as these entities were not considered businesses prior to February 1, 2018. | ||||||||
[8] | The Midstream segment includes $220 million for the acquisition of the Ozark pipeline and an investment of $500 million in MarEn Bakken related to the Bakken Pipeline system for the six months ended June 30, 2017. |
Segment Information - Reconcili
Segment Information - Reconciliation Of Segment Income From Operations To Income Before Income Taxes (Detail) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | |||
Jun. 30, 2018 | Jun. 30, 2017 | Jun. 30, 2018 | Jun. 30, 2017 | ||
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items] | |||||
Income from operations | $ 1,711 | $ 982 | $ 2,151 | $ 1,273 | |
Net interest and other financial income (costs) | 195 | 158 | 378 | 307 | |
Income before income taxes | 1,516 | 824 | 1,773 | 966 | |
Operating Segments | |||||
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items] | |||||
Income from operations | 1,801 | 1,132 | 2,330 | 1,506 | |
Corporate and Other | |||||
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items] | |||||
Income from operations | [1] | (91) | (83) | (180) | (166) |
Segment Reconciling Items | |||||
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items] | |||||
Litigation | 0 | (86) | 0 | (86) | |
Impairments | [2] | $ 1 | $ 19 | $ 1 | $ 19 |
[1] | Corporate and other unallocated items consists primarily of MPC’s corporate administrative expenses and costs related to certain non-operating assets, except for corporate overhead expenses attributable to MPLX, which are included in the Midstream segment. Corporate overhead expenses are not allocated to the Refining & Marketing and Speedway segments. | ||||
[2] | Includes MPC’s share of gains from the sale of assets remaining from the canceled Sandpiper pipeline project |
Segment Information - Reconci75
Segment Information - Reconciliation Of Segment Capital Expenditures And Investments To Total Capital Expenditures (Detail) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | |||||
Jun. 30, 2018 | Jun. 30, 2017 | Jun. 30, 2018 | Jun. 30, 2017 | ||||
Reconciliation Of Segment Capital Expenditures And Investments To Total Capital Expenditures [Line Items] | |||||||
Capital expenditures and investments | [1] | $ 918 | $ 784 | $ 1,666 | $ 2,109 | ||
Plus items not allocated to segments: | |||||||
Capital expenditures | [2] | 841 | 673 | 1,548 | 1,432 | ||
MarEn Bakken | |||||||
Reconciliation Of Segment Capital Expenditures And Investments To Total Capital Expenditures [Line Items] | |||||||
Less: Investments in equity method investees | 500 | 500 | |||||
Operating Segments | |||||||
Reconciliation Of Segment Capital Expenditures And Investments To Total Capital Expenditures [Line Items] | |||||||
Capital expenditures and investments | [3] | 885 | 752 | 1,597 | 2,049 | ||
Less: Investments in equity method investees | 77 | 111 | [4] | 118 | 677 | [4] | |
Corporate and Other | |||||||
Reconciliation Of Segment Capital Expenditures And Investments To Total Capital Expenditures [Line Items] | |||||||
Capital expenditures and investments | [5] | 33 | 32 | 69 | 60 | ||
Plus items not allocated to segments: | |||||||
Corporate | 17 | 18 | 35 | 34 | |||
Capitalized interest | $ 16 | $ 14 | $ 34 | $ 26 | |||
[1] | Capital expenditures include changes in capital accruals, acquisitions and investments in affiliates. | ||||||
[2] | Capital expenditures include changes in capital accruals. See Note 18 for a reconciliation of total capital expenditures to additions to property, plant and equipment as reported in the consolidated statements of cash flows.Revenues by product line were as follows: Three Months Ended June 30, Six Months Ended June 30,(In millions)2018 2017 2018 2017Refined products$19,292 $15,439 $35,450 $29,315Merchandise1,286 1,343 2,416 2,535Crude oil and refinery feedstocks978 824 1,861 1,511Midstream services, transportation and other562 427 1,085 806Sales and other operating revenues $22,118 $18,033 $40,812 $34,167 | ||||||
[3] | Capital expenditures include changes in capital accruals, acquisitions and investments in affiliates. See reconciliation from segment totals to MPC total capital expenditures below. | ||||||
[4] | The six months ended June 30, 2017 includes an investment of $500 million in MarEn Bakken related to the Bakken Pipeline system. | ||||||
[5] | Includes capitalized interest of $16 million and $14 million for the three months ended June 30, 2018 and 2017, respectively, and $34 million and $26 million for the six months ended June 30, 2018 and 2017, respectively. |
Segment Information - Revenues
Segment Information - Revenues by Product Line (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||||
Jun. 30, 2018 | Jun. 30, 2017 | Jun. 30, 2018 | Jun. 30, 2017 | |||
Revenue from External Customer [Line Items] | ||||||
Sales and other operating revenues, excluding consumer excise taxes | $ 22,118 | [1] | $ 40,812 | |||
Sales and other operating revenues, including consumer excise taxes | $ 18,033 | [1] | $ 34,167 | |||
Refined products | ||||||
Revenue from External Customer [Line Items] | ||||||
Sales and other operating revenues, excluding consumer excise taxes | 19,292 | 35,450 | ||||
Sales and other operating revenues, including consumer excise taxes | 15,439 | 29,315 | ||||
Merchandise | ||||||
Revenue from External Customer [Line Items] | ||||||
Sales and other operating revenues, excluding consumer excise taxes | 1,286 | 2,416 | ||||
Sales and other operating revenues, including consumer excise taxes | 1,343 | 2,535 | ||||
Crude oil and refinery feedstocks | ||||||
Revenue from External Customer [Line Items] | ||||||
Sales and other operating revenues, excluding consumer excise taxes | 978 | 1,861 | ||||
Sales and other operating revenues, including consumer excise taxes | 824 | 1,511 | ||||
Midstream services, transportation and other | ||||||
Revenue from External Customer [Line Items] | ||||||
Sales and other operating revenues, excluding consumer excise taxes | $ 562 | $ 1,085 | ||||
Sales and other operating revenues, including consumer excise taxes | $ 427 | $ 806 | ||||
[1] | The 2018 period reflects an election to present certain taxes on a net basis. See Notes 2 and 3 for further information. |
Other Items - Net Interest And
Other Items - Net Interest And Other Financial Costs (Detail) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2018 | Jun. 30, 2017 | Jun. 30, 2018 | Jun. 30, 2017 | |
Other Income and Expenses [Abstract] | ||||
Interest income | $ (25) | $ (4) | $ (45) | $ (9) |
Interest expense | 229 | 173 | 442 | 336 |
Interest capitalized | (16) | (18) | (34) | (33) |
Loss on extinguishment of debt | 0 | 0 | 4 | 0 |
Other financial costs | 7 | 7 | 11 | 13 |
Net interest and other financial costs | $ 195 | $ 158 | $ 378 | $ 307 |
Income Taxes - Additional Infor
Income Taxes - Additional Information (Detail) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2018 | Jun. 30, 2017 | Jun. 30, 2018 | Jun. 30, 2017 | |
Income Tax Disclosure [Abstract] | ||||
Combined federal, state and foreign income tax rate | 19.00% | 30.00% | 17.00% | 30.00% |
Statutory rate applied to income before income taxes | 21.00% | 35.00% | ||
Unrecognized benefits | $ 21 | $ 21 |
Inventories - Summary Of Invent
Inventories - Summary Of Inventories (Detail) - USD ($) $ in Millions | Jun. 30, 2018 | Dec. 31, 2017 |
Inventory Disclosure [Abstract] | ||
Crude oil and refinery feedstocks | $ 2,059 | $ 2,056 |
Refined products | 2,811 | 2,839 |
Materials and supplies | 455 | 494 |
Merchandise | 160 | 161 |
Total | $ 5,485 | $ 5,550 |
Inventories - Additional Inform
Inventories - Additional Information (Detail) $ in Millions | 6 Months Ended |
Jun. 30, 2018USD ($) | |
Inventory Disclosure [Abstract] | |
Impact on income as a result of LIFO liquidations | $ 0 |
Property, Plant And Equipment -
Property, Plant And Equipment - Summary Of Property, Plant And Equipment (Detail) - USD ($) $ in Millions | Feb. 01, 2018 | Jun. 30, 2018 | Dec. 31, 2017 | |
Property, Plant and Equipment [Line Items] | ||||
Property, plant and equipment, gross | $ 41,985 | $ 40,538 | ||
Less accumulated depreciation | 15,054 | 14,095 | ||
Property, plant and equipment, net | $ 26,931 | 26,443 | ||
