Andeavor Logistics (ANDX) 10-K 28 Feb 19 2018 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2018	Feb. 21, 2019	Jun. 30, 2018
Document and Entity Information [Abstract]
Entity Registrant Name	ANDEAVOR LOGISTICS LP
Entity Central Index Key	1,507,615
Document Type	10-K
Document Period End Date	Dec. 31, 2018
Amendment Flag	false
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	FY
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Shell Company	false
Entity Current Reporting Status	Yes
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Filer Category	Large Accelerated Filer
Entity Public Float			$ 3.8
Entity Common Stock, Shares Outstanding		245,551,332

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) shares in Millions, $ in Millions		12 Months Ended
		Dec. 31, 2018		Dec. 31, 2017		Dec. 31, 2016
Revenues	[1]	$ 2,380		$ 3,249		$ 1,669
Costs and Expenses
Operating expenses	[1]	885	[2]	691	[2]	560
General and Administrative Expense	[1]	121		158		106
Depreciation and amortization expenses	[3]	368		313		233	[4]
(Gain) loss on asset disposals and impairments	[1]	4		(25)		4	[3]
Operating Income	[1]	796		603		448
Interest and financing costs, net	[1]	(233)		(330)		(195)
Equity in earnings of equity method investments	[1]	31		22		13
Other Income, net	[1]	6		11		11
Net Earnings	[1],[4],[5]	600		306		277	[3]
Loss attributable to Predecessors		(28)		(43)		(62)
Net Earnings Attributable to Partners		628		349		339
Preferred unitholders’ interest in net earnings		(44)		(3)		0
Net Income (Loss) Allocated to General Partners		0		(79)		(152)
Limited partners’ interest in net earnings		$ 584		$ 267		$ 187
Net earnings per limited partner unit:
Common - basic (dollars per unit)	[6]	$ 2.57		$ 2.11		$ 1.87
Common - diluted (dollars per unit)	[6]	$ 2.57		$ 2.11		$ 1.87
Weighted average limited partner units outstanding:
Common units - basic (units)		228.7		126		98.2
Common units - diluted (units)	[7]	228.9		126.1		98.2
Cash distributions paid per unit		$ 4.0750		$ 3.8062		$ 3.3070
Oil and Gas, Purchased [Member]
Costs and Expenses
Cost of Goods and Services Sold	[1],[8]	$ 0		$ 1,244	[9],[10]	$ 316
Natural Gas, Midstream [Member]
Costs and Expenses
Cost of Goods and Services Sold	[1]	206		265	[10]	2
Affiliated Entity [Member]
Revenues		1,589		1,431		847
Affiliated Entity [Member] | Fee-Based Sales [Member]
Revenues	[1]	1,309		942		747
Affiliated Entity [Member] | Product-Based Sales [Member]
Revenues	[1],[8]	280		489		100
Third Party [Member] | Fee-Based Sales [Member]
Revenues	[1]	591		656		819
Third Party [Member] | Product-Based Sales [Member]
Revenues	[1],[8]	$ 200		$ 1,162		$ 3
[1]	All periods include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[2]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[3]	All periods include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[4]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[5]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[6]	Amounts may not recalculate due to rounding of dollar and unit information.
[7]	Diluted net earnings per unit include the effects of potentially dilutive units on our common units, which consist of unvested service and performance phantom units.
[8]	Due to the adoption of ASC 606 effective January 1, 2018, the revenues and costs associated with our fuel purchase and supply arrangements for year ended December 31, 2018 were netted. See Note 1 for further discussion.
[9]	Due to the adoption of ASC 606 effective January 1, 2018, the revenues and costs associated with our fuel purchase and supply arrangements for the year ended December 31, 2018 were netted. See Note 1 for further discussion.
[10]	Excludes direct operating expenses incurred across our operating segments and depreciation and amortization expenses.

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Current Assets
Cash and cash equivalents	$ 10	$ 75	[1]
Receivables, net of allowance for doubtful accounts
Trade and other	195	219	[1]
Affiliate	279	264	[1]
Prepayments and other current assets	79	27	[1]
Total Current Assets	563	585	[1]
Property, Plant and Equipment, Net	6,845	6,249	[1],[2]
Acquired Intangibles, Net	1,104	1,154	[1]
Goodwill	1,051	956	[1]
Equity Method Investments	602	440	[1]
Other Noncurrent Assets, Net	130	121	[1]
Total Assets	10,295	9,505	[1],[3]
Accounts payable
Trade and other	214	186	[1]
Affiliate	252	207	[1]
Accrued interest and financing costs	41	40	[1]
Current maturities of debt	504	1
Other current liabilities	81	84	[1]
Total Current Liabilities	1,092	518	[1]
Debt, Net of Unamortized Issuance Costs	4,460	4,127	[1]
Other Noncurrent Liabilities	69	54	[1]
Total Liabilities	5,621	4,699	[1]
Commitments and Contingencies			[1]
Equity
Equity of Predecessors	0	1,292	[1]
Preferred unitholders: 600,000 units issued and outstanding in 2018 and 2017	604	589	[1]
Common unitholders: 245,493,184 units issued and outstanding (217,097,057 in 2017)	4,070	2,925	[1]
Total Equity	4,674	4,806	[1]
Total Liabilities and Equity	$ 10,295	$ 9,505	[1]
[1]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[2]	Property, plant and equipment transferred to the Partnership in the 2018 Drop Down was recorded at historical costs. The Partnership recorded property, plant and equipment of $948 million and accumulated depreciation of $112 million as of December 31, 2017 in connection with the 2018 Drop Down.
[3]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

Combined Consolidated Balance S

Combined Consolidated Balance Sheets (Parenthetical) - shares	Dec. 31, 2018	Dec. 31, 2017
Statement of Financial Position [Abstract]
Limited Partners' Capital Account, Units Outstanding	245,493,184	217,097,057
Preferred Units, Outstanding	600,000	600,000

Consolidated Statements of Part

Consolidated Statements of Partners' Equity - USD ($) $ in Millions		Total		Equity of Predecessors		Common	Preferred	General Partner	Non-controlling Interest
Balance at Beginning of Period, Partnership at Dec. 31, 2015		$ 2,242		$ 464	[1]	$ 1,707	$ 0	$ (13)	$ 84
Partners' Capital
Sponsor contributions of equity to the Predecessors		515		515	[1]	0	0	0	0
Loss attributable to Predecessors		(62)		(62)	[1]	0	0	0	0
Net liabilities not assumed by Andeavor Logistics LP		(22)		(22)	[1]	0	0	0	0
Allocation of net assets acquired by the unitholders		0		(322)	[1]	310	0	12	0
Equity offering under ATM Program, net of issuance costs		71		0	[1]	71	0	0	0
Proceeds from issuance of units, net of issuance costs		293		0	[1]	293	0	0	0
Quarterly distributions to unitholders and general partner		(461)		0	[1]	(324)	0	(137)	0
Distributions to unitholders related to acquisitions		(765)		0	[1]	(679)	0	(86)	0
Contributions		42		0	[1]	39	0	3	0
Net Earnings Attributable to Partners		339		0	[1]	187	0	152	0
Partners' Capital Account, Exchanges and Conversions		(84)		0	[1]	0	0	0	(84)
Other		7		0	[1]	4	0	3	0
Balance at End of Period, Partnership at Dec. 31, 2016		2,159		617	[1]	1,608	0	(66)	0
Partners' Capital
Sponsor contributions of equity to the Predecessors		2,464		2,464	[1]	0	0	0	0
Loss attributable to Predecessors		(43)		(43)	[1]	0	0	0	0
Net liabilities not assumed by Andeavor Logistics LP		0
Allocation of net assets acquired by the unitholders		0		(1,713)	[1]	1,713	0	0	0
Proceeds from issuance of units, net of issuance costs		879		0	[1]	284	589	6	0
Partners' Capital Account, Unit-based Compensation	[1]	5		0		5	0	0	0
Quarterly distributions to unitholders and general partner		(661)		(33)	[1]	(501)	0	(127)	0
Distributions to unitholders related to acquisitions		(401)		0	[1]	(401)	0	0	0
Contributions		53		0	[1]	50	0	3	0
Net Earnings Attributable to Partners		349		0	[1]	229	0	120	0
Partners' Capital Account, Exchanges and Conversions		0		0	[1]	(60)	0	60	0
Other		2		0	[1]	(2)	0	4	0
Balance at End of Period, Partnership at Dec. 31, 2017		4,806	[2]	1,292	[1]	2,925	589	0	0
Partners' Capital
Sponsor contributions of equity to the Predecessors		374		374	[1]	0	0	0	0
Loss attributable to Predecessors		(28)		(28)	[1]	0	0	0	0
Net liabilities not assumed by Andeavor Logistics LP		(13)		(13)	[1]	0	0	0	0
Allocation of net assets acquired by the unitholders		0		(1,651)	[1]	1,651	0	0	0
Partners' Capital Account, Unit-based Compensation		9		0	[1]	9	0	0	0
Quarterly distributions to unitholders and general partner		(888)		0	[1]	(859)	(29)	0	0
Distributions to unitholders related to acquisitions		(300)		0	[1]	(300)	0	0	0
Contributions		81		0	[1]	81	0	0	0
Net Earnings Attributable to Partners		628		0	[1]	584	44	0	0
Partners' Capital Account, Exchanges and Conversions		(17)		0	[1]	(17)	0	0	0
Other		(4)		0	[1]	(4)	0	0	0
Balance at End of Period, Partnership at Dec. 31, 2018		$ 4,674		$ 0	[1]	$ 4,070	$ 604	$ 0	$ 0
[1]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[2]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018		Dec. 31, 2017		Dec. 31, 2016
Cash Flows From (Used In) Operating Activities:
Net earnings	[1],[2],[3]	$ 600		$ 306		$ 277	[4]
Adjustments to reconcile net earnings to net cash from operating activities:
Depreciation and amortization expenses	[4]	368		313		233	[2]
Amortization of debt issuance costs	[4]	10		10		9
Debt redemption charges	[4]	0		77		0
(Gain) loss on asset disposals and impairments	[3]	4		(25)		4	[4]
Unit-based compensation expense	[4]	9		9		6
Distributions received in excess of equity in earnings of equity method investments	[4]	21		17		16
Other non-cash operating activities		0		(6)		1	[4]
Changes in receivables	[4]	(17)		24		(172)
Changes in other current assets	[4]	(39)		1		(6)
Changes in current liabilities	[4]	104		3		81
Changes in other noncurrent assets and liabilities		(31)		(42)		(7)	[4]
Net cash from operating activities		1,029		687		442	[4]
Cash Flows From (Used In) Investing Activities:
Capital expenditures		(770)		(349)		(298)	[4]
Acquisitions, net of cash acquired		(379)		(1,231)		(332)	[4]
Proceeds from sale of assets		0		47		0	[4]
Deposits for acquisitions	[4]	0		0		(33)
Other investing activities	[4]	0		0		5
Net cash used in investing activities		(1,149)		(1,533)		(658)	[4]
Cash Flows From (Used In) Financing Activities:
Proceeds from debt offering	[4]	0		1,750		1,451
Proceeds from issuance of common units, net of issuance costs		0		284		364	[4]
Proceeds from issuance of preferred units, net of issuance costs	[4]	0		589		0
Proceeds from issuance of general partner units, net of issuance costs		0		6		0	[4]
Quarterly distributions to common unitholders		(859)		(530)		(324)	[4]
Distributions to preferred unitholders		(29)		0		0	[4]
Quarterly distributions to general partner		0		(131)		(137)	[4]
Distributions in connection with acquisitions from our Sponsor		(300)		(406)		(760)	[4]
Borrowings under revolving credit agreement		1,320		1,225		1,451	[4]
Repayments under revolving credit agreement		(498)		(1,152)		(1,426)	[4]
Repayments of Long-term Debt including capital leases	[4]	(1)		(2,070)		(251)
Premiums paid on debt redemption	[4]	0		(85)		0
Sponsor contributions of equity to the Predecessors		374		742		515
Financing costs	[4]	0		0		(7)
Payments of Debt Issuance Costs	[4]	0		(22)		(21)
Contributions from general partner	[4]	0		0		4
Capital Contributions by affiliate	[4]	51		34		29
Other Financing Activities		(3)		(1)		0	[4]
Net cash from (used in) financing activities		55		233		888	[4]
Increase (Decrease) in Cash and Cash Equivalents		(65)		(613)		672	[4]
Cash and Cash Equivalents, Beginning of Year		75	[5]	688	[4]	16	[4]
Cash and Cash Equivalents, End of Year		$ 10		$ 75	[5]	$ 688	[4]
[1]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[2]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[3]	All periods include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[4]	All periods include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[5]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

Organization and Basis of Prese

Organization and Basis of Presentation	12 Months Ended
	Dec. 31, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and Basis of Presentation	Note 1 - Organization and Basis of Presentation Description and Nature of Business Andeavor Logistics LP (“Andeavor Logistics” or the “Partnership”) is a growth-oriented Delaware limited partnership formed in December 2010 by Andeavor and its wholly-owned subsidiary, TLGP, our general partner, to own, operate, develop and acquire logistics and related assets and businesses. Unless the context otherwise requires, references in this report to “we,” “us,” “our,” or “ours” refer to Andeavor Logistics LP, one or more of its consolidated subsidiaries or all of them taken as a whole. Unless the context otherwise requires, references in this report to “Andeavor” or our “Sponsor” refer collectively to Andeavor for all activity through September 30, 2018, or Andeavor LLC, successor-by-merger to Andeavor effective October 1, 2018 and a wholly owned subsidiary of Marathon Petroleum Corporation, and any of Andeavor’s or Andeavor LLC’s subsidiaries, as applicable, other than Andeavor Logistics, its subsidiaries and its general partner. References in this report to “Marathon” or “MPC” refer to Marathon Petroleum Corporation, one or more of its consolidated subsidiaries, including Andeavor LLC, or all of them taken as a whole. Our logistics assets are integral to the success of Marathon’s refining and marketing operations and are used to gather crude oil and to distribute, transport and store crude oil and refined products. We are a full service logistics company operating primarily in the western and mid-continent regions of the United States. We own and operate a network of crude oil, refined products and natural gas pipelines as well as operate crude oil and refined products truck and marine terminals and provide crude oil and refined product storage capacity. In addition, we own and operate bulk petroleum distribution facilities and natural gas processing and fractionation complexes. Our assets are categorized into the following segments: Terminalling and Transportation, Gathering and Processing, and Wholesale. See Note 14 for additional information regarding our segments. We generate revenues by charging fees for terminalling, transporting and storing crude oil and refined products, gathering crude oil and produced water, gathering and processing natural gas and selling fuel through wholesale commercial contracts. We are generally not directly exposed to commodity price risk with respect to any of the crude oil, natural gas, NGLs or refined products that we handle as part of our normal operations. However, we may be subject to limited commodity risk exposure due to pipeline loss allowance provisions in many of our pipeline gathering and transportation contracts and a nominal amount of condensate retained as part of our natural gas gathering services. For the NGLs that we handle under keep-whole agreements, the Partnership has a fee-based processing agreement with our Sponsor, which minimizes the impact of commodity price movement during the annual period subsequent to renegotiation of terms and pricing each year. We do not engage in the trading of crude oil, natural gas, NGLs or refined products; therefore we have minimal direct exposure to risks associated with commodity price fluctuations. However, these risks indirectly influence our activities and results of operations over the long-term through their effects on our customers’ operations. As part of the WNRL Merger, we acquired a wholesale fuel business that has exposure to commodity prices while the refined product is being transported but is mitigated by fixed margin contracts. In the years ended December 31, 2018 , 2017 and 2016 , 67% , 44% and 51% of our revenue, respectively, was derived from our Sponsor under various long-term, fee-based commercial agreements, the majority of which include minimum volume commitments, and from wholesale fuel sales to our Sponsor. QEP Resources accounted for 13% of our total revenues in the year ended December 31, 2016 . No single customer, other than our Sponsor, accounted for more than 10% of our total revenues for the years ended December 31, 2018 and 2017 . Our Terminalling and Transportation segment consists of the Northwest Pipeline System, which includes a regulated common carrier products pipeline running from Salt Lake City, Utah to Spokane, Washington and a jet fuel pipeline to the Salt Lake City International Airport; a regulated common carrier refined products pipeline system connecting Marathon’s Kenai refinery to our terminals in Anchorage, Alaska; tankage and related equipment at Marathon’s Kenai refinery; crude oil and refined products terminals and storage facilities in the western, southwest and midwestern U.S.; and storage facilities located at Marathon’s refineries. It also consists of marine terminals in California and in Washington; asphalt terminalling and processing services at our asphalt plant and terminal in El Paso, stand-alone asphalt terminals in the southwest as well as a 50% interest in PNAC. The segment also includes a rail-car unloading facility in Washington; a manifest rail facility in Washington; an asphalt trucking operation and a petroleum coke handling and storage facility in Los Angeles; and other pipelines that transport products and crude oil from Marathon’s refineries to nearby facilities in Salt Lake City and Los Angeles. Our Gathering and Processing segment includes crude oil, natural gas, NGLs and produced water gathering systems in the Bakken Shale/Williston Basin area of the Bakken Region, the Green River Basin, the Rockies Region, the Permian Basin System and the Four Corners System. It also consists of the Great Northern Midstream and Fryburg pipelines, crude trucking operations and gas processing and fractionation complexes. Our Wholesale segment includes the operations of several bulk petroleum distribution plants and a fleet of refined product delivery trucks that distribute commercial wholesale petroleum products primarily in Arizona, Colorado, Nevada, New Mexico and Texas. The refined product trucking business delivers a significant portion of the volumes sold by our Wholesale segment. Principles of Consolidation and Basis of Presentation The accompanying consolidated financial statements include the accounts of Andeavor Logistics and its subsidiaries. All intercompany accounts and transactions have been eliminated. We have evaluated subsequent events through the filing of this Form 10-K. Any material subsequent events that occurred during this time have been properly recognized or disclosed in our financial statements. We have not reported comprehensive income due to the absence of items of other comprehensive income in the years presented. In 2018 , 2017 and 2016 , we entered into various transactions with our Sponsor and our general partner, TLGP, pursuant to which we acquired from our Sponsor the following: • gathering, storage and transportation assets in the Permian Basin; legacy Western Refining assets and associated crude terminals; the majority of our Sponsor’s remaining refining terminalling, transportation and storage assets; and equity method investments in ALRP, MPL and PNAC on August 6, 2018. In addition, the Conan Crude Oil Gathering System and LARIP were transferred at cost plus incurred interest; • crude oil, feedstock and refined products storage, the Anacortes marine terminal, a manifest rail facility and crude oil and refined products pipelines located in Anacortes, Washington on November 8, 2017; • logistic assets owned by WNRL, which consisted of pipelines, gathering, terminalling, storage, transportation and wholesale fuel distribution assets effective October 30, 2017; • tankage, refined product storage, marine terminal terminalling and storage assets, pipelines, causeway and ancillary equipment located in Martinez, California (the “Northern California Terminalling and Storage Assets”) effective November 21, 2016 ; and • all of the limited liability company interests in Tesoro Alaska Terminals, LLC, tankage, bulk tank farm, a truck rack and rail-loading facility, terminalling and other storage assets located in Kenai, Anchorage and Fairbanks, Alaska (the “Alaska Storage and Terminalling Assets”) completed in two stages on July 1, 2016 and September 16, 2016. These transactions are collectively referred to as “Acquisitions from our Sponsor” and the related assets, liabilities and results of the operations are collectively referred to as the “Predecessors.” The Acquisitions from our Sponsor were transfers between entities under common control. As an entity under common control with our Sponsor, we record the assets that we acquired from our Sponsor on our consolidated balance sheet at our Sponsor’s historical basis instead of fair value. Transfers of businesses between entities under common control are accounted for as if the transfer occurred at the beginning of the period, and prior periods are retrospectively adjusted to furnish comparative information. Accordingly, the accompanying financial statements and related notes of Andeavor Logistics have been retrospectively adjusted to include the historical results of the assets acquired in the Acquisitions from our Sponsor prior to the effective date of each acquisition. The acquisition of logistics assets located in Anacortes, Washington in 2017 was immaterial to our consolidated financial statements. While this acquisition is a common control transaction, prior periods have not been retrospectively adjusted as these assets do not constitute a business in accordance with ASU 2017-01, “Clarifying the Definition of a Business”. See Note 2 for additional information regarding the 2018 , 2017 and 2016 acquisitions. The accompanying financial statements and related notes present the combined financial position, results of operations, cash flows and equity of our Predecessors at historical cost. The financial statements of our Predecessors have been prepared from the separate records maintained by our Sponsor and may not necessarily be indicative of the conditions that would have existed or the results of operations if our Predecessors had been operated as an unaffiliated entity. Other than WNRL and certain assets acquired from the 2018 Drop Down, our Predecessors did not record revenue for transactions with our Sponsor. Accordingly, the revenues in our Predecessors’ historical combined financial statements relate only to amounts received from third parties for these services. Use of Estimates We prepare our consolidated financial statements in conformity with accounting principles generally accepted in the United States of America, which requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and revenues and expenses reported and presented as of and for the periods ended. We review our estimates on an ongoing basis using currently available information. Changes in facts and circumstances may result in revised estimates and actual results could differ from those estimates. Cash and Cash Equivalents Cash and cash equivalents include bank deposits and low-risk, short-term investments with original maturities of three months or less at the time of purchase. Cash equivalents are stated at cost, which approximates market value. We place our cash deposits and temporary cash investments with high credit quality financial institutions. At times, our cash and cash equivalents may be uninsured or in deposit accounts that exceed the Federal Deposit Insurance Corporation insurance limit. We had no cash and cash equivalents held in money market funds. Receivables A portion of the Partnership’s accounts receivable is due from our Affiliates. Credit for non-affiliated customers is extended based on an evaluation of each customer’s financial condition and in certain circumstances, collateral, such as letters of credit or guarantees, is required. Our allowance for doubtful accounts is based on various factors including current sales amounts, historical charge-offs and specific accounts identified as high risk. After reasonable efforts to collect the amounts have been exhausted, balances are deemed uncollectible and are charged against the allowance for doubtful accounts. Write-offs were immaterial in 2018 , 2017 and 2016 . We do not have any off-balance-sheet credit exposure related to our customers. Property, Plant and Equipment Property, plant and equipment are stated at the lower of historical cost less accumulated depreciation or fair value, if impaired. We capitalize all construction-related direct labor and material costs, as well as indirect construction costs. Indirect construction costs include general engineering and other allocated employee costs. Costs, including complete asset replacements and enhancements or upgrades that increase the original efficiency, productivity or capacity of property, plant and equipment, are also capitalized. The costs of repairs, minor replacements and maintenance projects that do not increase the original efficiency, productivity or capacity of property, plant and equipment are expensed as incurred. We capitalize interest as part of the cost of major projects during the construction period. Capitalized interest totaled $13 million , $8 million and $6 million for 2018 , 2017 and 2016 , respectively, and is recorded as a reduction to net interest and financing costs in our consolidated statements of operations. We compute depreciation of property, plant and equipment using the straight-line method, based on the estimated useful life and salvage value of each asset. When assets are placed into service, we make estimates with respect to their useful lives that we believe are reasonable. However, factors such as maintenance levels, economic conditions impacting the demand for these assets and regulatory or environmental requirements could cause us to change our estimates, thus impacting the future calculation of depreciation. We depreciate leasehold improvements and property acquired under capital leases over the lesser of the lease term or the economic life of the asset. Depreciation expense totaled $310 million , $262 million and $202 million for 2018 , 2017 and 2016 , respectively. When items of property, plant and equipment are sold or otherwise disposed of, any gains or losses are reported in net income. Gains on the disposal of property, plant and equipment are recognized when earned, which is generally at the time of closing. If a loss on disposal is expected, such losses are recognized when the assets are classified as held for sale. Asset Retirement Obligations We record AROs at fair value in the period in which we have a legal obligation to incur costs, whether by government action or contractual arrangement, to retire a tangible asset and can make a reasonable estimate of the fair value of the liability. AROs are calculated based on the present value of the estimated removal and other closure costs using our credit-adjusted risk-free rate given an estimated settlement date for the obligation. We estimate settlement dates by considering our past practice, industry practice, management’s intent and estimated economic lives. We cannot currently estimate the fair value for certain potential AROs primarily because we cannot estimate settlement dates (or range of dates) associated with these assets. These AROs include, but are not limited to, the removal or dismantlement of terminal facilities, pipelines and other buildings. AROs included in our consolidated balance sheets were $10 million and $11 million at December 31, 2018 and 2017 , respectively. Acquired Intangibles and Goodwill Acquired intangibles are recorded at fair value as of the date acquired and consist of customer relationships obtained in connection with the acquisitions of WNRL, the North Dakota Gathering and Processing Assets, and Andeavor Field Services, LLC, (the “Rockies Natural Gas Business Acquisition”). The value for the identified customer relationships consists of cash flow expected from existing contracts and future arrangements from the existing customer base. We amortize acquired intangibles with finite lives on a straight-line basis over an estimated weighted average useful life of 31 years and we include the amortization in depreciation and amortization expenses on our consolidated statements of operations. Goodwill represents the amount the purchase price exceeds the fair value of net assets acquired in a business combination. We do not amortize goodwill or indefinite-lived intangible assets. The goodwill recorded for the acquisition of WNRL represents goodwill recognized by our Sponsor. Goodwill represents future organic growth opportunities, anticipated synergies and intangible assets that did not qualify for separate recognition. We are required, however, to review goodwill and indefinite-lived intangible assets for impairment annually, or more frequently if events or changes in business circumstances indicate that the asset might be impaired. In such circumstances, we record the impairment in loss on asset disposals and impairments in our consolidated statements of operations. We review the recorded value of goodwill for impairment on November 1 st of each year, or sooner if events or changes in circumstances indicate the carrying amount may exceed fair value using qualitative and/or quantitative assessments at the reporting level. There were no impairments of goodwill during the years ended December 31, 2018 , 2017 and 2016 . Impairment of Long-Lived Assets We review property, plant and equipment and other long-lived assets, including acquired intangibles with finite lives, for impairment whenever events or changes in business circumstances indicate the net book values of the assets may not be recoverable. Impairment is indicated when the undiscounted cash flows estimated to be generated by those assets are less than the assets’ net book value. If this occurs, an impairment loss is recognized for the difference between the asset fair value and net book value. Factors that indicate potential impairment include: a significant decrease in the market value of the asset, operating or cash flow losses associated with the use of the asset and a significant change in the asset’s physical condition or use. Equity Method Investments and Joint Ventures For equity investments that are not required to be consolidated under the variable interest model, we evaluate the level of influence we are able to exercise over an entity’s operations to determine whether to use the equity method of accounting. We use equity method of accounting when we are able to have significant influence over an entity’s operations. Our judgment regarding the level of control over an equity method investment includes considering key factors such as our ownership interest, participation in policy-making and other significant decisions and material intercompany transactions. Amounts recognized for equity method investments are included in other noncurrent assets in our consolidated balance sheets and adjusted for our share of the net earnings or losses of the investee, which are presented separately in our statements of consolidated operations, capital contributions made and cash dividends received. We evaluate our equity method investments for impairment whenever events or changes in circumstances indicate that the carrying amounts of such investments may be impaired. An impairment loss is recorded in earnings in the current period to write down the carrying value of the investment to fair value if a decline in the value of an equity method investment is determined to be other than temporary. There were no impairments of our equity method investments during the years ended December 31, 2018 , 2017 and 2016 . Financial Instruments Financial instruments including cash and cash equivalents, receivables, accounts payable and accrued liabilities are recorded at their carrying value. We believe the carrying value of these financial instruments approximates fair value. Our fair value assessment incorporates a variety of considerations, including the short-term duration of the instruments and the expected future insignificance of bad debt expense, which includes an evaluation of counterparty credit risk. The fair value of our senior notes is based on prices from recent trade activity and is categorized in level 2 of the fair value hierarchy. The carrying value and fair value of our debt were $5.0 billion and $4.9 billion at December 31, 2018 , respectively, and were $4.2 billion and $4.3 billion at December 31, 2017 , respectively. These carrying and fair values of our debt do not consider the unamortized issuance costs, which are netted against our total debt. Income Taxes We are a limited partnership and, with the exception of three of our subsidiaries, are not subject to federal or state income taxes. Our taxable income or loss is included in the federal and state income tax returns of our partners. Taxable income may vary substantially from income or loss reported for financial reporting purposes due to differences in the tax bases and financial reporting bases of assets and liabilities, and due to certain taxable income allocation requirements of the partnership agreement. We are unable to readily determine the net difference in the bases of our assets and liabilities for financial and tax reporting purposes because individual unitholders have different investment bases depending upon the timing and price of acquisition of their partnership units. Contingencies Environmental Matters We are subject to federal, state and local laws and regulations governing environmental quality and pollution control. These laws and regulations require us to remove or remedy the effect of the disposal or release of specified substances at current and former operating sites. Our environmental liabilities are estimates using internal and third-party assessments and available information to date. It is possible these estimates will change as additional information becomes available. We capitalize environmental expenditures that extend the life or increase the capacity of facilities as well as expenditures that prevent environmental contamination. We expense costs that relate to an existing condition caused by past operations and that do not contribute to current or future revenue generation. We record liabilities when environmental assessments and/or remedial efforts are probable and can be reasonably estimated. Cost estimates are based on the expected timing and the extent of remedial actions required by governing agencies, experience gained from similar sites for which environmental assessments or remediation have been completed, and the amount of our anticipated liability considering the proportional liability and financial abilities of other responsible parties. Certain of our environmental liabilities, specific to long-term monitoring costs we believe are fixed and determinable, are recorded on a discounted basis. Where the available information is sufficient to estimate the amount of liability, that estimate is used. Where the information is only sufficient to establish a range of probable liability and no point within the range is more likely than another, the lower end of the range is used. Possible recoveries of some of these costs from other parties are not recognized in the financial statements until they become probable. Legal costs associated with environmental remediation are included as part of the estimated liability. The majority of our environmental liabilities are recorded on an undiscounted basis. Legal Matters In the ordinary course of business, we become party to lawsuits, administrative proceedings and governmental investigations. These matters may involve large or unspecified damages or penalties that may be sought from us and may require years to resolve. We record a liability related to a loss contingency attributable to such legal matters in other current liabilities or other noncurrent liabilities on our consolidated balance sheets, depending on the classification as current or noncurrent if we determine the loss to be both probable and estimable. The liability is recorded for an amount that is management’s best estimate of the loss, or when a best estimate cannot be made, the minimum loss amount of a range of possible outcomes. Acquisitions We use the acquisition method of accounting for the recognition of assets acquired and liabilities assumed with acquisitions at their estimated fair values as of the date of acquisition, with the exception of the Acquisitions from our Sponsor. As an entity under common control with our Sponsor, we record the assets that we acquired from our Sponsor on our consolidated balance sheet at our Sponsor’s historical basis instead of fair value. Any excess consideration transferred over the estimated fair values of the identifiable net assets acquired from third parties is recorded as goodwill. While we use our best estimates and assumptions to measure the fair value of the identifiable assets acquired and liabilities assumed at the acquisition date, our estimates are inherently uncertain and subject to refinement. As a result, during the measurement period, not to exceed one year from the date of acquisition, any changes in the estimated fair values of the net assets recorded for the acquisitions will result in an adjustment to goodwill. Upon the conclusion of the measurement period or final determination of the values of assets acquired or liabilities assumed, whichever comes first, any subsequent adjustments are recorded to our consolidated statements of operations. Our acquisitions are discussed further in Note 2 . Revenue Recognition See Note 13 for details of how we recognize revenue. See below for further discussion on our adoption of ASC 606. Reimbursements Pursuant to the Amended Omnibus Agreement and Carson Assets Indemnity Agreement, our Sponsor reimburses the Partnership for pressure testing, required repairs and maintenance identified as a result of the first inspection of certain pipeline and tank assets subsequent to the Acquisitions from our Sponsor, as well as maintenance projects identified in the Amended Omnibus Agreement for which the costs were not known at the date of the Acquisitions from our Sponsor. These amounts are recorded as a reduction to operating expense during the period the costs are incurred. These amounts were $15 million , $16 million and $17 million for the years ended December 31, 2018 , 2017 and 2016 , respectively. In addition, our Sponsor reimburses the Partnership for capital projects identified in the Amended Omnibus Agreement. These amounts are recorded as a capital contribution by affiliate and were $51 million , $34 million and $29 million for the years ended December 31, 2018 , 2017 and 2016 , respectively. Imbalances We experience volume gains and losses, which we sometimes refer to as imbalances, within our pipelines, terminals and storage facilities due to pressure and temperature changes, evaporation and variances in meter readings and in other measurement methods. On our crude oil gathering and transportation system in North Dakota and Montana (the “High Plains System”), we retain 0.20% of the crude oil shipped on our owned and operated common carrier pipelines in North Dakota and Montana and we bear any crude oil volume losses in excess of that amount. Under the Second Amended and Restated Master Terminalling Service Agreement, we retain 0.25% of the refined products we handle at certain of our terminals for Marathon, and bear any refined product volume losses in excess of that amount. The value of any crude oil or refined product imbalance settlements resulting from these tariffs or contractual provisions is determined by using the monthly average market prices for the applicable commodity, less a specified discount. The Partnership measures volume losses annually for the terminals and pipelines in the Northwest Pipeline System. We retain 0.125% of the distillates and 0.25% of the other refined products we handle at our terminals on the Northwest Pipeline System and we bear any refined product volume losses in excess of those amounts. The value of any refined product losses is determined by using the annual average market price for the applicable commodity. Any settlements under tariffs or contractual provisions where we bear any crude oil or refined product volume losses are recognized in the period they are realized. There are pipeline loss allowance provisions associated with the pipeline agreements acquired in the WNRL Merger. There is a 0.20% pipeline loss allowance for the crude oil shipped on these pipeline systems. Each month we invoice our Sponsor for 0.20% of the volume delivered to us by our Sponsor for the month as a volume loss at a price equal to that month's calendar day average for WTI crude oil, as quoted on the New York Mercantile Exchange, less $8.00 per barrel. Following the end of the month, we calculate the actual volume loss and provide a credit to our Sponsor for the amount of actual volume loss at a price equal to the month's calendar day average for WTI crude oil, as quoted on the New York Mercantile Exchange, less $8.00 per barrel. For all of our other terminals, and under our other commercial agreements with our Sponsor, we have no obligation to measure volume losses and have no liability for physical losses. The consolidated balance sheets also include offsetting natural gas imbalance receivables or payables resulting from differences in gas volumes received by customers and gas volumes delivered to interstate pipelines. Natural gas volumes owed to or by the Partnership that are subject to tariffs are valued at market index prices, as of the balance sheet dates, and are subject to cash settlement procedures. Other natural gas volumes owed to or by the Partnership are valued at our weighted average cost of natural gas as of the balance sheet dates and are settled in-kind. Cost Classification Cost of fuel and other includes the purchase cost of refined products sold within our Wholesale segment and the cost of inbound transportation and distribution costs incurred to transport product to our customers. NGL expense results from the cost of NGL purchases under our POP arrangements as well as the non-cash acquisition of replacement dry gas under our keep-whole arrangements associated with the acquired crude oil, natural gas and produced water gathering systems and two natural gas processing facilities from the North Dakota Gathering and Processing Assets. Operating expenses are comprised of direct operating costs including costs incurred for direct labor, repairs and maintenance, outside services, chemicals and catalysts, utility costs, including the purchase of electricity and natural gas used by our facilities, property taxes, environmental compliance costs related to current period operations, rent expense and other direct operating expenses incurred in the provision of services. Depreciation and amortization expenses consist of the depreciation and amortization of property, plant and equipment, deferred charges and intangible assets related to our operating segments along with our corporate operations. General and administrative expenses represent costs that are not directly or indirectly related to or otherwise are not allocated to our operations. Cost of fuel and other, NGL expense, direct operating expenses, and depreciation and amortization expenses recognized by our Terminalling and Transportation, Gathering and Processing, and Wholesale segments (refer to amounts disclosed in Note 14 ) constitute costs of revenue as defined by U.S. GAAP. Unit-Based Compensation Our general partner provides unit-based compensation to officers and non-employee directors for the Partnership, which includes service and performance phantom unit awards. The fair value of our service phantom unit awards on the date of grant is equal to the market price of our common units. We estimate the grant date fair value of performance phantom unit awards using a Monte Carlo simulation at the inception of the award. We amortize the fair value over the vesting period using the straight-line method. The phantom unit awards are settled in Andeavor Logistics common units. Expenses related to unit-based compensation are included in general and administrative expenses in our consolidated statements of operations. Total unit-based compensation expense totaled $9 million for the years ended December 31, 2018 and 2017 and $6 million for the year ended December 31, 2016 . The Partnership had 943,466 units available for future g