Undivided joint interest, ownership percentage | 33.00% | |||
Undivided joint interest | $ 155 | |||
Refining & Marketing | ||||
Property, Plant and Equipment [Line Items] | ||||
Property, plant and equipment, transfers | $ (830) | |||
Midstream | ||||
Property, Plant and Equipment [Line Items] | ||||
Property, plant and equipment, transfers | $ 830 | |||
Operating Segments | Refining & Marketing | ||||
Property, Plant and Equipment [Line Items] | ||||
Property, plant and equipment, gross | 18,314 | [1] | 19,490 | |
Operating Segments | Speedway | ||||
Property, Plant and Equipment [Line Items] | ||||
Property, plant and equipment, gross | 5,433 | 5,358 | ||
Operating Segments | Midstream | ||||
Property, Plant and Equipment [Line Items] | ||||
Property, plant and equipment, gross | 17,411 | [1] | 14,898 | |
Corporate and Other | ||||
Property, Plant and Equipment [Line Items] | ||||
Property, plant and equipment, gross | $ 827 | $ 792 | ||
[1] | On February 1, 2018, we contributed certain refining logistics assets and fuels distribution services to MPLX. In connection with this transaction, approximately $830 million of net property, plant and equipment was recorded to the Midstream segment with an offsetting reduction to the Refining & Marketing segment.We own a 33 percent undivided joint interest in the Capline Pipeline System (“Capline”), a crude oil pipeline that runs from St. James, LA to Patoka, IL. We account for this undivided joint interest by recognizing our proportionate share of Capline’s assets on our balance sheet, which are primarily classified as property, plant and equipment. Capline experienced a significant reduction in shipment volumes in the second quarter of 2018 primarily due to recently completed competing pipelines. The pipeline`s owners are proceeding with planning for the reversal of the pipeline to support southbound movements of crude oil as supported by shipper interest indicated during a non-binding open season conducted in 2017. Pending agreement among the owners, southbound service is estimated to commence by the second half of 2022. In the second quarter of 2018, we evaluated our share of Capline assets for impairment in accordance with ASC 360, and determined no impairment existed due to the probability of continuing future cash flows associated with a reversed Capline. As of June 30, 2018, our carrying value was $155 million. |
Fair Value Measurements - Asset
Fair Value Measurements - Assets and Liabilities Accounted for at Fair Value on Recurring Basis (Detail) - USD ($) $ in Millions | Jun. 30, 2018 | Dec. 31, 2017 | |
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||
Cash collateral netted with derivative liabilities | $ 37 | $ 8 | |
Embedded derivatives in commodity contracts | |||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||
Embedded derivatives, current | 12 | 12 | |
Fair Value, Measurements, Recurring | |||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||
Commodity derivative instruments, assets - netting and collateral | (134) | (118) | |
Commodity derivative instruments, assets - collateral pledged not offset | 16 | 8 | |
Other assets | 3 | 3 | |
Total assets at fair value | 3 | 12 | |
Commodity derivative instruments, liabilities - netting and collateral | (171) | (126) | |
Commodity derivative instruments, liabilities - collateral pledged not offset | 0 | 0 | |
Total liabilities at fair value | 68 | 66 | |
Fair Value, Measurements, Recurring | Commodity derivatives | |||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||
Commodity derivative instruments, assets - netting and collateral | [1] | (134) | (118) |
Commodity derivative instruments, assets - net carrying value on balance sheet | [2] | 0 | 9 |
Commodity derivative instruments, assets - collateral pledged not offset | 16 | 8 | |
Commodity derivative instruments, liabilities - netting and collateral | [1] | (171) | (126) |
Commodity derivative instruments, liabilities - net carrying value on balance sheet | [2] | 2 | 2 |
Commodity derivative instruments, liabilities - collateral pledged not offset | 0 | 0 | |
Fair Value, Measurements, Recurring | Embedded derivatives in commodity contracts | |||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||
Commodity derivative instruments, liabilities - netting and collateral | 0 | 0 | |
Commodity derivative instruments, liabilities - net carrying value on balance sheet | [2] | 66 | 64 |
Commodity derivative instruments, liabilities - collateral pledged not offset | 0 | 0 | |
Fair Value, Measurements, Recurring | Level 1 | |||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||
Other assets | 3 | 3 | |
Total assets at fair value | 137 | 130 | |
Total liabilities at fair value | 171 | 126 | |
Fair Value, Measurements, Recurring | Level 1 | Commodity derivatives | |||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||
Commodity derivative instruments, assets - gross | 134 | 127 | |
Commodity derivative instruments, liabilities - gross | 171 | 126 | |
Fair Value, Measurements, Recurring | Level 1 | Embedded derivatives in commodity contracts | |||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||
Commodity derivative instruments, liabilities - gross | 0 | 0 | |
Fair Value, Measurements, Recurring | Level 2 | |||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||
Other assets | 0 | 0 | |
Total assets at fair value | 0 | 0 | |
Total liabilities at fair value | 0 | 0 | |
Fair Value, Measurements, Recurring | Level 2 | Commodity derivatives | |||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||
Commodity derivative instruments, assets - gross | 0 | 0 | |
Commodity derivative instruments, liabilities - gross | 0 | 0 | |
Fair Value, Measurements, Recurring | Level 2 | Embedded derivatives in commodity contracts | |||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||
Commodity derivative instruments, liabilities - gross | 0 | 0 | |
Fair Value, Measurements, Recurring | Level 3 | |||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||
Other assets | 0 | 0 | |
Total assets at fair value | 0 | 0 | |
Total liabilities at fair value | 68 | 66 | |
Fair Value, Measurements, Recurring | Level 3 | Commodity derivatives | |||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||
Commodity derivative instruments, assets - gross | 0 | 0 | |
Commodity derivative instruments, liabilities - gross | 2 | 2 | |
Fair Value, Measurements, Recurring | Level 3 | Embedded derivatives in commodity contracts | |||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||
Commodity derivative instruments, liabilities - gross | [3] | $ 66 | $ 64 |
[1] | Represents the impact of netting assets, liabilities and cash collateral when a legal right of offset exists. As of June 30, 2018, cash collateral of $37 million was netted with the mark-to-market derivative liabilities. As of December 31, 2017, $8 million was netted with mark-to-market derivative liabilities. | ||
[2] | We have no derivative contracts that are subject to master netting arrangements reflected gross on the balance sheet. | ||
[3] | Level 3 includes $12 million classified as current at both June 30, 2018 and December 31, 2017. |
Fair Value Measurements - Recur
Fair Value Measurements - Recurring Narrative (Detail) | 6 Months Ended |
Jun. 30, 2018USD ($) | |
Commodity derivatives | Level 3 | Minimum | |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |
Forward commodity price | $ 0.70 |
Commodity derivatives | Level 3 | Maximum | |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |
Forward commodity price | $ 1.58 |
Embedded derivatives in commodity contracts | |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |
Embedded derivative renewal term | 5 years |
Embedded derivatives in commodity contracts | Level 3 | |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |
Probability of renewal first term | 65.00% |
Probability of renewal second term | 84.00% |
Fair Value Measurements - Recon
Fair Value Measurements - Reconciliation of Net Beginning and Ending Balances Recorded for Net Assets and Liabilities Classified as Level 3 (Detail) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2018 | Jun. 30, 2017 | Jun. 30, 2018 | Jun. 30, 2017 | |
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | ||||
Beginning balance | $ 60 | $ 175 | $ 66 | $ 190 |
Contingent consideration payment | 0 | (131) | 0 | (131) |
Unrealized and realized (gains) losses included in net income | 12 | (2) | 9 | (14) |
Settlements of derivative instruments | (4) | (1) | (7) | (4) |
Ending balance | $ 68 | $ 41 | $ 68 | $ 41 |
Fair Value Measurements - Losse
Fair Value Measurements - Losses Included in Earnings Relating to Assets Still Held at End of Period (Details) - Fair Value, Measurements, Recurring - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2018 | Jun. 30, 2017 | Jun. 30, 2018 | Jun. 30, 2017 | |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
The amount of total losses for the period included in earnings attributable to the change in unrealized losses relating to assets still held at the end of period: | $ 11 | $ (1) | $ 5 | $ (11) |
Derivative | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
The amount of total losses for the period included in earnings attributable to the change in unrealized losses relating to assets still held at the end of period: | 11 | (1) | 5 | (12) |
Contingent Consideration | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
The amount of total losses for the period included in earnings attributable to the change in unrealized losses relating to assets still held at the end of period: | $ 0 | $ 0 | $ 0 | $ 1 |
Fair Value Measurements - Finan
Fair Value Measurements - Financial Instruments at Fair Value, Excluding Derivative Financial Instruments and Contingent Consideration (Detail) - USD ($) $ in Millions | Jun. 30, 2018 | Dec. 31, 2017 | |
Fair Value | |||
Financial assets: | |||
Environmental receivables and misc. deposits | $ 30 | $ 17 | |
Total financial assets | 30 | 17 | |
Financial liabilities: | |||
Long-term debt | [1] | 17,321 | 13,893 |
Deferred credits and other liabilities | 116 | 122 | |
Total financial liabilities | 17,437 | 14,015 | |
Carrying Value | |||
Financial assets: | |||
Environmental receivables and misc. deposits | 30 | 17 | |
Total financial assets | 30 | 17 | |
Financial liabilities: | |||
Long-term debt | [1] | 17,023 | 12,642 |
Deferred credits and other liabilities | 107 | 109 | |
Total financial liabilities | $ 17,130 | $ 12,751 | |
[1] | Excludes capital leases and debt issuance costs; includes amount classified as debt due within one year. |
Derivatives - Classification of
Derivatives - Classification of Gross Fair Values of Derivative Instruments, Excluding Cash Collateral (Detail) - Commodity derivatives - USD ($) $ in Millions | Jun. 30, 2018 | Dec. 31, 2017 | |
Other current assets | |||
Derivatives, Fair Value [Line Items] | |||
Asset | $ 134 | $ 127 | |
Liability | 171 | 126 | |
Other current liabilities(a) | |||
Derivatives, Fair Value [Line Items] | |||
Asset | 0 | 0 | |
Liability | [1] | 14 | 14 |
Deferred credits and other liabilities | |||
Derivatives, Fair Value [Line Items] | |||
Asset | 0 | 0 | |
Liability | [1] | $ 54 | $ 52 |
[1] | Includes embedded derivatives. |
Derivatives - Open Commodity De
Derivatives - Open Commodity Derivative Contracts - Crude Oil (Details) - Crude Oil - Exchange Traded bbl in Thousands | 3 Months Ended | |
Jun. 30, 2018bbl | ||
Derivative [Line Items] | ||
Percentage of derivative contracts expiring in the period | 98.60% | |
Derivative contract expiration date | Sep. 30, 2017 | |
Long | ||
Derivative [Line Items] | ||
Notional contracts (in thousands of Total Barrels) | 31,732 | [1] |
Short | ||
Derivative [Line Items] | ||
Notional contracts (in thousands of Total Barrels) | 33,530 | [1] |
[1] | of the exchange-traded contracts expire in the third quarter of 2018. |
Derivatives - Open Commodity 89
Derivatives - Open Commodity Derivative Contracts - Refined Products (Detail) - Refined products - Exchange Traded gal in Thousands | 3 Months Ended | |
Jun. 30, 2018gal | ||
Derivative [Line Items] | ||
Percentage of derivative contracts expiring in the period | 92.50% | |
Derivative contract expiration date | Sep. 30, 2017 | |
Long | ||
Derivative [Line Items] | ||
Notional contracts (in thousands of Total Gallons) | 111,762 | [1] |
Short | ||
Derivative [Line Items] | ||
Notional contracts (in thousands of Total Gallons) | 228,396 | [1] |
[1] | of the exchange-traded contracts expire in the third quarter of 2018. |
Derivatives - Effect of Commodi
Derivatives - Effect of Commodity Derivative Instruments in Statements of Income (Detail) - Commodity derivatives - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2018 | Jun. 30, 2017 | Jun. 30, 2018 | Jun. 30, 2017 | |
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Gain (Loss) | $ (57) | $ (5) | $ (85) | $ (13) |
Sales and other operating revenues | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Gain (Loss) | (1) | 2 | (2) | 18 |
Cost of revenues | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Gain (Loss) | $ (56) | $ (7) | $ (83) | $ (31) |
Debt - Outstanding Borrowings (
Debt - Outstanding Borrowings (Detail) - USD ($) $ in Millions | 6 Months Ended | ||||
Jun. 30, 2018 | Feb. 08, 2018 | Dec. 31, 2017 | |||
Debt Instrument [Line Items] | |||||
Commercial paper | $ 0 | ||||
Total | 17,801 | $ 13,418 | |||
Unamortized debt issuance costs | (107) | (59) | |||
Unamortized discount | [1] | (427) | (413) | ||
Amounts due within one year | (26) | (624) | |||
Total long-term debt due after one year | 17,241 | 12,322 | |||
MPLX LP | |||||
Debt Instrument [Line Items] | |||||
Amounts due within one year | (1) | (1) | |||
Total long-term debt due after one year | 11,874 | 6,945 | |||
Senior Notes | MPLX LP | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 5,500 | ||||
Senior Notes | MarkWest | MPLX LP | |||||
Debt Instrument [Line Items] | |||||
Unamortized discount | (349) | (374) | |||
Trade receivables securitization facility due July 2019 | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | 0 | ||||
MPLX bank revolving credit facility due 2022 | Line of Credit | MPLX LP | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | 0 | ||||
MPLX senior notes, 3.375%, due March 2023 | Senior Notes | MPLX LP | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 500 | ||||
Debt instrument, interest rate | 3.375% | ||||
MPLX senior notes, 4.000%, due March 2028 | Senior Notes | MPLX LP | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 1,250 | ||||
Debt instrument, interest rate | 4.00% | ||||
MPLX senior notes, 4.500%, due April 2038 | Senior Notes | MPLX LP | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 1,750 | ||||
Debt instrument, interest rate | 4.50% | ||||
MPLX senior notes, 4.700%, due April 2048 | Senior Notes | MPLX LP | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 1,500 | ||||
Debt instrument, interest rate | 4.70% | ||||
MPLX senior notes, 4.900%, due April 2058 | Senior Notes | MPLX LP | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 500 | ||||
Debt instrument, interest rate | 4.90% | ||||
Marathon Petroleum Corporation | |||||
Debt Instrument [Line Items] | |||||
Commercial paper | 0 | 0 | |||
Marathon Petroleum Corporation | Capital Lease Obligations | |||||
Debt Instrument [Line Items] | |||||
Capital lease obligations | $ 344 | 356 | |||
Debt instrument maturity year, start | Jan. 1, 2018 | ||||
Debt instrument maturity year, end | Mar. 31, 2033 | ||||
Marathon Petroleum Corporation | 364-day bank revolving credit facility due July 2018 | Line of Credit | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 0 | [2] | 0 | ||
Line of credit facility, expiration date | Jul. 20, 2018 | ||||
Marathon Petroleum Corporation | Trade receivables securitization facility due July 2019 | Secured Debt | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 0 | 0 | |||
Line of credit facility, expiration date | Jul. 19, 2019 | ||||
Marathon Petroleum Corporation | Bank revolving credit facility due 2022 | Line of Credit | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 0 | 0 | |||
Line of credit facility, expiration date | Jul. 21, 2022 | ||||
Marathon Petroleum Corporation | Senior notes, 2.700% due December 2018 | Senior Notes | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 0 | 600 | |||