Acquisitions (Notes)

Acquisitions (Notes)	12 Months Ended
	Dec. 31, 2018
Business Combinations [Abstract]
Acquisitions	Note 2 - Acquisitions 2018 Acquisitions 2018 Drop Down On August 6, 2018, we completed the 2018 Drop Down for total consideration of $1.55 billion comprised of $300 million in cash financed with borrowings under our Dropdown Credit Facility and 28,283,742 newly issued common units of the Partnership with a fair value of $1.25 billion . These assets include gathering, storage and transportation assets in the Permian Basin; legacy Western Refining assets and associated crude terminals; the majority of Andeavor's remaining refining terminalling, transportation and storage assets; and equity method investments in ALRP, MPL and PNAC. In addition, the Conan Crude Oil Gathering System and the LARIP were transferred at cost plus incurred interest. In conjunction with the 2018 Drop Down, we entered into additional commercial agreements with Marathon. See Note 3 for further information regarding these agreements. The 2018 Drop Down includes: • Crude oil and other feedstock storage tankage and refined product storage tankage at Marathon’s Mandan, Salt Lake City and Los Angeles refineries; • Rail terminals and truck racks at Marathon’s Mandan, Salt Lake City and Los Angeles refineries for the loading and unloading of various refined products from manifest and other railcars and trucks, respectively; • Interconnecting pipeline facilities in the Los Angeles area as well as other railroad tracks and adjoining lands; • Mesquite and Yucca truck unloading stations in New Mexico for the unloading of crude trucks and injection of crude into the TexNew Mex pipeline; • Mason East and Jackrabbit (“Wink”) truck unloading and injection stations in Texas that receive crude via the T-Station line and trucks for injection into the Kinder Morgan and Bobcat Pipeline; • The Jal storage, injection and rail unloading facility in New Mexico that stores and supplies natural gas liquids for use in Marathon’s El Paso refinery; • Natural gas liquid storage tankage, a rail and truck terminal for the loading and unloading of natural gas liquids from railcars and trucks as well as from the waterline at the Wingate facility in New Mexico; • Crude oil and other feedstock storage tankage at the Clearbrook terminal in Minnesota; • Bobcat Pipeline that transports crude oil between the Mason East Station and the Wink Station; • Benny Pipeline that delivers crude oil from the Conan terminal in Texas to a connection with gathering lines in New Mexico; • All of the issued and outstanding limited liability company interests in: (i) Tesoro Great Plains Midstream LLC, which owns BakkenLink Pipeline LLC, (ii) Andeavor MPL Holdings LLC, which holds the investment in MPL, (iii) Andeavor Logistics CD LLC, (iv) Western Refining Conan Gathering, LLC, which owns the Conan Crude Oil Gathering System, (v) Western Refining Delaware Basin Storage, LLC, (vi) Asphalt Terminals LLC, which holds the investment in PNAC, and (vii) 67% of all of the issued and outstanding limited liability company interests in ALRP; and • Certain related real property interests. SLC Core Pipeline System On May 1, 2018, we completed our acquisition of the SLC Core Pipeline System (formerly referred to as the Wamsutter Pipeline System) from Plains All American Pipeline, L.P. for total consideration of $180 million . The system consists of pipelines that transport crude oil to another third-party pipeline system that supply Salt Lake City area refineries, including Marathon’s Salt Lake City refinery. We financed the acquisition using our Revolving Credit Facility. This acquisition is not material to our consolidated financial statements and its operating results are reported in our Terminalling and Transportation segment. 2017 Acquisitions Anacortes Logistics Assets On November 8, 2017 , we acquired the Anacortes Logistics Assets from a subsidiary of our Sponsor for total consideration of $445 million . The Anacortes Logistics Assets include crude oil, feedstock and refined products storage at Marathon’s Anacortes Refinery, the Anacortes marine terminal with feedstock and refined product throughput, a manifest rail facility and crude oil and refined products pipelines. We paid $445 million , including $400 million of cash financed with borrowings on our revolving credit facilities and $45 million in common units issued to our Sponsor. WNRL Merger Effective October 30, 2017, we closed the WNRL Merger, exchanging all outstanding common units of WNRL for units of Andeavor Logistics, representing an equity value of $1.7 billion . We accounted for the WNRL Merger as a common control transaction and, accordingly, inherited our Sponsor’s basis in WNRL’s net assets. Our Sponsor accounted for the acquisition of WNRL using the acquisition method of accounting, which requires, among other things, that assets acquired at their fair values and liabilities assumed be recognized on the balance sheet as of the acquisition date, or June 1, 2017, the date our Sponsor acquired WNRL. The purchase price allocation for the WNRL Merger has been allocated based on fair values of the assets acquired and liabilities assumed at the acquisition date. The allocation of the WNRL purchase price was final as of May 31, 2018. We recorded adjustments to the allocation to reduce property, plant and equipment and increase goodwill by $55 million during 2018. Preliminary Acquisition Date Purchase Price Allocation (in millions) Cash $ 22 Receivables 112 Inventories 11 Prepayments and Other Current Assets 25 Property, Plant and Equipment (a) 1,295 Goodwill 620 Acquired Intangibles 130 Other Noncurrent Assets 2 Accounts Payable (167 ) Accrued Liabilities (41 ) Debt (347 ) Total purchase price $ 1,662 (a) Estimated useful lives ranging from 3 to 22 years have been assumed based on the valuation. Goodwill We evaluated several factors that contributed to the amount of goodwill presented above. These factors include the acquisition of a logistics business located in advantageous areas where there is crude oil marketing capabilities and meaningful refining offtake with an assembled workforce that cannot be duplicated at the same costs by a new entrant. Further, the WNRL Merger provides a platform for future growth through operating efficiencies we expect to gain from the application of best practices across the combined company and an ability to realize synergies from the geographic diversification of Andeavor Logistics’ business and rationalization of general and administrative costs. We allocated $374 million , $197 million and $49 million of goodwill to the Gathering and Processing, Terminalling and Transportation, and Wholesale segments, respectively. Property, Plant and Equipment The fair value of property, plant and equipment is $1.3 billion . This fair value is based on a valuation using a combination of the income, cost and market approaches. The useful lives are based on similar assets of the Partnership. Acquired Intangible Assets We estimated the fair value of the acquired identifiable intangible assets at $130 million . This fair value is based on a valuation completed for the business enterprise, along with the related tangible assets, using a combination of the income method, cost method and comparable market transactions. We recognized intangible assets associated with customer relationships of $130 million with third parties, all of which will be amortized on a straight-line basis over an estimated weighted average useful life of 15 years. The gross carrying value of our finite life intangibles acquired from the WNRL Merger was $130 million and the accumulated amortization was $14 million as of December 31, 2018 . Amortization expense is expected to be approximately $9 million per year over the remaining useful life. Acquisition Costs We recognized acquisition costs related to the WNRL Merger of $17 million in general and administrative expenses and $3 million of severance costs for the year ended December 31, 2017. WNRL Revenues and Net Earnings For the years ended December 31, 2018 and 2017 , we recognized $415 million and $1.5 billion , respectively, in revenues and $115 million and $40 million , respectively, of net earnings related to the business acquired. Revenues for 2018 were accounted for under ASC 606, further discussed in Notes 1 and 13. Net earnings for the year ended December 31, 2017 included related acquisition and severance costs. Pro Forma Financial Information The unaudited pro forma information combines the historical operations of Andeavor Logistics and WNRL, giving effect to the WNRL Merger and related transactions as if they had been consummated on January 1, 2017. For the year ended December 31, 2017 , the unaudited pro forma consolidated revenues and net earnings was $4.3 billion and $403 million , respectively. Pro forma net earnings for the year ended December 31, 2017 includes a significant non-recurring adjustment to recognize the WNRL Merger acquisition and integration costs. We recognized acquisition costs related to the WNRL Merger of $17 million as well as $3 million of severance costs for the year ended December 31, 2017 . North Dakota Gathering and Processing Assets On January 1, 2017 , we acquired the North Dakota Gathering and Processing Assets for total consideration of $705 million , including payments for working capital amounts, funded with cash on-hand, which included borrowings under our Revolving Credit Facility. The North Dakota Gathering and Processing Assets include crude oil, natural gas, and produced water gathering pipelines, natural gas processing and fractionation capacity in the Sanish and Pronghorn fields of the Williston Basin in North Dakota. With this acquisition, we expanded the assets in our Gathering and Processing segment located in the Williston Basin area of North Dakota to further grow our integrated, full-service logistics capabilities in support of third-party demand for crude oil, natural gas and water gathering services as well as natural gas processing services. In addition, this acquisition increases our capacity and capabilities while extending our crude oil, natural gas and water gathering and associated gas processing footprint to enhance overall basin logistics efficiencies. 2016 Acquisitions Northern California Terminalling and Storage Assets Effective November 21, 2016 , we acquired certain terminalling and storage assets located in Martinez, California from subsidiaries of our Sponsor for total consideration of $400 million , comprised of $360 million in cash financed with borrowings under our Dropdown Credit Facility, and the issuance of our equity securities with a fair value of $40 million . The Northern California Terminalling and Storage Assets include crude oil, feedstock, and refined product storage capacity at Marathon’s Martinez Refinery along with the Avon marine terminal capable of handling feedstock and refined product throughput. The equity consideration was comprised of 860,933 units in the form of common units and 17,570 units in the form of general partner units. Alaska Storage and Terminalling Assets Effective July 1, 2016 , we entered into an agreement to purchase certain terminalling and storage assets owned by our Sponsor for total consideration of $444 million , which was completed in two phases. On July 1, 2016 , we completed the acquisition of the first phase consisting of tankage, related equipment and ancillary facilities used for the operations at our Sponsor’s Kenai Refinery. The second phase was completed on September 16, 2016 and consisted of refined product terminals in Anchorage and Fairbanks. Consideration paid for the first phase was $266 million , comprised of $240 million in cash, financed with borrowings under the Dropdown Credit Facility, and the issuance of 162,375 general partner units and 390,282 common units to our Sponsor with a combined fair value of $26 million . Consideration paid for the second phase was $178 million , comprised of $160 million in cash, financed with borrowings under the Dropdown Credit Facility, and the issuance of 20,440 general partner units and 358,712 common units to our Sponsor with a combined fair value of $18 million . Combined Consolidated Financial Information As discussed further in Note 1, we refer to the historical results of the Alaska Storage and Terminalling Assets (phase 1 prior to July 1, 2016 and phase 2 from June 20, 2016 to September 16, 2016), Northern California Terminalling and Storage Assets (prior to November 21, 2016), WNRL (from June 1, 2017 to October 30, 2017) and the 2018 Drop Down (prior to August 6, 2018), collectively as our “Predecessors.” The following tables present our results of operations disaggregated to present results relating to the Partnership and the Predecessors for the assets acquired from our Sponsor and the total amounts included in our combined consolidated financial statements for the years ended December 31, 2018 , 2017 and 2016 . Reconciliation of Combined Financial Statements (in millions) Year Ended December 31, 2018 Combined Andeavor Logistics LP Predecessors Revenues: Fee-based: Affiliate $ 1,309 $ 1,288 $ 21 Third-party 591 582 9 Product-based: Affiliate 280 280 — Third-party 200 200 — Total Revenues 2,380 2,350 30 Costs and Expenses NGL expense (exclusive of items shown separately below) 206 206 — Operating expenses (exclusive of depreciation and amortization) 885 845 40 General and administrative expenses 121 112 9 Depreciation and amortization expenses 368 346 22 Loss on asset disposals and impairments 4 4 — Operating Income (Loss) 796 837 (41 ) Interest and financing costs, net (233 ) (229 ) (4 ) Equity in earnings of equity method investments 31 15 16 Other income, net 6 5 1 Net Earnings (Loss) $ 600 $ 628 $ (28 ) Loss attributable to Predecessors 28 — 28 Net Earnings Attributable to Partners 628 628 — Preferred unitholders’ interest in net earnings (44 ) (44 ) — Limited Partners’ Interest in Net Earnings $ 584 $ 584 $ — Year Ended December 31, 2017 Combined Andeavor Logistics LP Predecessors Revenues: Fee-based: Affiliate $ 942 $ 796 $ 146 Third-party 656 647 9 Product-based: Affiliate 489 213 276 Third-party 1,162 495 667 Total Revenues 3,249 2,151 1,098 Costs and Expenses Cost of fuel and other (excluding items shown separately below) 1,244 330 914 NGL expense (exclusive of items shown separately below) 265 265 — Operating expenses (exclusive of depreciation and amortization) 691 554 137 General and administrative expenses 158 121 37 Depreciation and amortization expenses 313 255 58 Gain on asset disposals and impairments (25 ) (24 ) (1 ) Operating Income (Loss) 603 650 (47 ) Interest and financing costs, net (330 ) (321 ) (9 ) Equity in earnings of equity method investments 22 10 12 Other income, net 11 10 1 Net Earnings (Loss) $ 306 $ 349 $ (43 ) Loss attributable to Predecessors 43 — 43 Net Earnings Attributable to Partners 349 349 — Preferred unitholders’ interest in net earnings (3 ) (3 ) — General partner’s interest in net earnings, including IDRs (79 ) (79 ) — Limited Partners’ Interest in Net Earnings $ 267 $ 267 $ — Year Ended December 31, 2016 Combined Andeavor Logistics LP Predecessors Revenues: Fee-based: Affiliate $ 747 $ 615 $ 132 Third-party 819 502 317 Product-based: Affiliate 100 100 — Third-party 3 3 — Total Revenues 1,669 1,220 449 Costs and Expenses Cost of fuel and other (excluding items shown separately below) 316 — 316 NGL expense (exclusive of items shown separately below) 2 2 — Operating expenses (exclusive of depreciation and amortization) 560 426 134 General and administrative expenses 106 94 12 Depreciation and amortization expenses 233 183 50 Loss on asset disposals and impairments 4 4 — Operating Income (Loss) 448 511 (63 ) Interest and financing costs, net (195 ) (196 ) 1 Equity in earnings of equity method investments 13 13 — Other income, net 11 11 — Net Earnings (Loss) $ 277 $ 339 $ (62 ) Loss attributable to Predecessors 62 — 62 Net Earnings Attributable to Partners 339 339 — General partner’s interest in net earnings, including IDRs (152 ) (152 ) — Limited Partners’ Interest in Net Earnings $ 187 $ 187 $ — Divestitures On June 2, 2017, due to our Sponsor’s consent decree with the state of Alaska associated with the acquisition of the Alaska Storage and Terminalling Assets, we sold one of our existing Alaska products terminals (“Alaska Terminal”) for $28 million . The sale resulted in a $25 million gain on sale in our consolidated statements of operations for the year ended December 31, 2017. The Alaska Terminal divestiture did not have a material impact on our operations.

Related-Party Transactions (Not

Related-Party Transactions (Notes)	12 Months Ended
	Dec. 31, 2018
Related Party Transactions [Abstract]
Related-Party Transactions	Note 3 - Related-Party Transactions Commercial Agreements We have various long-term, fee-based commercial agreements with our Sponsor, under which we provide pipeline transportation, wholesale, trucking, terminal distribution and storage services to Marathon, and Marathon commits to provide us with minimum monthly throughput volumes of crude oil, refined products and other. If, in any calendar month, Marathon fails to meet its minimum volume commitments under these agreements, it will be required to pay us a shortfall payment. These shortfall payments may be applied as a credit against any amounts due above their minimum volume commitments for up to twelve months after the shortfall occurs. Each of these agreements has fees that are indexed annually for inflation or, in certain circumstances, allows for a quarterly rate adjustment based on a comparison of competitive rates. Commercial Agreements with Marathon Termination Provisions Commercial Agreement Initiation Date Term Years Renewals Refinery Shutdown Notice Period (a) Force Majeure Amended Transportation Services Agreement (High Plains System) Apr-11 10 2 x 5 years 12 months Unilateral Second Amended and Restated Master Terminalling Agreement Apr-11 10 2 x 5 years 12 months Unilateral Salt Lake City Storage Agreement Apr-11 10 2 x 5 years 12 months Unilateral Amended and Restated Transportation Services Agreement (Salt Lake City Short Haul Pipeline) Apr-11 10 2 x 5 years 12 months Unilateral Amorco Terminal Use and Throughput Agreement (Martinez Marine) Apr-12 10 2 x 5 years 12 months Unilateral Transportation Services Agreement (LAR Short Haul Pipelines) Sep-12 10 2 x 5 years N/A Unilateral Amended Anacortes Track Use and Throughput Agreement Nov-12 10 2 x 5 years N/A Unilateral Long Beach Storage Services Agreement Dec-12 10 2 x 5 years N/A Unilateral Terminalling Services Agreement for Northwest Pipeline System Jun-13 1 Year to year N/A Unilateral Southern California Terminalling & Dedicated Services Agreement Jun-13 10 2 x 5 years N/A Unilateral Amended Carson Storage Services Agreement Jun-13 10 2 x 5 years N/A Unilateral Carson Tank Farm Storage Agreement Jun-13 10 2 x 5 years N/A Unilateral Amended Terminalling, Transportation and Storage Services Agreement (WNRL) Oct-13 10 2 x 5 years 12 months Unilateral Amended Pipeline and Gathering Services Agreement (WNRL) Oct-13 10 2 x 5 years 12 months Unilateral Carson Coke Handling Service Agreement Dec-13 10 2 x 5 years N/A Unilateral Amended and Restated Long Beach Berth Access Use and Throughput Agreement Dec-13 10 2 x 5 years N/A Unilateral Long Beach Pipeline Throughput Agreement (b) Dec-13 10 2 x 5 years N/A Unilateral Amended Transportation Services Agreement (SoCal Pipelines) Dec-13 10 2 x 5 years N/A Unilateral Bakken Area Storage Hub Storage - TRMC Tanks Apr-14 5 2 x 5 years N/A Unilateral Terminalling & Dedicated Storage Services Agreement - Martinez Jul-14 10 2 x 5 years N/A Unilateral Terminalling & Dedicated Storage Services Agreement - Anacortes Jul-14 10 2 x 5 years N/A Unilateral THPP Reversal Open Season Northbound Commitment Sep-14 7 None N/A Unilateral Tesoro Alaska Pipeline Throughput Agreement Sep-14 10 2 x 5 years N/A Unilateral Amended Crude Oil Trucking Transportation Services Agreement (WNRL) Oct-14 10 None N/A Unilateral Fuel Distribution and Supply Agreement (WNRL) Oct-14 10 None N/A Unilateral Amended Product Supply Agreement (WNRL) Oct-14 10 None N/A Unilateral Keep-Whole Commodity Fee Agreement Dec-14 5 1 year auto 90 days prior to expiration Bilateral Sale of Natural Gas Oct-15 1 month Evergreen N/A Bilateral Amended Asphalt Trucking Services Agreement (WNRL) Jan-16 10 2 x 5 years N/A Unilateral Green River Processing Crude Oil Sales Agreement Feb-16 1 Evergreen N/A Bilateral Tank #2030 Use, Storage and Throughput Agreement Apr-16 6 months 6 months N/A Bilateral Asphalt and Propane Rack Loading Services Agreement (Kenai) May-16 10 2 x 5 years N/A Unilateral Kenai Storage Services Agreement Jul-16 10 2 x 5 years N/A Unilateral Termination Provisions Commercial Agreement Initiation Date Term Years Renewals Refinery Shutdown Notice Period (a) Force Majeure Terminalling, Transportation and Storage Services Agreement (St. Paul Park) Sep-16 10 2 x 5 years 12 months Unilateral Alaska Terminalling Services Agreement Sep-16 10 2 x 5 years N/A Unilateral Martinez Storage Services Agreement Nov-16 10 2 x 5 years N/A Unilateral Avon Marine Terminal Use and Throughput Agreement Jan-17 10 2 x 5 years N/A Unilateral Belfield Crude & Oil Gathering Jan-17 2 None N/A Unilateral Amended Renewal Trucking Transportation Services Agreement Apr-17 1 Evergreen 2 months prior to expiration Unilateral Transportation Services Agreement (Anacortes Short Haul Pipelines) Nov-17 10 2 x 5 years N/A Unilateral Anacortes Manifest Rail Terminalling Services Agreement Nov-17 10 2 x 5 years N/A Unilateral Anacortes Marine Terminal Operating Agreement Nov-17 17 None N/A Unilateral Storage Services Agreement - Anacortes II Nov-17 10 2 x 5 years N/A Unilateral Product Transportation Agreement (TRMC, WRSW, WRCLP, SPPRC) Jan-18 1 Evergreen N/A Unilateral Plant Dedication Agreement (Robinson Lake and Belfield) Apr-18 3 Month to month N/A Bilateral Product Sales Agreement - Robinson Lake Apr-18 3 N/A N/A Bilateral Product Sales Agreement - Belfield Apr-18 3 N/A N/A Bilateral Product Sales Agreement Y-Grade - Robinson Lake May-18 1 month Month to month N/A Bilateral SLC Core Crude Throughput May-18 0.2 Evergreen N/A Unilateral Truck Loading (H2S) Little Knife Jun-18 6 None N/A Unilateral Truck Unloading Facility Throughput Agreement (Stanley LACT) Jun-18 3 None N/A Unilateral Transportation Services Agreement (LAR Interconnecting Pipelines) Aug-18 10 2 x 5 years 12 months Unilateral Amended Master Terminalling Services Agreement - Clearbrook, Fryburg, Jal, LAR, Mandan, Wingate Aug-18 10 2 x 5 years N/A Unilateral Master Unloading and Storage Agreement (WNRL) Aug-18 10 2 x 5 years N/A Unilateral Amended Asphalt Terminalling, Transportation and Storage Services Agreement Aug-18 10 2 x 5 years 30 days Unilateral Fryburg Terminal Services Agreement Aug-18 2.6 1 month N/A Unilateral Transloading Services Agreement - Salt Lake City Spur Oct-18 3 None N/A Unilateral Natural Gas Liquids Marketing Agreement Oct-18 3 3 year extension with 60 days notice by AFS N/A Bilateral (a) Fixed minimum volumes remain in effect during routine turnarounds. (b) Agreement gives Marathon the option to renew for two five-year terms, or Marathon may modify the term of the agreements to a twenty-year term by providing notice in accordance with each agreement. We charge fixed fees based on the total storage capacity of our assets under several of our agreements with Marathon. We recognized $407 million , $277 million and $193 million of revenue under these agreements where we were considered to be the lessor during the years ended December 31, 2018 , 2017 and 2016 , respectively. Committed minimum payments for each of the five years following December 31, 2018 , are expected to be approximately $478 million to $530 million per year and an aggregate $1.5 billion remaining after 2023. Fourth Amended and Restated Omnibus Agreement We entered into an omnibus agreement with our Sponsor at the closing of our Initial Offering. The agreement has been amended for each of the Acquisitions from our Sponsor and was amended and restated in connection with the 2018 Drop Down. The amendment increased the annual administrative fee payable by us to our Sponsor under the Amended Omnibus Agreement to $17 million as of December 31, 2018 , for the provision of various general and administrative services, including executive management, legal, accounting, treasury, human resources, health, safety and environmental, information technology, certain insurance coverage, administration and other corporate services. In addition, we reimburse our Sponsor for all other direct or allocated costs and expenses incurred by Marathon or its affiliates on our behalf. On January 1, 2019, the Amended Omnibus Agreement was further amended to add Marathon Petroleum Company LP (“MPCLP”) as a party to the agreement and to make certain other related conforming changes to reflect MPCLP’s addition. Under the Amended Omnibus Agreement, Marathon indemnifies us for certain matters, including known environmental, title and tax matters associated with the ownership of our assets at or before the closing of the Initial Offering and the subsequent acquisitions from our Sponsor, with certain exceptions that are covered by the Carson Assets Indemnity Agreement. With respect to assets that we acquired from our Sponsor, indemnification for unknown environmental and title liabilities is limited to pre-closing conditions identified prior to the earlier of the date that our Sponsor no longer controls our general partner or five years after the date of closing. The indemnification under the Initial Offering for unknown environmental matters expired on April 26, 2016. Under the Amended Omnibus Agreement, the aggregate annual deductible for each type of liability (unknown environmental liabilities or title matters) is $1 million as of December 31, 2018 , before we are entitled to indemnification in any calendar year in consideration of Initial Offering assets and all subsequent acquisitions from our Sponsor, with the exception of the indemnifications for the acquisition of the six marketing and storage terminal facilities (the “Los Angeles Terminal Assets”) and the acquisition of the remaining logistics assets (the “Los Angeles Logistics Assets”) initially acquired by us as part of the Los Angeles acquisition in Southern California (the “Los Angeles Logistics Assets Acquisition”). In addition, with respect to the assets that we acquired from our Sponsor, we have agreed to indemnify Marathon for events and conditions associated with the ownership or operation of our assets that occur after the closing of the Initial Offering, and the subsequent acquisitions from our Sponsor, and for environmental liabilities related to our assets to the extent Marathon is not required to indemnify us for such liabilities. See Note 10 for additional information regarding the Amended Omnibus Agreement. Carson Assets Indemnity Agreement We entered into the Carson Assets Indemnity Agreement at the closing of the Los Angeles Logistics Assets Acquisition effective December 6, 2013, establishing indemnification for certain matters including known and unknown environmental liabilities arising out of the use or operation of the Los Angeles Terminal Assets and the Los Angeles Logistics Assets prior to the respective acquisition dates. Under the Carson Assets Indemnity Agreement, our Sponsor retained responsibility for remediation of known environmental liabilities due to the use or operation of the Los Angeles Terminal Assets and the Los Angeles Logistics Assets prior to the respective acquisition dates, and has indemnified us for any losses incurred by us arising out of those remediation obligations. The indemnification for unknown pre-closing remediation liabilities is limited to five years. However, with respect to Terminal 2 at the Long Beach marine terminal, which was included in the Los Angeles Logistics Assets Acquisition, the indemnification for unknown pre-closing remediation liabilities is limited to ten years. Indemnification of the Los Angeles Terminal Assets’ and the Los Angeles Logistics Assets’ environmental liabilities is not subject to a deductible. See Note 10 for additional information regarding the Carson Assets Indemnity Agreement. Keep-Whole Commodity Fee Agreement Following the completion of the Rockies Natural Gas Business Acquisition, we began processing gas for certain producers under keep-whole processing agreements. Under a keep-whole agreement, a producer transfers title to the NGLs produced during gas processing, and the processor, in exchange, delivers to the producer natural gas with a BTU content equivalent to the NGLs removed. The operating margin for these contracts is typically determined by the spread between NGLs sales prices and the price paid to purchase the replacement natural gas (“Shrink Gas”). At that time, we entered into the Keep-Whole Commodity Agreement with our Sponsor. Under the Keep-Whole Commodity Agreement, our Sponsor pays us a processing fee for NGLs related to keep-whole agreements and delivers Shrink Gas to the producers on our behalf. We pay our Sponsor a marketing fee in exchange for assuming the commodity risk. In February 2016, the parties entered into the First Amendment to the Keep-Whole Commodity Agreement (the “Keep-Whole Amendment”) that adjusted the contract to provide for a tiered pricing structure for different NGL production levels. The Keep-Whole Amendment continues to provide for annual purchase orders setting forth service fees for the base and incremental volumes; however, the Keep-Whole Amendment provides that the service fees payable for incremental volumes of natural gas liquids above 315,000 gallons per day shall be calculated with reference to the costs of (i) processing, (ii) conditioning, (iii) handling, (iv) fractionation, (v) storage, truck and rail loading at the Blacks Fork processing complex, and (vi) pipeline transportation fees on the MAPL pipeline system and fractionation fees at Mt. Belvieu, Texas for transportation and fractionation services provided to processors by MAPL, Cedar Bayou Fractionators, and Enterprise Products Partners L.P. for natural gas liquids sold pursuant to the Keep-Whole Commodity Agreement. The pricing for both the base and incremental volumes are subject to revision each year. Secondment Agreements We entered into the Andeavor Secondment Agreement with Andeavor to govern the provision of seconded employees to or from Andeavor, the Partnership, and its subsidiaries, as applicable. On August 6, 2018, TLGP and certain of its indirect subsidiaries amended and restated the Andeavor Secondment Agreement. As amended and restated, the Amended Secondment Agreement incorporated the changes made in previous amendments into the body of the agreement and added WNRL and its affiliates as parties. The Andeavor Secondment Agreement also governed the use of certain facilities of the parties by the various entities. The services to be provided by such seconded employees, along with the fees for such services, were provided on the service schedules attached to the Andeavor Secondment Agreement. Specialized services and the use of various facilities, along with the fees for such services, will be provided for in service orders to be executed by parties requesting and receiving the service. For the years ended December 31, 2018 , 2017 and 2016 , we charged our Sponsor $8 million , $8 million and $5 million , respectively, and our Sponsor charged us $77 million , $29 million and $18 million , respectively, pursuant to the Andeavor Secondment Agreement. On January 30, 2019, TLGP and certain of its indirect subsidiaries entered into the 2019 Secondment Agreements with MPLS and MRLS. Under the 2019 Secondment Agreements, MPLS and MRLS will second certain employees to occupy positions within our business and organization and to conduct business on our behalf. While seconded by MPLS and MRLS to us, seconded employees will remain on the payroll of MPLS or MRLS, as the case may be, and will be eligible to participate in all MPLS or MRLS benefit plans that they would be eligible to participate in absent the secondment, but will work for and be under our general direction, supervision and control. We will reimburse MPLS or MRLS, as the case may be, for the payroll costs of the seconded employees, including base pay, bonuses and other incentive compensation plus a burden rate associated with benefits and other payroll costs for the portion of the employee’s time that is allocated to us. The 2019 Secondment Agreements are for a term of 10 years , but may be sooner terminated by us, MPLS or MRLS upon 60 days written notice. In connection with the entry into the 2019 Secondment Agreements, on January 30, 2019, our Sponsor entered into an agreement (the “Termination Agreement”) that terminated the Andeavor Secondment Agreement. The Termination Agreement had an effective date of January 1, 2019. Summary of Affiliate Transactions Summary of Revenue and Expense Transactions with Marathon, including Predecessors (in millions) Year Ended December 31, 2018 2017 2016 Revenues $ 1,589 $ 1,431 $ 847 Operating expenses (exclusive of depreciation and amortization) (a) 272 251 308 General and administrative expenses 98 101 80 (a) Includes net imbalance settlement gains of $12 million and $7 million in the years ended December 31, 2017 and 2016 , respectively. Due to the adoption of ASC 606 effective January 1, 2018, imbalance settlement gains of $16 million in the year ended December 31, 2018 were included in revenues. Includes reimbursements primarily related to pressure testing and repairs and maintenance costs pursuant to the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement of $15 million , $16 million and $17 million in the years ended December 31, 2018 , 2017 and 2016 , respectively. Predecessor Transactions Related-party transactions of our Predecessors were settled through equity. The balance in receivables and accounts payable from affiliated companies represents the amount owed from or to Marathon related to certain affiliate transactions. Other than WNRL and certain assets acquired from the 2018 Drop Down, our Predecessors did not record revenue for transactions with Marathon. Distributions In accordance with our partnership agreement, our limited partner interests are entitled to receive quarterly distributions of available cash. We paid quarterly cash distributions to our Sponsor, including IDRs, totaling $493 million , $336 million and $245 million in 2018 , 2017 and 2016 , respectively. In connection with the IDR/GP Transaction, our general partner no longer holds IDRs. On January 25, 2019 , in accordance with our partnership agreement, we announced the declaration of a quarterly cash distribution, based on the results of the fourth quarter of 2018 , of $1.03 per unit, of which $146 million was paid to Marathon on February 14, 2019 , to unitholders of record on February 5, 2019 .