Debt instrument, maturity date | Dec. 14, 2018 | ||||
Debt instrument, interest rate | 2.70% | ||||
Marathon Petroleum Corporation | Senior notes, 3.400% due December 2020 | Senior Notes | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 650 | 650 | |||
Debt instrument, maturity date | Dec. 15, 2020 | ||||
Debt instrument, interest rate | 3.40% | ||||
Marathon Petroleum Corporation | Senior notes, 5.125% due March 2021 | Senior Notes | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 1,000 | 1,000 | |||
Debt instrument, maturity date | Mar. 1, 2021 | ||||
Debt instrument, interest rate | 5.125% | ||||
Marathon Petroleum Corporation | Senior notes, 3.625%, due September 2024 | Senior Notes | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 750 | 750 | |||
Debt instrument, maturity date | Sep. 15, 2024 | ||||
Debt instrument, interest rate | 3.625% | ||||
Marathon Petroleum Corporation | Senior notes, 6.500%, due March 2041 | Senior Notes | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 1,250 | 1,250 | |||
Debt instrument, maturity date | Mar. 1, 2041 | ||||
Debt instrument, interest rate | 6.50% | ||||
Marathon Petroleum Corporation | Senior notes, 4.750%, due September 2044 | Senior Notes | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 800 | 800 | |||
Debt instrument, maturity date | Sep. 15, 2044 | ||||
Debt instrument, interest rate | 4.75% | ||||
Marathon Petroleum Corporation | Senior notes, 5.850% due December 2045 | Senior Notes | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 250 | 250 | |||
Debt instrument, maturity date | Dec. 15, 2045 | ||||
Debt instrument, interest rate | 5.85% | ||||
Marathon Petroleum Corporation | Senior notes, 5.000%, due September 2054 | Senior Notes | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 400 | 400 | |||
Debt instrument, maturity date | Sep. 15, 2054 | ||||
Debt instrument, interest rate | 5.00% | ||||
MPLX LP | Senior Notes | MarkWest | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 63 | 63 | |||
MPLX LP | Capital Lease Obligations | |||||
Debt Instrument [Line Items] | |||||
Capital lease obligations | $ 7 | 7 | |||
Debt instrument maturity year, start | Jan. 1, 2018 | ||||
Debt instrument maturity year, end | Mar. 31, 2020 | ||||
MPLX LP | MPLX bank revolving credit facility due 2022 | Line of Credit | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 0 | 505 | |||
Line of credit facility, expiration date | Jul. 21, 2022 | ||||
MPLX LP | MPLX senior notes, 5.500%, due February 2023 | Senior Notes | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 710 | 710 | |||
Debt instrument, maturity date | Feb. 15, 2023 | ||||
Debt instrument, interest rate | 5.50% | ||||
MPLX LP | MPLX senior notes, 5.500%, due February 2023 | Senior Notes | MarkWest | |||||
Debt Instrument [Line Items] | |||||
Debt instrument, maturity date | Feb. 15, 2023 | ||||
Debt instrument, interest rate | 5.50% | ||||
MPLX LP | MPLX senior notes, 3.375%, due March 2023 | Senior Notes | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 500 | 0 | |||
Debt instrument, maturity date | Mar. 15, 2023 | ||||
Debt instrument, interest rate | 3.375% | ||||
MPLX LP | MPLX senior notes, 4.500%, due July 2023 | Senior Notes | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 989 | 989 | |||
Debt instrument, maturity date | Jul. 15, 2023 | ||||
Debt instrument, interest rate | 4.50% | ||||
MPLX LP | MPLX senior notes, 4.500%, due July 2023 | Senior Notes | MarkWest | |||||
Debt Instrument [Line Items] | |||||
Debt instrument, maturity date | Jul. 15, 2023 | ||||
Debt instrument, interest rate | 4.50% | ||||
MPLX LP | MPLX senior notes, 4.875%, due December 2024 | Senior Notes | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 1,149 | 1,149 | |||
Debt instrument, maturity date | Dec. 1, 2024 | ||||
Debt instrument, interest rate | 4.875% | ||||
MPLX LP | MPLX senior notes, 4.875%, due December 2024 | Senior Notes | MarkWest | |||||
Debt Instrument [Line Items] | |||||
Debt instrument, maturity date | Dec. 1, 2024 | ||||
Debt instrument, interest rate | 4.875% | ||||
MPLX LP | MPLX senior notes, 4.000%, due February 2025 | Senior Notes | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 500 | 500 | |||
Debt instrument, maturity date | Feb. 15, 2025 | ||||
Debt instrument, interest rate | 4.00% | ||||
MPLX LP | MPLX senior notes, 4.875%, due June 2025 | Senior Notes | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 1,189 | 1,189 | |||
Debt instrument, maturity date | Jun. 1, 2025 | ||||
Debt instrument, interest rate | 4.875% | ||||
MPLX LP | MPLX senior notes, 4.875%, due June 2025 | Senior Notes | MarkWest | |||||
Debt Instrument [Line Items] | |||||
Debt instrument, maturity date | Jun. 1, 2025 | ||||
Debt instrument, interest rate | 4.875% | ||||
MPLX LP | MPLX senior notes, 4.125%, due March 2027 | Senior Notes | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 1,250 | 1,250 | |||
Debt instrument, maturity date | Mar. 1, 2027 | ||||
Debt instrument, interest rate | 4.125% | ||||
MPLX LP | MPLX senior notes, 4.000%, due March 2028 | Senior Notes | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 1,250 | 0 | |||
Debt instrument, maturity date | Mar. 15, 2028 | ||||
Debt instrument, interest rate | 4.00% | ||||
MPLX LP | MPLX senior notes, 4.500%, due April 2038 | Senior Notes | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 1,750 | 0 | |||
Debt instrument, maturity date | Apr. 15, 2038 | ||||
Debt instrument, interest rate | 4.50% | ||||
MPLX LP | MPLX senior notes, 5.200%, due March 2047 | Senior Notes | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 1,000 | 1,000 | |||
Debt instrument, maturity date | Mar. 1, 2047 | ||||
Debt instrument, interest rate | 5.20% | ||||
MPLX LP | MPLX senior notes, 4.700%, due April 2048 | Senior Notes | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 1,500 | 0 | |||
Debt instrument, maturity date | Apr. 15, 2048 | ||||
Debt instrument, interest rate | 4.70% | ||||
MPLX LP | MPLX senior notes, 4.900%, due April 2058 | Senior Notes | |||||
Debt Instrument [Line Items] | |||||
Long-term debt, gross | $ 500 | $ 0 | |||
Debt instrument, maturity date | Apr. 15, 2058 | ||||
Debt instrument, interest rate | 4.90% | ||||
[1] | Includes $349 million and $374 million of unamortized discount as of June 30, 2018 and December 31, 2017, respectively, related to the difference between the fair value and the principal amount of assumed MarkWest debt. | ||||
[2] | The 364-day facility expired on July 20, 2018. |
Debt - Commercial Paper (Detail
Debt - Commercial Paper (Details) - USD ($) $ in Millions | 6 Months Ended | |
Jun. 30, 2018 | Jun. 30, 2017 | |
Debt Disclosure [Abstract] | ||
Commercial paper – issued | $ 0 | $ 300 |
Commercial paper - repayments | 0 | $ 300 |
Commercial paper, outstanding balance | $ 0 |
Debt - Trade Receivables Securi
Debt - Trade Receivables Securitization Facility (Details) - Trade receivables securitization facility due July 2019 $ in Millions | 6 Months Ended |
Jun. 30, 2018USD ($) | |
Debt Instrument [Line Items] | |
Borrowings | $ 0 |
Repayments | 0 |
Long-term debt, gross | $ 0 |
Debt - MPC Bank Revolving Credi
Debt - MPC Bank Revolving Credit Facilities (Details) - Marathon Petroleum Corporation - Bank revolving credit facility due 2022 - USD ($) $ in Millions | Jun. 30, 2018 | Dec. 31, 2017 |
Letter of Credit | ||
Debt Instrument [Line Items] | ||
Long-term line of credit | $ 0 | |
Line of Credit | ||
Debt Instrument [Line Items] | ||
Long-term debt, gross | $ 0 | $ 0 |
Debt - MPC Senior Notes (Detail
Debt - MPC Senior Notes (Details) - Senior notes, 2.700% due December 2018 $ in Millions | Mar. 15, 2018USD ($) |
Debt Instrument [Line Items] | |
Repayments of long-term debt | $ 600 |
Make whole premium | $ 2.5 |
Debt - MPLX Credit Agreement (D
Debt - MPLX Credit Agreement (Details) - MPLX LP - MPLX bank revolving credit facility due 2022 $ in Millions | 6 Months Ended |
Jun. 30, 2018USD ($) | |
Debt Instrument [Line Items] | |
Borrowings | $ 50 |
Interest rate during period | 3.00% |
Repayments | $ 555 |
Remaining borrowing capacity | 2,250 |
Letter of Credit | |
Debt Instrument [Line Items] | |
Long-term line of credit | 3 |
Line of Credit | |
Debt Instrument [Line Items] | |
Long-term debt, gross | $ 0 |
Debt - MPLX 364-Day Term Loan (
Debt - MPLX 364-Day Term Loan (Details) - MPLX LP - MPLX 364-day term loan - USD ($) $ in Billions | Feb. 08, 2018 | Feb. 01, 2018 | Jan. 02, 2018 |
Debt Instrument [Line Items] | |||
Maximum borrowing capacity | $ 4.1 | $ 4.1 | |
Debt instrument, term | 364 days | 364 days | |
Borrowings | $ 4.1 | ||
Repayments of short-term debt | $ 4.1 |
Debt - MPLX Senior Notes (Detai
Debt - MPLX Senior Notes (Details) - MPLX LP $ in Millions | Feb. 08, 2018USD ($) |
MPLX 364-day term loan | |
Debt Instrument [Line Items] | |
Repayments of short-term debt | $ 4,100 |
Senior Notes | |
Debt Instrument [Line Items] | |
Long-term debt, gross | 5,500 |
Senior Notes | MPLX senior notes, 3.375%, due March 2023 | |
Debt Instrument [Line Items] | |
Long-term debt, gross | $ 500 |
Debt instrument, interest rate | 3.375% |
Senior Notes | MPLX senior notes, 4.000%, due March 2028 | |
Debt Instrument [Line Items] | |
Long-term debt, gross | $ 1,250 |
Debt instrument, interest rate | 4.00% |
Senior Notes | MPLX senior notes, 4.500%, due April 2038 | |
Debt Instrument [Line Items] | |
Long-term debt, gross | $ 1,750 |
Debt instrument, interest rate | 4.50% |
Senior Notes | MPLX senior notes, 4.700%, due April 2048 | |
Debt Instrument [Line Items] | |
Long-term debt, gross | $ 1,500 |
Debt instrument, interest rate | 4.70% |
Senior Notes | MPLX senior notes, 4.900%, due April 2058 | |
Debt Instrument [Line Items] | |
Long-term debt, gross | $ 500 |
Debt instrument, interest rate | 4.90% |
Supplemental Cash Flow Inform99
Supplemental Cash Flow Information - Summary of Supplemental Cash Flow Information (Detail) - USD ($) $ in Millions | 6 Months Ended | ||
Jun. 30, 2018 | Jun. 30, 2017 | ||
Net cash provided by operating activities included: | |||
Interest paid (net of amounts capitalized) | $ 279 | $ 231 | |
Income taxes paid to taxing authorities | 40 | 198 | |
Non-cash investing and financing activities: | |||
Contribution of assets to joint venture | $ 0 | $ 337 | [1] |
[1] | MarkWest’s contribution of assets to Sherwood Midstream and Sherwood Midstream Holdings. See Note 5. |
Supplemental Cash Flow Infor100
Supplemental Cash Flow Information - Cash, Cash Equalivalents and Restricted Cash (Details) - USD ($) $ in Millions | Jun. 30, 2018 | Dec. 31, 2017 | Jun. 30, 2017 | Dec. 31, 2016 | |||
Supplemental Cash Flow Elements [Abstract] | |||||||
Cash and cash equivalents | $ 4,999 | $ 3,011 | |||||
Restricted cash | [1] | 5 | 4 | ||||
Cash, cash equivalents and restricted cash | $ 5,004 | [2] | $ 3,015 | [2] | $ 1,454 | $ 892 | |
[1] | The restricted cash balance is included within “Other current assets” on the consolidated balance sheets | ||||||
[2] | As a result of the adoption of ASU 2016-18, the consolidated statements of cash flows now explain the change during the period of both “Cash and cash equivalents” and “Restricted cash.” |
Supplemental Cash Flow Infor101
Supplemental Cash Flow Information - Reconciliation of Additions to Property, Plant and Equipment to Total Capital Expenditures (Detail) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||||
Jun. 30, 2018 | Jun. 30, 2017 | Jun. 30, 2018 | Jun. 30, 2017 | |||
Supplemental Cash Flow Elements [Abstract] | ||||||
Additions to property, plant and equipment per the consolidated statements of cash flows | $ 1,466 | $ 1,265 | ||||
Asset retirement expenditures | 5 | 1 | ||||
Increase (decrease) in capital accruals | 77 | (54) | ||||
Total capital expenditures before acquisitions | 1,548 | 1,212 | ||||
Acquisitions | 0 | 220 | [1] | |||
Capital expenditures | [2] | $ 841 | $ 673 | $ 1,548 | $ 1,432 | |
[1] | The six months ended June 30, 2017 reflects the acquisition of the Ozark pipeline. | |||||
[2] | Capital expenditures include changes in capital accruals. See Note 18 for a reconciliation of total capital expenditures to additions to property, plant and equipment as reported in the consolidated statements of cash flows.Revenues by product line were as follows: Three Months Ended June 30, Six Months Ended June 30,(In millions)2018 2017 2018 2017Refined products$19,292 $15,439 $35,450 $29,315Merchandise1,286 1,343 2,416 2,535Crude oil and refinery feedstocks978 824 1,861 1,511Midstream services, transportation and other562 427 1,085 806Sales and other operating revenues $22,118 $18,033 $40,812 $34,167 |
Accumulated Other Comprehens102
Accumulated Other Comprehensive Loss - Changes in Accumulated Other Comprehensive Loss by Component (Detail) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | |||
Jun. 30, 2018 | Jun. 30, 2017 | Jun. 30, 2018 | Jun. 30, 2017 | ||
Accumulated Other Comprehensive Income (Loss) [Line Items] | |||||
Beginning balance | $ (231) | $ (234) | |||
Other comprehensive loss before reclassifications | (1) | 1 | |||
Amortization - prior service cost (credit) | (18) | (21) | |||
Amortization - actuarial loss | 17 | 17 | |||
Amortization - settlement loss | 2 | 1 | |||
Amounts reclassified from accumulated other comprehensive loss: | |||||
Other | (2) | (1) | |||
Tax effect | 0 | 1 | |||
Other comprehensive income (loss) | $ 0 | $ 1 | (2) | (2) | |
Ending balance | (233) | (236) | (233) | (236) | |
Accumulated Defined Benefit Plans Adjustment | Pension Benefits | |||||
Accumulated Other Comprehensive Income (Loss) [Line Items] | |||||
Beginning balance | (190) | (233) | |||
Other comprehensive loss before reclassifications | 2 | 1 | |||
Amortization - prior service cost (credit) | [1] | (16) | (19) | ||
Amortization - actuarial loss | [1] | 17 | 18 | ||
Amortization - settlement loss | [1] | 2 | 1 | ||
Amounts reclassified from accumulated other comprehensive loss: | |||||
Tax effect | (1) | (1) | |||
Other comprehensive income (loss) | 4 | 0 | |||
Ending balance | (186) | (233) | (186) | (233) | |
Accumulated Defined Benefit Plans Adjustment | Other Benefits | |||||
Accumulated Other Comprehensive Income (Loss) [Line Items] | |||||
Beginning balance | (48) | (7) | |||
Other comprehensive loss before reclassifications | (1) | 0 | |||
Amortization - prior service cost (credit) | [1] | (2) | (2) | ||
Amortization - actuarial loss | [1] | 0 | (1) | ||
Amortization - settlement loss | 0 | 0 | |||
Amounts reclassified from accumulated other comprehensive loss: | |||||
Tax effect | 1 | 2 | |||
Other comprehensive income (loss) | (2) | (1) | |||
Ending balance | (50) | (8) | (50) | (8) | |
Gain on Cash Flow Hedge | |||||
Accumulated Other Comprehensive Income (Loss) [Line Items] | |||||
Beginning balance | 4 | 4 | |||
Other comprehensive loss before reclassifications | (2) | 0 | |||
Amounts reclassified from accumulated other comprehensive loss: | |||||
Tax effect | 0 | 0 | |||
Other comprehensive income (loss) | (2) | 0 | |||
Ending balance | 2 | 4 | 2 | 4 | |
Workers Compensation | |||||
Accumulated Other Comprehensive Income (Loss) [Line Items] | |||||
Beginning balance | 3 | 2 | |||
Other comprehensive loss before reclassifications | 0 | 0 | |||
Amounts reclassified from accumulated other comprehensive loss: | |||||
Other | (2) | (1) | |||
Tax effect | 0 | 0 | |||
Other comprehensive income (loss) | (2) | (1) | |||
Ending balance | $ 1 | $ 1 | $ 1 | $ 1 | |
[1] | These accumulated other comprehensive loss components are included in the computation of net periodic benefit cost. See Note 20. |
Defined Benefit Pension and 103
Defined Benefit Pension and Other Postretirement Plans - Components of Net Periodic Benefit Costs (Detail) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2018 | Jun. 30, 2017 | Jun. 30, 2018 | Jun. 30, 2017 | |
Pension Benefits | ||||
Components of net periodic benefit cost: | ||||
Service cost | $ 35 | $ 35 | $ 71 | $ 66 |
Interest cost | 18 | 18 | 36 | 37 |
Expected return on plan assets | (24) | (24) | (50) | (50) |
Amortization – prior service credit | (8) | (9) | (16) | (19) |
Amortization – actuarial loss (gain) | 8 | 9 | 17 | 18 |
Amortization - settlement loss | 1 | 1 | 2 | 1 |
Net periodic benefit cost | 30 | 30 | 60 | 53 |
Other Benefits | ||||
Components of net periodic benefit cost: | ||||
Service cost | 8 | 6 | 15 | 13 |
Interest cost | 8 | 7 | 15 | 15 |