Property, Plant and Equipment (

Property, Plant and Equipment (Notes)	12 Months Ended
	Dec. 31, 2018
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Note 4 - Property, Plant and Equipment Property, Plant and Equipment (in millions) Estimated Depreciable Lives (Years) (a) December 31, 2018 2017 (b) Terminals and tankage 3 - 40 $ 3,749 $ 3,557 Pipelines 5 - 30 3,411 2,825 Land and leasehold improvements 3 - 29 297 282 Buildings and improvements 3 - 28 87 91 Other 1 - 28 82 142 Construction in progress — 519 346 Property, Plant and Equipment, at Cost (c) 8,145 7,243 Accumulated depreciation (c) (1,300 ) (994 ) Property, Plant and Equipment, Net $ 6,845 $ 6,249 (a) The above excludes assets not being depreciated. (b) Property, plant and equipment transferred to the Partnership in the 2018 Drop Down was recorded at historical costs. The Partnership recorded property, plant and equipment of $948 million and accumulated depreciation of $112 million as of December 31, 2017 in connection with the 2018 Drop Down. (c) Assets owned by us for which we are the lessor under operating leases were $691 million and $643 million before accumulated depreciation of $224 million and $195 million as of December 31, 2018 and 2017 , respectively.

Note 5 - Acquired Intangibles a

Note 5 - Acquired Intangibles and Goodwill Acquired Intangibles and Goodwill (Notes)	12 Months Ended
	Dec. 31, 2018
Goodwill and Intangible Assets Disclosure [Abstract]
Acquired Intangibles and Goodwill	Note 5 - Acquired Intangibles and Goodwill Acquired Intangibles The acquired intangible assets, net of accumulated amortization, were $1.1 billion and $1.2 billion at December 31, 2018 and 2017 , respectively, consisting of customer relationships associated with WNRL, the North Dakota Gathering and Processing Assets and the natural gas processing and gathering operations from the Rockies Natural Gas Business Acquisition. The value for the identified customer relationships consists of cash flows expected from existing contracts and future arrangements from the existing customer base. Accumulated amortization was $156 million and $106 million at December 31, 2018 and 2017 , respectively. Amortization expense of acquired intangible assets was $50 million , $46 million and $29 million for the years ended December 31, 2018 , 2017 and 2016 , respectively. As of December 31, 2018 , amortization expense is expected to be approximately $50 million per year through 2023. Goodwill Goodwill by Operating Segment (in millions) December 31, 2018 2017 (a) Terminalling and Transportation (b) (c) $ 284 $ 260 Gathering and Processing (b) (c) 718 607 Wholesale (b) 49 89 Goodwill $ 1,051 $ 956 (a) Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion. (b) In connection with the finalization of the purchase price allocation associated with the WNRL Merger during 2018, we reallocated goodwill amongst the segments. (c) Goodwill transferred to the Partnership in the 2018 Drop Down was recorded at historical cost. We recorded goodwill of $39 million and $225 million in our Terminalling and Transportation and Gathering and Processing segments, respectively, as of December 31, 2017 as a result of the 2018 Drop Down. For 2018, we elected to perform our annual goodwill impairment assessment using a quantitative assessment process on our goodwill. As part of our quantitative goodwill impairment process, we engaged a third-party appraisal firm to assist in the determination of estimated fair value. This determination includes estimating the fair value using both the income and market approaches. The income approach requires management to estimate a number of factors, including projected future operating results, economic projections, anticipated future cash flows and discount rates. The market approach estimates fair value using comparable marketplace fair value data from within a comparable industry grouping. The determination of the fair value requires us to make significant estimates and assumptions. These estimates and assumptions primarily include, but are not limited to, the selection of appropriate peer group companies, control premiums appropriate for acquisitions in the industries in which we compete, the discount rates, terminal growth rates, and forecasts of revenue, operating income and capital expenditures. We determined that no impairment charges resulted from our November 1, 2018 goodwill impairment assessments. The fair value of our five reporting units was in excess of their carrying value. There were no impairments of goodwill during the years ended December 31, 2018 , 2017 and 2016 .

Note 6 - Equity Method Investme

Note 6 - Equity Method Investments and Joint Ventures Equity Method Investments and Joint Ventures (Notes)	12 Months Ended
	Dec. 31, 2018
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments and Joint Ventures	Note 6 - Equity Method Investments and Joint Ventures For each of the following investments, we have the ability to exercise significant influence through our participation in the management committees, which make all significant decisions. However, since we have equal or proportionate influence over each committee as a joint interest partner and all significant decisions require the consent of the other investor(s) without regard to economic interest, we have determined that these entities should not be consolidated and apply the equity method of accounting with respect to our investments in each entity. • ALRP - We own a 67% interest in ALRP, a recently constructed crude oil pipeline located in the Delaware and Midland basins in west Texas. • MPL - We own a 17% interest in MPL, which owns and operates a crude oil pipeline in Minnesota. • PNAC - We own a 50% interest in PNAC, which owns and operates an asphalt terminal in Nevada. • RGS - We own a 78% interest in RGS, which owns and operates the infrastructure that transports gas from certain fields to several re-delivery points in southwestern Wyoming, including natural gas processing facilities that are owned by us or a third party. • TRG - We own a 50% interest in TRG located in the southeastern Uinta Basin, which transports natural gas gathered by UBFS and other third-party volumes to gas processing facilities. • UBFS - We own a 38% interest in UBFS, which owns and operates the natural gas gathering infrastructure located in the southeastern Uinta Basin. Equity Method Investments (in millions) ALRP (a) MPL (a) PNAC (a) RGS TRG UBFS Total Balance at December 31, 2016 $ — $ — $ — $ 281 $ 40 $ 16 $ 337 Acquired interests — 120 — — — — 120 Equity in earnings — 12 — 6 2 2 22 Distributions received — (12 ) — (19 ) (5 ) (3 ) (39 ) Balance at December 31, 2017 (b) — 120 — 268 37 15 440 Acquired interests 159 — 27 — — — 186 Equity in earnings (loss) 6 17 (1 ) 5 3 1 31 Cumulative effect of accounting standard adoption — — — — (3 ) — (3 ) Distributions received (5 ) (20 ) — (20 ) (5 ) (2 ) (52 ) Balance at December 31, 2018 (b) $ 160 $ 117 $ 26 $ 253 $ 32 $ 14 $ 602 (a) These equity method investments were included in the 2018 Drop Down. Amounts were adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion. (b) The carrying amounts of our investments that exceed the underlying equity in net assets are amortized over the useful life of the underlying fixed assets and included in equity in earnings. The carrying amount of our investments in these equity method investments exceeded the underlying equity in net assets as shown below. December 31, (in millions) 2018 2017 (c) ALRP $ 75 $ — MPL 34 35 PNAC 17 — RGS 125 130 TRG 14 15 UBFS 6 6 (c) Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion. We acquired 67% of all of the issued and outstanding limited liability company interests in ALRP as part of the 2018 Drop Down. ALRP is a variable interest entity. We are not the primary beneficiary of ALRP under the partnership agreement because the Partnership and the other minor shareholder jointly direct the activities of ALRP that most significantly impact its economic performance. In addition, we have a 78% interest in RGS. ALRP and RGS are unconsolidated variable interest entities and we use the equity method of accounting with respect to our investments in each entity.

Other Current Assets and Liabil

Other Current Assets and Liabilities (Notes)	12 Months Ended
	Dec. 31, 2018
Other Liabilities, Current [Abstract]
Other Current Assets and Liabilities	Note 7 - Other Current Assets and Liabilities Other Current Assets (in millions) December 31, 2018 2017 (a) Deferred charges $ 45 $ — Inventories 22 12 Prepayments 12 15 Total Other Current Assets $ 79 $ 27 (a) Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion. Other Current Liabilities (in millions) December 31, 2018 2017 (a) Deferred income $ 24 $ 23 Taxes other than income taxes 22 20 Employee costs 11 7 Asset retirement obligation 10 11 Accrued environmental liabilities 4 12 Other 10 11 Total Other Current Liabilities $ 81 $ 84 (a) Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

Debt (Notes)

Debt (Notes)	12 Months Ended
	Dec. 31, 2018
Debt Disclosure [Abstract]
Debt	Note 8 - Debt Debt Balance, Net of Unamortized Issuance Costs (in millions) December 31, 2018 2017 Revolving Credit Facility $ 945 $ 423 Dropdown Credit Facility 300 — MPC Loan Agreement — — 5.500% Senior Notes due 2019 500 500 3.500% Senior Notes due 2022 (a) 500 500 6.250% Senior Notes due 2022 300 300 6.375% Senior Notes due 2024 450 450 5.250% Senior Notes due 2025 750 750 4.250% Senior Notes due 2027 (a) 750 750 5.200% Senior Notes due 2047 (a) 500 500 Capital lease obligations 15 9 Total Debt 5,010 4,182 Unamortized issuance costs (a) (46 ) (54 ) Current maturities, net of unamortized issuance costs (504 ) (1 ) Debt, Net of Current Maturities and Unamortized Issuance Costs $ 4,460 $ 4,127 (a) Unamortized discounts of $4 million and $5 million associated with these senior notes are included in unamortized issuance costs at December 31, 2018 and 2017 , respectively. The aggregate maturities of our debt, including the principal payments of our capital lease obligations, for each of the five years following December 31, 2018 are $504 million in 2019 , $2 million in 2020 , $1.2 billion in 2021 , $802 million in 2022 and $1 million in 2023 . Revolving Credit Facility and Dropdown Credit Facility We are party to our $1.1 billion Revolving Credit Facility and our $1.0 billion Dropdown Credit Facility (together, the “Credit Facilities”). On January 5, 2018 , we amended our Credit Facilities to, among other things, (i) increase the aggregate commitments from $600 million to $1.1 billion , (ii) add certain financial institutions as additional lenders under the Revolving Credit Facility and (iii) make certain changes to our Credit Facilities to permit the incurrence of incremental loans (to be shared between the Credit Facilities), subject to the satisfaction of certain conditions. The total aggregate available facility limits for the Credit Facilities totaled $2.1 billion at December 31, 2018 . The Credit Facilities mature on January 29, 2021. On December 20, 2018, we amended our Credit Facilities to, among other things, (i) grant additional flexibility to the Partnership and its subsidiaries to create liens and incur indebtedness, subject to the negative financial covenant that requires us to maintain a Consolidated Leverage Ratio (as defined in the credit agreements) of no greater than 5.0 to 1.0 (or 5.5 to 1.0 during the two fiscal quarters following certain acquisitions), (ii) remove restrictions on the ability of the Partnership and its subsidiaries to make investments and (iii) grant additional flexibility to the Partnership and its subsidiaries to enter into acquisitions, sell or dispose of assets and enter into related party transactions. In addition, we amended our Credit Facilities to make certain legal and technical updates to the revolving credit facility agreements, including the removal of collateral and security provisions that are no longer applicable and changes to reflect the previously reported acquisition of Andeavor by MPC effective on October 1, 2018. Our Revolving Credit Facility provided for total loan capacity of $1.1 billion as of December 31, 2018 . Our Revolving Credit Facility is non-recourse to Marathon, except for TLGP, and is guaranteed by substantially all of our consolidated subsidiaries. As of December 31, 2018 , there was $945 million in borrowings outstanding under the Revolving Credit Facility, which had unused credit availability of $155 million , or 14% of the borrowing capacity. The weighted average interest rate for borrowings under our Revolving Credit Facility was 4.33% at December 31, 2018 . As of December 31, 2018 , the Dropdown Credit Facility provided for total loan availability of $1.0 billion . We had $300 million in borrowings outstanding under the Dropdown Credit Facility, which had unused credit availability of $700 million , or 70% of the borrowing capacity. The weighted average interest rate for borrowings under our Dropdown Credit Facility was 4.14% at December 31, 2018 . Covenants Our Credit Facility agreements both contain representations and warranties, affirmative and negative covenants, and events of default that we consider usual and customary for agreements of these types. The sole financial covenant that we are required to maintain, as of the last day of the fiscal quarter, is a Consolidated Leverage Ratio (as defined in the Credit Facility agreements) of no greater than 5.00 to 1.00. As of December 31, 2018 , we were in compliance with this financial covenant. Loan Agreement On December 21, 2018, we entered into the MPC Loan Agreement. Under the terms of the MPC Loan Agreement, MPC will make a loan to the Partnership on a revolving basis as requested by the Partnership and as agreed to by MPC, in an amount or amounts that do not result in the aggregate principal amount of all loans outstanding exceeding $500 million at any one time. The MPC Loan Agreement matures and the entire unpaid principal amount of the Loan, together with all accrued and unpaid interest and other amounts, if any, owed by the Partnership under the MPC Loan Agreement will become due and payable on December 21, 2023, provided that MPC may demand payment of all or any portion of the outstanding principal amount of the Loan, together with all accrued and unpaid interest and other amounts, if any, at any time prior to the maturity date. Interest will accrue on the unpaid principal amount of the Loan at a rate equal to the sum of (i) the one-month term LIBOR for dollar deposits, plus (ii) a premium of 175 basis points (or such lower premium then applicable under the Partnership’s credit agreements). There were no borrowings under the MPC Loan Agreement during 2018 . WNRL Repayment At the time of the WNRL Merger, WNRL had a $500 million senior secured revolving credit facility (“WNRL Revolving Credit Facility”) and $300 million of 7.5% senior notes (the “WNRL Senior Notes”). In connection with the WNRL Merger, all amounts outstanding were repaid with borrowings on the Revolving Credit Facility and the WNRL Revolving Credit Facility was terminated. In addition, the WNRL Senior Notes were repaid for $326 million , including accrued interest of $4 million and a premium of $22 million , with borrowings on the Revolving Credit Facility. Senior Notes 5.500% Senior Notes Due 2019 In October 2014 , we completed a private offering of $1.3 billion aggregate principal amount of senior notes pursuant to a private placement transaction conducted under Rule 144A and Regulation S of the Securities Act of 1933, as amended. The $1.3 billion of aggregate principal senior notes consisted of $500 million senior notes due in 2019 (the “ 2019 Notes”) at 5.500% , which approximates the effective interest rate, and $800 million of 6.250% senior notes due in 2022 (the “ 6.250% 2022 Notes”). The proceeds from the 2019 Notes were used to repay amounts outstanding under our Revolving Credit Facility and to fund the Rockies Natural Gas Business Acquisition. We completed a registered exchange offer to exchange the 2019 Notes for debt securities with substantially identical terms in April 2016. The 2019 Notes have no sinking fund requirements. We may redeem some or all of the 2019 Notes prior to September 15, 2019 , at a make-whole price, and at par thereafter, plus accrued and unpaid interest. The 2019 Notes are unsecured and guaranteed by all of our consolidated subsidiaries, with the exception of Tesoro Logistics Finance Corp., the co-issuer, and are non-recourse to Marathon, except for TLGP, and contain customary terms, events of default and covenants for an issuance of non-investment grade securities. 3.500% Senior Notes Due 2022 In November 2017 , we issued $500 million aggregate principal amount of senior notes due in 2022 at 3.500% (the “ 3.500% 2022 Notes”), which approximates the effective interest rate. The proceeds from the 3.500% 2022 Notes were used to repay a portion of our 5.875% senior notes due in 2020 and 6.125% senior notes due in 2021 , as well as borrowings under the Dropdown Credit Facility. The 3.500% 2022 Notes will mature on December 1, 2022 and have no sinking fund requirements. The 3.500% 2022 Notes may be redeemable in whole at any time or in part from time to time, at our option, prior to November 1, 2022. We may redeem the 3.500% 2022 Notes at a redemption price equal to the greater of 100% of the principal amount or the sum of the present value of the remaining scheduled principal and interest payments. The 3.500% 2022 Notes are unsecured and guaranteed by all of our consolidated subsidiaries, with the exception of Tesoro Logistics Finance Corp., the co-issuer, and are non-recourse to Marathon, except for TLGP, and contain customary terms, events of default and covenants for an issuance of investment grade securities. 6.250% Senior Notes Due 2022 In October 2014 , we issued the 6.250% 2022 Notes, which approximates the effective interest rate. The proceeds from the 6.250% 2022 Notes were used to fund a portion of the Rockies Natural Gas Business Acquisition. We used the net proceeds from the sale of 600,000 Preferred Units to primarily redeem $500 million principal amount of our 6.250% 2022 Notes. The 6.250% 2022 Notes have no sinking fund requirements. The 6.250% 2022 Notes may be redeemed at premiums equal to 3.125% through October 15, 2019; 1.563% from October 15, 2019 through October 15, 2020; and at par thereafter, plus accrued and unpaid interest. The 6.250% 2022 Notes are unsecured and guaranteed by all of our consolidated subsidiaries, with the exception of Tesoro Logistics Finance Corp., the co-issuer, and are non-recourse to Marathon, except for TLGP, and contain customary terms, events of default and covenants for an issuance of non-investment grade securities. 6.375% Senior Notes Due 2024 In May 2016 , we issued $450 million aggregate principal amount of senior notes due in 2024 (the “ 2024 Notes”) at 6.375% , which approximates the effective interest rate. We used the proceeds of the offering to repay amounts outstanding under the Revolving Credit Facility and for general partnership purposes. The 2024 Notes have no sinking fund requirements and we may redeem some or all of the 2024 Notes, prior to May 1, 2019, at a make-whole price plus accrued and unpaid interest, if any. On or after May 1, 2019, the 2024 Notes may be redeemed at premiums equal to 4.781% through May 1, 2020; 3.188% through May 1, 2021; 1.594% from May 1, 2021 through May 1, 2022; and at par thereafter, plus accrued and unpaid interest. We will have the right to redeem up to 35% of the aggregate principal amount at 106.375% face value with proceeds from certain equity issuances through May 1, 2019. The 2024 Notes are unsecured and guaranteed by all of our consolidated subsidiaries, except Tesoro Logistics Finance Corp., the co-issuer, and are non-recourse to Marathon, except for TLGP, and contain customary terms, events of default and covenants for an issuance of non-investment grade securities. 5.250% Senior Notes Due 2025 In December 2016 , we issued $750 million aggregate principal amount of the senior notes due in 2025 (the “ 2025 Notes”) at 5.250% , which approximates the effective interest rate. The proceeds from this offering were used to repay amounts outstanding under the Dropdown Credit Facility. The 2025 Notes have no sinking fund requirements. We may redeem some or all of the 2025 Notes prior to January 15, 2021, at a make-whole price, plus any accrued and unpaid interest. On or after January 15, 2021, the 2025 Notes may be redeemed at premiums equal to 2.625% through January 15, 2022; 1.313% through January 15, 2023; and at par thereafter, plus accrued and unpaid interest. We will have the right to redeem up to 35% of the aggregate principal amount at 105.250% of face value with proceeds from certain equity issuances through January 15, 2020. The 2025 Notes are unsecured and guaranteed by all of our consolidated subsidiaries, except Tesoro Logistics Finance Corp., the co-issuer, and are non-recourse to Marathon, except for TLGP, and contain customary terms, events of default and covenants for an issuance of non-investment grade securities. 4.250% Senior Notes Due 2027 In November 2017 , we issued $750 million aggregate principal amount of senior notes due in 2027 (the “ 2027 Notes”) at 4.250% , which approximates the effective interest rate. The proceeds from the 2027 Notes were used to repay a portion of our 5.875% senior notes due in 2020 and 6.125% senior notes due in 2021 , as well as borrowings under the Dropdown Credit Facility. The 2027 Notes will mature on December 1, 2027 and have no sinking fund requirement. The 2027 Notes may be redeemable in whole at any time or in part from time to time, at our option, prior to September 1, 2027. We may redeem the 2027 Notes at a redemption price equal to the greater of 100% of the principal amount or the sum of the present value of the remaining scheduled principal and interest payments as defined in the prospectus supplement. The 2027 Notes are unsecured and guaranteed by all of our consolidated subsidiaries, with the exception of Tesoro Logistics Finance Corp., the co-issuer, and are non-recourse to Marathon, except for TLGP, and contain customary terms, events of default and covenants for an issuance of investment grade securities. 5.200% Senior Notes Due 2047 In November 2017 , we issued $500 million aggregate principal amount of senior notes due in 2047 (the “ 2047 Notes”) at 5.200% , which approximates the effective interest rate. The proceeds from the 2047 Notes were used to repay a portion of our 5.875% senior notes due in 2020 and 6.125% senior notes due in 2021 , as well as borrowings under the Dropdown Credit Facility. The 2047 Notes will mature on December 1, 2047 and have no sinking fund requirements. The 2047 Notes may be redeemable in whole at any time or in part from time to time, at our option, prior to June 1, 2047. We may redeem the 2047 Notes at a redemption price equal to the greater of 100% of the principal amount or the sum of the present value of the remaining scheduled principal and interest payments as defined in the prospectus supplement. The 2047 Notes are unsecured and guaranteed by all of our consolidated subsidiaries, with the exception of Tesoro Logistics Finance Corp., the co-issuer, and are non-recourse to Marathon, except for TLGP, and contain customary terms, events of default and covenants for an issuance of investment grade securities. Capital Lease Obligations Our capital lease obligations relate to two leases of facilities used for trucking operations in North Dakota with initial terms of 15 years , with five -year renewal options, leases of vehicles and equipment and a right of way with an initial term of 31 years . The total cost of assets under capital leases was $18 million and $11 million at December 31, 2018 and 2017 , respectively, and accumulated amortization was $4 million and $3 million at December 31, 2018 and 2017 , respectively. We include the amortization of the cost of assets under capital leases in depreciation and amortization expenses in our consolidated statements of operations. Future Minimum Annual Lease Payments, Including Interest for Capital Leases (in millions) December 31, 2018 2019 $ 4 2020 3 2021 3 2022 2 2023 2 Thereafter 4 Total minimum lease payments 18 Less amount representing interest (3 ) Capital lease obligations $ 15

Benefit Plans (Notes)

Benefit Plans (Notes)	12 Months Ended
	Dec. 31, 2018
Pension and Other Postretirement Benefits Cost (Reversal of Cost) [Abstract]
Benefit Plans	Note 9 - Benefit Plans Employees supporting our operations participate in the benefit plans and the employee thrift plan of Marathon. Marathon allocates expense to us for costs associated with the benefit plans based on the salaries of Marathon’s employees that provide services to us as a percentage of total Marathon salaries. The Predecessors were allocated expenses for costs associated with the benefit plans primarily based on the percentage of the Predecessors’ allocated salaries compared to our Sponsor’s total salaries. Our portion of our Sponsor’s employee benefit plan expenses was $35 million , $34 million and $25 million for the years ended December 31, 2018 , 2017 and 2016 , respectively. These employee benefit plan expenses and the related payroll costs are included in operating expenses and general and administrative expenses in our consolidated statements of operations and include amounts allocated to the Predecessors.

Note 10 - Commitments and Conti

Note 10 - Commitments and Contingencies Commitments and Contingencies (Notes)	12 Months Ended
	Dec. 31, 2018
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Note 10 - Commitments and Contingencies Operating Leases, Purchase Obligations and Other Commitments Future Minimum Annual Payments Applicable to all Non-Cancellable Operating Leases and Purchase Obligations (in millions) Payments Due by Period 2019 2020 2021 2022 2023 Thereafter Total Purchase obligations $ 2,078 $ 2,084 $ 2,054 $ 2,013 $ 2,013 $ 1,673 $ 11,915 Operating leases 17 17 15 13 13 105 180 Total $ 2,095 $ 2,101 $ 2,069 $ 2,026 $ 2,026 $ 1,778 $ 12,095 We have various cancellable and non-cancellable operating leases related to land, trucks, terminals, right-of-way permits and other operating facilities. In general, these leases have remaining primary terms up to 26 years and typically contain multiple renewal options. Total lease expense for all operating leases, including leases with a term of one month or less, was $25 million , $19 million and $11 million for the years ended December 31, 2018 , 2017 and 2016 , respectively. See Note 8 for information related to our capital leases. See Note 3 for a discussion of revenue recognized under agreements where we are considered the lessor. Our purchase obligations include enforceable and legally binding service agreement commitments that meet any of the following criteria: (1) they are non-cancellable, (2) we would incur a penalty if the agreement was canceled or (3) we must make specified minimum payments even if we do not take delivery of the contracted products or services. If we can unilaterally terminate the agreement simply by providing a certain number of days’ notice or by paying a termination fee, we have included the termination fee or the amount that would be paid over the notice period. Contracts that can be unilaterally terminated without a penalty are not included. Future purchase obligations primarily include fuel costs associated with our wholesale product supply agreement, NGLs transportation costs, fractionation fees, and fixed charges under the Amended Omnibus Agreement and the 2019 Secondment Agreements. Our Amended Omnibus Agreement remains in effect between the applicable parties until a change in control of the Partnership. As we are unable to estimate the termination of the omnibus agreement, we have included the fees for each of the five years following December 31, 2018 for disclosure purposes in the table above. Total expense under the Amended Omnibus Agreement and the Andeavor Secondment Agreement was $311 million , $232 million and $192 million for the years ended December 31, 2018 , 2017 and 2016 , respectively. In addition to these purchase commitments, we also have minimum contractual capital spending commitments for approximately $297 million in 2019 . Indemnification Under the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement, Marathon indemnifies us for certain matters, including environmental, title and tax matters associated with the ownership of our assets at or before the closing of the Initial Offering and the subsequent acquisitions from our Sponsor. Under the Amended Omnibus Agreement, with respect to assets that we acquired from our Sponsor, excluding the Los Angeles Terminal Assets and the Los Angeles Logistics Assets, indemnification for unknown environmental and title liabilities is limited to pre-closing conditions identified prior to the earlier of the date that our Sponsor no longer controls our general partner or five years after the date of closing. Under the Amended Omnibus Agreement, the aggregate annual deductible for each type of liability (unknown environmental liabilities or title matters) is $1 million , as of December 31, 2018 , before we are entitled to indemnification in any calendar year in consideration of the Initial Offering assets and all subsequent acquisitions from our Sponsor, with the exception of the Los Angeles Terminal Assets Acquisition and the Los Angeles Logistics Assets Acquisition. In addition, with respect to the assets that we acquired from our Sponsor, we have agreed to indemnify Marathon for events and conditions associated with the ownership or operation of our assets that occur after the closing of the Initial Offering, and the subsequent acquisitions from our Sponsor, and for environmental liabilities related to our assets to the extent Marathon is not required to indemnify us for such liabilities. Under the Carson Assets Indemnity Agreement, our Sponsor retained responsibility for remediation of known environmental liabilities due to the use or operation of the Los Angeles Terminal Assets and the Los Angeles Logistics Assets prior to the acquisition dates, and has indemnified us for any losses we incurred arising out of those remediation obligations. The indemnification for unknown pre-closing remediation liabilities is limited to five years . However, with respect to Terminal 2 at the Long Beach marine terminal, which was included in the Los Angeles Logistics Assets Acquisition, the indemnification for unknown pre-closing remediation liabilities is limited to ten years . Indemnification of the Los Angeles Terminal Assets’ and the Los Angeles Logistics Assets’ environmental liabilities are not subject to a deductible. Other Contingencies In the ordinary course of business, we may become party to lawsuits, administrative proceedings and governmental investigations, including environmental, regulatory and other matters. The outcome of these matters cannot always be predicted accurately, but we will accrue liabilities for these matters if the amount is probable and can be reasonably estimated. Contingencies arising after the closing of the Initial Offering from conditions existing before the Initial Offering, and the subsequent acquisitions from our Sponsor that have been identified after the closing of each transaction, will be recorded in accordance with the indemnification terms set forth in the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement. Any contingencies arising from events after the Initial Offering, and the subsequent acquisitions from our Sponsor, will be our responsibility. Environmental Liabilities Changes in our Environmental Liabilities (in millions) Tioga Crude Oil Pipeline Release Other Liabilities Total At December 31, 2016 $ 16 $ 6 $ 22 Additions 19 1 20 Expenditures (25 ) (1 ) (26 ) At December 31, 2017 10 6 16 Additions 1 5 6 Expenditures (11 ) (5 ) (16 ) At December 31, 2018 $ — $ 6 $ 6 Resolved Matters Tioga, North Dakota Crude Oil Pipeline Release In September 2013 , we responded to the release of crude oil in a rural field northeast of Tioga, North Dakota (the “Crude Oil Pipeline Release”). This incident was covered by our pollution liability insurance policy, subject to a $1 million deductible and a $25 million loss limit in place at the time of the release. Pursuant to this policy, there were no insurance recovery receivables related to the Crude Oil Pipeline Release at both December 31, 2018 and 2017 . The remediation costs of $93 million exceeded our policy loss limit by $68 million as of December 31, 2018 . We received no insurance proceeds for the years ended December 31, 2018 , 2017 and 2016 . Other than described above, we do not have any other material outstanding lawsuits, administrative proceedings or governmental investigations. See current legal proceedings in Item 3.