Expected return on plan assets | 0 | 0 | 0 | 0 |
Amortization – prior service credit | (1) | (1) | (2) | (2) |
Amortization – actuarial loss (gain) | 0 | (1) | 0 | (1) |
Amortization - settlement loss | 0 | 0 | 0 | 0 |
Net periodic benefit cost | $ 15 | $ 11 | $ 28 | $ 25 |
Defined Benefit Pension and 104
Defined Benefit Pension and Other Postretirement Plans - Additional Information (Detail) $ in Millions | 6 Months Ended |
Jun. 30, 2018USD ($) | |
Pension Benefits | |
Defined Benefit Plan Disclosure [Line Items] | |
Employer contributions | $ 0 |
Other Pension Plan | |
Defined Benefit Plan Disclosure [Line Items] | |
Benefits paid | 7 |
Other Benefits | |
Defined Benefit Plan Disclosure [Line Items] | |
Benefits paid | $ 16 |
Stock-Based Compensation Pla105
Stock-Based Compensation Plans - Summary of Stock Option Award Activity (Detail) - Stock Options | 6 Months Ended |
Jun. 30, 2018$ / sharesshares | |
Number of Shares | |
Outstanding, beginning balance | shares | 8,465,398 |
Granted | shares | 903,797 |
Exercised | shares | (796,571) |
Forfeited or expired | shares | (11,219) |
Outstanding, ending balance | shares | 8,561,405 |
Weighted Average Exercise Price | |
Outstanding, beginning balance (in USD per share) | $ / shares | $ 33.74 |
Granted (in USD per share) | $ / shares | 67.71 |
Exercised (in USD per share) | $ / shares | 25.89 |
Forfeited or expired (in USD per share) | $ / shares | 51.67 |
Outstanding, ending balance (in USD per share) | $ / shares | $ 38.03 |
Stock-Based Compensation Pla106
Stock-Based Compensation Plans - Narrative (Detail) | 6 Months Ended |
Jun. 30, 2018$ / shares | |
Stock Options | |
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |
Grant date fair value (in USD per share) | $ 17.21 |
Performance Unit Awards | |
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |
Granted (in USD per share) | $ 0.83 |
Stock-Based Compensation Pla107
Stock-Based Compensation Plans - Summary of Restricted Stock Award Activity (Detail) | 6 Months Ended |
Jun. 30, 2018$ / sharesshares | |
Restricted Stock | |
Number of Shares | |
Outstanding, beginning balance | shares | 1,188,662 |
Granted | shares | 432,792 |
RS Vested/RSUs Issued | shares | (544,900) |
Forfeited | shares | (31,280) |
Outstanding, ending balance | shares | 1,045,274 |
Weighted Average Grant Date Fair Value | |
Outstanding, beginning balance (in USD per share) | $ / shares | $ 45.07 |
Granted (in USD per share) | $ / shares | 70.31 |
RS's Vested/RSU's Issued (in USD per share) | $ / shares | 44.83 |
Forfeited (in USD per share) | $ / shares | 47.13 |
Outstanding, ending balance (in USD per share) | $ / shares | $ 55.58 |
Restricted Stock Units | |
Number of Shares | |
Outstanding, beginning balance | shares | 285,164 |
Granted | shares | 14,019 |
RS Vested/RSUs Issued | shares | (1,829) |
Forfeited | shares | 0 |
Outstanding, ending balance | shares | 297,354 |
Weighted Average Grant Date Fair Value | |
Outstanding, beginning balance (in USD per share) | $ / shares | $ 29.95 |
Granted (in USD per share) | $ / shares | 70.54 |
RS's Vested/RSU's Issued (in USD per share) | $ / shares | 43.28 |
Forfeited (in USD per share) | $ / shares | 0 |
Outstanding, ending balance (in USD per share) | $ / shares | $ 31.78 |
Stock-Based Compensation Pla108
Stock-Based Compensation Plans - Summary of Performance Unit Awards (Detail) - Performance Unit Awards | 6 Months Ended |
Jun. 30, 2018$ / sharesshares | |
Number of Units | |
Outstanding, beginning balance | shares | 6,851,542 |
Granted | shares | 3,830,000 |
Vested | shares | (2,052,959) |
Forfeited | shares | (10,000) |
Outstanding, ending balance | shares | 8,618,583 |
Weighted Average Grant Date Fair Value | |
Outstanding, beginning balance (in USD per share) | $ / shares | $ 0.81 |
Granted (in USD per share) | $ / shares | 0.83 |
Vested (in USD per share) | $ / shares | 0.95 |
Forfeited (in USD per share) | $ / shares | 0.92 |
Outstanding, ending balance (in USD per share) | $ / shares | $ 0.79 |
Commitments and Contingencies (
Commitments and Contingencies (Detail) | 6 Months Ended |
Jun. 30, 2018 | |
Pending Litigation | |
Loss Contingencies [Line Items] | |
Loss contingency, inestimable loss | For matters for which we have not recorded a liability, we are unable to estimate a range of possible loss because the issues involved have not been fully developed through pleadings, discovery or court proceedings. |
Commitments and Contingencies -
Commitments and Contingencies - Environmental Matters (Details) - USD ($) $ in Millions | Jun. 30, 2018 | Dec. 31, 2017 |
Commitments and Contingencies Disclosure [Abstract] | ||
Accrued liabilities for remediation | $ 108 | $ 114 |
Receivables for recoverable costs | $ 48 | $ 45 |
Commitments and Contingencie111
Commitments and Contingencies - MarkWest Environmental Proceeding (Details) - MarkWest Liberty Midstream Pipeline Launcher/Receiver Site - USD ($) $ in Millions | 1 Months Ended | 6 Months Ended |
Apr. 30, 2018 | Jun. 30, 2018 | |
Cash | Pending Litigation | ||
Loss Contingencies [Line Items] | ||
Damages sought | $ 0.6 | |
Cash | Settled Litigation | ||
Loss Contingencies [Line Items] | ||
Damages sought | $ 0.6 | |
Other Liabilities | Pending Litigation | ||
Loss Contingencies [Line Items] | ||
Damages sought | $ 2.4 | |
Other Liabilities | Settled Litigation | ||
Loss Contingencies [Line Items] | ||
Damages sought | $ 2.4 |
Commitments and Contingencie112
Commitments and Contingencies - Other Lawsuits (Details) - Pending Litigation $ in Millions | 6 Months Ended |
Jun. 30, 2018USD ($) | |
Construction Work at MarkWest Processing and Fractionation Complexes | Minimum | |
Loss Contingencies [Line Items] | |
Damages sought | $ 40 |
Construction Work at MarkWest Processing and Fractionation Complexes | Minimum | MPLX LP | |
Loss Contingencies [Line Items] | |
Damages sought | $ 10 |
Emergency Pricing And Consumer Protection Laws | |
Loss Contingencies [Line Items] | |
Plaintiff | Commonwealth of Kentucky |
Damages sought | $ 89 |
Loss contingency, period of occurrence | during September and October 2005 |
Commitments and Contingencie113
Commitments and Contingencies - Guarantees (Details) $ in Millions | 6 Months Ended |
Jun. 30, 2018USD ($) | |
Other Guarantees | |
Loss Contingencies [Line Items] | |
Maximum potential undiscounted payments | $ 92 |
Guarantee obligations maximum exposure per event | $ 50 |
LOOP and LOCAP LLC | Guarantee of Indebtedness of Others | Financial Guarantee | |
Loss Contingencies [Line Items] | |
Line of credit facility, expiration date | Dec. 31, 2037 |
Maximum potential undiscounted payments | $ 160 |
Centennial | Guarantee of Indebtedness of Others | Financial Guarantee | |
Loss Contingencies [Line Items] | |
Maximum potential undiscounted payments | $ 23 |
Centennial | Master Shelf Agreement [Member] | Financial Guarantee | |
Loss Contingencies [Line Items] | |
Line of credit facility, expiration date | Dec. 31, 2024 |
Crowley Ocean Partners | |
Loss Contingencies [Line Items] | |
Equity method investments, ownership percentage | 50.00% |
Crowley Ocean Partners | Guarantee of Indebtedness of Others | Financial Guarantee | |
Loss Contingencies [Line Items] | |
Maximum potential undiscounted payments | $ 163 |
Crowley Ocean Partners | Guarantee of Indebtedness of Others | Financial Guarantee | Crowley Term Loan | |
Loss Contingencies [Line Items] | |
Maximum borrowing capacity | $ 325 |
Crowley Blue Water Partners | |
Loss Contingencies [Line Items] | |
Equity method investments, ownership percentage | 50.00% |
Crowley Blue Water Partners | Guarantee of Indebtedness of Others | Financial Guarantee | |
Loss Contingencies [Line Items] | |
Maximum potential undiscounted payments | $ 132 |
Marathon Oil Companies | Indemnification Agreement | |
Loss Contingencies [Line Items] | |
Guarantee obligation current carrying value | $ 2 |
Commitments and Contingencie114
Commitments and Contingencies - Contractual Commitments and Contingencies (Details) $ in Millions | 6 Months Ended |
Jun. 30, 2018USD ($) | |
Commitments and Contingencies Disclosure [Abstract] | |
Contractual commitments to acquire property, plant and equipment and advance funds to equity method investees | $ 901 |
Supplementary Statistics - Supp