Note 11 - Equity and Net Earnin

Note 11 - Equity and Net Earnings per Unit Equity and Net Earnings per Unit (Notes)	12 Months Ended
	Dec. 31, 2018
Equity [Abstract]
Equity and Net Earnings per Unit	Note 11 - Equity and Net Earnings per Unit We had 89,320,056 common public units and 600,000 preferred units outstanding as of December 31, 2018 . Additionally, as of December 31, 2018 , Marathon owned 156,173,128 of our common units, constituting a 64% ownership interest in us. Marathon also held 80,000 TexNew Mex Units and all of the outstanding non-economic general partner units as of December 31, 2018 . Unit Issuance In connection with the 2018 Drop Down, we issued 28,283,742 common units to Andeavor. In connection with the WNRL Merger, we issued 15,182,996 publicly held common units and 14,853,542 common units to subsidiaries of Andeavor. In addition, In October 2017, we issued 78,000,000 of our common units to TLGP in connection with the IDR/GP Transaction and converted our general partner units into non-economic general partner units. In February 2017, we closed a registered public offering of 5.0 million common units representing limited partner interests at a public offering price of $56.19 per unit. The net proceeds of $281 million were used to repay borrowings outstanding under our Revolving Credit Facility and for general partnership purposes. Also, general partner units of 101,980 were issued for proceeds of $6 million . In June 2016, we closed a registered public offering of 6.3 million common units, including the over-allotment option exercised by the underwriter for the purchase of an additional 825,000 common units, at a public offering price of $47.13 per unit. The net proceeds of $293 million were used for general partnership purposes, including debt repayment, acquisitions, capital expenditures and additions to working capital. Issuance of Preferred Units In December 2017, we issued and sold the Preferred Units, at a price to the public of $1,000 per unit. We used the net proceeds from the sale of the Preferred Units (i) to primarily redeem $500 million principal amount of our 6.250% 2022 Notes, (ii) to repay a portion of the borrowings under our Revolving Credit Facility and (iii) to pay fees and expenses associated with the foregoing. At any time on or after February 15, 2023 , we may redeem the Preferred Units, in whole or in part at a redemption price of $1,000 per Preferred Unit plus an amount equal to all accumulated and unpaid distributions up to, but not including, the date of redemption, whether or not declared. In addition, upon the occurrence of certain rating agency events as described in the prospectus, we may redeem the Preferred Units, in whole but not in part, at a price of $1,020 per Preferred Unit, plus an amount equal to all accumulated and unpaid distributions up to, but not including, the date of redemption, whether or not declared. Distributions on the Preferred Units will accrue and be cumulative from the original issue date of the Preferred Units and will be payable semi-annually in arrears on the 15th day of February and August of each year through and including February 15, 2023, with the first such payment made on February 15, 2018, and after February 15, 2023, quarterly in arrears on the 15th day of February, May, August, and November of each year to holders of record as of the close of business on the first business day of the month of the applicable Distribution Payment Date. If any Distribution Payment Date otherwise would fall on a day that is not a business day, declared distributions will be paid on the immediately succeeding business day without the accumulation of additional distributions. The initial distribution rate for the Preferred Units from and including the original issue date of the Preferred Units to, but not including, February 15, 2023 will be 6.875% per annum of the $1,000 liquidation preference per Preferred Unit (equal to $68.75 per Preferred Unit per annum). On and after February 15, 2023, distributions on the Preferred Units will accumulate for each distribution period at a percentage of the liquidation preference equal to the three-month LIBOR plus a spread of 4.652% . TexNew Mex Units At the effective time of the WNRL Merger, each WNRL TexNew Mex unit was automatically converted into a right to receive TexNew Mex Units, which has substantially equivalent rights and obligations as the WNRL TexNew Mex unit. Prior to any distributions of available cash to holders of common units, available cash with respect to any quarter will first be distributed to the holders of the TexNew Mex Units, pro rata, as of the record date, in an amount equal to 80% of the excess, if any, of (1) the TexNew Mex Shared Segment Distributable Cash Flow with respect to the applicable quarter over (2) the TexNew Mex Base Amount with respect to such quarter, less any amounts reserved with the consent of holders of a majority of the TexNew Mex Units in accordance with our partnership agreement. As of December 31, 2018 , we had 80,000 TexNew Mex Units outstanding. We did not separately disclose these units in the consolidated balance sheets and consolidated statements of partners’ equity because the equity balance was less than $1 million as of December 31, 2018 and 2017. No distributions to TexNew Mex unitholders were declared during 2018 or 2017. ATM Program In August 2017, we filed a prospectus supplement to our shelf registration filed with the SEC in August 2015, authorizing the continuous issuance of up to an aggregate of $750 million of common units, in amounts, at prices and on terms to be determined by market conditions and other factors at the time of our offerings (such program referred to as our “2017 ATM Program”). During the year ended December 31, 2017 , we issued an aggregate of 72,857 common units under our 2017 ATM Program, generating proceeds of $3 million before issuance costs. The net proceeds from sales under the 2017 ATM Program were used for general partnership purposes, which may include debt repayment, future acquisitions, capital expenditures and additions to working capital. There were no issuances in 2018. On August 24, 2015 , we filed a prospectus supplement to its shelf registration statement filed with the SEC in August 2015 , authorizing the continuous issuance of up to an aggregate of $750 million of common units, in amounts, at prices and on terms to be determined by market conditions and other factors at the time of our offerings (such program referred to as the “2015 ATM Program”). During the year ended December 31, 2016, we issued under both the 2015 ATM Program an aggregate of 1,492,637 common units generating proceeds of $72 million before issuance costs. Issuance of Additional Securities Our partnership agreement authorizes us to issue an unlimited number of additional partnership securities for the consideration and on the terms and conditions determined by our general partner without the approval of the unitholders. Costs associated with the issuance of securities are allocated to all unitholders’ capital accounts based on their ownership interest at the time of issuance. Net Earnings per Unit Prior to the WNRL Merger, we used the two-class method when calculating the net earnings per unit applicable to limited partners, because we had more than one participating security consisting of limited partner common units, general partner units and IDRs. Net earnings earned by the Partnership were allocated between the limited and general partners in accordance with our partnership agreement. As a result of the IDR/GP Transaction, the general partner units no longer participate in earnings or distributions, including IDRs. With the issuance of the Preferred Units, earnings are allocated first to the Preferred Units equal to their fixed distribution rate. We base our calculation of net earnings per unit using the weighted-average number of common limited partner units outstanding during the period. Net Earnings per Unit (in millions, except per unit amounts) Year Ended December 31, 2018 (a) 2017 (a) 2016 (a) Net earnings $ 600 $ 306 $ 277 Special Allocation (b) — 1 3 Net earnings, including special allocations 600 307 280 Distributions on Preferred Units (c) (41 ) (3 ) — Net earnings attributable to common units 559 304 280 General partner’s distributions — (6 ) (10 ) General partner’s IDRs (d) — (75 ) (148 ) Limited partners’ distributions on common units (890 ) (611 ) (344 ) Distributions on common units greater than earnings $ (331 ) $ (388 ) $ (222 ) General partner’s earnings: Distributions $ — $ 6 $ 10 General partners IDRs (d) — 75 148 Allocation of distributions (greater) less than earnings (e) (28 ) (44 ) (65 ) Total general partner’s earnings $ (28 ) $ 37 $ 93 Limited partners’ earnings on common units: Distributions (f) $ 890 $ 611 $ 344 Special allocation (f) — (1 ) (3 ) Allocation of distributions greater than earnings (303 ) (344 ) (157 ) Total limited partners’ earnings on common units $ 587 $ 266 $ 184 Weighted average limited partner units outstanding: Common units - basic 228.7 126.0 98.2 Common units - diluted (g) 228.9 126.1 98.2 Net earnings per limited partner unit: (h) Common - basic $ 2.57 $ 2.11 $ 1.87 Common - diluted $ 2.57 $ 2.11 $ 1.87 (a) Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion. (b) Normal allocations according to percentage interests are made after giving effect, if any, to priority income allocations in an amount equal to incentive cash distributions fully allocated to the general partner and any special allocations. The adjustment reflects the special allocation to common units held by TLGP for the interest incurred in connection with borrowings on the Dropdown Credit Facility in lieu of using cash on hand to fund the North Dakota Gathering and Processing Assets in 2017 and the Alaska Storage and Terminalling Assets acquisition in 2016 . (c) The Preferred Units entitle unitholders to receive preferred distributions on a semi-annually basis. (d) IDRs entitled the general partner to receive increasing percentages, up to 50% , of quarterly distributions in excess of $0.3881 per unit per quarter. The amount above reflects earnings distributed to our general partner net of $50 million of IDRs for the year ended December 31, 2017 waived by TLGP. Our general partner no longer holds IDRs as a result of the IDR/GP Transaction. (e) We have revised the historical allocation of general partner earnings to include the Predecessors’ losses of $28 million , $43 million and $62 million for the years ended December 31, 2018 , 2017 and 2016 , respectively. (f) Distributions of earnings for limited partners’ common units for the years ended December 31, 2018 and 2017 is net of a $60 million and $25 million waiver, respectively, from our Sponsor in connection with the WNRL Merger. (g) Diluted net earnings per unit include the effects of potentially dilutive units on our common units, which consist of unvested service and performance phantom units. (h) Amounts may not recalculate due to rounding of dollar and unit information. Allocations of the General Partner’s Interest in Net Earnings (in millions, except percentage of ownership interest) Year Ended December 31, 2018 2017 2016 Net earnings attributable to partners $ 628 $ 349 $ 339 Distributions on Preferred Units (41 ) (3 ) — General partner’s IDRs — (75 ) (148 ) Special allocation — 1 3 Net earnings available to partners $ 587 $ 272 $ 194 General partner’s ownership interest (a) — % — % 2.0 % General partner’s allocated interest in net earnings (b) $ — $ 4 $ 4 General partner’s IDRs — 75 148 Allocation of Predecessors’ impact to general partner interest (28 ) (43 ) (62 ) Total general partner’s interest in net earnings $ (28 ) $ 36 $ 90 (a) In connection with the IDR/GP Transaction, our general partner units converted into non-economic general partner units. (b) Prior to the IDR/GP Transaction, we allocated net earnings to our general partner based on its ownership interest. Changes in the Number of Units Outstanding (in million units) Common Preferred General Partner Total At December 31, 2015 93.5 — 1.9 95.4 Issuances under ATM Program 1.4 — — 1.4 Issuance of units in June 2016 for cash 6.3 — — 6.3 Issuance in July 2016 in connection with the Alaska Storage and Terminalling Assets acquisition 0.4 — 0.2 0.6 Issuance in September 2016 in connection with the Alaska Storage and Terminalling Assets acquisition 0.4 — — 0.4 Issuance in November 2016 in connection with the Northern California Terminalling and Storage Assets acquisition 0.9 — — 0.9 Unit-based compensation awards 0.1 — — 0.1 At December 31, 2016 103.0 — 2.1 105.1 Issuances under ATM Program 0.1 — — 0.1 Issuance of units in February 2017 for cash 5.0 — 0.1 5.1 Issuance in October 2017 in connection with the WNRL Merger 108.0 — — 108.0 Issuance in November 2017 in connection with the Anacortes Logistics Assets acquisition 1.0 — — 1.0 Issuance of Preferred Units in December 2017 — 0.6 — 0.6 At December 31, 2017 217.1 0.6 2.2 219.9 Issuance in August 2018 in connection with the 2018 Drop Down 28.3 — — 28.3 Unit-based compensation awards 0.1 — — 0.1 At December 31, 2018 245.5 0.6 2.2 248.3 Equity Transactions related to Acquisitions Distributions to unitholders and the general partner include $300 million , $406 million and $760 million in cash payments for Acquisitions from our Sponsor during 2018 , 2017 and 2016 , respectively. As an entity under common control with Marathon, we record the assets that we acquire from our Sponsor in our consolidated balance sheets at our Sponsor’s historical book value instead of fair value, and any difference in amounts paid compared to the historical book value of the assets acquired from our Sponsor is recorded within equity. The Acquisitions from our Sponsor resulted in net increases of $1.4 billion and $1.3 billion in our equity balance during 2018 and 2017 , respectively, and a net decrease of $443 million in our equity balance during 2016 . The 2017 increase includes $1.7 billion in basis received in connection with the WNRL Merger. Cash Distributions On January 25, 2019 , in accordance with our partnership agreement, we announced the declaration of a quarterly cash distribution, based on the results of the fourth quarter of 2018, totaling $238 million , or $1.03 per limited partner unit. This distribution was paid on February 14, 2019 to unitholders of record on February 5, 2019 . During the year ended December 31, 2018, we paid distributions associated with our Preferred Units of $29 million . During January 2019, we declared a distribution associated with our Preferred Units in the amount of $21 million , which will be paid on February 15, 2019. Our distributions are declared subsequent to quarter end; therefore, the following table represents total cash distributions applicable to the period in which the distributions are earned. Total Quarterly Cash Distributions to General and Limited Partners (in millions) Year Ended December 31, 2018 2017 2016 General partner’s distributions: General partner’s distributions $ — $ (6 ) $ (10 ) General partner’s IDRs (a) — (75 ) (148 ) Total general partner’s distributions $ — $ (81 ) $ (158 ) Limited partners’ distributions: Common $ (890 ) $ (611 ) $ (344 ) Total limited partners’ distributions (890 ) (611 ) (344 ) Total Cash Distributions $ (890 ) $ (692 ) $ (502 ) (a) As a result of the IDR/GP Transaction that occurred on October 30, 2017, our general partner no longer receives IDRs.

Note 12 - Supplemental Cash Flo

Note 12 - Supplemental Cash Flow Information	12 Months Ended
	Dec. 31, 2018
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	Note 12 - Supplemental Cash Flow Information Supplemental disclosure of cash activities includes interest paid, net of capitalized interest, of $209 million , $243 million and $165 million for the years ended December 31, 2018 , 2017 and 2016 , respectively. Supplemental Disclosures of Non-Cash Investing and Financing Activities (in millions) Year Ended December 31, 2018 2017 2016 Capital expenditures included in accounts payable at period end $ 105 $ 50 $ 30 Capital expenditures included in affiliate payable at period end — — 8 Capital leases and other — — 2 Predecessors’ net liabilities not assumed by Andeavor Logistics 13 — 22 Receivable from affiliate for capital expenditures 26 4 4

Note 13 - Revenues Revenues (No

Note 13 - Revenues Revenues (Notes)	12 Months Ended
	Dec. 31, 2018
Revenue from Contract with Customer [Abstract]
Revenues	Note 13 - Revenues We recognize revenue upon transfer of control of promised products or services to customers in an amount that reflects the consideration to which we expect to be entitled in exchange for those products or services. For the year ended December 31, 2018 , revenues from contracts with customers were $2.0 billion , which excludes lease revenues of $425 million . Upon adoption of ASC 606, revenue is recognized net of amounts collected from customers for taxes assessed by governmental authorities on, and concurrent with, specific revenue-producing transactions. Service Revenue We generate service revenue for gathering and transporting crude oil, natural gas and water; processing and fractionating natural gas and NGLs; and terminalling, transporting, and storing crude oil and refined products. We perform these services under various contractual arrangements with our customers. Under fee-based arrangements, we receive a fixed rate per volumetric unit for services we provide. For many of these fee-based arrangements, customers are required to make deficiency payments when they do not meet their minimum throughput volume commitments. Some of these contracts allow our customers to claw-back all or a portion of prior deficiency payments against excess volumes in future periods. Under keep-whole arrangements, we gather and process natural gas from producer-customers, retain and sell extracted NGLs, and return to the producer Shrink Gas with an equivalent British thermal unit content of the NGLs retained. For these arrangements, we receive from the producer a combination of fixed rate-per unit of cash consideration as well as non-cash consideration in the form of retained NGLs. Other agreements with producers consist of POP arrangements for which we gather and purchase natural gas from the producers, process purchased natural gas, and sell resulting NGLs and shrink gas at market prices. Reimbursements of certain costs and fees received under these purchase arrangements are recorded as a reduction to NGL expense. See further discussion below on our accounting for product revenues related to the sales of products resulting from our processing activities. We recognize service revenue over time, as customers simultaneously receive and consume the related benefits of the services that we stand ready to provide. Revenue is recognized using an output measure, such as the throughput volume or capacity utilization, as these measures most accurately depict the satisfaction of our performance obligations. Where contracts contain variable pricing terms, the variability is either resolved within the reporting period, or the variable consideration is allocated to the specific unit of service to which it relates. Deficiency payments under contracts with claw-back provisions are deferred and recognized as revenue as customers reclaim amounts by throughputting excess volumes. To the extent it is probable a customer will not recover all or a portion of the deficiency payment, the estimated residual deficiency is recognized ratably over the claw-back period. Payments for services rendered are generally received no later than 60 days from the month of service, with the exception of deficiency payments described above. For our keep-whole arrangements, we recognize service revenue for the fair value of non-cash consideration we receive in the form of NGLs. We obtain control of the NGLs we receive from our customers, have discretion in establishing price and have the ability to direct their use. We estimate the fair value of non-cash consideration at the date we obtain control of the respective NGLs, using the monthly average published price of underlying commodity adjusted for geography and commodity specifications. We experience volume gains and losses, which we sometimes refer to as imbalances, within our pipelines, terminals and storage facilities due to pressure and temperature changes, evaporations and variances in meter reading in other measurement methods. Some of our arrangements require us to bear losses when actual volume losses exceed a contractually specified percentage. Similarly, we receive a benefit when actual volume losses are lower than the contractually specified percentage. For gains and losses which are cash settled, we include the settlement amounts in our service revenues. We recognize non-cash consideration for the stated percentage of commodity we retain and control. We record this non-cash consideration at fair value on a gross basis in service revenue and operating expense. The total amount of service revenue and NGL expense recorded associated with these arrangements is not material to our consolidated statements of operations. Product Revenue We generate product revenue from the sale of NGLs and related products along with the sale of gasoline and diesel fuel within our wholesale business. We sell NGLs, Shrink Gas and condensate using natural gas we acquire from producers under our POP arrangements. We record revenues for the sale of these NGLs and related products at market prices, and record the payments to producers for the agreed-upon percentage of the total sales proceeds as NGL expense, net of certain charges, which is reported within costs and expenses in our consolidated statements of operations. We have certain fuel purchase and sale arrangements under which we receive minimum guaranteed margins with upside potential on a portion of our branded and unbranded fuel sales. Marathon retains control of fuel and is the principal in these affiliate arrangements. Therefore, we net the purchase and sale of fuel in our consolidated statements of operations. NGLs received under keep-whole arrangements are sold to our affiliate. In return, we receive shrink gas which we then remit to the producers. This transaction is treated as a sale, for which we record the fair value of the non-cash consideration at the date we obtain control of the shrink gas. We utilize a monthly average of the published price of the commodity, adjusted for geography. Our product sales arrangements are for specified goods for which enforceable rights and obligations are created when sales volumes are determined, which typically occurs as orders are issued or spot sales are made, but may be determined at contract inception. Each barrel, gallon or other unit of measure of product, is separately identifiable and represents a distinct performance obligation to which the transaction price is allocated based on stand-alone selling price. We use observable market prices for the products we sell to determine the stand-alone selling price of each separate performance obligation. Product revenues are recognized at a point-in-time, which generally occurs upon delivery and transfer of title to the customer. Payments for product sales are generally received within 30 days from when control has transferred. Other Arrangements Based on the terms of certain storage and other agreements in which the counterparty is primarily our Sponsor, we are considered to be the lessor under these implicit operating lease arrangements. Income from these leases is excluded from the scope of the new revenue standard. Customer Contract Assets Our receivables are primarily associated with customer contracts. Our payment terms vary by product or service type, and the period between invoicing and payment is not significant. Included in our receivables are balances associated with commodity sales on behalf of our producer customers, for which we remit the net sales price back to the producer customers upon completion of each sale. These balances are commingled in our receivables, net of allowance for doubtful accounts in our consolidated balance sheets. Our contract assets include amounts recognized for deficiency payments associated with minimum volume commitments which have not been billed to customers. These contract assets are included in prepayments and other current assets in our consolidated balance sheets and are shown in the “Summary of Customer Contract Assets and Liabilities” table below. Customer Contract Liabilities For certain products or services, we receive payment in advance of when performance obligations are satisfied. These liabilities from contracts with customers consist primarily of certain deficiency payments for minimum volume commitments and customer reimbursements of costs for capital projects. Customer advances for capital projects are generally recognized over the contract term. We do not have a material impact for financing components associated with these customer advances. Payments for minimum volume commitments and other customer advances are included in deferred income within other current liabilities and other noncurrent liabilities based on timing of expected recognition, which generally extend up to 15 years . During the year ended December 31, 2018 , we recognized $29 million in revenue from contract liabilities existing as of January 1, 2018, after cumulative adjustments for the adoption of ASC 606. Summary of Customer Contract Assets and Liabilities (in millions) December 31, 2017 (a) Adjustments for ASC 606 (b)(c) Balance at January 1, 2018 December 31, Contract assets — 34 34 32 Deferred income, current 23 — 23 24 Deferred income, noncurrent 43 16 59 57 (a) Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion. (b) These amounts exclude balances associated with equity method investments. We recognized a cumulative adjustment of $3 million as a decrease to Equity Method Investments in our consolidated balance sheets as of January 1, 2018 for the impacts related to our equity method investment in TRG. There were no material impacts to this balance during the year ended December 31, 2018 due to the adoption. (c) Included in the $34 million change to contract assets is a $32 million reclass from Receivables for amounts for which we were not allowed to invoice as of January 1, 2018. Remaining Performance Obligations We do not disclose the value of unsatisfied performance obligations for contracts with original expected terms of one year or less or the value of variable consideration related to unsatisfied performance obligations, when such values are not required to be estimated for purposes of allocation and recognition. Revenues associated with remaining obligations under contracts with terms in excess of one year related primarily to arrangements for which the customer has agreed to fixed consideration based on minimum throughput volume commitments or capacity utilization. As of December 31, 2018 , we had $4.0 billion of expected revenues from remaining performance obligations. The future revenues from our service arrangements with fixed fees or minimum throughput volume commitments will be recognized over the period of performance to which the fixed fee or commitment relates, which generally ranges from 1 year to 15 years . We expect approximately 85% of our total remaining obligations to be recognized within 5 years . Disaggregation We disaggregate our revenues by product and services, and further by product line. For additional information regarding our operating segments, see Note 14 . Revenue Disaggregation by Type and Product Line (in millions) Year Ended December 31, 2018 Terminalling and Transportation (a) Gathering and Processing (a) Wholesale Service Revenues (b) Refined products $ 898 $ — $ 17 Crude oil and water 153 438 — Natural gas — 391 — Other 3 — — Total Service Revenues 1,054 829 17 Product Revenues NGL products — 434 — Refined products — — 46 Total Product Revenues — 434 46 Total Revenues $ 1,054 $ 1,263 $ 63 (a) Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion. (b) Includes $425 million of lease revenues for the year ended December 31, 2018 .

Operating Segments (Notes)

Operating Segments (Notes)	12 Months Ended
	Dec. 31, 2018
Segment Reporting, Disclosure of Entity's Reportable Segments [Abstract]
Operating Segments	Note 14 - Operating Segments Our revenues are derived from three operating segments: Terminalling and Transportation, Gathering and Processing and Wholesale. Refer to Note 1 for discussion of the operations included within each of our operating segments. We evaluate the performance of our segments based primarily on segment operating income and EBITDA. For the purposes of our operating segment disclosure, we present operating income as it is the most comparable measure to the amounts presented in our statements of consolidated operations. Segment operating income includes those revenues and expenses that are directly attributable to management of the respective segment. Certain general and administrative expenses, interest and financing costs and equity in earnings of equity method investments are excluded from segment operating income as they are not directly attributable to a specific operating segment. Identifiable assets are those used by the segment, whereas other assets are principally cash, deposits and other assets that are not associated with a specific operating segment. Segment Information (in millions) Year Ended December 31, 2018 (a) 2017 (a) 2016 (a) Revenues Terminalling and Transportation: Terminalling $ 888 $ 690 $ 480 Pipeline transportation 160 130 125 Other revenues 6 18 — Total Terminalling and Transportation 1,054 838 605 Gathering and Processing: NGL sales 436 369 103 Gas gathering and processing 330 333 264 Crude oil and water gathering 336 262 582 Pass-thru and other 161 165 115 Total Gathering and Processing 1,263 1,129 1,064 Wholesale: Fuel sales (b) 46 1,267 — Other wholesale 33 15 — Total Wholesale 79 1,282 — Intersegment wholesale revenues (16 ) — — Total Segment Revenues $ 2,380 $ 3,249 $ 1,669 Segment Operating Income Terminalling and Transportation $ 498 $ 397 $ 240 Gathering and Processing 310 245 235 Wholesale 27 15 — Total Segment Operating Income 835 657 475 Unallocated general and administrative expenses (39 ) (54 ) (27 ) Operating Income 796 603 448 Interest and financing costs, net (233 ) (330 ) (195 ) Equity in earnings of equity method investments 31 22 13 Other income, net 6 11 11 Net Earnings $ 600 $ 306 $ 277 Depreciation and Amortization Expense Terminalling and Transportation $ 144 $ 117 $ 95 Gathering and Processing 213 191 138 Wholesale 11 5 — Total Depreciation and Amortization Expense $ 368 $ 313 $ 233 Capital Expenditures Terminalling and Transportation $ 205 $ 188 $ 193 Gathering and Processing 545 175 119 Wholesale 1 — — Total Capital Expenditures $ 751 $ 363 $ 312 (a) Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion. (b) The presentation of wholesale fuel sales was impacted by adoption of ASC 606 on January 1, 2018. Beginning January 1, 2018, the revenues and costs associated with our fuel purchase and supply arrangements were netted. Total Identifiable Assets by Operating Segment (in millions) December 31, 2018 2017 (a) Identifiable Assets Terminalling and Transportation $ 3,458 $ 3,045 Gathering and Processing 6,488 6,006 Wholesale 255 342 Other 94 112 Total Identifiable Assets $ 10,295 $ 9,505 (a) Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

Note 15 - Quarterly Financial D

Note 15 - Quarterly Financial Data (Unaudited)	12 Months Ended
	Dec. 31, 2018
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Data (Unaudited)	Note 15 - Quarterly Financial Data (Unaudited) Quarters First Second Third Fourth Total Year 2018 (a) (In millions, except per unit amounts) Revenues $ 546 $ 569 $ 642 $ 623 $ 2,380 NGL expense (b) 48 45 73 40 206 Operating expenses 201 221 236 227 885 Operating income 177 180 215 224 796 Net earnings 131 132 166 171 600 Limited partners' interest in net earnings 125 138 160 161 584 Net earnings per limited partner unit (c): Common - basic $ 0.59 $ 0.63 $ 0.68 $ 0.66 $ 2.57 Common - diluted $ 0.59 $ 0.63 $ 0.68 $ 0.66 $ 2.57 2017 (a) Revenues $ 427 $ 614 $ 1,094 $ 1,114 $ 3,249 Cost of fuel and other (b)(d) — 162 554 528 1,244 NGL expense (b) 59 56 64 86 265 Operating expenses 142 171 199 179 691 Operating income 131 146 147 179 603 Net earnings 73 90 90 53 306 Limited partners' interest in net earnings (c) 55 70 97 47 267 Net earnings per limited partner unit (c): Common - basic $ 0.51 $ 0.63 $ 0.90 $ 0.25 $ 2.11 Common - diluted $ 0.51 $ 0.63 $ 0.90 $ 0.25 $ 2.11 (a) Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion. (b) Excludes direct operating expenses incurred across our operating segments and depreciation and amortization expenses. (c) The sum of four quarters may not equal annual results due to rounding or the quarterly number of units outstanding. (d) Due to the adoption of ASC 606 effective January 1, 2018, the revenues and costs associated with our fuel purchase and supply arrangements for the year ended December 31, 2018 were netted. See Note 1 for further discussion.