Supplementary Statistics - Supplementary Statistics (Detail) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | |||||||
Jun. 30, 2018 | Jun. 30, 2017 | Jun. 30, 2018 | Jun. 30, 2017 | ||||||
Supplementary Statistics [Line Items] | |||||||||
Income from operations | $ 1,711 | $ 982 | $ 2,151 | $ 1,273 | |||||
Capital expenditures and investments | [1] | 918 | 784 | 1,666 | 2,109 | ||||
MarEn Bakken | |||||||||
Supplementary Statistics [Line Items] | |||||||||
Cash paid to acquire equity method investments | 500 | 500 | |||||||
Refining & Marketing | Refining Logistics & Fuels Distribution [Member] | |||||||||
Supplementary Statistics [Line Items] | |||||||||
Income from operations | (232) | (413) | |||||||
Midstream | Refining Logistics & Fuels Distribution [Member] | |||||||||
Supplementary Statistics [Line Items] | |||||||||
Income from operations | 232 | 413 | |||||||
Midstream | Ozark Pipeline | |||||||||
Supplementary Statistics [Line Items] | |||||||||
Capital expenditures and investments | 220 | 220 | |||||||
Operating Segments | |||||||||
Supplementary Statistics [Line Items] | |||||||||
Income from operations | 1,801 | 1,132 | 2,330 | 1,506 | |||||
Capital expenditures and investments | [2] | 885 | 752 | 1,597 | 2,049 | ||||
Cash paid to acquire equity method investments | 77 | 111 | [3] | 118 | 677 | [3] | |||
Operating Segments | Refining & Marketing | |||||||||
Supplementary Statistics [Line Items] | |||||||||
Income from operations | 1,025 | [4] | 562 | 892 | [4] | 492 | |||
Capital expenditures and investments | 196 | 180 | 387 | 372 | |||||
Operating Segments | Speedway | |||||||||
Supplementary Statistics [Line Items] | |||||||||
Income from operations | 159 | 238 | 254 | 373 | |||||
Capital expenditures and investments | 88 | 78 | 127 | 113 | |||||
Operating Segments | Midstream | |||||||||
Supplementary Statistics [Line Items] | |||||||||
Income from operations | 617 | [4] | 332 | 1,184 | [4] | 641 | |||
Capital expenditures and investments | 601 | 494 | 1,083 | 1,564 | [5] | ||||
Corporate and Other | |||||||||
Supplementary Statistics [Line Items] | |||||||||
Income from operations | [6] | (91) | (83) | (180) | (166) | ||||
Capital expenditures and investments | [7] | 33 | 32 | 69 | 60 | ||||
Capitalized interest | 16 | 14 | 34 | 26 | |||||
Segment Reconciling Items | |||||||||
Supplementary Statistics [Line Items] | |||||||||
Litigation | 0 | (86) | 0 | (86) | |||||
Impairments | [8] | $ 1 | $ 19 | $ 1 | $ 19 | ||||
[1] | Capital expenditures include changes in capital accruals, acquisitions and investments in affiliates. | ||||||||
[2] | Capital expenditures include changes in capital accruals, acquisitions and investments in affiliates. See reconciliation from segment totals to MPC total capital expenditures below. | ||||||||
[3] | The six months ended June 30, 2017 includes an investment of $500 million in MarEn Bakken related to the Bakken Pipeline system. | ||||||||
[4] | On February 1, 2018, we contributed certain refining logistics assets and fuels distributions services to MPLX. The results of these new businesses are reported in the Midstream segment prospectively from February 1, resulting in a net reduction of $232 million and $413 million to Refining & Marketing segment results and a net increase to Midstream segment results of the same amount for the three and six months ended June 30, 2018, respectively. No effect was given to prior periods as these entities were not considered businesses prior to February 1, 2018. | ||||||||
[5] | The Midstream segment includes $220 million for the acquisition of the Ozark pipeline and an investment of $500 million in MarEn Bakken related to the Bakken Pipeline system for the six months ended June 30, 2017. | ||||||||
[6] | Corporate and other unallocated items consists primarily of MPC’s corporate administrative expenses and costs related to certain non-operating assets, except for corporate overhead expenses attributable to MPLX, which are included in the Midstream segment. Corporate overhead expenses are not allocated to the Refining & Marketing and Speedway segments. | ||||||||
[7] | Includes capitalized interest of $16 million and $14 million for the three months ended June 30, 2018 and 2017, respectively, and $34 million and $26 million for the six months ended June 30, 2018 and 2017, respectively. | ||||||||
[8] | Includes MPC’s share of gains from the sale of assets remaining from the canceled Sandpiper pipeline project |
Supplementary Statistics - Oper
Supplementary Statistics - Operating Statistics (Detail) bbl / d in Thousands, gal in Millions, CFPD in Millions, $ in Millions | 3 Months Ended | 6 Months Ended | ||||
Jun. 30, 2018USD ($)bbl / dCFPDStore$ / bbl$ / galgal | Jun. 30, 2017USD ($)bbl / dCFPDStore$ / bbl$ / galgal | Jun. 30, 2018USD ($)bbl / dCFPDStore$ / bbl$ / galgal | Jun. 30, 2017USD ($)bbl / dCFPDStore$ / bbl$ / galgal | |||
Operating Statistics [Line Items ] | ||||||
MPC Consolidated Refined Product Sales Volumes (thousands of barrels per day) | [1] | 2,404 | 2,370 | 2,340 | 2,228 | |
Speedway Operating Statistics | ||||||
Sales and other operating revenues, including consumer excise taxes | $ | $ 18,033 | [2] | $ 34,167 | |||
Merchandise | ||||||
Speedway Operating Statistics | ||||||
Sales and other operating revenues, including consumer excise taxes | $ | $ 1,343 | $ 2,535 | ||||
Refining & Marketing | ||||||
Refining & Marketing Operating Statistics | ||||||
Refining & Marketing refined product sales volume (thousands of barrels per day) | [3] | 2,392 | 2,358 | 2,327 | 2,215 | |
Export sales volume (thousands of barrels per day) | 311 | 313 | 292 | 271 | ||
Refining & Marketing margin (dollars per barrel) | $ / bbl | [4] | 15.40 | 11.32 | 13.08 | 11.47 | |
Crude oil capacity utilization percent | [5] | 99.90% | 102.60% | 96.30% | 92.90% | |
Refinery throughputs (thousands of barrels per day) | [6] | 2,038 | 2,023 | 1,972 | 1,867 | |
Sour crude oil throughput percent | 55.00% | 62.00% | 53.00% | 64.00% | ||
WTI-priced crude oil throughput percent | 28.00% | 20.00% | 27.00% | 18.00% | ||
Refined product yields (thousands of barrels per day) | [6] | 2,078 | 2,060 | 2,008 | 1,905 | |
Inter-refinery transfers | 64 | 87 | 53 | 71 | ||
Refinery direct operating costs (dollars per barrel): | ||||||
Planned turnaround and major maintenance | $ / bbl | [7] | 0.98 | 1.01 | 1.58 | 1.96 | |
Depreciation and amortization | $ / bbl | [7] | 1.27 | 1.39 | 1.32 | 1.50 | |
Other manufacturing | $ / bbl | [7],[8] | 3.54 | 3.84 | 3.80 | 4.24 | |
Total | $ / bbl | [7] | 5.79 | 6.24 | 6.70 | 7.70 | |
Speedway Operating Statistics | ||||||
Sales and other operating revenues, including consumer excise taxes | $ | $ 12,691 | $ 23,912 | ||||
Refining & Marketing | Crude oil refined | ||||||
Refining & Marketing Operating Statistics | ||||||
Refinery throughputs (thousands of barrels per day) | [6] | 1,878 | 1,864 | 1,812 | 1,688 | |
Refining & Marketing | Other charge and blendstocks | ||||||
Refining & Marketing Operating Statistics | ||||||
Refinery throughputs (thousands of barrels per day) | [6] | 160 | 159 | 160 | 179 | |
Refining & Marketing | Gasoline | ||||||
Refining & Marketing Operating Statistics | ||||||
Refined product yields (thousands of barrels per day) | [6] | 970 | 922 | 943 | 895 | |
Refining & Marketing | Distillates | ||||||
Refining & Marketing Operating Statistics | ||||||
Refined product yields (thousands of barrels per day) | [6] | 691 | 665 | 651 | 605 | |
Refining & Marketing | Propane | ||||||
Refining & Marketing Operating Statistics | ||||||
Refined product yields (thousands of barrels per day) | [6] | 40 | 38 | 35 | 33 | |
Refining & Marketing | Feedstocks and special products | ||||||
Refining & Marketing Operating Statistics | ||||||
Refined product yields (thousands of barrels per day) | [6] | 278 | 331 | 283 | 277 | |
Refining & Marketing | Heavy fuel oil | ||||||
Refining & Marketing Operating Statistics | ||||||
Refined product yields (thousands of barrels per day) | [6] | 27 | 34 | 31 | 32 | |
Refining & Marketing | Asphalt | ||||||
Refining & Marketing Operating Statistics | ||||||
Refined product yields (thousands of barrels per day) | [6] | 72 | 70 | 65 | 63 | |