Organization and Basis of Pre_2

Organization and Basis of Presentation (Policies)	12 Months Ended
	Dec. 31, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Principles of Consolidated and Basis of Presentation, Policy	Principles of Consolidation and Basis of Presentation The accompanying consolidated financial statements include the accounts of Andeavor Logistics and its subsidiaries. All intercompany accounts and transactions have been eliminated. We have evaluated subsequent events through the filing of this Form 10-K. Any material subsequent events that occurred during this time have been properly recognized or disclosed in our financial statements. We have not reported comprehensive income due to the absence of items of other comprehensive income in the years presented. In 2018 , 2017 and 2016 , we entered into various transactions with our Sponsor and our general partner, TLGP, pursuant to which we acquired from our Sponsor the following: • gathering, storage and transportation assets in the Permian Basin; legacy Western Refining assets and associated crude terminals; the majority of our Sponsor’s remaining refining terminalling, transportation and storage assets; and equity method investments in ALRP, MPL and PNAC on August 6, 2018. In addition, the Conan Crude Oil Gathering System and LARIP were transferred at cost plus incurred interest; • crude oil, feedstock and refined products storage, the Anacortes marine terminal, a manifest rail facility and crude oil and refined products pipelines located in Anacortes, Washington on November 8, 2017; • logistic assets owned by WNRL, which consisted of pipelines, gathering, terminalling, storage, transportation and wholesale fuel distribution assets effective October 30, 2017; • tankage, refined product storage, marine terminal terminalling and storage assets, pipelines, causeway and ancillary equipment located in Martinez, California (the “Northern California Terminalling and Storage Assets”) effective November 21, 2016 ; and • all of the limited liability company interests in Tesoro Alaska Terminals, LLC, tankage, bulk tank farm, a truck rack and rail-loading facility, terminalling and other storage assets located in Kenai, Anchorage and Fairbanks, Alaska (the “Alaska Storage and Terminalling Assets”) completed in two stages on July 1, 2016 and September 16, 2016. These transactions are collectively referred to as “Acquisitions from our Sponsor” and the related assets, liabilities and results of the operations are collectively referred to as the “Predecessors.” The Acquisitions from our Sponsor were transfers between entities under common control. As an entity under common control with our Sponsor, we record the assets that we acquired from our Sponsor on our consolidated balance sheet at our Sponsor’s historical basis instead of fair value. Transfers of businesses between entities under common control are accounted for as if the transfer occurred at the beginning of the period, and prior periods are retrospectively adjusted to furnish comparative information. Accordingly, the accompanying financial statements and related notes of Andeavor Logistics have been retrospectively adjusted to include the historical results of the assets acquired in the Acquisitions from our Sponsor prior to the effective date of each acquisition. The acquisition of logistics assets located in Anacortes, Washington in 2017 was immaterial to our consolidated financial statements. While this acquisition is a common control transaction, prior periods have not been retrospectively adjusted as these assets do not constitute a business in accordance with ASU 2017-01, “Clarifying the Definition of a Business”. See Note 2 for additional information regarding the 2018 , 2017 and 2016 acquisitions. The accompanying financial statements and related notes present the combined financial position, results of operations, cash flows and equity of our Predecessors at historical cost. The financial statements of our Predecessors have been prepared from the separate records maintained by our Sponsor and may not necessarily be indicative of the conditions that would have existed or the results of operations if our Predecessors had been operated as an unaffiliated entity. Other than WNRL and certain assets acquired from the 2018 Drop Down, our Predecessors did not record revenue for transactions with our Sponsor. Accordingly, the revenues in our Predecessors’ historical combined financial statements relate only to amounts received from third parties for these services.
Use of Estimates, Policy	Use of Estimates We prepare our consolidated financial statements in conformity with accounting principles generally accepted in the United States of America, which requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and revenues and expenses reported and presented as of and for the periods ended. We review our estimates on an ongoing basis using currently available information. Changes in facts and circumstances may result in revised estimates and actual results could differ from those estimates.
Cash and Cash Equivalents, Policy	Cash and Cash Equivalents Cash and cash equivalents include bank deposits and low-risk, short-term investments with original maturities of three months or less at the time of purchase. Cash equivalents are stated at cost, which approximates market value. We place our cash deposits and temporary cash investments with high credit quality financial institutions. At times, our cash and cash equivalents may be uninsured or in deposit accounts that exceed the Federal Deposit Insurance Corporation insurance limit. We had no cash and cash equivalents held in money market funds.
Receivables, Policy	Receivables A portion of the Partnership’s accounts receivable is due from our Affiliates. Credit for non-affiliated customers is extended based on an evaluation of each customer’s financial condition and in certain circumstances, collateral, such as letters of credit or guarantees, is required. Our allowance for doubtful accounts is based on various factors including current sales amounts, historical charge-offs and specific accounts identified as high risk. After reasonable efforts to collect the amounts have been exhausted, balances are deemed uncollectible and are charged against the allowance for doubtful accounts. Write-offs were immaterial in 2018 , 2017 and 2016 . We do not have any off-balance-sheet credit exposure related to our customers.
Property, Plant and Equipment, Policy	Property, Plant and Equipment Property, plant and equipment are stated at the lower of historical cost less accumulated depreciation or fair value, if impaired. We capitalize all construction-related direct labor and material costs, as well as indirect construction costs. Indirect construction costs include general engineering and other allocated employee costs. Costs, including complete asset replacements and enhancements or upgrades that increase the original efficiency, productivity or capacity of property, plant and equipment, are also capitalized. The costs of repairs, minor replacements and maintenance projects that do not increase the original efficiency, productivity or capacity of property, plant and equipment are expensed as incurred. We capitalize interest as part of the cost of major projects during the construction period. Capitalized interest totaled $13 million , $8 million and $6 million for 2018 , 2017 and 2016 , respectively, and is recorded as a reduction to net interest and financing costs in our consolidated statements of operations. We compute depreciation of property, plant and equipment using the straight-line method, based on the estimated useful life and salvage value of each asset. When assets are placed into service, we make estimates with respect to their useful lives that we believe are reasonable. However, factors such as maintenance levels, economic conditions impacting the demand for these assets and regulatory or environmental requirements could cause us to change our estimates, thus impacting the future calculation of depreciation. We depreciate leasehold improvements and property acquired under capital leases over the lesser of the lease term or the economic life of the asset. Depreciation expense totaled $310 million , $262 million and $202 million for 2018 , 2017 and 2016 , respectively. When items of property, plant and equipment are sold or otherwise disposed of, any gains or losses are reported in net income. Gains on the disposal of property, plant and equipment are recognized when earned, which is generally at the time of closing. If a loss on disposal is expected, such losses are recognized when the assets are classified as held for sale.
Asset Retirement Obligations, Policy	Asset Retirement Obligations We record AROs at fair value in the period in which we have a legal obligation to incur costs, whether by government action or contractual arrangement, to retire a tangible asset and can make a reasonable estimate of the fair value of the liability. AROs are calculated based on the present value of the estimated removal and other closure costs using our credit-adjusted risk-free rate given an estimated settlement date for the obligation. We estimate settlement dates by considering our past practice, industry practice, management’s intent and estimated economic lives. We cannot currently estimate the fair value for certain potential AROs primarily because we cannot estimate settlement dates (or range of dates) associated with these assets. These AROs include, but are not limited to, the removal or dismantlement of terminal facilities, pipelines and other buildings. AROs included in our consolidated balance sheets were $10 million and $11 million at December 31, 2018 and 2017 , respectively.
Acquired Intangibles, Policy	Acquired Intangibles and Goodwill Acquired intangibles are recorded at fair value as of the date acquired and consist of customer relationships obtained in connection with the acquisitions of WNRL, the North Dakota Gathering and Processing Assets, and Andeavor Field Services, LLC, (the “Rockies Natural Gas Business Acquisition”). The value for the identified customer relationships consists of cash flow expected from existing contracts and future arrangements from the existing customer base. We amortize acquired intangibles with finite lives on a straight-line basis over an estimated weighted average useful life of 31 years and we include the amortization in depreciation and amortization expenses on our consolidated statements of operations.
Goodwill, Policy	Goodwill represents the amount the purchase price exceeds the fair value of net assets acquired in a business combination. We do not amortize goodwill or indefinite-lived intangible assets. The goodwill recorded for the acquisition of WNRL represents goodwill recognized by our Sponsor. Goodwill represents future organic growth opportunities, anticipated synergies and intangible assets that did not qualify for separate recognition. We are required, however, to review goodwill and indefinite-lived intangible assets for impairment annually, or more frequently if events or changes in business circumstances indicate that the asset might be impaired. In such circumstances, we record the impairment in loss on asset disposals and impairments in our consolidated statements of operations. We review the recorded value of goodwill for impairment on November 1 st of each year, or sooner if events or changes in circumstances indicate the carrying amount may exceed fair value using qualitative and/or quantitative assessments at the reporting level. There were no impairments of goodwill during the years ended December 31, 2018 , 2017 and 2016 .
Impairment of Long-Lived Assets, Policy	Impairment of Long-Lived Assets We review property, plant and equipment and other long-lived assets, including acquired intangibles with finite lives, for impairment whenever events or changes in business circumstances indicate the net book values of the assets may not be recoverable. Impairment is indicated when the undiscounted cash flows estimated to be generated by those assets are less than the assets’ net book value. If this occurs, an impairment loss is recognized for the difference between the asset fair value and net book value. Factors that indicate potential impairment include: a significant decrease in the market value of the asset, operating or cash flow losses associated with the use of the asset and a significant change in the asset’s physical condition or use.
Investment in Equity Method Investments, Policy	Equity Method Investments and Joint Ventures For equity investments that are not required to be consolidated under the variable interest model, we evaluate the level of influence we are able to exercise over an entity’s operations to determine whether to use the equity method of accounting. We use equity method of accounting when we are able to have significant influence over an entity’s operations. Our judgment regarding the level of control over an equity method investment includes considering key factors such as our ownership interest, participation in policy-making and other significant decisions and material intercompany transactions. Amounts recognized for equity method investments are included in other noncurrent assets in our consolidated balance sheets and adjusted for our share of the net earnings or losses of the investee, which are presented separately in our statements of consolidated operations, capital contributions made and cash dividends received. We evaluate our equity method investments for impairment whenever events or changes in circumstances indicate that the carrying amounts of such investments may be impaired. An impairment loss is recorded in earnings in the current period to write down the carrying value of the investment to fair value if a decline in the value of an equity method investment is determined to be other than temporary. There were no impairments of our equity method investments during the years ended December 31, 2018 , 2017 and 2016 .
Financial Instruments, Policy	Financial Instruments Financial instruments including cash and cash equivalents, receivables, accounts payable and accrued liabilities are recorded at their carrying value. We believe the carrying value of these financial instruments approximates fair value. Our fair value assessment incorporates a variety of considerations, including the short-term duration of the instruments and the expected future insignificance of bad debt expense, which includes an evaluation of counterparty credit risk. The fair value of our senior notes is based on prices from recent trade activity and is categorized in level 2 of the fair value hierarchy. The carrying value and fair value of our debt were $5.0 billion and $4.9 billion at December 31, 2018 , respectively, and were $4.2 billion and $4.3 billion at December 31, 2017 , respectively. These carrying and fair values of our debt do not consider the unamortized issuance costs, which are netted against our total debt.
Income Taxes, Policy	Income Taxes We are a limited partnership and, with the exception of three of our subsidiaries, are not subject to federal or state income taxes. Our taxable income or loss is included in the federal and state income tax returns of our partners. Taxable income may vary substantially from income or loss reported for financial reporting purposes due to differences in the tax bases and financial reporting bases of assets and liabilities, and due to certain taxable income allocation requirements of the partnership agreement. We are unable to readily determine the net difference in the bases of our assets and liabilities for financial and tax reporting purposes because individual unitholders have different investment bases depending upon the timing and price of acquisition of their partnership units.
Environmental Matters, Policy	Contingencies Environmental Matters We are subject to federal, state and local laws and regulations governing environmental quality and pollution control. These laws and regulations require us to remove or remedy the effect of the disposal or release of specified substances at current and former operating sites. Our environmental liabilities are estimates using internal and third-party assessments and available information to date. It is possible these estimates will change as additional information becomes available. We capitalize environmental expenditures that extend the life or increase the capacity of facilities as well as expenditures that prevent environmental contamination. We expense costs that relate to an existing condition caused by past operations and that do not contribute to current or future revenue generation. We record liabilities when environmental assessments and/or remedial efforts are probable and can be reasonably estimated. Cost estimates are based on the expected timing and the extent of remedial actions required by governing agencies, experience gained from similar sites for which environmental assessments or remediation have been completed, and the amount of our anticipated liability considering the proportional liability and financial abilities of other responsible parties. Certain of our environmental liabilities, specific to long-term monitoring costs we believe are fixed and determinable, are recorded on a discounted basis. Where the available information is sufficient to estimate the amount of liability, that estimate is used. Where the information is only sufficient to establish a range of probable liability and no point within the range is more likely than another, the lower end of the range is used. Possible recoveries of some of these costs from other parties are not recognized in the financial statements until they become probable. Legal costs associated with environmental remediation are included as part of the estimated liability. The majority of our environmental liabilities are recorded on an undiscounted basis.
Legal Matters, Policy	Legal Matters In the ordinary course of business, we become party to lawsuits, administrative proceedings and governmental investigations. These matters may involve large or unspecified damages or penalties that may be sought from us and may require years to resolve. We record a liability related to a loss contingency attributable to such legal matters in other current liabilities or other noncurrent liabilities on our consolidated balance sheets, depending on the classification as current or noncurrent if we determine the loss to be both probable and estimable. The liability is recorded for an amount that is management’s best estimate of the loss, or when a best estimate cannot be made, the minimum loss amount of a range of possible outcomes.
Acquisitions, Policy	Acquisitions We use the acquisition method of accounting for the recognition of assets acquired and liabilities assumed with acquisitions at their estimated fair values as of the date of acquisition, with the exception of the Acquisitions from our Sponsor. As an entity under common control with our Sponsor, we record the assets that we acquired from our Sponsor on our consolidated balance sheet at our Sponsor’s historical basis instead of fair value. Any excess consideration transferred over the estimated fair values of the identifiable net assets acquired from third parties is recorded as goodwill. While we use our best estimates and assumptions to measure the fair value of the identifiable assets acquired and liabilities assumed at the acquisition date, our estimates are inherently uncertain and subject to refinement. As a result, during the measurement period, not to exceed one year from the date of acquisition, any changes in the estimated fair values of the net assets recorded for the acquisitions will result in an adjustment to goodwill. Upon the conclusion of the measurement period or final determination of the values of assets acquired or liabilities assumed, whichever comes first, any subsequent adjustments are recorded to our consolidated statements of operations. Our acquisitions are discussed further in Note 2 .
Reimbursements, Policy	Reimbursements Pursuant to the Amended Omnibus Agreement and Carson Assets Indemnity Agreement, our Sponsor reimburses the Partnership for pressure testing, required repairs and maintenance identified as a result of the first inspection of certain pipeline and tank assets subsequent to the Acquisitions from our Sponsor, as well as maintenance projects identified in the Amended Omnibus Agreement for which the costs were not known at the date of the Acquisitions from our Sponsor. These amounts are recorded as a reduction to operating expense during the period the costs are incurred. These amounts were $15 million , $16 million and $17 million for the years ended December 31, 2018 , 2017 and 2016 , respectively. In addition, our Sponsor reimburses the Partnership for capital projects identified in the Amended Omnibus Agreement. These amounts are recorded as a capital contribution by affiliate and were $51 million , $34 million and $29 million for the years ended December 31, 2018 , 2017 and 2016 , respectively.
Imbalances, Policy	Imbalances We experience volume gains and losses, which we sometimes refer to as imbalances, within our pipelines, terminals and storage facilities due to pressure and temperature changes, evaporation and variances in meter readings and in other measurement methods. On our crude oil gathering and transportation system in North Dakota and Montana (the “High Plains System”), we retain 0.20% of the crude oil shipped on our owned and operated common carrier pipelines in North Dakota and Montana and we bear any crude oil volume losses in excess of that amount. Under the Second Amended and Restated Master Terminalling Service Agreement, we retain 0.25% of the refined products we handle at certain of our terminals for Marathon, and bear any refined product volume losses in excess of that amount. The value of any crude oil or refined product imbalance settlements resulting from these tariffs or contractual provisions is determined by using the monthly average market prices for the applicable commodity, less a specified discount. The Partnership measures volume losses annually for the terminals and pipelines in the Northwest Pipeline System. We retain 0.125% of the distillates and 0.25% of the other refined products we handle at our terminals on the Northwest Pipeline System and we bear any refined product volume losses in excess of those amounts. The value of any refined product losses is determined by using the annual average market price for the applicable commodity. Any settlements under tariffs or contractual provisions where we bear any crude oil or refined product volume losses are recognized in the period they are realized. There are pipeline loss allowance provisions associated with the pipeline agreements acquired in the WNRL Merger. There is a 0.20% pipeline loss allowance for the crude oil shipped on these pipeline systems. Each month we invoice our Sponsor for 0.20% of the volume delivered to us by our Sponsor for the month as a volume loss at a price equal to that month's calendar day average for WTI crude oil, as quoted on the New York Mercantile Exchange, less $8.00 per barrel. Following the end of the month, we calculate the actual volume loss and provide a credit to our Sponsor for the amount of actual volume loss at a price equal to the month's calendar day average for WTI crude oil, as quoted on the New York Mercantile Exchange, less $8.00 per barrel. For all of our other terminals, and under our other commercial agreements with our Sponsor, we have no obligation to measure volume losses and have no liability for physical losses. The consolidated balance sheets also include offsetting natural gas imbalance receivables or payables resulting from differences in gas volumes received by customers and gas volumes delivered to interstate pipelines. Natural gas volumes owed to or by the Partnership that are subject to tariffs are valued at market index prices, as of the balance sheet dates, and are subject to cash settlement procedures. Other natural gas volumes owed to or by the Partnership are valued at our weighted average cost of natural gas as of the balance sheet dates and are settled in-kind.
Cost of Sales, Policy	Cost Classification Cost of fuel and other includes the purchase cost of refined products sold within our Wholesale segment and the cost of inbound transportation and distribution costs incurred to transport product to our customers. NGL expense results from the cost of NGL purchases under our POP arrangements as well as the non-cash acquisition of replacement dry gas under our keep-whole arrangements associated with the acquired crude oil, natural gas and produced water gathering systems and two natural gas processing facilities from the North Dakota Gathering and Processing Assets. Operating expenses are comprised of direct operating costs including costs incurred for direct labor, repairs and maintenance, outside services, chemicals and catalysts, utility costs, including the purchase of electricity and natural gas used by our facilities, property taxes, environmental compliance costs related to current period operations, rent expense and other direct operating expenses incurred in the provision of services. Depreciation and amortization expenses consist of the depreciation and amortization of property, plant and equipment, deferred charges and intangible assets related to our operating segments along with our corporate operations. General and administrative expenses represent costs that are not directly or indirectly related to or otherwise are not allocated to our operations. Cost of fuel and other, NGL expense, direct operating expenses, and depreciation and amortization expenses recognized by our Terminalling and Transportation, Gathering and Processing, and Wholesale segments (refer to amounts disclosed in Note 14 ) constitute costs of revenue as defined by U.S. GAAP.
Unit-based Compensation, Policy	Unit-Based Compensation Our general partner provides unit-based compensation to officers and non-employee directors for the Partnership, which includes service and performance phantom unit awards. The fair value of our service phantom unit awards on the date of grant is equal to the market price of our common units. We estimate the grant date fair value of performance phantom unit awards using a Monte Carlo simulation at the inception of the award. We amortize the fair value over the vesting period using the straight-line method. The phantom unit awards are settled in Andeavor Logistics common units. Expenses related to unit-based compensation are included in general and administrative expenses in our consolidated statements of operations. Total unit-based compensation expense totaled $9 million for the years ended December 31, 2018 and 2017 and $6 million for the year ended December 31, 2016 . The Partnership had 943,466 units available for future grants under the long-term incentive plan at December 31, 2018 .
Net Earnings per Limited Partner Unit, Policy	Net Earnings per Limited Partner Unit Effective October 30, 2017, we closed the WNRL Merger. Prior to the WNRL Merger, we used the two-class method when calculating the net earnings per unit applicable to limited partners, because we had more than one participating security consisting of limited partner common units, general partner units and IDRs. Net earnings earned by the Partnership were allocated between the limited and general partners in accordance with our partnership agreement. However, as a result of the IDR/GP Transaction in October 2017, our general partner and its IDRs no longer participate in earnings or distributions. See Note 2 for additional information regarding the WNRL Merger. We base our calculation of net earnings per limited partner common unit on the weighted average number of common limited partner units outstanding during the period. Diluted net earnings per unit includes the effects of potentially dilutive units on our common units, which consist of unvested service and performance phantom units.
New Accounting Standards and Disclosures, Policy	New Accounting Standards and Disclosures Revenue Recognition In May 2014, the FASB issued ASC 606 to replace existing revenue recognition rules with a single comprehensive model to use in accounting for revenue arising from contracts with customers. Under ASC 606, revenue is recognized when a customer obtains control of promised goods or services for an amount that reflects the consideration the entity expects to receive in exchange for those goods or services. In addition, ASC 606 requires expanded disclosure of the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. We adopted ASC 606 on January 1, 2018 utilizing the modified retrospective method. We recognized a $17 million reduction to the opening balance of partners’ equity as of January 1, 2018 for the cumulative effect adjustment related to contracts in process but not substantially complete as of that date. We reflected the aggregate impact of all modifications executed and effective as of January 1, 2018 in applying the new standard to these contracts. The cumulative effect adjustment is primarily related to the period over which revenue is recognized on contracts for which customers pay minimum throughput volume commitments and claw-back provisions apply. Additionally, upon the adoption of ASC 606, the gross versus net presentation of certain contractual arrangements and taxes has changed as further described in Note 13 . The current period results and balances are presented in accordance with ASC 606, while comparative periods continue to be presented in accordance with the accounting standards in effect for those periods. For the year ended December 31, 2018 , we recorded lower revenues of $2.6 billion and lower costs and expenses of $2.6 billion for presentation impacts of applying ASC 606. These impacts were primarily associated with the netting of revenues and costs associated with our fuel purchase and supply arrangements, as further described in Note 13 . We recorded lower revenues of $6 million primarily associated with minimum volume commitments during the year ended December 31, 2018 as a result of applying the new standard. There were no material impacts during the period to the consolidated balance sheets or consolidated statement of consolidated cash flows, as a result of the adoption. Leases In February 2016, the FASB issued ASU 2016-02, “Leases” (“ASU 2016-02”) to record virtually all leases on the balance sheet. The ASU 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 guidance is effective for fiscal years beginning after December 15, 2018, and interim periods within those years. We transitioned to the new guidance by recording leases on our balance sheet as of January 1, 2019. We evaluated the impact of this standard on our financial statements, disclosures, internal controls and accounting policies. This evaluation process included 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 implemented a third-party supported lease accounting information system to account for our lease population in accordance with this new standard and established internal controls over the new system. We completed the design and testing of the new system and completed lease data loading and testing. We expect that adoption of the standard will result in the recognition of additional ROU assets and lease liabilities for operating leases in the range of approximately $115 million to $145 million . Credit Losses In June 2016, the FASB issued ASU 2016-13, “Measurement of Credit Losses on Financial Instruments” (“ASU 2016-13”), which amends guidance on the impairment of financial instruments. The ASU requires the estimation of credit losses based on expected losses and provides for a simplified accounting model for purchased financial assets with credit deterioration. ASU 2016-13 is effective for annual reporting periods beginning after December 15, 2019, and interim reporting periods within those annual reporting periods. Early adoption is permitted for annual reporting periods beginning after December 15, 2018. While we are still evaluating the impact of ASU 2016-13, we do not expect to early adopt ASU 2016-13 nor expect the adoption of this standard to have a material impact on our consolidated financial statements. Restricted Cash In November 2016, the FASB issued ASU 2016-18, "Restricted Cash" (“ASU 2016-18”), which clarifies how restricted cash and restricted cash equivalents are presented in the statements of cash flows. The ASU requires that changes in restricted cash that result from transfers between cash, cash equivalents and restricted cash should not be presented as cash flow activities in the statements of cash flows. ASU 2016-18 was effective for annual reporting periods beginning after December 15, 2017, and interim reporting periods within those annual reporting periods. We adopted ASU 2016-08 as of January 1, 2018 on a retrospective basis. Adoption of this standard resulted in an increase in cash and cash equivalents during the second quarter of 2017 of $14 million , but the restriction was released during the third quarter of 2017 as the cash was used to reinvest in assets used in our business and as a payment of debt. As a result, the adoption of this standard did not have an impact on our consolidated statement of cash flows for the year ended December 31, 2018 . Pension and Postretirement Costs In March 2017, the FASB issued ASU 2017-07, “Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost” (“ASU 2017-07”), which requires the current service-cost component of net benefit costs to be presented similarly with other current compensation costs for related employees on the statement of consolidated operations and stipulates that only the service cost component of net benefit cost is eligible for capitalization. Additionally, the Partnership will present other components of net benefit costs elsewhere on the consolidated statements of operations since these costs are allocated to the Partnership’s financial statements by Marathon. The amendments to the presentation of the consolidated statements of operations in this update should be applied retrospectively while the change in capitalized benefit cost is to be applied prospectively. We adopted ASU 2017-07 as of January 1, 2018. Adoption of the standard resulted in an increase to interest and financing costs of $7 million with a corresponding increase to other income of $7 million for the year ended December 31, 2017 with no impact to net earnings. ASU 2017-07 does not impact the consolidated balance sheets or consolidated statements of cash flows. Stock Compensation In June 2018, the FASB issued ASU 2018-07, “Improvements to Nonemployee Share-Based Payment Accounting,” which expands the scope of Topic 718 to include share-based payment awards to nonemployees and eliminates the classification differences for employee and nonemployee share-based payment awards. This guidance is effective for interim and annual periods beginning after December 15, 2018. We do not expect the adoption of this standard to have a material impact on our consolidated financial statements.

Note 13 - Revenues Revenues (Po

Note 13 - Revenues Revenues (Policies)	12 Months Ended
	Dec. 31, 2018
Revenue from Contract with Customer [Abstract]
Revenue Recognition, Policy	We recognize revenue upon transfer of control of promised products or services to customers in an amount that reflects the consideration to which we expect to be entitled in exchange for those products or services. For the year ended December 31, 2018 , revenues from contracts with customers were $2.0 billion , which excludes lease revenues of $425 million . Upon adoption of ASC 606, revenue is recognized net of amounts collected from customers for taxes assessed by governmental authorities on, and concurrent with, specific revenue-producing transactions.
Revenue Recognition, Sales of Services	Service Revenue We generate service revenue for gathering and transporting crude oil, natural gas and water; processing and fractionating natural gas and NGLs; and terminalling, transporting, and storing crude oil and refined products. We perform these services under various contractual arrangements with our customers. Under fee-based arrangements, we receive a fixed rate per volumetric unit for services we provide. For many of these fee-based arrangements, customers are required to make deficiency payments when they do not meet their minimum throughput volume commitments. Some of these contracts allow our customers to claw-back all or a portion of prior deficiency payments against excess volumes in future periods. Under keep-whole arrangements, we gather and process natural gas from producer-customers, retain and sell extracted NGLs, and return to the producer Shrink Gas with an equivalent British thermal unit content of the NGLs retained. For these arrangements, we receive from the producer a combination of fixed rate-per unit of cash consideration as well as non-cash consideration in the form of retained NGLs. Other agreements with producers consist of POP arrangements for which we gather and purchase natural gas from the producers, process purchased natural gas, and sell resulting NGLs and shrink gas at market prices. Reimbursements of certain costs and fees received under these purchase arrangements are recorded as a reduction to NGL expense. See further discussion below on our accounting for product revenues related to the sales of products resulting from our processing activities. We recognize service revenue over time, as customers simultaneously receive and consume the related benefits of the services that we stand ready to provide. Revenue is recognized using an output measure, such as the throughput volume or capacity utilization, as these measures most accurately depict the satisfaction of our performance obligations. Where contracts contain variable pricing terms, the variability is either resolved within the reporting period, or the variable consideration is allocated to the specific unit of service to which it relates. Deficiency payments under contracts with claw-back provisions are deferred and recognized as revenue as customers reclaim amounts by throughputting excess volumes. To the extent it is probable a customer will not recover all or a portion of the deficiency payment, the estimated residual deficiency is recognized ratably over the claw-back period. Payments for services rendered are generally received no later than 60 days from the month of service, with the exception of deficiency payments described above. For our keep-whole arrangements, we recognize service revenue for the fair value of non-cash consideration we receive in the form of NGLs. We obtain control of the NGLs we receive from our customers, have discretion in establishing price and have the ability to direct their use. We estimate the fair value of non-cash consideration at the date we obtain control of the respective NGLs, using the monthly average published price of underlying commodity adjusted for geography and commodity specifications. We experience volume gains and losses, which we sometimes refer to as imbalances, within our pipelines, terminals and storage facilities due to pressure and temperature changes, evaporations and variances in meter reading in other measurement methods. Some of our arrangements require us to bear losses when actual volume losses exceed a contractually specified percentage. Similarly, we receive a benefit when actual volume losses are lower than the contractually specified percentage. For gains and losses which are cash settled, we include the settlement amounts in our service revenues. We recognize non-cash consideration for the stated percentage of commodity we retain and control. We record this non-cash consideration at fair value on a gross basis in service revenue and operating expense. The total amount of service revenue and NGL expense recorded associated with these arrangements is not material to our consolidated statements of operations.
Revenue Recognition, Sales of Goods	Product Revenue We generate product revenue from the sale of NGLs and related products along with the sale of gasoline and diesel fuel within our wholesale business. We sell NGLs, Shrink Gas and condensate using natural gas we acquire from producers under our POP arrangements. We record revenues for the sale of these NGLs and related products at market prices, and record the payments to producers for the agreed-upon percentage of the total sales proceeds as NGL expense, net of certain charges, which is reported within costs and expenses in our consolidated statements of operations. We have certain fuel purchase and sale arrangements under which we receive minimum guaranteed margins with upside potential on a portion of our branded and unbranded fuel sales. Marathon retains control of fuel and is the principal in these affiliate arrangements. Therefore, we net the purchase and sale of fuel in our consolidated statements of operations. NGLs received under keep-whole arrangements are sold to our affiliate. In return, we receive shrink gas which we then remit to the producers. This transaction is treated as a sale, for which we record the fair value of the non-cash consideration at the date we obtain control of the shrink gas. We utilize a monthly average of the published price of the commodity, adjusted for geography. Our product sales arrangements are for specified goods for which enforceable rights and obligations are created when sales volumes are determined, which typically occurs as orders are issued or spot sales are made, but may be determined at contract inception. Each barrel, gallon or other unit of measure of product, is separately identifiable and represents a distinct performance obligation to which the transaction price is allocated based on stand-alone selling price. We use observable market prices for the products we sell to determine the stand-alone selling price of each separate performance obligation. Product revenues are recognized at a point-in-time, which generally occurs upon delivery and transfer of title to the customer. Payments for product sales are generally received within 30 days from when control has transferred.

Note 2 - Acquisitions Acquisiti

Note 2 - Acquisitions Acquisitions (Tables)	12 Months Ended
	Dec. 31, 2018
Business Combinations [Abstract]
Schedule of Preliminary Acquisition Date Purchase Price Allocation	Preliminary Acquisition Date Purchase Price Allocation (in millions) Cash $ 22 Receivables 112 Inventories 11 Prepayments and Other Current Assets 25 Property, Plant and Equipment (a) 1,295 Goodwill 620 Acquired Intangibles 130 Other Noncurrent Assets 2 Accounts Payable (167 ) Accrued Liabilities (41 ) Debt (347 ) Total purchase price $ 1,662 (a) Estimated useful lives ranging from 3 to 22 years have been assumed based on the valuation.
Reconciliation of Combined Financial Statements	Reconciliation of Combined Financial Statements (in millions) Year Ended December 31, 2018 Combined Andeavor Logistics LP Predecessors Revenues: Fee-based: Affiliate $ 1,309 $ 1,288 $ 21 Third-party 591 582 9 Product-based: Affiliate 280 280 — Third-party 200 200 — Total Revenues 2,380 2,350 30 Costs and Expenses NGL expense (exclusive of items shown separately below) 206 206 — Operating expenses (exclusive of depreciation and amortization) 885 845 40 General and administrative expenses 121 112 9 Depreciation and amortization expenses 368 346 22 Loss on asset disposals and impairments 4 4 — Operating Income (Loss) 796 837 (41 ) Interest and financing costs, net (233 ) (229 ) (4 ) Equity in earnings of equity method investments 31 15 16 Other income, net 6 5 1 Net Earnings (Loss) $ 600 $ 628 $ (28 ) Loss attributable to Predecessors 28 — 28 Net Earnings Attributable to Partners 628 628 — Preferred unitholders’ interest in net earnings (44 ) (44 ) — Limited Partners’ Interest in Net Earnings $ 584 $ 584 $ — Year Ended December 31, 2017 Combined Andeavor Logistics LP Predecessors Revenues: Fee-based: Affiliate $ 942 $ 796 $ 146 Third-party 656 647 9 Product-based: Affiliate 489 213 276 Third-party 1,162 495 667 Total Revenues 3,249 2,151 1,098 Costs and Expenses Cost of fuel and other (excluding items shown separately below) 1,244 330 914 NGL expense (exclusive of items shown separately below) 265 265 — Operating expenses (exclusive of depreciation and amortization) 691 554 137 General and administrative expenses 158 121 37 Depreciation and amortization expenses 313 255 58 Gain on asset disposals and impairments (25 ) (24 ) (1 ) Operating Income (Loss) 603 650 (47 ) Interest and financing costs, net (330 ) (321 ) (9 ) Equity in earnings of equity method investments 22 10 12 Other income, net 11 10 1 Net Earnings (Loss) $ 306 $ 349 $ (43 ) Loss attributable to Predecessors 43 — 43 Net Earnings Attributable to Partners 349 349 — Preferred unitholders’ interest in net earnings (3 ) (3 ) — General partner’s interest in net earnings, including IDRs (79 ) (79 ) — Limited Partners’ Interest in Net Earnings $ 267 $ 267 $ — Year Ended December 31, 2016 Combined Andeavor Logistics LP Predecessors Revenues: Fee-based: Affiliate $ 747 $ 615 $ 132 Third-party 819 502 317 Product-based: Affiliate 100 100 — Third-party 3 3 — Total Revenues 1,669 1,220 449 Costs and Expenses Cost of fuel and other (excluding items shown separately below) 316 — 316 NGL expense (exclusive of items shown separately below) 2 2 — Operating expenses (exclusive of depreciation and amortization) 560 426 134 General and administrative expenses 106 94 12 Depreciation and amortization expenses 233 183 50 Loss on asset disposals and impairments 4 4 — Operating Income (Loss) 448 511 (63 ) Interest and financing costs, net (195 ) (196 ) 1 Equity in earnings of equity method investments 13 13 — Other income, net 11 11 — Net Earnings (Loss) $ 277 $ 339 $ (62 ) Loss attributable to Predecessors 62 — 62 Net Earnings Attributable to Partners 339 339 — General partner’s interest in net earnings, including IDRs (152 ) (152 ) — Limited Partners’ Interest in Net Earnings $ 187 $ 187 $ —

Related-Party Transactions (Tab

Related-Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2018
Related Party Transactions [Abstract]
Commercial Agreements	Commercial Agreements with Marathon Termination Provisions Commercial Agreement Initiation Date Term Years Renewals Refinery Shutdown Notice Period (a) Force Majeure Amended Transportation Services Agreement (High Plains System) Apr-11 10 2 x 5 years 12 months Unilateral Second Amended and Restated Master Terminalling Agreement Apr-11 10 2 x 5 years 12 months Unilateral Salt Lake City Storage Agreement Apr-11 10 2 x 5 years 12 months Unilateral Amended and Restated Transportation Services Agreement (Salt Lake City Short Haul Pipeline) Apr-11 10 2 x 5 years 12 months Unilateral Amorco Terminal Use and Throughput Agreement (Martinez Marine) Apr-12 10 2 x 5 years 12 months Unilateral Transportation Services Agreement (LAR Short Haul Pipelines) Sep-12 10 2 x 5 years N/A Unilateral Amended Anacortes Track Use and Throughput Agreement Nov-12 10 2 x 5 years N/A Unilateral Long Beach Storage Services Agreement Dec-12 10 2 x 5 years N/A Unilateral Terminalling Services Agreement for Northwest Pipeline System Jun-13 1 Year to year N/A Unilateral Southern California Terminalling & Dedicated Services Agreement Jun-13 10 2 x 5 years N/A Unilateral Amended Carson Storage Services Agreement Jun-13 10 2 x 5 years N/A Unilateral Carson Tank Farm Storage Agreement Jun-13 10 2 x 5 years N/A Unilateral Amended Terminalling, Transportation and Storage Services Agreement (WNRL) Oct-13 10 2 x 5 years 12 months Unilateral Amended Pipeline and Gathering Services Agreement (WNRL) Oct-13 10 2 x 5 years 12 months Unilateral Carson Coke Handling Service Agreement Dec-13 10 2 x 5 years N/A Unilateral Amended and Restated Long Beach Berth Access Use and Throughput Agreement Dec-13 10 2 x 5 years N/A Unilateral Long Beach Pipeline Throughput Agreement (b) Dec-13 10 2 x 5 years N/A Unilateral Amended Transportation Services Agreement (SoCal Pipelines) Dec-13 10 2 x 5 years N/A Unilateral Bakken Area Storage Hub Storage - TRMC Tanks Apr-14 5 2 x 5 years N/A Unilateral Terminalling & Dedicated Storage Services Agreement - Martinez Jul-14 10 2 x 5 years N/A Unilateral Terminalling & Dedicated Storage Services Agreement - Anacortes Jul-14 10 2 x 5 years N/A Unilateral THPP Reversal Open Season Northbound Commitment Sep-14 7 None N/A Unilateral Tesoro Alaska Pipeline Throughput Agreement Sep-14 10 2 x 5 years N/A Unilateral Amended Crude Oil Trucking Transportation Services Agreement (WNRL) Oct-14 10 None N/A Unilateral Fuel Distribution and Supply Agreement (WNRL) Oct-14 10 None N/A Unilateral Amended Product Supply Agreement (WNRL) Oct-14 10 None N/A Unilateral Keep-Whole Commodity Fee Agreement Dec-14 5 1 year auto 90 days prior to expiration Bilateral Sale of Natural Gas Oct-15 1 month Evergreen N/A Bilateral Amended Asphalt Trucking Services Agreement (WNRL) Jan-16 10 2 x 5 years N/A Unilateral Green River Processing Crude Oil Sales Agreement Feb-16 1 Evergreen N/A Bilateral Tank #2030 Use, Storage and Throughput Agreement Apr-16 6 months 6 months N/A Bilateral Asphalt and Propane Rack Loading Services Agreement (Kenai) May-16 10 2 x 5 years N/A Unilateral Kenai Storage Services Agreement Jul-16 10 2 x 5 years N/A Unilateral Termination Provisions Commercial Agreement Initiation Date Term Years Renewals Refinery Shutdown Notice Period (a) Force Majeure Terminalling, Transportation and Storage Services Agreement (St. Paul Park) Sep-16 10 2 x 5 years 12 months Unilateral Alaska Terminalling Services Agreement Sep-16 10 2 x 5 years N/A Unilateral Martinez Storage Services Agreement Nov-16 10 2 x 5 years N/A Unilateral Avon Marine Terminal Use and Throughput Agreement Jan-17 10 2 x 5 years N/A Unilateral Belfield Crude & Oil Gathering Jan-17 2 None N/A Unilateral Amended Renewal Trucking Transportation Services Agreement Apr-17 1 Evergreen 2 months prior to expiration Unilateral Transportation Services Agreement (Anacortes Short Haul Pipelines) Nov-17 10 2 x 5 years N/A Unilateral Anacortes Manifest Rail Terminalling Services Agreement Nov-17 10 2 x 5 years N/A Unilateral Anacortes Marine Terminal Operating Agreement Nov-17 17 None N/A Unilateral Storage Services Agreement - Anacortes II Nov-17 10 2 x 5 years N/A Unilateral Product Transportation Agreement (TRMC, WRSW, WRCLP, SPPRC) Jan-18 1 Evergreen N/A Unilateral Plant Dedication Agreement (Robinson Lake and Belfield) Apr-18 3 Month to month N/A Bilateral Product Sales Agreement - Robinson Lake Apr-18 3 N/A N/A Bilateral Product Sales Agreement - Belfield Apr-18 3 N/A N/A Bilateral Product Sales Agreement Y-Grade - Robinson Lake May-18 1 month Month to month N/A Bilateral SLC Core Crude Throughput May-18 0.2 Evergreen N/A Unilateral Truck Loading (H2S) Little Knife Jun-18 6 None N/A Unilateral Truck Unloading Facility Throughput Agreement (Stanley LACT) Jun-18 3 None N/A Unilateral Transportation Services Agreement (LAR Interconnecting Pipelines) Aug-18 10 2 x 5 years 12 months Unilateral Amended Master Terminalling Services Agreement - Clearbrook, Fryburg, Jal, LAR, Mandan, Wingate Aug-18 10 2 x 5 years N/A Unilateral Master Unloading and Storage Agreement (WNRL) Aug-18 10 2 x 5 years N/A Unilateral Amended Asphalt Terminalling, Transportation and Storage Services Agreement Aug-18 10 2 x 5 years 30 days Unilateral Fryburg Terminal Services Agreement Aug-18 2.6 1 month N/A Unilateral Transloading Services Agreement - Salt Lake City Spur Oct-18 3 None N/A Unilateral Natural Gas Liquids Marketing Agreement Oct-18 3 3 year extension with 60 days notice by AFS N/A Bilateral (a) Fixed minimum volumes remain in effect during routine turnarounds. (b) Agreement gives Marathon the option to renew for two five-year terms, or Marathon may modify the term of the agreements to a twenty-year term by providing notice in accordance with each agreement.
Summary of Related-Party Transactions	Summary of Revenue and Expense Transactions with Marathon, including Predecessors (in millions) Year Ended December 31, 2018 2017 2016 Revenues $ 1,589 $ 1,431 $ 847 Operating expenses (exclusive of depreciation and amortization) (a) 272 251 308 General and administrative expenses 98 101 80 (a) Includes net imbalance settlement gains of $12 million and $7 million in the years ended December 31, 2017 and 2016 , respectively. Due to the adoption of ASC 606 effective January 1, 2018, imbalance settlement gains of $16 million in the year ended December 31, 2018 were included in revenues. Includes reimbursements primarily related to pressure testing and repairs and maintenance costs pursuant to the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement of $15 million , $16 million and $17 million in the years ended December 31, 2018 , 2017 and 2016 , respectively.

Property, Plant and Equipment_2

Property, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2018
Property, Plant and Equipment [Abstract]
Summary of Property, Plant and Equipment	Property, Plant and Equipment (in millions) Estimated Depreciable Lives (Years) (a) December 31, 2018 2017 (b) Terminals and tankage 3 - 40 $ 3,749 $ 3,557 Pipelines 5 - 30 3,411 2,825 Land and leasehold improvements 3 - 29 297 282 Buildings and improvements 3 - 28 87 91 Other 1 - 28 82 142 Construction in progress — 519 346 Property, Plant and Equipment, at Cost (c) 8,145 7,243 Accumulated depreciation (c) (1,300 ) (994 ) Property, Plant and Equipment, Net $ 6,845 $ 6,249 (a) The above excludes assets not being depreciated. (b) Property, plant and equipment transferred to the Partnership in the 2018 Drop Down was recorded at historical costs. The Partnership recorded property, plant and equipment of $948 million and accumulated depreciation of $112 million as of December 31, 2017 in connection with the 2018 Drop Down. (c) Assets owned by us for which we are the lessor under operating leases were $691 million and $643 million before accumulated depreciation of $224 million and $195 million as of December 31, 2018 and 2017 , respectively.

Note 5 - Acquired Intangibles_2

Note 5 - Acquired Intangibles and Goodwill Acquired Intangibles and Goodwill (Tables)	12 Months Ended
	Dec. 31, 2018
Goodwill and Intangible Assets Disclosure [Abstract]
Summary of Goodwill by Operating Segment	Goodwill by Operating Segment (in millions) December 31, 2018 2017 (a) Terminalling and Transportation (b) (c) $ 284 $ 260 Gathering and Processing (b) (c) 718 607 Wholesale (b) 49 89 Goodwill $ 1,051 $ 956 (a) Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion. (b) In connection with the finalization of the purchase price allocation associated with the WNRL Merger during 2018, we reallocated goodwill amongst the segments. (c) Goodwill transferred to the Partnership in the 2018 Drop Down was recorded at historical cost. We recorded goodwill of $39 million and $225 million in our Terminalling and Transportation and Gathering and Processing segments, respectively, as of December 31, 2017 as a result of the 2018 Drop Down.

Note 6 - Equity Method Invest_2

Note 6 - Equity Method Investments and Joint Ventures Equity Method Investments and Joint Ventures (Tables)	12 Months Ended
	Dec. 31, 2018
Equity Method Investments and Joint Ventures [Abstract]
Schedule of Equity Method Investments	Equity Method Investments (in millions) ALRP (a) MPL (a) PNAC (a) RGS TRG UBFS Total Balance at December 31, 2016 $ — $ — $ — $ 281 $ 40 $ 16 $ 337 Acquired interests — 120 — — — — 120 Equity in earnings — 12 — 6 2 2 22 Distributions received — (12 ) — (19 ) (5 ) (3 ) (39 ) Balance at December 31, 2017 (b) — 120 — 268 37 15 440 Acquired interests 159 — 27 — — — 186 Equity in earnings (loss) 6 17 (1 ) 5 3 1 31 Cumulative effect of accounting standard adoption — — — — (3 ) — (3 ) Distributions received (5 ) (20 ) — (20 ) (5 ) (2 ) (52 ) Balance at December 31, 2018 (b) $ 160 $ 117 $ 26 $ 253 $ 32 $ 14 $ 602 (a) These equity method investments were included in the 2018 Drop Down. Amounts were adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion. (b) The carrying amounts of our investments that exceed the underlying equity in net assets are amortized over the useful life of the underlying fixed assets and included in equity in earnings. The carrying amount of our investments in these equity method investments exceeded the underlying equity in net assets as shown below. December 31, (in millions) 2018 2017 (c) ALRP $ 75 $ — MPL 34 35 PNAC 17 — RGS 125 130 TRG 14 15 UBFS 6 6 (c) Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

Other Current Assets and Liab_2

Other Current Assets and Liabilities (Tables)	12 Months Ended
	Dec. 31, 2018
Other Liabilities, Current [Abstract]
Schedule of Other Current Assets	Other Current Assets (in millions) December 31, 2018 2017 (a) Deferred charges $ 45 $ — Inventories 22 12 Prepayments 12 15 Total Other Current Assets $ 79 $ 27 (a) Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
Schedule of Other Current Liabilities	Other Current Liabilities (in millions) December 31, 2018 2017 (a) Deferred income $ 24 $ 23 Taxes other than income taxes 22 20 Employee costs 11 7 Asset retirement obligation 10 11 Accrued environmental liabilities 4 12 Other 10 11 Total Other Current Liabilities $ 81 $ 84 (a) Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

Debt (Tables)

Debt (Tables)	12 Months Ended
	Dec. 31, 2018
Debt Instrument
Schedule of Debt	Debt Balance, Net of Unamortized Issuance Costs (in millions) December 31, 2018 2017 Revolving Credit Facility $ 945 $ 423 Dropdown Credit Facility 300 — MPC Loan Agreement — — 5.500% Senior Notes due 2019 500 500 3.500% Senior Notes due 2022 (a) 500 500 6.250% Senior Notes due 2022 300 300 6.375% Senior Notes due 2024 450 450 5.250% Senior Notes due 2025 750 750 4.250% Senior Notes due 2027 (a) 750 750 5.200% Senior Notes due 2047 (a) 500 500 Capital lease obligations 15 9 Total Debt 5,010 4,182 Unamortized issuance costs (a) (46 ) (54 ) Current maturities, net of unamortized issuance costs (504 ) (1 ) Debt, Net of Current Maturities and Unamortized Issuance Costs $ 4,460 $ 4,127 (a) Unamortized discounts of $4 million and $5 million associated with these senior notes are included in unamortized issuance costs at December 31, 2018 and 2017 , respectively.
Schedule of Future Minimum Annual Lease Payments for Capital Leases	Future Minimum Annual Lease Payments, Including Interest for Capital Leases (in millions) December 31, 2018 2019 $ 4 2020 3 2021 3 2022 2 2023 2 Thereafter 4 Total minimum lease payments 18 Less amount representing interest (3 ) Capital lease obligations $ 15

Note 10 - Commitments and Con_2

Note 10 - Commitments and Contingencies Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2018
Commitments and Contingencies Disclosure [Abstract]
Schedule of Future Minimum Annual Payments	Future Minimum Annual Payments Applicable to all Non-Cancellable Operating Leases and Purchase Obligations (in millions) Payments Due by Period 2019 2020 2021 2022 2023 Thereafter Total Purchase obligations $ 2,078 $ 2,084 $ 2,054 $ 2,013 $ 2,013 $ 1,673 $ 11,915 Operating leases 17 17 15 13 13 105 180 Total $ 2,095 $ 2,101 $ 2,069 $ 2,026 $ 2,026 $ 1,778 $ 12,095
Changes in Environmental Liabilities	Changes in our Environmental Liabilities (in millions) Tioga Crude Oil Pipeline Release Other Liabilities Total At December 31, 2016 $ 16 $ 6 $ 22 Additions 19 1 20 Expenditures (25 ) (1 ) (26 ) At December 31, 2017 10 6 16 Additions 1 5 6 Expenditures (11 ) (5 ) (16 ) At December 31, 2018 $ — $ 6 $ 6

Note 11 - Equity and Net Earn_2

Note 11 - Equity and Net Earnings per Unit Equity and Net Earnings per Unit (Tables)	12 Months Ended
	Dec. 31, 2018
Equity [Abstract]
Schedule of Net Earnings per Unit	Net Earnings per Unit (in millions, except per unit amounts) Year Ended December 31, 2018 (a) 2017 (a) 2016 (a) Net earnings $ 600 $ 306 $ 277 Special Allocation (b) — 1 3 Net earnings, including special allocations 600 307 280 Distributions on Preferred Units (c) (41 ) (3 ) — Net earnings attributable to common units 559 304 280 General partner’s distributions — (6 ) (10 ) General partner’s IDRs (d) — (75 ) (148 ) Limited partners’ distributions on common units (890 ) (611 ) (344 ) Distributions on common units greater than earnings $ (331 ) $ (388 ) $ (222 ) General partner’s earnings: Distributions $ — $ 6 $ 10 General partners IDRs (d) — 75 148 Allocation of distributions (greater) less than earnings (e) (28 ) (44 ) (65 ) Total general partner’s earnings $ (28 ) $ 37 $ 93 Limited partners’ earnings on common units: Distributions (f) $ 890 $ 611 $ 344 Special allocation (f) — (1 ) (3 ) Allocation of distributions greater than earnings (303 ) (344 ) (157 ) Total limited partners’ earnings on common units $ 587 $ 266 $ 184 Weighted average limited partner units outstanding: Common units - basic 228.7 126.0 98.2 Common units - diluted (g) 228.9 126.1 98.2 Net earnings per limited partner unit: (h) Common - basic $ 2.57 $ 2.11 $ 1.87 Common - diluted $ 2.57 $ 2.11 $ 1.87 (a) Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion. (b) Normal allocations according to percentage interests are made after giving effect, if any, to priority income allocations in an amount equal to incentive cash distributions fully allocated to the general partner and any special allocations. The adjustment reflects the special allocation to common units held by TLGP for the interest incurred in connection with borrowings on the Dropdown Credit Facility in lieu of using cash on hand to fund the North Dakota Gathering and Processing Assets in 2017 and the Alaska Storage and Terminalling Assets acquisition in 2016 . (c) The Preferred Units entitle unitholders to receive preferred distributions on a semi-annually basis. (d) IDRs entitled the general partner to receive increasing percentages, up to 50% , of quarterly distributions in excess of $0.3881 per unit per quarter. The amount above reflects earnings distributed to our general partner net of $50 million of IDRs for the year ended December 31, 2017 waived by TLGP. Our general partner no longer holds IDRs as a result of the IDR/GP Transaction. (e) We have revised the historical allocation of general partner earnings to include the Predecessors’ losses of $28 million , $43 million and $62 million for the years ended December 31, 2018 , 2017 and 2016 , respectively. (f) Distributions of earnings for limited partners’ common units for the years ended December 31, 2018 and 2017 is net of a $60 million and $25 million waiver, respectively, from our Sponsor in connection with the WNRL Merger. (g) Diluted net earnings per unit include the effects of potentially dilutive units on our common units, which consist of unvested service and performance phantom units. (h) Amounts may not recalculate due to rounding of dollar and unit information.
Allocations of the General Partner's Interest in Net Earnings	Allocations of the General Partner’s Interest in Net Earnings (in millions, except percentage of ownership interest) Year Ended December 31, 2018 2017 2016 Net earnings attributable to partners $ 628 $ 349 $ 339 Distributions on Preferred Units (41 ) (3 ) — General partner’s IDRs — (75 ) (148 ) Special allocation — 1 3 Net earnings available to partners $ 587 $ 272 $ 194 General partner’s ownership interest (a) — % — % 2.0 % General partner’s allocated interest in net earnings (b) $ — $ 4 $ 4 General partner’s IDRs — 75 148 Allocation of Predecessors’ impact to general partner interest (28 ) (43 ) (62 ) Total general partner’s interest in net earnings $ (28 ) $ 36 $ 90 (a) In connection with the IDR/GP Transaction, our general partner units converted into non-economic general partner units. (b) Prior to the IDR/GP Transaction, we allocated net earnings to our general partner based on its ownership interest.
Changes in the Number of Units Outstanding	Changes in the Number of Units Outstanding (in million units) Common Preferred General Partner Total At December 31, 2015 93.5 — 1.9 95.4 Issuances under ATM Program 1.4 — — 1.4 Issuance of units in June 2016 for cash 6.3 — — 6.3 Issuance in July 2016 in connection with the Alaska Storage and Terminalling Assets acquisition 0.4 — 0.2 0.6 Issuance in September 2016 in connection with the Alaska Storage and Terminalling Assets acquisition 0.4 — — 0.4 Issuance in November 2016 in connection with the Northern California Terminalling and Storage Assets acquisition 0.9 — — 0.9 Unit-based compensation awards 0.1 — — 0.1 At December 31, 2016 103.0 — 2.1 105.1 Issuances under ATM Program 0.1 — — 0.1 Issuance of units in February 2017 for cash 5.0 — 0.1 5.1 Issuance in October 2017 in connection with the WNRL Merger 108.0 — — 108.0 Issuance in November 2017 in connection with the Anacortes Logistics Assets acquisition 1.0 — — 1.0 Issuance of Preferred Units in December 2017 — 0.6 — 0.6 At December 31, 2017 217.1 0.6 2.2 219.9 Issuance in August 2018 in connection with the 2018 Drop Down 28.3 — — 28.3 Unit-based compensation awards 0.1 — — 0.1 At December 31, 2018 245.5 0.6 2.2 248.3
Schedule of Total Quarterly Cash Distributions to General and Limited Partners	Total Quarterly Cash Distributions to General and Limited Partners (in millions) Year Ended December 31, 2018 2017 2016 General partner’s distributions: General partner’s distributions $ — $ (6 ) $ (10 ) General partner’s IDRs (a) — (75 ) (148 ) Total general partner’s distributions $ — $ (81 ) $ (158 ) Limited partners’ distributions: Common $ (890 ) $ (611 ) $ (344 ) Total limited partners’ distributions (890 ) (611 ) (344 ) Total Cash Distributions $ (890 ) $ (692 ) $ (502 ) (a) As a result of the IDR/GP Transaction that occurred on October 30, 2017, our general partner no longer receives IDRs.

Note 12 - Supplemental Cash F_2

Note 12 - Supplemental Cash Flow Information Supplemental Cash Flow Information (Tables)	12 Months Ended
	Dec. 31, 2018
Supplemental Cash Flow Elements [Abstract]
Schedule of Supplemental Disclosures of Non-Cash Investing and Financing Activities	Supplemental Disclosures of Non-Cash Investing and Financing Activities (in millions) Year Ended December 31, 2018 2017 2016 Capital expenditures included in accounts payable at period end $ 105 $ 50 $ 30 Capital expenditures included in affiliate payable at period end — — 8 Capital leases and other — — 2 Predecessors’ net liabilities not assumed by Andeavor Logistics 13 — 22 Receivable from affiliate for capital expenditures 26 4 4

Note 13 - Revenues Revenues (Ta

Note 13 - Revenues Revenues (Tables)	12 Months Ended
	Dec. 31, 2018
Revenue from Contract with Customer [Abstract]
Schedule of Customer Contract Asset and Liabilities	Summary of Customer Contract Assets and Liabilities (in millions) December 31, 2017 (a) Adjustments for ASC 606 (b)(c) Balance at January 1, 2018 December 31, Contract assets — 34 34 32 Deferred income, current 23 — 23 24 Deferred income, noncurrent 43 16 59 57 (a) Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion. (b) These amounts exclude balances associated with equity method investments. We recognized a cumulative adjustment of $3 million as a decrease to Equity Method Investments in our consolidated balance sheets as of January 1, 2018 for the impacts related to our equity method investment in TRG. There were no material impacts to this balance during the year ended December 31, 2018 due to the adoption. (c) Included in the $34 million change to contract assets is a $32 million reclass from Receivables for amounts for which we were not allowed to invoice as of January 1, 2018.
Schedule of Revenue Disaggregation by Type and Product Line	Revenue Disaggregation by Type and Product Line (in millions) Year Ended December 31, 2018 Terminalling and Transportation (a) Gathering and Processing (a) Wholesale Service Revenues (b) Refined products $ 898 $ — $ 17 Crude oil and water 153 438 — Natural gas — 391 — Other 3 — — Total Service Revenues 1,054 829 17 Product Revenues NGL products — 434 — Refined products — — 46 Total Product Revenues — 434 46 Total Revenues $ 1,054 $ 1,263 $ 63 (a) Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion. (b) Includes $425 million of lease revenues for the year ended December 31, 2018 .

Operating Segments (Tables)

Operating Segments (Tables)	12 Months Ended
	Dec. 31, 2018
Segment Reporting, Disclosure of Entity's Reportable Segments [Abstract]
Schedule of Segment Reporting Information, by Segment	Segment Information (in millions) Year Ended December 31, 2018 (a) 2017 (a) 2016 (a) Revenues Terminalling and Transportation: Terminalling $ 888 $ 690 $ 480 Pipeline transportation 160 130 125 Other revenues 6 18 — Total Terminalling and Transportation 1,054 838 605 Gathering and Processing: NGL sales 436 369 103 Gas gathering and processing 330 333 264 Crude oil and water gathering 336 262 582 Pass-thru and other 161 165 115 Total Gathering and Processing 1,263 1,129 1,064 Wholesale: Fuel sales (b) 46 1,267 — Other wholesale 33 15 — Total Wholesale 79 1,282 — Intersegment wholesale revenues (16 ) — — Total Segment Revenues $ 2,380 $ 3,249 $ 1,669 Segment Operating Income Terminalling and Transportation $ 498 $ 397 $ 240 Gathering and Processing 310 245 235 Wholesale 27 15 — Total Segment Operating Income 835 657 475 Unallocated general and administrative expenses (39 ) (54 ) (27 ) Operating Income 796 603 448 Interest and financing costs, net (233 ) (330 ) (195 ) Equity in earnings of equity method investments 31 22 13 Other income, net 6 11 11 Net Earnings $ 600 $ 306 $ 277 Depreciation and Amortization Expense Terminalling and Transportation $ 144 $ 117 $ 95 Gathering and Processing 213 191 138 Wholesale 11 5 — Total Depreciation and Amortization Expense $ 368 $ 313 $ 233 Capital Expenditures Terminalling and Transportation $ 205 $ 188 $ 193 Gathering and Processing 545 175 119 Wholesale 1 — — Total Capital Expenditures $ 751 $ 363 $ 312 (a) Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion. (b) The presentation of wholesale fuel sales was impacted by adoption of ASC 606 on January 1, 2018. Beginning January 1, 2018, the revenues and costs associated with our fuel purchase and supply arrangements were netted. Total Identifiable Assets by Operating Segment (in millions) December 31, 2018 2017 (a) Identifiable Assets Terminalling and Transportation $ 3,458 $ 3,045 Gathering and Processing 6,488 6,006 Wholesale 255 342 Other 94 112 Total Identifiable Assets $ 10,295 $ 9,505 (a) Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

Note 15 - Quarterly Financial_2

Note 15 - Quarterly Financial Data (Unaudited) Quarterly Financial Data (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2018
Quarterly Financial Information Disclosure [Abstract]
Schedule of Quarterly Financial Data (Unaudited)	Quarters First Second Third Fourth Total Year 2018 (a) (In millions, except per unit amounts) Revenues $ 546 $ 569 $ 642 $ 623 $ 2,380 NGL expense (b) 48 45 73 40 206 Operating expenses 201 221 236 227 885 Operating income 177 180 215 224 796 Net earnings 131 132 166 171 600 Limited partners' interest in net earnings 125 138 160 161 584 Net earnings per limited partner unit (c): Common - basic $ 0.59 $ 0.63 $ 0.68 $ 0.66 $ 2.57 Common - diluted $ 0.59 $ 0.63 $ 0.68 $ 0.66 $ 2.57 2017 (a) Revenues $ 427 $ 614 $ 1,094 $ 1,114 $ 3,249 Cost of fuel and other (b)(d) — 162 554 528 1,244 NGL expense (b) 59 56 64 86 265 Operating expenses 142 171 199 179 691 Operating income 131 146 147 179 603 Net earnings 73 90 90 53 306 Limited partners' interest in net earnings (c) 55 70 97 47 267 Net earnings per limited partner unit (c): Common - basic $ 0.51 $ 0.63 $ 0.90 $ 0.25 $ 2.11 Common - diluted $ 0.51 $ 0.63 $ 0.90 $ 0.25 $ 2.11 (a) Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion. (b) Excludes direct operating expenses incurred across our operating segments and depreciation and amortization expenses. (c) The sum of four quarters may not equal annual results due to rounding or the quarterly number of units outstanding. (d) Due to the adoption of ASC 606 effective January 1, 2018, the revenues and costs associated with our fuel purchase and supply arrangements for the year ended December 31, 2018 were netted. See Note 1 for further discussion.

Note 1 - Organization and Basis

Note 1 - Organization and Basis of Presentation Description and Nature of Business (Details)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Percentage of revenue	67.00%	44.00%	51.00%
Customer Concentration Risk
Percentage of revenue			13.00%

Note 1 - Organization and Bas_2

Note 1 - Organization and Basis of Presentation Principles of Consolidated and Basis of Presentation (Details) - USD ($)		3 Months Ended															12 Months Ended
		Dec. 31, 2018	Sep. 30, 2018		Jun. 30, 2018		Mar. 31, 2018		Dec. 31, 2017		Sep. 30, 2017		Jun. 30, 2017		Mar. 31, 2017		Dec. 31, 2018		Dec. 31, 2017		Dec. 31, 2016
Finite-Lived Intangible Asset, Useful Life																	31 years
Money Market Funds, at Carrying Value		$ 0															$ 0
Interest Costs Capitalized																	13,000,000		$ 8,000,000		$ 6,000,000
Asset Retirement Obligation		10,000,000							$ 11,000,000								10,000,000		11,000,000
Long-term Debt, Gross		5,000,000,000							4,200,000,000								5,000,000,000		4,200,000,000
Debt Instrument, Fair Value Disclosure		$ 4,900,000,000							4,300,000,000								4,900,000,000		4,300,000,000
Reimbursements from Andeavor																	15,000,000		16,000,000		17,000,000
Proceeds From Contributions From Sponsor	[1]																51,000,000		34,000,000		29,000,000
Unit-based compensation expense	[1]																$ 9,000,000		9,000,000		6,000,000
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Available for Grant		943,466															943,466
Depreciation																	$ 310,000,000		262,000,000		202,000,000
Revenues		$ 623,000,000	$ 642,000,000	[2]	$ 569,000,000	[2]	$ 546,000,000	[2]	1,114,000,000	[2]	$ 1,094,000,000	[2]	$ 614,000,000	[2]	$ 427,000,000	[2]	2,380,000,000	[3]	3,249,000,000	[3]	1,669,000,000	[3]
Other Income, net	[3]																6,000,000		11,000,000		11,000,000
Limited partners’ interest in net earnings		$ 161,000,000	$ 160,000,000		$ 138,000,000		$ 125,000,000		$ 47,000,000	[4]	$ 97,000,000	[4]	70,000,000	[4]	$ 55,000,000	[4]	584,000,000		267,000,000		187,000,000
Goodwill, Impairment Loss																	0		0		0
Equity Method Investment, Other than Temporary Impairment																	$ 0		0		$ 0
Maximum
Maturity Period Of Short-Term Investments																	3 months
Crude Oil
Products Retained For Volume Losses, Percent																	0.20%
Pipeline Loss Allowance		0.20%															0.20%
Pipeline Loss Allowance, Price Differential		$ 8															$ 8
Petroleum Products
Products Retained For Volume Losses, Percent																	0.25%
Petroleum Products | Northwest Products System
Products Retained For Volume Losses, Percent																	0.25%
Distillates | Northwest Products System
Products Retained For Volume Losses, Percent																	0.125%
Accounting Standards Update 2016-18 [Member]
Restricted Cash													$ 14,000,000
Accounting Standards Update 2017-07 [Member]
Interest and Debt Expense																			7,000,000
Other Income, net																			7,000,000
Limited partners’ interest in net earnings																			$ 0
Difference between Revenue Guidance in Effect before and after Topic 606 [Member] | Accounting Standards Update 2014-09 [Member]
Retained Earnings (Accumulated Deficit)		17,000,000															$ 17,000,000
Difference between Revenue Guidance in Effect before and after Topic 606 [Member] | Accounting Standards Update 2016-02 [Member] | Maximum
Operating Lease, Right-of-Use Asset		145,000,000															145,000,000
Difference between Revenue Guidance in Effect before and after Topic 606 [Member] | Accounting Standards Update 2016-02 [Member] | Minimum
Operating Lease, Right-of-Use Asset		$ 115,000,000															115,000,000
Wholesale [Member] | Difference between Revenue Guidance in Effect before and after Topic 606 [Member] | Accounting Standards Update 2014-09 [Member]
Revenues																	2,600,000,000
Cost of Goods and Services Sold																	2,600,000,000
Gathering and Processing [Member] | Difference between Revenue Guidance in Effect before and after Topic 606 [Member] | Accounting Standards Update 2014-09 [Member]
Revenues																	$ 6,000,000
PNAC [Member]
Equity Method Investment, Ownership Percentage		50.00%															50.00%
[1]	All periods include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[2]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[3]	All periods include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[4]	The sum of four quarters may not equal annual results due to rounding or the quarterly number of units outstanding.

Note 2 - Acquisitions Acquisi_2

Note 2 - Acquisitions Acquisitions (Details) - USD ($) $ in Millions

Aug. 06, 2018

May 01, 2018

Nov. 08, 2017

Nov. 21, 2016

Sep. 16, 2016

Jul. 01, 2016

Sep. 30, 2018

Sep. 30, 2018

Dec. 31, 2018

Dec. 31, 2017

Dec. 31, 2016

[1]

Business Acquisition [Line Items]

Borrowings under revolving credit agreement

$ 1,320

$ 1,225

$ 1,451

Payments to Acquire Businesses, Gross

$ 300

$ 300

$ 406

$ 760

Business Acquisition, Equity Interest Issued or Issuable, Value Assigned

$ 1,250

$ 1,250

Business Acquisition, Equity Interest Issued or Issuable, Number of Shares

28,283,742

Logistics Assets Drop Down and Asset Transfer [Member]

Business Acquisition [Line Items]

Business Combination, Consideration Transferred

$ 1,550

Wamsutter Pipeline System [Member]

Business Acquisition [Line Items]

Payments to Acquire Businesses, Gross

$ 180

Alaska Logistics Assets [Member]

Business Acquisition [Line Items]

Business Combination, Consideration Transferred

$ 444

Anacortes Logistics Assets [Member]

Business Acquisition [Line Items]

Business Combination, Consideration Transferred

$ 445

Borrowings under revolving credit agreement

400

Business Combination, Consideration Transferred, Equity Interests Issued and Issuable

$ 45

Martinez Logistics Assets [Member]

Business Acquisition [Line Items]

Business Combination, Consideration Transferred

$ 400

Payments to Acquire Businesses, Gross

360

Business Acquisition, Equity Interest Issued or Issuable, Value Assigned

$ 40

Martinez Logistics Assets [Member] | Common

Business Acquisition [Line Items]

Business Acquisition, Equity Interest Issued or Issuable, Number of Shares

860,933

Martinez Logistics Assets [Member] | General Partner

Business Acquisition [Line Items]

Business Acquisition, Equity Interest Issued or Issuable, Number of Shares

17,570

Alaska Logistics Assets [Member] | Phase One

Business Acquisition [Line Items]

Business Combination, Consideration Transferred

266

Payments to Acquire Businesses, Gross

240

Business Acquisition, Equity Interest Issued or Issuable, Value Assigned

$ 26

Alaska Logistics Assets [Member] | Phase Two

Business Acquisition [Line Items]

Business Combination, Consideration Transferred

$ 178

Payments to Acquire Businesses, Gross

160

Business Acquisition, Equity Interest Issued or Issuable, Value Assigned

$ 18

Alaska Logistics Assets [Member] | Common | Phase One

Business Acquisition [Line Items]

Business Acquisition, Equity Interest Issued or Issuable, Number of Shares

390,282

Alaska Logistics Assets [Member] | Common | Phase Two

Business Acquisition [Line Items]

Business Acquisition, Equity Interest Issued or Issuable, Number of Shares

358,712

Alaska Logistics Assets [Member] | General Partner | Phase One

Business Acquisition [Line Items]

Business Acquisition, Equity Interest Issued or Issuable, Number of Shares

162,375

Alaska Logistics Assets [Member] | General Partner | Phase Two

Business Acquisition [Line Items]

Business Acquisition, Equity Interest Issued or Issuable, Number of Shares

20,440

Rangeland RIO Pipeline, LLC [Member]

Business Acquisition [Line Items]

Equity Method Investment, Ownership Percentage

67.00%

[1]

All periods include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

Note 2 - Acquisitions Western R

Note 2 - Acquisitions Western Refining Logistics LP Acquisition (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017	[1]
Business Acquisition [Line Items]
Goodwill		$ 1,051	$ 956
WNRL Merger [Member]
Business Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Cash and Equivalents		22
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Receivables		112
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Inventory		11
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Prepaid Expense and Other Assets		25
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment	[2]	1,295
Goodwill		620
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill		130
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets		2
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Accounts Payable		(167)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Other		(41)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-term Debt		(347)
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Less Noncontrolling Interest		$ 1,662
Minimum | WNRL Merger [Member]
Business Acquisition [Line Items]
Property, Plant and Equipment, Useful Life		3 years
Maximum | WNRL Merger [Member]
Business Acquisition [Line Items]
Property, Plant and Equipment, Useful Life		22 years
[1]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[2]	Estimated useful lives ranging from 3 to 22 years have been assumed based on the valuation.

Note 2 - Acquisitions WNRL Para

Note 2 - Acquisitions WNRL Paragraph (Details) - USD ($) $ in Millions		3 Months Ended															12 Months Ended
		Dec. 31, 2018	Sep. 30, 2018	[2]	Jun. 30, 2018	[2]	Mar. 31, 2018	[2]	Dec. 31, 2017		Sep. 30, 2017	[2]	Jun. 30, 2017	[2]	Mar. 31, 2017	[2]	Dec. 31, 2018		Dec. 31, 2017		Dec. 31, 2016
Business Acquisition [Line Items]
Goodwill		$ 1,051							$ 956	[1]							$ 1,051		$ 956	[1]
Finite-Lived Intangible Assets, Accumulated Amortization		156							106								156		106
Finite-Lived Intangible Assets, Amortization Expense, Next Twelve Months		50															50
Finite-Lived Intangible Assets, Amortization Expense, Year Two		50															50
Finite-Lived Intangible Assets, Amortization Expense, Year Three		50															50
Finite-Lived Intangible Assets, Amortization Expense, Year Four		50															50
Finite-Lived Intangible Assets, Amortization Expense, Year Five		50															50
Revenues		623	$ 642		$ 569		$ 546		$ 1,114	[2]	$ 1,094		$ 614		$ 427		2,380	[3]	3,249	[3]	$ 1,669	[3]
Net Earnings Attributable to Partners																	628		349		$ 339
WNRL Merger [Member]
Business Acquisition [Line Items]
Goodwill, Purchase Accounting Adjustments																	55
Goodwill		620															620
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment	[4]	1,295															1,295
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill		130															$ 130
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life																	15 years
Finite-Lived Intangible Assets, Accumulated Amortization		14															$ 14
Finite-Lived Intangible Assets, Amortization Expense, Next Twelve Months		9															9
Finite-Lived Intangible Assets, Amortization Expense, Year Two		9															9
Finite-Lived Intangible Assets, Amortization Expense, Year Three		9															9
Finite-Lived Intangible Assets, Amortization Expense, Year Four		9															9
Finite-Lived Intangible Assets, Amortization Expense, Year Five		9															9
Business Acquisition, Transaction Costs		17															17
Business Combination, Integration Related Costs																	3
Business Acquisition, Pro Forma Revenue																			4,300
Business Acquisition, Pro Forma Net Income (Loss)																			403
Revenues																	415		1,500
Net Earnings Attributable to Partners																	115		$ 40
Gathering and Processing [Member] | WNRL Merger [Member]
Business Acquisition [Line Items]
Goodwill		374															374
Terminalling and Transportation Segment [Member] | WNRL Merger [Member]
Business Acquisition [Line Items]
Goodwill		197															197
Wholesale Segment [Member] | WNRL Merger [Member]
Business Acquisition [Line Items]
Goodwill		$ 49															$ 49
[1]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[2]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[3]	All periods include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[4]	Estimated useful lives ranging from 3 to 22 years have been assumed based on the valuation.

Note 2 - Acquisitions Predecess

Note 2 - Acquisitions Predecessor Reconciliation (Details) - USD ($) $ in Millions		3 Months Ended																12 Months Ended
		Dec. 31, 2018		Sep. 30, 2018		Jun. 30, 2018		Mar. 31, 2018		Dec. 31, 2017		Sep. 30, 2017		Jun. 30, 2017		Mar. 31, 2017		Dec. 31, 2018		Dec. 31, 2017		Dec. 31, 2016
Revenues		$ 623		$ 642	[1]	$ 569	[1]	$ 546	[1]	$ 1,114	[1]	$ 1,094	[1]	$ 614	[1]	$ 427	[1]	$ 2,380	[2]	$ 3,249	[2]	$ 1,669	[2]
Operating expenses		227		236	[1]	221	[1]	201	[1]	179	[1]	199	[1]	171	[1]	142	[1]	885	[1],[2]	691	[1],[2]	560	[2]
General and Administrative Expense	[2]																	121		158		106
Depreciation and amortization expenses	[3]																	368		313		233	[4]
(Gain) loss on asset disposals and impairments	[2]																	4		(25)		4	[3]
Operating Income		224		215	[1]	180	[1]	177	[1]	179	[1]	147	[1]	146	[1]	131	[1]	796	[2]	603	[2]	448	[2]
Interest and financing costs, net	[2]																	(233)		(330)		(195)
Equity in earnings of equity method investments	[2]																	31		22		13
Other Income, net	[2]																	6		11		11
Net Earnings		171		166	[1]	132	[1]	131	[1]	53	[1]	90	[1]	90	[1]	73	[1]	600	[2],[4],[5]	306	[2],[4],[5]	277	[2],[3],[4],[5]
Net Income (Loss) Attributable To Predecessors																		28		43		62
Net Earnings Attributable to Partners																		628		349		339
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable																		(44)		(3)		0
Net Income (Loss) Allocated to General Partners																		0		(79)		(152)
Limited partners’ interest in net earnings		161		160		138		125		47	[6]	97	[6]	70	[6]	55	[6]	584		267		187
Oil and Gas, Purchased [Member]
Cost of Goods and Services Sold										528	[7],[8]	554	[7],[8]	162	[7],[8]	0	[7],[8]	0	[2],[9]	1,244	[2],[7],[8],[9]	316	[2],[9]
Natural Gas, Midstream [Member]
Cost of Goods and Services Sold		$ 40	[8]	$ 73	[8]	$ 45	[8]	$ 48	[8]	$ 86	[8]	$ 64	[8]	$ 56	[8]	$ 59	[8]	206	[2]	265	[2],[8]	2	[2]
Affiliated Entity [Member]
Revenues																		1,589		1,431		847
Affiliated Entity [Member] | Fee-Based Sales [Member]
Revenues	[2]																	1,309		942		747
Affiliated Entity [Member] | Product-Based Sales [Member]
Revenues	[2],[9]																	280		489		100
Third Party [Member] | Fee-Based Sales [Member]
Revenues	[2]																	591		656		819
Third Party [Member] | Product-Based Sales [Member]
Revenues	[2],[9]																	200		1,162		3
Successor [Member]
Revenues	[2]																	2,350		2,151		1,220
Operating expenses																		845	[1]	554	[1]	426	[2]
General and Administrative Expense	[2]																	112		121		94
Depreciation and amortization expenses	[3]																	346		255		183
(Gain) loss on asset disposals and impairments	[2]																	4		(24)		4
Operating Income	[2]																	837		650		511
Interest and financing costs, net	[2]																	(229)		(321)		(196)
Equity in earnings of equity method investments	[2]																	15		10		13
Other Income, net	[2]																	5		10		11
Net Earnings																		628	[4]	349	[4]	339	[2]
Net Income (Loss) Attributable To Predecessors																		0		0		0
Net Earnings Attributable to Partners																		628		349		339
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable																		(44)		(3)
Net Income (Loss) Allocated to General Partners																				(79)		(152)
Limited partners’ interest in net earnings																		584		267		187
Successor [Member] | Oil and Gas, Purchased [Member]
Cost of Goods and Services Sold	[2],[9]																			330		0
Successor [Member] | Natural Gas, Midstream [Member]
Cost of Goods and Services Sold	[2]																	206		265		2
Successor [Member] | Affiliated Entity [Member] | Fee-Based Sales [Member]
Revenues	[2]																	1,288		796		615
Successor [Member] | Affiliated Entity [Member] | Product-Based Sales [Member]
Revenues	[2],[9]																	280		213		100
Successor [Member] | Third Party [Member] | Fee-Based Sales [Member]
Revenues	[2]																	582		647		502
Successor [Member] | Third Party [Member] | Product-Based Sales [Member]
Revenues	[2],[9]																	200		495		3
Predecessor [Member]
Revenues	[2]																	30		1,098		449
Operating expenses																		40	[1]	137	[1]	134	[2]
General and Administrative Expense	[2]																	9		37		12
Depreciation and amortization expenses	[3]																	22		58		50
(Gain) loss on asset disposals and impairments	[2]																	0		(1)		0
Operating Income	[2]																	(41)		(47)		(63)
Interest and financing costs, net	[2]																	(4)		(9)		1
Equity in earnings of equity method investments	[2]																	16		12		0
Other Income, net	[2]																	1		1		0
Net Earnings																		(28)	[4]	(43)	[4]	(62)	[2]
Net Income (Loss) Attributable To Predecessors																		28		43		62
Net Earnings Attributable to Partners																		0		0		0
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable																		0		0
Net Income (Loss) Allocated to General Partners																				0		0
Limited partners’ interest in net earnings																		0		0		0
Predecessor [Member] | Oil and Gas, Purchased [Member]
Cost of Goods and Services Sold	[2],[9]																			914		316
Predecessor [Member] | Natural Gas, Midstream [Member]
Cost of Goods and Services Sold	[2]																	0		0		0
Predecessor [Member] | Affiliated Entity [Member] | Fee-Based Sales [Member]
Revenues	[2]																	21		146		132
Predecessor [Member] | Affiliated Entity [Member] | Product-Based Sales [Member]
Revenues	[2],[9]																	0		276		0
Predecessor [Member] | Third Party [Member] | Fee-Based Sales [Member]
Revenues	[2]																	9		9		317
Predecessor [Member] | Third Party [Member] | Product-Based Sales [Member]
Revenues	[2],[9]																	$ 0		$ 667		$ 0
[1]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[2]	All periods include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[3]	All periods include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[4]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[5]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[6]	The sum of four quarters may not equal annual results due to rounding or the quarterly number of units outstanding.
[7]	Due to the adoption of ASC 606 effective January 1, 2018, the revenues and costs associated with our fuel purchase and supply arrangements for the year ended December 31, 2018 were netted. See Note 1 for further discussion.
[8]	Excludes direct operating expenses incurred across our operating segments and depreciation and amortization expenses.
[9]	Due to the adoption of ASC 606 effective January 1, 2018, the revenues and costs associated with our fuel purchase and supply arrangements for year ended December 31, 2018 were netted. See Note 1 for further discussion.