Refining & Marketing | Gulf Coast: | ||||||
Refining & Marketing Operating Statistics | ||||||
Refinery throughputs (thousands of barrels per day) | [9] | 1,346 | 1,365 | 1,285 | 1,219 | |
Sour crude oil throughput percent | 65.00% | 74.00% | 63.00% | 78.00% | ||
WTI-priced crude oil throughput percent | 16.00% | 12.00% | 15.00% | 8.00% | ||
Refined product yields (thousands of barrels per day) | [9] | 1,383 | 1,398 | 1,318 | 1,252 | |
Refinery direct operating costs (dollars per barrel): | ||||||
Planned turnaround and major maintenance | $ / bbl | [7] | 0.56 | 0.91 | 1.65 | 2.40 | |
Depreciation and amortization | $ / bbl | [7] | 0.99 | 1.10 | 1.04 | 1.21 | |
Other manufacturing | $ / bbl | [7],[8] | 3.21 | 3.45 | 3.54 | 3.96 | |
Total | $ / bbl | [7] | 4.76 | 5.46 | 6.23 | 7.57 | |
Refining & Marketing | Gulf Coast: | Crude oil refined | ||||||
Refining & Marketing Operating Statistics | ||||||
Refinery throughputs (thousands of barrels per day) | [9] | 1,156 | 1,147 | 1,106 | 999 | |
Refining & Marketing | Gulf Coast: | Other charge and blendstocks | ||||||
Refining & Marketing Operating Statistics | ||||||
Refinery throughputs (thousands of barrels per day) | [9] | 190 | 218 | 179 | 220 | |
Refining & Marketing | Gulf Coast: | Gasoline | ||||||
Refining & Marketing Operating Statistics | ||||||
Refined product yields (thousands of barrels per day) | [9] | 570 | 537 | 552 | 518 | |
Refining & Marketing | Gulf Coast: | Distillates | ||||||
Refining & Marketing Operating Statistics | ||||||
Refined product yields (thousands of barrels per day) | [9] | 458 | 432 | 410 | 371 | |
Refining & Marketing | Gulf Coast: | Propane | ||||||
Refining & Marketing Operating Statistics | ||||||
Refined product yields (thousands of barrels per day) | [9] | 26 | 27 | 22 | 24 | |
Refining & Marketing | Gulf Coast: | Feedstocks and special products | ||||||
Refining & Marketing Operating Statistics | ||||||
Refined product yields (thousands of barrels per day) | [9] | 290 | 360 | 294 | 302 | |
Refining & Marketing | Gulf Coast: | Heavy fuel oil | ||||||
Refining & Marketing Operating Statistics | ||||||
Refined product yields (thousands of barrels per day) | [9] | 16 | 23 | 20 | 20 | |
Refining & Marketing | Gulf Coast: | Asphalt | ||||||
Refining & Marketing Operating Statistics | ||||||
Refined product yields (thousands of barrels per day) | [9] | 23 | 19 | 20 | 17 | |
Refining & Marketing | Midwest: | ||||||
Refining & Marketing Operating Statistics | ||||||
Refinery throughputs (thousands of barrels per day) | [9] | 756 | 745 | 740 | 719 | |
Sour crude oil throughput percent | 39.00% | 42.00% | 38.00% | 43.00% | ||
WTI-priced crude oil throughput percent | 49.00% | 34.00% | 48.00% | 32.00% | ||
Refined product yields (thousands of barrels per day) | [9] | 759 | 749 | 743 | 724 | |
Refinery direct operating costs (dollars per barrel): | ||||||
Planned turnaround and major maintenance | $ / bbl | [7] | 1.65 | 1.06 | 1.33 | 1.02 | |
Depreciation and amortization | $ / bbl | [7] | 1.66 | 1.76 | 1.71 | 1.84 | |
Other manufacturing | $ / bbl | [7],[8] | 3.81 | 4.13 | 3.98 | 4.31 | |
Total | $ / bbl | [7] | 7.12 | 6.95 | 7.02 | 7.17 | |
Refining & Marketing | Midwest: | Crude oil refined | ||||||
Refining & Marketing Operating Statistics | ||||||
Refinery throughputs (thousands of barrels per day) | [9] | 722 | 717 | 706 | 689 | |
Refining & Marketing | Midwest: | Other charge and blendstocks | ||||||
Refining & Marketing Operating Statistics | ||||||
Refinery throughputs (thousands of barrels per day) | [9] | 34 | 28 | 34 | 30 | |
Refining & Marketing | Midwest: | Gasoline | ||||||
Refining & Marketing Operating Statistics | ||||||
Refined product yields (thousands of barrels per day) | [9] | 400 | 385 | 391 | 377 | |
Refining & Marketing | Midwest: | Distillates | ||||||
Refining & Marketing Operating Statistics | ||||||
Refined product yields (thousands of barrels per day) | [9] | 233 | 233 | 241 | 234 | |
Refining & Marketing | Midwest: | Propane | ||||||
Refining & Marketing Operating Statistics | ||||||
Refined product yields (thousands of barrels per day) | [9] | 14 | 12 | 13 | 10 | |
Refining & Marketing | Midwest: | Feedstocks and special products | ||||||
Refining & Marketing Operating Statistics | ||||||
Refined product yields (thousands of barrels per day) | [9] | 52 | 56 | 42 | 45 | |
Refining & Marketing | Midwest: | Heavy fuel oil | ||||||
Refining & Marketing Operating Statistics | ||||||
Refined product yields (thousands of barrels per day) | [9] | 11 | 12 | 11 | 12 | |
Refining & Marketing | Midwest: | Asphalt | ||||||
Refining & Marketing Operating Statistics | ||||||
Refined product yields (thousands of barrels per day) | [9] | 49 | 51 | 45 | 46 | |
Speedway | ||||||
Speedway Operating Statistics | ||||||
Convenience stores at period-end | Store | 2,744 | 2,729 | 2,744 | 2,729 | ||
Gasoline and distillate sales (millions of gallons) | gal | 1,450 | 1,475 | 2,843 | 2,868 | ||
Gasoline and distillate margin (dollars per gallon) | $ / gal | [10] | 0.1645 | 0.1835 | 0.1604 | 0.1704 | |
Sales and other operating revenues, including consumer excise taxes | $ | $ 4,794 | $ 9,175 | ||||
Merchandise margin (in millions) | $ | $ 366 | $ 371 | $ 685 | $ 691 | ||
Merchandise margin percent | 28.50% | 29.20% | 28.40% | 28.80% | ||
Same store gasoline sales volume (period over period) percentage | [11] | (2.60%) | (0.50%) | (2.10%) | (0.80%) | |
Merchandise sales excluding cigarettes (period over period) percentage | [12] | 2.90% | 2.10% | 2.60% | 2.10% | |
Speedway | Merchandise | ||||||
Speedway Operating Statistics | ||||||
Sales and other operating revenues, including consumer excise taxes | $ | $ 1,285 | $ 1,271 | $ 2,414 | $ 2,398 | ||
Midstream | ||||||
Speedway Operating Statistics | ||||||
Sales and other operating revenues, including consumer excise taxes | $ | $ 548 | $ 1,080 | ||||
Midstream Operating Statistics | ||||||
Crude oil and refined product pipeline throughputs (thousands of barrels per day) | [13] | 3,789 | 3,439 | 3,625 | 3,165 | |
Terminal throughput (thousands of barrels per day) | 1,485 | 1,489 | 1,465 | 1,456 | ||
Gathering system throughput (MMcf/d) | CFPD | [14] | 4,295 | 3,326 | 4,233 | 3,255 | |
Natural gas processed (MMcf/d) | CFPD | [14] | 6,850 | 6,292 | 6,740 | 6,212 | |
C2 and NGLs fractionated (thousands barrels per day) | [14] | 439 | 387 | 432 | 377 | |
[1] | Total average daily volumes of refined product sales to wholesale, branded and retail customers. | |||||
[2] | The 2018 period reflects an election to present certain taxes on a net basis. See Notes 2 and 3 for further information. | |||||
[3] | Includes intersegment sales. | |||||
[4] | Sales revenue less cost of refinery inputs and purchased products, divided by total refinery throughputs. | |||||
[5] | Based on calendar-day capacity, which is an annual average that includes down time for planned maintenance and other normal operating activities. | |||||
[6] | Excludes inter-refinery volumes of 64 mbpd and 87 mbpd for the three months ended June 30, 2018 and 2017, respectively, and 53 mbpd and 71 mbpd for the six months ended June 30, 2018 and 2017, respectively. | |||||
[7] | Per barrel of total refinery throughputs. Effective with the February 1, 2018 dropdown, direct operating costs related to certain refining logistics assets are now reported in the Midstream segment. No effect was given to prior periods as this entity was not considered a business prior to February 1, 2018. | |||||
[8] | Includes utilities, labor, routine maintenance and other operating costs. | |||||
[9] | Includes inter-refinery transfer volumes. | |||||
[10] | The price paid by consumers less the cost of refined products, including transportation, consumer excise taxes and bank card processing fees, divided by gasoline and distillate sales volume. | |||||
[11] | Same store comparison includes only locations owned at least 13 months. | |||||
[12] | Excludes cigarettes. | |||||
[13] | Includes common-carrier pipelines and private pipelines owned or operated by MPLX, excluding equity method investments. | |||||
[14] | Includes amounts related to unconsolidated equity method investments on a 100 percent basis. |