Note 2 - Acquisitions Whiting A

Note 2 - Acquisitions Whiting Assets (Details) $ in Millions	Jan. 01, 2017USD ($)
North Dakota Gathering and Processing Assets [Member]
Business Acquisition [Line Items]
Business Combination, Consideration Transferred	$ 705

Note 2 - Acquisitions Divestitu

Note 2 - Acquisitions Divestitures (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	[1]
Business Acquisition [Line Items]
Proceeds from sale of assets		$ 0	$ 47	$ 0
Gain (Loss) on Disposition of Property Plant Equipment	[2]	$ (4)	25	$ (4)
Alaska Terminal [Member]
Business Acquisition [Line Items]
Proceeds from sale of assets			28
Gain (Loss) on Disposition of Property Plant Equipment			$ (25)
[1]	All periods include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[2]	All periods include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

Related-Party Transactions, Agr

Related-Party Transactions, Agreements (Details) $ in Millions		3 Months Ended	12 Months Ended
		Mar. 31, 2019	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)
Related Party Transaction
Operating Leases, Income Statement, Lease Revenue			$ 425	$ 277	$ 193
Other Commitments
2018, Commitment			530
2022, Commitment			478
Operating Leases, Future Minimum Payments Receivable, Thereafter			1,500
Indemnification deductible			$ 1
Second Amended and Restated Trucking Transportation Services Agreement (High Plains System)
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Apr11
Term (years)			10 years
Other Commitments
Term Of Renewal			5 years
Length Of Time For Continuing Minimum Payments			12 months
Second Amended and Restated Master Terminalling Agreement [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Apr11
Term (years)			10 years
Other Commitments
Term Of Renewal			5 years
Length Of Time For Continuing Minimum Payments			12 months
Salt Lake City Storage Agreement [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Apr11
Term (years)			10 years
Other Commitments
Term Of Renewal			5 years
Length Of Time For Continuing Minimum Payments			12 months
Transportation Services Agreement (LAR Short Haul Pipeline) [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Sep12
Term (years)			10 years
Other Commitments
Term Of Renewal			5 years
Amended Anacortes Track Use and Throughput Agreement [Member]
Related Party Transaction
Number Of Contract Renewals			0
Service Agreement Initiation Date			Nov12
Term (years)			10 years
Other Commitments
Term Of Renewal			1 year
Amorco Terminal Use and Throughput Agreement (Martinez Marine)
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Apr12
Term (years)			10 years
Other Commitments
Term Of Renewal			5 years
Length Of Time For Continuing Minimum Payments			12 months
Long Beach Storage Services Agreement [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Dec12
Term (years)			10 years
Other Commitments
Term Of Renewal			5 years
Terminalling Services Agreement for Northwest Product System [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Jun13
Term (years)			1 year
Other Commitments
Term Of Renewal			5 years
Terminalling, Transportation, and Storage Services Agreement - WNRL [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Apr16
Term (years)			6 months
Other Commitments
Term Of Renewal			5 years
Long Beach Pipeline Throughput Agreement [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Dec13
Term (years)			10 years
Other Commitments
Term Of Renewal			5 years
Transportation Services Agreement (SoCal Pipelines) [Member]
Related Party Transaction
Number Of Contract Renewals			0
Service Agreement Initiation Date			Dec13
Term (years)			10 years
Other Commitments
Term Of Renewal			0 years
Bakken Area Storage Hub Storage - TRMC Tanks [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Apr14
Term (years)			5 years
Other Commitments
Term Of Renewal			5 years
Transportation Services Agreement (LAR Short Haul Pipeline) [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Jul14
Term (years)			10 years
Other Commitments
Term Of Renewal			5 years
Terminalling & Dedicated Storage Services Agreement - Anacortes [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Jul14
Term (years)			10 years
Other Commitments
Term Of Renewal			5 years
THPP Reversal Open Season Northbound Commitment [Member]
Related Party Transaction
Service Agreement Initiation Date			Sep14
Term (years)			7 years
Tesoro Alaska Pipeline Throughput Agreement [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Sep14
Term (years)			10 years
Other Commitments
Term Of Renewal			5 years
Keep-Whole Commodity Fee Agreement
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Dec14
Term (years)			5 years
Other Commitments
Term Of Renewal			5 years
Crude OIl Trucking Transportation Services Agreement - WNRL [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Oct14
Term (years)			10 years
Other Commitments
Term Of Renewal			5 years
Fuel Distribution and Supply Agreement [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Oct14
Term (years)			10 years
Other Commitments
Term Of Renewal			5 years
Product Supply Agreement - WNRL [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Oct14
Term (years)			10 years
Other Commitments
Term Of Renewal			5 years
Kenai Storage Services Agreement [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Jul16
Term (years)			10 years
Other Commitments
Term Of Renewal			5 years
Terminalling, Transportation and Storage Services Agreement - St. Paul Park [Member]
Related Party Transaction
Service Agreement Initiation Date			Sep16
Term (years)			10 years
Other Commitments
Length Of Time For Continuing Minimum Payments			12 months
Alaska Terminalling Services Agreement [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Sep16
Term (years)			10 years
Other Commitments
Term Of Renewal			5 years
Martinez Storage Services Agreement [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Nov16
Term (years)			10 years
Other Commitments
Term Of Renewal			5 years
Crude OIl Trucking Transportation Services Agreement - WNRL [Member]
Related Party Transaction
Number Of Contract Renewals			0
Service Agreement Initiation Date			Oct15
Term (years)			1 month
Other Commitments
Term Of Renewal			0 years
Fuel Distribution and Supply Agreement [Member]
Related Party Transaction
Number Of Contract Renewals			0
Service Agreement Initiation Date			Jan16
Term (years)			10 years
Other Commitments
Term Of Renewal			0 years
Product Supply Agreement - WNRL [Member]
Related Party Transaction
Number Of Contract Renewals			0
Service Agreement Initiation Date			Feb16
Term (years)			1 year
Other Commitments
Term Of Renewal			0 years
Carson Tank Farm Storage Agreement
Related Party Transaction
Number Of Contract Renewals	[1]		2
Service Agreement Initiation Date	[1]		Jun13
Term (years)	[1]		10 years
Other Commitments
Term Of Renewal	[1]		5 years
Term Of Modification	[1]		20 years
Terminalling, Transportation, and Storage Services Agreement - WNRL [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Oct13
Term (years)			10 years
Other Commitments
Term Of Renewal			5 years
Length Of Time For Continuing Minimum Payments			12 months
Amended Pipeline and Gathering Services Agreement - WNRL [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Oct13
Term (years)			10 years
Other Commitments
Term Of Renewal			5 years
Length Of Time For Continuing Minimum Payments			12 months
Asphalt and Propane Rack Loading Services Agreement [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			May16
Term (years)			10 years
Other Commitments
Term Of Renewal			5 years
Southern California Terminalling Services Agreement [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Jun13
Term (years)			10 years
Other Commitments
Term Of Renewal			5 years
Carson Storage Services Agreement [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Jun13
Term (years)			10 years
Other Commitments
Term Of Renewal			5 years
Avon Marine Terminal Use and Throughput Agreement [Member]
Related Party Transaction
Number Of Contract Renewals			0
Service Agreement Initiation Date			Jan17
Term (years)			10 years
Other Commitments
Term Of Renewal			0 years
Belfield Crude & Oil Gathering [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Jan17
Term (years)			2 years
Other Commitments
Term Of Renewal			5 years
Amended Renewal Trucking Transportation Services Agreement [Member]
Related Party Transaction
Service Agreement Initiation Date			Apr17
Term (years)			1 year
Product Transportation Agreement (TRMC, WRSW, WRCLP, SPPRC) [Member]
Related Party Transaction
Service Agreement Initiation Date			Jan18
Term (years)			1 year
Plant Dedication Agreement (Robinson Lake and Belfield) [Member]
Related Party Transaction
Service Agreement Initiation Date			Apr18
Term (years)			3 years
Product Sales Agreement - Robinson Lake [Member]
Related Party Transaction
Service Agreement Initiation Date			Apr18
Term (years)			3 years
Product Sales Agreement - Belfield [Member]
Related Party Transaction
Service Agreement Initiation Date			Apr18
Term (years)			3 years
Product Sales Agreement Y-Grade - Robinson Lake [Member]
Related Party Transaction
Service Agreement Initiation Date			May18
Term (years)			1 month
SLC Core Crude Throughput [Member]
Related Party Transaction
Service Agreement Initiation Date			May18
Term (years)			2 months 12 days
Truck Loading (H2S) Little Knife [Member]
Related Party Transaction
Service Agreement Initiation Date			Jun18
Term (years)			6 years
Truck Unloading Facility Throughput Agreement (Stanley LACT) [Member]
Related Party Transaction
Service Agreement Initiation Date			Jun18
Term (years)			3 years
Transportation Services Agreement (LAR Interconnecting Pipelines) [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Aug18
Term (years)			10 years
Other Commitments
Term Of Renewal			5 years
Length Of Time For Continuing Minimum Payments			12 months
Amended Master Terminalling Services Agreement [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Aug18
Term (years)			10 years
Other Commitments
Term Of Renewal			5 years
Master Unloading and Storage Agreement [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Aug18
Term (years)			10 years
Other Commitments
Term Of Renewal			5 years
Amended Asphalt Terminalling, Transportation and Storage Services Agreement [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Aug18
Term (years)			10 years
Other Commitments
Term Of Renewal			5 years
Length Of Time For Continuing Minimum Payments			30 days
Fryburg Terminal Services Agreement [Member]
Related Party Transaction
Service Agreement Initiation Date			Aug18
Term (years)			2 years 7 months
Transloading Services Agreement - Salt Lake City Spur [Member]
Related Party Transaction
Service Agreement Initiation Date			Oct18
Term (years)			3 years
Natural Gas Liquids Marketing Agreement [Member]
Related Party Transaction
Service Agreement Initiation Date			Oct18
Term (years)			3 years
Amended Salt Lake City Storage and Transportation Services Agreement [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Apr11
Term (years)			10 years
Other Commitments
Term Of Renewal			5 years
Length Of Time For Continuing Minimum Payments			12 months
Carson Coke Handling Services Agreement [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Dec13
Term (years)			10 years
Other Commitments
Term Of Renewal			5 years
Amended and Restated Long Beach Berth Access Use and Throughput Agreement [Member]
Related Party Transaction
Number Of Contract Renewals			2
Service Agreement Initiation Date			Dec13
Term (years)			10 years
Other Commitments
Term Of Renewal			5 years
Transportation Services Agreement (Anacortes Short Haul Pipelines) [Member]
Related Party Transaction
Service Agreement Initiation Date			Nov17
Term (years)			10 years
Anacortes Manifest Rail Terminalling Services Agreement [Member]
Related Party Transaction
Service Agreement Initiation Date			Nov17
Term (years)			10 years
Anacortes Marine Terminal Operating Agreement [Member]
Related Party Transaction
Service Agreement Initiation Date			Nov17
Term (years)			17 years
Storage Services Agreement-Anacortes II [Member]
Related Party Transaction
Service Agreement Initiation Date			Nov17
Term (years)			10 years
Partner to Andeavor [Member] | Omnibus Agreement
Other Commitments
Payment for Administrative Fees			$ 17
Partner to Andeavor [Member] | Secondment and Logistics Services Agreement
Other Commitments
Long-term Purchase Commitment, Amount			8	$ 8	$ 5
Affiliated Entity [Member]
Related Party Transaction
Operating Leases, Income Statement, Lease Revenue			$ 407
Subsequent Event | Secondment and Logistics Services Agreement
Related Party Transaction
Term (years)		10 years
Other Commitments
Length Of Time For Continuing Minimum Payments		60 days
[1]	Agreement gives Marathon the option to renew for two five-year terms, or Marathon may modify the term of the agreements to a twenty-year term by providing notice in accordance with each agreement.

Related-Party Transactions, Sum

Related-Party Transactions, Summary of Affiliate Transactions (Details) - USD ($) $ / shares in Units, $ in Millions

3 Months Ended

12 Months Ended

Mar. 31, 2019

Dec. 31, 2018

Sep. 30, 2018

[1]

Jun. 30, 2018

[1]

Mar. 31, 2018

[1]

Dec. 31, 2017

[1]

Sep. 30, 2017

[1]

Jun. 30, 2017

[1]

Mar. 31, 2017

[1]

Dec. 31, 2018

Dec. 31, 2017

Dec. 31, 2016

Related Party Transaction

Revenues

$ 623

$ 642

$ 569

$ 546

$ 1,114

$ 1,094

$ 614

$ 427

$ 2,380

[2]

$ 3,249

[2]

$ 1,669

[2]

Operating and maintenance expenses

[3]

272

251

308

General and administrative expenses

98

101

80

Imbalance settlement gains

(16)

(12)

(7)

Reimbursements from Andeavor

15

16

17

Quarterly cash distributions, including IDRs

(493)

(336)

(245)

Subsequent Event

Related Party Transaction

Quarterly cash distributions, including IDRs

$ (146)

Distribution Made to Limited Partner, Declaration Date

Jan. 25, 2019

Date of distribution

Feb. 14, 2019

Distribution Made to Limited Partner, Date of Record

Feb. 5, 2019

Secondment and Logistics Services Agreement | Subsequent Event

Related Party Transaction

Length Of Time For Continuing Minimum Payments

60 days

Term Of Agreement

10 years

Secondment and Logistics Services Agreement | Partner to Andeavor [Member]

Related Party Transaction

Long-term Purchase Commitment, Amount

8

8

5

Secondment and Logistics Services Agreement | Andeavor to Partner [Member]

Related Party Transaction

Long-term Purchase Commitment, Amount

77

29

18

Affiliated Entity [Member]

Related Party Transaction

Revenues

$ 1,589

$ 1,431

$ 847

Omnibus Agreement

Related Party Transaction

Years To Identify Conditions For Indemnification

5 years

Common | Subsequent Event

Related Party Transaction

Cash distributions paid per unit

$ 1.03

[1]

Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

[2]

All periods include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

[3]

Includes net imbalance settlement gains of $12 million and $7 million in the years ended December 31, 2017 and 2016, respectively. Due to the adoption of ASC 606 effective January 1, 2018, imbalance settlement gains of $16 million in the year ended December 31, 2018 were included in revenues. Includes reimbursements primarily related to pressure testing and repairs and maintenance costs pursuant to the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement of $15 million, $16 million and $17 million in the years ended December 31, 2018, 2017 and 2016, respectively.

Property, Plant and Equipment_3

Property, Plant and Equipment (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017
Property, Plant and Equipment
Property, Plant and Equipment, at Cost	[1]	$ 8,145	$ 7,243	[2]
Accumulated depreciation	[1]	(1,300)	(994)	[2]
Property, Plant and Equipment, Net		6,845	6,249	[2],[3]
Property Subject to or Available for Operating Lease, Gross		691	643
Property Subject to or Available for Operating Lease, Accumulated Depreciation		224	195
Terminals and tankage
Property, Plant and Equipment
Property, Plant and Equipment, at Cost		3,749	3,557	[2]
Pipelines
Property, Plant and Equipment
Property, Plant and Equipment, at Cost		3,411	2,825	[2]
Land and leasehold improvements
Property, Plant and Equipment
Property, Plant and Equipment, at Cost		297	282	[2]
Buildings and improvements
Property, Plant and Equipment
Property, Plant and Equipment, at Cost		87	91	[2]
Other
Property, Plant and Equipment
Property, Plant and Equipment, at Cost		82	142	[2]
Construction in progress
Property, Plant and Equipment
Property, Plant and Equipment, at Cost		$ 519	346	[2]
Maximum | Terminals and tankage
Property, Plant and Equipment
Property, Plant and Equipment, Useful Life	[4]	40 years
Maximum | Pipelines
Property, Plant and Equipment
Property, Plant and Equipment, Useful Life	[4]	30 years
Maximum | Land and leasehold improvements
Property, Plant and Equipment
Property, Plant and Equipment, Useful Life	[4]	29 years
Maximum | Buildings and improvements
Property, Plant and Equipment
Property, Plant and Equipment, Useful Life	[4]	28 years
Maximum | Other
Property, Plant and Equipment
Property, Plant and Equipment, Useful Life	[4]	28 years
Minimum | Terminals and tankage
Property, Plant and Equipment
Property, Plant and Equipment, Useful Life	[4]	3 years
Minimum | Pipelines
Property, Plant and Equipment
Property, Plant and Equipment, Useful Life	[4]	5 years
Minimum | Land and leasehold improvements
Property, Plant and Equipment
Property, Plant and Equipment, Useful Life	[4]	3 years
Minimum | Buildings and improvements
Property, Plant and Equipment
Property, Plant and Equipment, Useful Life	[4]	3 years
Minimum | Other
Property, Plant and Equipment
Property, Plant and Equipment, Useful Life	[4]	1 year
Predecessor [Member]
Property, Plant and Equipment
Property, Plant and Equipment, at Cost			948
Accumulated depreciation			$ (112)
[1]	Assets owned by us for which we are the lessor under operating leases were $691 million and $643 million before accumulated depreciation of $224 million and $195 million as of December 31, 2018 and 2017, respectively.
[2]	Property, plant and equipment transferred to the Partnership in the 2018 Drop Down was recorded at historical costs. The Partnership recorded property, plant and equipment of $948 million and accumulated depreciation of $112 million as of December 31, 2017 in connection with the 2018 Drop Down.
[3]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[4]	The above excludes assets not being depreciated.

Note 5 - Acquired Intangibles_3

Note 5 - Acquired Intangibles and Goodwill Acquired Intangibles and Goodwill (Details)	12 Months Ended
	Dec. 31, 2018USD ($)		Dec. 31, 2017USD ($)		Dec. 31, 2016USD ($)
Goodwill
Acquired Intangibles, Net	$ 1,104,000,000		$ 1,154,000,000	[1]
Finite-Lived Intangible Assets, Accumulated Amortization	156,000,000		106,000,000
Amortization of Intangible Assets	50,000,000		46,000,000		$ 29,000,000
Finite-Lived Intangible Assets, Amortization Expense, Next Twelve Months	50,000,000
Finite-Lived Intangible Assets, Amortization Expense, Year Two	50,000,000
Finite-Lived Intangible Assets, Amortization Expense, Year Three	50,000,000
Finite-Lived Intangible Assets, Amortization Expense, Year Four	50,000,000
Finite-Lived Intangible Assets, Amortization Expense, Year Five	50,000,000
Goodwill	1,051,000,000		956,000,000	[1]
Goodwill, Impairment Loss	$ 0		0		$ 0
Number of Reporting Units	5
Operating Segments [Member] | Terminalling and Transportation Segment [Member]
Goodwill
Goodwill	$ 284,000,000	[2]	260,000,000	[3],[4]
Operating Segments [Member] | Gathering and Processing [Member]
Goodwill
Goodwill	718,000,000	[2]	607,000,000	[3],[4]
Operating Segments [Member] | Wholesale [Member]
Goodwill
Goodwill	$ 49,000,000	[2]	89,000,000
Predecessor [Member] | Operating Segments [Member] | Terminalling and Transportation Segment [Member]
Goodwill
Goodwill			39,000,000
Predecessor [Member] | Operating Segments [Member] | Gathering and Processing [Member]
Goodwill
Goodwill			$ 225,000,000
[1]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[2]	In connection with the finalization of the purchase price allocation associated with the WNRL Merger during 2018, we reallocated goodwill amongst the segments.
[3]	Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.
[4]	Goodwill transferred to the Partnership in the 2018 Drop Down was recorded at historical cost. We recorded goodwill of $39 million and $225 million in our Terminalling and Transportation and Gathering and Processing segments, respectively, as of December 31, 2017 as a result of the 2018 Drop Down.

Note 6 - Equity Method Invest_3

Note 6 - Equity Method Investments and Joint Ventures Equity Method Investments, Narrative (Details)	Dec. 31, 2018
Rangeland RIO Pipeline, LLC [Member]
Equity Method Investment, Ownership Percentage	67.00%
Minnesota Pipe Line Company, LLC [Member]
Equity Method Investment, Ownership Percentage	17.00%
PNAC [Member]
Equity Method Investment, Ownership Percentage	50.00%
Rendezvous Gas Services, L.L.C.
Equity Method Investment, Ownership Percentage	78.00%
Three Rivers Gathering, LLC
Equity Method Investment, Ownership Percentage	50.00%
Uintah Basin Field Services, LLC
Equity Method Investment, Ownership Percentage	38.00%

Note 6 - Equity Method Invest_4

Note 6 - Equity Method Investments and Joint Ventures Equity Method Investments, Table (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018		Dec. 31, 2017		Dec. 31, 2016
Schedule of Equity Method Investments [Line Items]
Payments to Acquire Equity Method Investments		$ 186		$ 120
Equity Method Investments		440	[1]	337
Equity in earnings	[2]	31		22		$ 13
Cumulative Effect of New Accounting Principle in Period of Adoption		(3)
Distributions received		(52)		(39)
Equity Method Investments		602		440	[1]	337
Rangeland RIO Pipeline, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Payments to Acquire Equity Method Investments	[3]	159		0
Equity Method Investments	[3]	0	[4]	0
Equity in earnings	[3]	6		0
Cumulative Effect of New Accounting Principle in Period of Adoption	[3]	0
Distributions received	[3]	(5)		0
Equity Method Investments		160	[4]	0	[3],[4]	0	[3]
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity		75		0	[5]
Minnesota Pipe Line Company, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Payments to Acquire Equity Method Investments	[3]	0		120
Equity Method Investments	[3]	120	[4]	0
Equity in earnings	[3]	17		12
Cumulative Effect of New Accounting Principle in Period of Adoption	[3]	0
Distributions received	[3]	(20)		(12)
Equity Method Investments		117	[4]	120	[3],[4]	0	[3]
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity		34		35	[5]
PNAC [Member]
Schedule of Equity Method Investments [Line Items]
Payments to Acquire Equity Method Investments	[3]	27		0
Equity Method Investments	[3]	0	[4]	0
Equity in earnings	[3]	(1)		0
Cumulative Effect of New Accounting Principle in Period of Adoption	[3]	0
Distributions received	[3]	0		0
Equity Method Investments		26	[4]	0	[3],[4]	0	[3]
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity		17		0	[5]
Rendezvous Gas Services, L.L.C.
Schedule of Equity Method Investments [Line Items]
Payments to Acquire Equity Method Investments		0		0	[3]
Equity Method Investments		268	[4]	281
Equity in earnings		5		6
Cumulative Effect of New Accounting Principle in Period of Adoption		0
Distributions received		(20)		(19)
Equity Method Investments		253	[4]	268	[4]	281
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity		125		130
Three Rivers Gathering, LLC
Schedule of Equity Method Investments [Line Items]
Payments to Acquire Equity Method Investments		0		0	[3]
Equity Method Investments		37	[4]	40
Equity in earnings		3		2
Cumulative Effect of New Accounting Principle in Period of Adoption		(3)
Distributions received		(5)		(5)
Equity Method Investments		32	[4]	37	[4]	40
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity		14		15
Uintah Basin Field Services, LLC
Schedule of Equity Method Investments [Line Items]
Payments to Acquire Equity Method Investments		0		0	[3]
Equity Method Investments		15	[4]	16
Equity in earnings		1		2
Cumulative Effect of New Accounting Principle in Period of Adoption		0
Distributions received		(2)		(3)
Equity Method Investments		14	[4]	15	[4]	$ 16
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity		$ 6		$ 6
[1]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[2]	All periods include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[3]	These equity method investments were included in the 2018 Drop Down. Amounts were adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[4]	The carrying amounts of our investments that exceed the underlying equity in net assets are amortized over the useful life of the underlying fixed assets and included in equity in earnings. The carrying amount of our investments in these equity method investments exceeded the underlying equity in net assets as shown below. December 31,(in millions)2018 2017 (c)ALRP$75 $—MPL34 35PNAC17 —RGS125 130TRG14 15UBFS6 6
[5]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

Other Current Assets and Liab_3

Other Current Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Prepaid Expense and Other Assets, Current [Abstract]
Deferred charges	$ 45	$ 0	[1]
Inventories	22	12	[1]
Prepayments	12	15	[1]
Total Other Current Assets	79	27	[2]
Accrued Liabilities, Current [Abstract]
Deferred income	24	23	[3]
Taxes other than income taxes	22	20	[3]
Employee costs	11	7	[3]
Asset retirement obligation	10	11	[3]
Accrued environmental liabilities	4	12	[3]
Other	10	11	[3]
Total Other Current Liabilities	$ 81	$ 84	[2]
[1]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[2]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[3]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

Debt, Total (Details)

Debt, Total (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Debt Instrument
Capital lease obligations	$ 15	$ 9
Total Debt	5,010	4,182
Debt Instrument, Unamortized Discount (Premium) and Debt Issuance Costs, Net	(46)	(54)
Long-term Debt and Capital Lease Obligations, Current	(504)	(1)
Debt, Net of Current Maturities and Unamortized Issuance Costs	4,460	4,127	[1]
Debt Instrument, Unamortized Discount	4	5
Long-term Debt, Maturities, Repayments of Principal in Next Rolling Twelve Months	504
Long-term Debt, Maturities, Repayments of Principal in Year Two	2
Long-term Debt, Maturities, Repayments of Principal in Year Three	1,200
Long-term Debt, Maturities, Repayments of Principal in Year Four	802
Long-term Debt, Maturities, Repayments of Principal in Year Five	1
Loans Payable [Member] | MPC Loan Agreement [Member]
Debt Instrument
Revolving Credit Facility	0	0
Senior Notes [Member] | 5.200% Senior Notes due 2047 [Member]
Debt Instrument
Senior Notes	500	500
Senior Notes [Member] | 4.250% Senior Notes due 2027 [Member]
Debt Instrument
Senior Notes	750	750
Senior Notes [Member] | 5.250% Senior Notes due 2025
Debt Instrument
Senior Notes	750	750
Senior Notes [Member] | 6.375% Senior Notes due 2024
Debt Instrument
Senior Notes	450	450
Senior Notes [Member] | 6.250% Senior Notes Due 2022
Debt Instrument
Senior Notes	300	300
Senior Notes [Member] | 5.50% Senior Notes Due 2019 [Member]
Debt Instrument
Senior Notes	500	500
Senior Notes [Member] | 3.500% Senior Notes due 2022 [Member]
Debt Instrument
Senior Notes	500	500
Revolving Credit Facility | Revolving Credit Facility
Debt Instrument
Revolving Credit Facility	945	423
Revolving Credit Facility | Dropdown Credit Facility
Debt Instrument
Revolving Credit Facility	$ 300	$ 0
[1]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

Debt, Senior Notes (Details)

Debt, Senior Notes (Details) - USD ($) $ in Millions		Oct. 29, 2014	Dec. 31, 2018	Dec. 31, 2017		Dec. 31, 2016	Oct. 30, 2017
Repayments of Long-term Debt	[1]		$ 1	$ 2,070		$ 251
Accrued interest and financing costs			$ 41	$ 40	[2]
Debt Instrument, Face Amount		$ 1,300
Preferred Units, Outstanding			600,000	600,000
6.125% Senior Notes due 2021
Debt Instrument, Interest Rate, Stated Percentage			6.125%
5.875% Senior Notes due 2020
Debt Instrument, Interest Rate, Stated Percentage			5.875%
6.250% Senior Notes Due 2022
Debt Instrument, Interest Rate, Stated Percentage		6.25%
Debt Instrument, Maturity Date		Oct. 15, 2022
6.375% Senior Notes due 2024
Redemption premium, percentage of face value			35.00%
Senior Notes [Member] | 7.5% Senior Notes due 2023 [Member]
Debt Instrument, Interest Rate, Stated Percentage							7.50%
Repayments of Long-term Debt	[1]			$ 326
Accrued interest and financing costs							$ 4
Debt Instrument, Premium Paid							22
Debt Instrument, Face Amount							$ 300
Senior Notes [Member] | 6.125% Senior Notes due 2021
Debt Instrument, Maturity Date			Aug. 31, 2021
Senior Notes [Member] | 5.875% Senior Notes due 2020
Debt Instrument, Maturity Date			Sep. 14, 2020
Senior Notes [Member] | 5.5% Senior Notes due 2019
Debt Instrument, Interest Rate, Stated Percentage			5.50%
Debt Instrument, Maturity Date		Oct. 15, 2019
Debt Instrument, Face Amount		$ 500
Senior Notes [Member] | 6.250% Senior Notes Due 2022
Debt Instrument, Interest Rate, Stated Percentage		6.25%
Debt Instrument, Maturity Date		Oct. 15, 2022
Senior Notes			$ 300	300
Debt Instrument, Face Amount		$ 800
Senior Notes [Member] | 6.250% Senior Notes Due 2022 | Debt Instrument, Redemption Period One
Debt Instrument Redemption Premium Percentage			3.125%
Senior Notes [Member] | 6.250% Senior Notes Due 2022 | Debt Instrument, Redemption Period Two
Debt Instrument Redemption Premium Percentage			1.563%
Senior Notes [Member] | 3.500% Senior Notes due 2022 [Member]
Debt Instrument, Interest Rate, Stated Percentage			3.50%
Debt Instrument, Maturity Date			Dec. 1, 2022
Senior Notes			$ 500	500
Debt Instrument, Face Amount				500
Senior Notes [Member] | 6.375% Senior Notes due 2024
Debt Instrument, Interest Rate, Stated Percentage			6.375%
Debt Instrument, Maturity Date			May 1, 2024
Senior Notes			$ 450	450
Debt Instrument, Face Amount			$ 450
Debt Instrument Redemption With Equity Proceeds			106.375%
Senior Notes [Member] | 6.375% Senior Notes due 2024 | Debt Instrument, Redemption Period One
Debt Instrument Redemption Premium Percentage			4.781%
Senior Notes [Member] | 6.375% Senior Notes due 2024 | Debt Instrument, Redemption Period Two
Debt Instrument Redemption Premium Percentage			3.188%
Senior Notes [Member] | 6.375% Senior Notes due 2024 | Debt Instrument, Redemption, Period Three
Debt Instrument Redemption Premium Percentage			1.594%
Senior Notes [Member] | 5.250% Senior Notes due 2025
Debt Instrument, Interest Rate, Stated Percentage			5.25%
Debt Instrument, Maturity Date			Jan. 15, 2025
Senior Notes			$ 750	750
Debt Instrument, Face Amount			$ 750
Redemption premium, percentage of face value			35.00%
Senior Notes [Member] | 5.250% Senior Notes due 2025 | Debt Instrument, Redemption Period One
Debt Instrument Redemption Premium Percentage			2.625%
Senior Notes [Member] | 5.250% Senior Notes due 2025 | Debt Instrument, Redemption Period Two
Debt Instrument Redemption Premium Percentage			1.313%
Debt Instrument Redemption With Equity Proceeds			105.25%
Senior Notes [Member] | 4.250% Senior Notes due 2027 [Member]
Debt Instrument, Interest Rate, Stated Percentage			4.25%
Debt Instrument, Maturity Date			Dec. 1, 2027
Senior Notes			$ 750	750
Senior Notes [Member] | 5.200% Senior Notes due 2047 [Member]
Debt Instrument, Interest Rate, Stated Percentage			5.20%
Debt Instrument, Maturity Date			Dec. 1, 2047
Senior Notes			$ 500	$ 500
[1]	All periods include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[2]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

Note 8 - Debt Debt, Credit Faci

Note 8 - Debt Debt, Credit Facilities (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Jan. 05, 2018	Dec. 31, 2017	Oct. 30, 2017
Line of Credit Facility [Line Items]
Debt Instrument, Unamortized Discount	$ 4		$ 5
Line of Credit Facility, Current Borrowing Capacity	2,100
Loans Payable [Member] | MPC Loan Agreement [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	$ 500
Debt Instrument, Basis Spread on Variable Rate	175.00%
Long-term Line of Credit	$ 0		0
Revolving Credit Facility | Dropdown Credit Facility [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	1,000
Long-term Line of Credit	300
Line of Credit Facility, Remaining Borrowing Capacity	$ 700
Line Of Credit Facility, Remaining Borrowing Capacity Percentage	70.00%
Debt, Weighted Average Interest Rate	4.14%
Revolving Credit Facility | Revolving Credit Facility
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	$ 1,100	$ 1,100	600
Long-term Line of Credit	945		$ 423
Line of Credit Facility, Remaining Borrowing Capacity	$ 155
Line Of Credit Facility, Remaining Borrowing Capacity Percentage	14.00%
Debt, Weighted Average Interest Rate	4.33%
Revolving Credit Facility | WNRL Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity				$ 500

Debt, Capital Lease (Details)

Debt, Capital Lease (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Capital Leased Assets
Capital lease renewal option	5 years
Total cost of assets under capital lease	$ 18	$ 11
Capital leases, accumulated amortization	4	$ 3
2,019	4
2,020	3
2,021	3
2,022	2
2,023	2
Thereafter	4
Total minimum lease payments	18
Less amount representing interest	(3)
Capital lease obligations	$ 15
Capital Lease Obligations
Capital Leased Assets
Capital lease initial term	15 years
Right Of Way
Capital Leased Assets
Capital lease initial term	31 years

Benefit Plans (Details)

Benefit Plans (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Pension and Other Postretirement Benefits Cost (Reversal of Cost) [Abstract]
Employee benefit plan expenses	$ 35	$ 34	$ 25

Note 10 - Commitments and Con_3

Note 10 - Commitments and Contingencies Operating Leases (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Operating Leases, Future Minimum Payments Due, Next Twelve Months	$ 17
Operating Leases, Future Minimum Payments, Due in Two Years	17
Operating Leases, Future Minimum Payments, Due in Three Years	15
Operating Leases, Future Minimum Payments, Due in Four Years	13
Operating Leases, Future Minimum Payments, Due in Five Years	13
Operating Leases, Future Minimum Payments, Due Thereafter	105
Operating Leases, Future Minimum Payments Due	180
Purchase Obligation, Due in Next Twelve Months	2,078
Purchase Obligation, Due in Second Year	2,084
Purchase Obligation, Due in Third Year	2,054
Purchase Obligation, Due in Fourth Year	2,013
Purchase Obligation, Due in Fifth Year	2,013
Purchase Obligation, Due after Fifth Year	1,673
Purchase Obligation	11,915
Contractual Obligation, Due in Next Fiscal Year	2,095
Contractual Obligation, Due in Second Year	2,101
Contractual Obligation, Due in Third Year	2,069
Contractual Obligation, Due in Fourth Year	2,026
Contractual Obligation, Due in Fifth Year	2,026
Contractual Obligation, Due after Fifth Year	1,778
Contractual Obligation	12,095
Operating Leases, Rent Expense	25	$ 19	$ 11
Unrecorded Unconditional Purchase Obligation, Purchases	311	$ 232	$ 192
Contractual Obligation, Future Minimum Payments Due, Remainder of Fiscal Year	297
Indemnification deductible	$ 1
Maximum
Lessee, Operating Lease, Term of Contract	26 years
Omnibus Agreement
Years To Identify Conditions For Indemnification	5 years
Keep-Whole Commodity Fee Agreement
Years To Identify Conditions For Indemnification	5 years
Los Angeles Logistics Assets [Member]
Years To Identify Conditions For Indemnification	10 years

Note 10 - Commitments and Con_4

Note 10 - Commitments and Contingencies Other Contingencies (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Loss Contingencies
Balance at December 31,	$ 16,000,000	$ 22,000,000
Additions	6,000,000	20,000,000
Expenditures	(16,000,000)	(26,000,000)
Balance at December 31,	6,000,000	16,000,000	$ 22,000,000
Fuel Spill Remediation Site Two
Loss Contingencies
Balance at December 31,	10,000,000	16,000,000
Additions	1,000,000	19,000,000
Expenditures	(11,000,000)	(25,000,000)
Balance at December 31,	0	10,000,000	16,000,000
Environmental Liability Insurance Deductible	1,000,000
Environmental Liabilities Insurance Coverage Limit	25,000,000
Insurance Settlements Receivable	0	0
Environmental Remediation Expense	93,000,000
Accrual for Environmental Loss Contingencies, Period Increase (Decrease)	68,000,000
Insurance proceeds from environmental expenditures	0	0	0
Other Liabilities
Loss Contingencies
Balance at December 31,	6,000,000	6,000,000
Additions	5,000,000	1,000,000
Expenditures	(5,000,000)	(1,000,000)
Balance at December 31,	$ 6,000,000	$ 6,000,000	$ 6,000,000

Note 11 - Equity and Net Earn_3

Note 11 - Equity and Net Earnings per Unit Equity, Unit Issuance and ATM Program (Details) - USD ($) $ / shares in Units, $ in Millions		Feb. 27, 2017	Jun. 01, 2016	Oct. 29, 2014	Sep. 30, 2018	Dec. 31, 2018	Dec. 31, 2017		Dec. 31, 2016		Dec. 01, 2017	Oct. 30, 2017	Aug. 22, 2017	Jun. 10, 2016	Dec. 31, 2015	Aug. 24, 2015
Preferred Stock, Dividend Rate, Percentage							6.875%
Limited Partners' Capital Account, Units Outstanding						245,493,184	217,097,057
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares					28,283,742
Preferred Units, Outstanding						600,000	600,000
Limited Partners' Capital Account, Units Issued (units)		5,000,000
Price per unit (dollars per unit)		$ 56.19	$ 47.13
Proceeds from Issuance of Common Limited Partners Units						$ 0	$ 284		$ 364	[1]
General partner units issued (units)		101,980
Proceeds from issuance of units, net of issuance costs							$ 879		293
Preferred Stock, Redemption Price Per Share											$ 1,000
Debt Instrument, Face Amount				$ 1,300
Preferred Units, Description							February 15, 2023
Preferred Stock, Par or Stated Value Per Share							$ 1,020				$ 1,000
Preferred Stock, Liquidation Preference Per Share							$ 68.75
Partners' Capital						4,674	$ 4,806	[2]	2,159						$ 2,242
Distribution Made to Limited Partner, Cash Distributions Declared						$ 890	$ 611		$ 344
Common Units Aggregate Value													$ 750			$ 750
Partners' Capital Account, Units, Sale of Units							5,100,000		6,300,000
Equity offering under ATM Program, net of issuance costs									$ 71
Common Unit, Issued			6,300,000											825,000
Limited Partner Units, Public
Limited Partners' Capital Account, Units Outstanding						89,320,056
Limited Partner Units, Affiliate
Limited Partners' Capital Account, Units Outstanding						156,173,128
General partner’s ownership interest						64.00%
TexNew Mex Units [Member]
Limited Partners' Capital Account, Units Outstanding						80,000
Cash distribution percent excess							80.00%
Partners' Capital						$ 1	$ 1
Distribution Made to Limited Partner, Cash Distributions Declared						0	0
Common
Proceeds from Issuance of Common Limited Partners Units		$ 281	$ 293
Proceeds from issuance of units, net of issuance costs							284		293
Partners' Capital						4,070	2,925		1,608						1,707
Distribution Made to Limited Partner, Cash Distributions Declared	[3]					890	$ 611		$ 344
Partners' Capital Account, Units, Sale of Units							5,000,000		6,300,000
Equity offering under ATM Program, net of issuance costs									$ 71
General Partner
Proceeds from issuance of units, net of issuance costs							$ 6		0
Partners' Capital						$ 0	$ 0		$ (66)						$ (13)
Partners' Capital Account, Units, Sale of Units							100,000		0
Equity offering under ATM Program, net of issuance costs									$ 0
2017 ATM Program [Member]
Partners' Capital Account, Units, Sale of Units						0	72,857
Equity offering under ATM Program, net of issuance costs							$ 3
2015ATMProgram [Member]
Common Unit, Issued									1,492,637
Proceeds from Sale of Interest in Partnership Unit									$ 72
WNRL Merger [Member] | Limited Partner Units, Public
Limited Partners' Capital Account, Units Issued (units)							15,182,996
WNRL Merger [Member] | Limited Partner Units, Affiliate
Limited Partners' Capital Account, Units Issued (units)							14,853,542
IDR/GP transaction [Member]
Limited Partners' Capital Account, Units Issued (units)												78,000,000
6.250% Senior Notes Due 2022
Debt Instrument, Interest Rate, Stated Percentage				6.25%
Debt Instrument, Maturity Date				Oct. 15, 2022
London Interbank Offered Rate (LIBOR) [Member] | Preferred Stock [Member]
Preferred Units, Description of Variable Rate Basis							4.652%
Senior Notes [Member] | 3.500% Senior Notes due 2022 [Member]
Debt Instrument, Face Amount							$ 500
Debt Instrument, Interest Rate, Stated Percentage						3.50%
Debt Instrument, Maturity Date						Dec. 1, 2022
Senior Notes [Member] | 6.250% Senior Notes Due 2022
Debt Instrument, Face Amount				$ 800
Debt Instrument, Interest Rate, Stated Percentage				6.25%
Debt Instrument, Maturity Date				Oct. 15, 2022
[1]	All periods include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[2]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[3]	Distributions of earnings for limited partners’ common units for the years ended December 31, 2018 and 2017 is net of a $60 million and $25 million waiver, respectively, from our Sponsor in connection with the WNRL Merger.

Note 11 - Equity and Net Earn_4

Note 11 - Equity and Net Earnings per Unit Equity, Net Earnings per Unit (Details) $ / shares in Units, shares in Millions, $ in Millions		3 Months Ended																9 Months Ended	12 Months Ended
		Dec. 31, 2018USD ($)$ / shares		Sep. 30, 2018USD ($)$ / shares		Jun. 30, 2018USD ($)$ / shares		Mar. 31, 2018USD ($)$ / shares		Dec. 31, 2017USD ($)$ / shares		Sep. 30, 2017USD ($)$ / shares		Jun. 30, 2017USD ($)$ / shares		Mar. 31, 2017USD ($)$ / shares		Sep. 30, 2017$ / shares	Dec. 31, 2018USD ($)$ / sharesshares		Dec. 31, 2017USD ($)$ / sharesshares		Dec. 31, 2016USD ($)$ / sharesshares
Net earnings		$ 171		$ 166	[1]	$ 132	[1]	$ 131	[1]	$ 53	[1]	$ 90	[1]	$ 90	[1]	$ 73	[1]		$ 600	[2],[3],[4]	$ 306	[2],[3],[4]	$ 277	[2],[3],[4],[5]
Special Allocation Of Net Earnings																			0		(1)	[6]	(3)	[6]
Net Earnings, Excluding Noncontrolling Interest and Including Special Allocations																			600		307		280
Distributions on Preferred Units (c)	[7]																		(41)		(3)		0
Net earnings attributable to common units	[2]																		559		304		280
General Partner Distributions																			0		(81)		(158)
General partner's IDRs																					(50)
Limited Partner's Distributions on units																			(890)		(611)		(344)
Distributions greater than earnings																			$ (331)		$ (388)		$ (222)
Common units - basic (units) | shares																			228.7		126		98.2
Common units - diluted (units) | shares	[8]																		228.9		126.1		98.2
Common - basic (dollars per unit) | $ / shares		$ 0.66	[9]	$ 0.68	[9]	$ 0.63	[9]	$ 0.59	[9]	$ 0.25	[9]	$ 0.90	[9]	$ 0.63	[9]	$ 0.51	[9]		$ 2.57	[10]	$ 2.11	[10]	$ 1.87	[10]
Common - diluted (dollars per unit) | $ / shares		$ 0.66	[9]	$ 0.68	[9]	$ 0.63	[9]	$ 0.59	[9]	$ 0.25	[9]	$ 0.90	[9]	$ 0.63	[9]	$ 0.51	[9]		$ 2.57	[10]	$ 2.11	[10]	$ 1.87	[10]
Incentive Distribution, Distribution Split Marginal Percentage																		50.00%
Incentive Distribution, Minimum Distribution Level | $ / shares																		0.3881
Distribution to Partner, Waived Distribution																			$ 60		$ 25
Loss attributable to Predecessors																			(28)		(43)		$ (62)
General Partner
General Partner Distributions																			0		(6)		(10)
Distributions greater than earnings	[11]																		28		44		65
Total partner's earnings (loss) on units																			(28)		37		93
Loss attributable to Predecessors																			0		0		0
Common
Special Allocation Of Net Earnings																			0		(1)	[6]	(3)	[6]
Limited Partner's Distributions on units	[12]																		(890)		(611)		(344)
Distributions greater than earnings																			(303)		(344)		(157)
Total partner's earnings (loss) on units																			587		266		184
Loss attributable to Predecessors																			$ 0		$ 0		$ 0
[1]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[2]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[3]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[4]	All periods include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[5]	All periods include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[6]	Normal allocations according to percentage interests are made after giving effect, if any, to priority income allocations in an amount equal to incentive cash distributions fully allocated to the general partner and any special allocations. The adjustment reflects the special allocation to common units held by TLGP for the interest incurred in connection with borrowings on the Dropdown Credit Facility in lieu of using cash on hand to fund the North Dakota Gathering and Processing Assets in 2017 and the Alaska Storage and Terminalling Assets acquisition in 2016.
[7]	The Preferred Units entitle unitholders to receive preferred distributions on a semi-annually basis.
[8]	Diluted net earnings per unit include the effects of potentially dilutive units on our common units, which consist of unvested service and performance phantom units.
[9]	The sum of four quarters may not equal annual results due to rounding or the quarterly number of units outstanding.
[10]	Amounts may not recalculate due to rounding of dollar and unit information.
[11]	We have revised the historical allocation of general partner earnings to include the Predecessors’ losses of $28 million, $43 million and $62 million for the years ended December 31, 2018, 2017 and 2016, respectively.
[12]	Distributions of earnings for limited partners’ common units for the years ended December 31, 2018 and 2017 is net of a $60 million and $25 million waiver, respectively, from our Sponsor in connection with the WNRL Merger.

Note 11 - Equity and Net Earn_5

Note 11 - Equity and Net Earnings per Unit Equity, Allocation of General Partner (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017		Dec. 31, 2016
Net Earnings Attributable to Partners		$ 628	$ 349		$ 339
Distributions on Preferred Units (c)	[1]	(41)	(3)		0
Special Allocation		0	1	[2]	3	[2]
Net Earnings Available To Partners		$ 587	$ 272		$ 194
General partner’s ownership interest	[3]	0.00%	0.00%		2.00%
Loss attributable to Predecessors		$ (28)	$ (43)		$ (62)
Net Income (Loss) Allocated to General Partners		0	(79)		(152)
General Partner
Net Earnings Attributable to Partners		0	120		152
General partner's IDRs		0	(75)	[4]	(148)	[4]
Net Income (Loss) Allocated To General Partners, Excluding Incentive Distribution	[5]	0	4		4
Loss attributable to Predecessors		0	0		0
Net Income (Loss) Allocated to General Partners		$ (28)	$ 36		$ 90
[1]	The Preferred Units entitle unitholders to receive preferred distributions on a semi-annually basis.
[2]	Normal allocations according to percentage interests are made after giving effect, if any, to priority income allocations in an amount equal to incentive cash distributions fully allocated to the general partner and any special allocations. The adjustment reflects the special allocation to common units held by TLGP for the interest incurred in connection with borrowings on the Dropdown Credit Facility in lieu of using cash on hand to fund the North Dakota Gathering and Processing Assets in 2017 and the Alaska Storage and Terminalling Assets acquisition in 2016.
[3]	In connection with the IDR/GP Transaction, our general partner units converted into non-economic general partner units.
[4]	IDRs entitled the general partner to receive increasing percentages, up to 50%, of quarterly distributions in excess of $0.3881 per unit per quarter. The amount above reflects earnings distributed to our general partner net of $50 million of IDRs for the year ended December 31, 2017 waived by TLGP. Our general partner no longer holds IDRs as a result of the IDR/GP Transaction.
[5]	Prior to the IDR/GP Transaction, we allocated net earnings to our general partner based on its ownership interest.

Note 11 - Equity and Net Earn_6

Note 11 - Equity and Net Earnings per Unit Equity, Changes in Equity (Details) - shares shares in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Partners' Capital Account, Units	219.9	105.1	95.4
Partners' Capital Account, Units, Sale of Units		5.1	6.3
Partners' Capital Account, Units, Unit-based Compensation	0.1		0.1
Partners' Capital Account, Units	248.3	219.9	105.1
Common
Partners' Capital Account, Units	217.1	103	93.5
Partners' Capital Account, Units, Sale of Units		5	6.3
Partners' Capital Account, Units, Unit-based Compensation	0.1		0.1
Partners' Capital Account, Units	245.5	217.1	103
Preferred
Partners' Capital Account, Units	0.6	0	0
Partners' Capital Account, Units, Sale of Units		0	0
Partners' Capital Account, Units, Unit-based Compensation	0		0
Partners' Capital Account, Units	0.6	0.6	0
General Partner
Partners' Capital Account, Units	2.2	2.1	1.9
Partners' Capital Account, Units, Sale of Units		0.1	0
Partners' Capital Account, Units, Unit-based Compensation	0		0
Partners' Capital Account, Units	2.2	2.2	2.1
Northern California Term. and Stor. Assets
Partners' Capital Account, Units, Acquisitions			0.9
Northern California Term. and Stor. Assets | Common
Partners' Capital Account, Units, Acquisitions			0.9
Northern California Term. and Stor. Assets | Preferred
Partners' Capital Account, Units, Acquisitions			0
Northern California Term. and Stor. Assets | General Partner
Partners' Capital Account, Units, Acquisitions			0
Anacortes Logistics Assets
Partners' Capital Account, Units, Acquisitions		1
Anacortes Logistics Assets | Common
Partners' Capital Account, Units, Acquisitions		1
Anacortes Logistics Assets | Preferred
Partners' Capital Account, Units, Acquisitions		0
Anacortes Logistics Assets | General Partner
Partners' Capital Account, Units, Acquisitions		0
ATM Program
Partners' Capital Account, Units, Sale of Units		0.1	1.4
ATM Program | Common
Partners' Capital Account, Units, Sale of Units		0.1	1.4
ATM Program | Preferred
Partners' Capital Account, Units, Sale of Units		0	0
ATM Program | General Partner
Partners' Capital Account, Units, Sale of Units		0	0
Preferred Stock [Member]
Partners' Capital Account, Units, Sale of Units		0.6
Preferred Stock [Member] | Common
Partners' Capital Account, Units, Sale of Units		0
Preferred Stock [Member] | Preferred
Partners' Capital Account, Units, Sale of Units		0.6
Preferred Stock [Member] | General Partner
Partners' Capital Account, Units, Sale of Units		0
Phase One | Alaska Logistics Assets
Partners' Capital Account, Units, Acquisitions			0.6
Phase One | Alaska Logistics Assets | Common
Partners' Capital Account, Units, Acquisitions			0.4
Phase One | Alaska Logistics Assets | Preferred
Partners' Capital Account, Units, Acquisitions			0
Phase One | Alaska Logistics Assets | General Partner
Partners' Capital Account, Units, Acquisitions			0.2
Phase Two | Alaska Logistics Assets
Partners' Capital Account, Units, Acquisitions			0.4
Phase Two | Alaska Logistics Assets | Common
Partners' Capital Account, Units, Acquisitions			0.4
Phase Two | Alaska Logistics Assets | Preferred
Partners' Capital Account, Units, Acquisitions			0
Phase Two | Alaska Logistics Assets | General Partner
Partners' Capital Account, Units, Acquisitions			0
WNRL Merger [Member]
Partners' Capital Account, Units, Acquisitions	28.3	108
WNRL Merger [Member] | Common
Partners' Capital Account, Units, Acquisitions	28.3	108
WNRL Merger [Member] | Preferred
Partners' Capital Account, Units, Acquisitions	0	0
WNRL Merger [Member] | General Partner
Partners' Capital Account, Units, Acquisitions	0	0

Note 11 - Equity and Net Earn_7

Note 11 - Equity and Net Earnings per Unit Equity, Equity Transactions related to Acquisitions (Details) - USD ($) $ in Millions		9 Months Ended	12 Months Ended
		Sep. 30, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Class of Stock [Line Items]
Allocation of net assets acquired by the unitholders			$ 0	$ 0	$ 0
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest	[1]		0.00%	0.00%	2.00%
Payments to Acquire Businesses, Gross		$ 300	$ 300	$ 406	$ 760	[2]
Increase (Decrease) In Equity Balance Due To Acquisitions			(1,400)	(1,300)	443
Common
Class of Stock [Line Items]
Allocation of net assets acquired by the unitholders			$ 1,651	$ 1,713	$ 310
[1]	In connection with the IDR/GP Transaction, our general partner units converted into non-economic general partner units.
[2]	All periods include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

Note 11 - Equity and Net Earn_8

Note 11 - Equity and Net Earnings per Unit Equity, Cash Distributions (Details) - USD ($) $ / shares in Units, $ in Millions		3 Months Ended	12 Months Ended
		Mar. 31, 2019	Dec. 31, 2018	Dec. 31, 2017		Dec. 31, 2016
Distribution Made to Limited Partner, Cash Distributions Declared			$ (890)	$ (611)		$ (344)
General Partner Distributions			0	(81)		(158)
Distribution Made To Partners, Total Cash Distributions			(890)	(692)		(502)
Distributions to preferred unitholders			29	0		0	[1]
Subsequent Event
Distribution Made to Limited Partner, Declaration Date		Jan. 25, 2019
Distribution Made to Limited Partner, Date of Record		Feb. 5, 2019
Distribution Made to Limited Partner, Distribution Date		Feb. 14, 2019
Distributions to preferred unitholders		$ 21
General Partner
General Partner Distributions			0	(6)		(10)
General partner's IDRs			0	(75)	[2]	(148)	[2]
Common
Distribution Made to Limited Partner, Cash Distributions Declared	[3]		$ (890)	$ (611)		$ (344)
Common | Subsequent Event
Distribution Made to Limited Partner, Cash Distributions Declared		$ (238)
Cash distributions paid per unit		$ 1.03
[1]	All periods include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[2]	IDRs entitled the general partner to receive increasing percentages, up to 50%, of quarterly distributions in excess of $0.3881 per unit per quarter. The amount above reflects earnings distributed to our general partner net of $50 million of IDRs for the year ended December 31, 2017 waived by TLGP. Our general partner no longer holds IDRs as a result of the IDR/GP Transaction.
[3]	Distributions of earnings for limited partners’ common units for the years ended December 31, 2018 and 2017 is net of a $60 million and $25 million waiver, respectively, from our Sponsor in connection with the WNRL Merger.

Note 12 - Supplemental Cash F_3

Note 12 - Supplemental Cash Flow Information Supplemental Cash Flow Information Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Supplemental Cash Flow Additional Information
Interest paid, net	$ 209	$ 243	$ 165

Supplemental Cash Flow Informat

Supplemental Cash Flow Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Capital leases and other	$ 0	$ 0	$ 2
Predecessors’ net liabilities not assumed by Andeavor Logistics	13	0	22
Receivable from affiliate for capital expenditures	26	4	4
Accounts Payable [Member]
Capital Expenditures Incurred but Not yet Paid	105	50	30
Affiliate Payable [Member]
Capital Expenditures Incurred but Not yet Paid	$ 0	$ 0	$ 8

Note 13 - Revenues Revenues, Cu

Note 13 - Revenues Revenues, Customer Contract Assets and Liabilities (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018	Jan. 01, 2018	Dec. 31, 2017		Dec. 31, 2016
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Contract with Customer, Asset, Net		$ 32	$ 34	$ 0	[1]
Equity Method Investments		602		440	[2]	$ 337
Revenue, Remaining Performance Obligation, Amount		$ 4,000
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period		5 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Percent		85.00%
Contract with Customer, Liability, Revenue Recognized		$ 29
Deferred Revenue, Current		24	23	23	[1]
Deferred Revenue, Noncurrent		57	59	$ 43	[1]
Difference between Revenue Guidance in Effect before and after Topic 606 [Member] | Accounting Standards Update 2014-09 [Member]
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Contract with Customer, Asset, Net	[3],[4]		34
Contract with Customer, Asset, Reclassified to Receivable	[4]	$ 32
Equity Method Investments			3
Deferred Revenue, Current	[4]		0
Deferred Revenue, Noncurrent	[4]		$ 16
Maximum
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period		15 years
Minimum
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period		1 year
[1]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[2]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[3]	Included in the $34 million change to contract assets is a $32 million reclass from Receivables for amounts for which we were not allowed to invoice as of January 1, 2018.
[4]	These amounts exclude balances associated with equity method investments. We recognized a cumulative adjustment of $3 million as a decrease to Equity Method Investments in our consolidated balance sheets as of January 1, 2018 for the impacts related to our equity method investment in TRG. There were no material impacts to this balance during the year ended December 31, 2018 due to the adoption.

Note 13 - Revenues Revenues, Re

Note 13 - Revenues Revenues, Revenue Disaggregation (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		$ 2,000
Operating Leases, Income Statement, Lease Revenue		425	$ 277	$ 193
Wholesale [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		63
Wholesale [Member] | Refined Products [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	17
Wholesale [Member] | Crude oil and water gathering [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	0
Wholesale [Member] | Natural Gas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	0
Wholesale [Member] | Other Services [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	0
Wholesale [Member] | Service Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	17
Wholesale [Member] | Natural Gas Liquids [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0
Wholesale [Member] | Crude Oil Refined Products And Blending Products [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		46
Wholesale [Member] | Product Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		46
Gathering and Processing [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		1,263
Gathering and Processing [Member] | Refined Products [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1],[2]	0
Gathering and Processing [Member] | Crude oil and water gathering [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1],[2]	438
Gathering and Processing [Member] | Natural Gas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	391
Gathering and Processing [Member] | Other Services [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	0
Gathering and Processing [Member] | Service Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	829
Gathering and Processing [Member] | Natural Gas Liquids [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		434
Gathering and Processing [Member] | Crude Oil Refined Products And Blending Products [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0
Gathering and Processing [Member] | Product Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		434
Terminalling and Transportation Segment [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		1,054
Terminalling and Transportation Segment [Member] | Refined Products [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1],[2]	898
Terminalling and Transportation Segment [Member] | Crude oil and water gathering [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1],[2]	153
Terminalling and Transportation Segment [Member] | Natural Gas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	0
Terminalling and Transportation Segment [Member] | Other Services [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	3
Terminalling and Transportation Segment [Member] | Service Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	1,054
Terminalling and Transportation Segment [Member] | Natural Gas Liquids [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0
Terminalling and Transportation Segment [Member] | Crude Oil Refined Products And Blending Products [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0
Terminalling and Transportation Segment [Member] | Product Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		$ 0
[1]	Includes $425 million of lease revenues for the year ended December 31, 2018.
[2]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

Operating Segments, Narrative I

Operating Segments, Narrative Information (Details)	12 Months Ended
	Dec. 31, 2018segments
Segment Reporting, Disclosure of Entity's Reportable Segments [Abstract]
Number of Reportable Segments	3

Operating Segments, Results (De

Operating Segments, Results (Details) - USD ($) $ in Millions		3 Months Ended															12 Months Ended
		Dec. 31, 2018	Sep. 30, 2018	[1]	Jun. 30, 2018	[1]	Mar. 31, 2018	[1]	Dec. 31, 2017		Sep. 30, 2017	[1]	Jun. 30, 2017	[1]	Mar. 31, 2017	[1]	Dec. 31, 2018		Dec. 31, 2017		Dec. 31, 2016
Segment Reporting Information
Revenues		$ 623	$ 642		$ 569		$ 546		$ 1,114	[1]	$ 1,094		$ 614		$ 427		$ 2,380	[2]	$ 3,249	[2]	$ 1,669	[2]
Operating Income		224	215		180		177		179	[1]	147		146		131		796	[2]	603	[2]	448	[2]
Segment Reporting Operating Income Loss	[3]																835		657		475
Unallocated general and administrative expenses	[3]																(39)		(54)		(27)
Interest and financing costs, net	[2]																(233)		(330)		(195)
Equity in earnings of equity method investments	[2]																31		22		13
Other Income, net	[2]																6		11		11
Net Earnings		171	$ 166		$ 132		$ 131		53	[1]	$ 90		$ 90		$ 73		600	[2],[3],[4]	306	[2],[3],[4]	277	[2],[3],[4],[5]
Depreciation and amortization expenses	[5]																368		313		233	[3]
Additions to Other Assets, Amount	[3]																751		363		312
Total Assets		10,295							9,505	[6],[7]							10,295		9,505	[6],[7]
Operating Segments [Member] | Terminalling and Transportation Segment [Member]
Segment Reporting Information
Revenues																	1,054		838		605
Operating Income	[3]																498		397		240
Depreciation and amortization expenses	[3]																144		117		95
Additions to Other Assets, Amount	[3]																205		188		193
Total Assets		3,458							3,045	[7]							3,458		3,045	[7]
Operating Segments [Member] | Gathering and Processing [Member]
Segment Reporting Information
Revenues																	1,263		1,129		1,064
Operating Income	[3]																310		245		235
Depreciation and amortization expenses	[3]																213		191		138
Additions to Other Assets, Amount	[3]																545		175		119
Total Assets		6,488							6,006	[7]							6,488		6,006	[7]
Operating Segments [Member] | Wholesale Segment [Member]
Segment Reporting Information
Revenues																	79		1,282		0
Operating Income																	27		15		0
Depreciation and amortization expenses																	11		5		0
Additions to Other Assets, Amount																	1		0		0
Total Assets		255							342								255		342
Intersegment Eliminations [Member]
Segment Reporting Information
Revenues																	(16)		0		0
Corporate, Non-Segment [Member]
Segment Reporting Information
Total Assets		$ 94							$ 112								94		112
Terminalling revenues [Member] | Operating Segments [Member] | Terminalling and Transportation Segment [Member]
Segment Reporting Information
Revenues	[3]																888		690		480
Pipeline transportation revenues [Member] | Operating Segments [Member] | Terminalling and Transportation Segment [Member]
Segment Reporting Information
Revenues																	160		130		125
Other Terminalling and Transportation Revenue [Member] | Operating Segments [Member] | Terminalling and Transportation Segment [Member]
Segment Reporting Information
Revenues																	6		18		0
Sales of natural gas, NGLS and condensate [Member] | Operating Segments [Member] | Gathering and Processing [Member]
Segment Reporting Information
Revenues																	436		369		103
Gas gathering and processing [Member] | Operating Segments [Member] | Gathering and Processing [Member]
Segment Reporting Information
Revenues																	330		333		264
Crude oil and water gathering [Member] | Operating Segments [Member] | Gathering and Processing [Member]
Segment Reporting Information
Revenues	[3]																336		262		582
Pass-thru and other revenue [Member] | Operating Segments [Member] | Gathering and Processing [Member]
Segment Reporting Information
Revenues																	161		165		115
Fuel Sales [Member] | Operating Segments [Member] | Wholesale Segment [Member]
Segment Reporting Information
Revenues	[8]																46		1,267		0
Other Non-fuel [Member] | Operating Segments [Member] | Wholesale Segment [Member]
Segment Reporting Information
Revenues																	$ 33		$ 15		$ 0
[1]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[2]	All periods include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[3]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[4]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[5]	All periods include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[6]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[7]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[8]	The presentation of wholesale fuel sales was impacted by adoption of ASC 606 on January 1, 2018. Beginning January 1, 2018, the revenues and costs associated with our fuel purchase and supply arrangements were netted.

Quarterly Financial Data (Unaud

Quarterly Financial Data (Unaudited) (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended																12 Months Ended
	Dec. 31, 2018		Sep. 30, 2018		Jun. 30, 2018		Mar. 31, 2018		Dec. 31, 2017		Sep. 30, 2017		Jun. 30, 2017		Mar. 31, 2017		Dec. 31, 2018		Dec. 31, 2017		Dec. 31, 2016
Quarterly Financial Data
Revenues	$ 623		$ 642	[1]	$ 569	[1]	$ 546	[1]	$ 1,114	[1]	$ 1,094	[1]	$ 614	[1]	$ 427	[1]	$ 2,380	[2]	$ 3,249	[2]	$ 1,669	[2]
Operating expenses	227		236	[1]	221	[1]	201	[1]	179	[1]	199	[1]	171	[1]	142	[1]	885	[1],[2]	691	[1],[2]	560	[2]
Operating income	224		215	[1]	180	[1]	177	[1]	179	[1]	147	[1]	146	[1]	131	[1]	796	[2]	603	[2]	448	[2]
Net earnings	171		166	[1]	132	[1]	131	[1]	53	[1]	90	[1]	90	[1]	73	[1]	600	[2],[3],[4]	306	[2],[3],[4]	277	[2],[3],[4],[5]
Limited partners’ interest in net earnings	$ 161		$ 160		$ 138		$ 125		$ 47	[6]	$ 97	[6]	$ 70	[6]	$ 55	[6]	$ 584		$ 267		$ 187
Net earnings (loss) per limited partner unit:
Common - basic (dollars per unit)	$ 0.66	[6]	$ 0.68	[6]	$ 0.63	[6]	$ 0.59	[6]	$ 0.25	[6]	$ 0.90	[6]	$ 0.63	[6]	$ 0.51	[6]	$ 2.57	[7]	$ 2.11	[7]	$ 1.87	[7]
Common - diluted (dollars per unit)	$ 0.66	[6]	$ 0.68	[6]	$ 0.63	[6]	$ 0.59	[6]	$ 0.25	[6]	$ 0.90	[6]	$ 0.63	[6]	$ 0.51	[6]	$ 2.57	[7]	$ 2.11	[7]	$ 1.87	[7]
Natural Gas, Midstream [Member]
Quarterly Financial Data
Cost of Goods and Services Sold	$ 40	[8]	$ 73	[8]	$ 45	[8]	$ 48	[8]	$ 86	[8]	$ 64	[8]	$ 56	[8]	$ 59	[8]	$ 206	[2]	$ 265	[2],[8]	$ 2	[2]
Oil and Gas, Purchased [Member]
Quarterly Financial Data
Cost of Goods and Services Sold									$ 528	[8],[9]	$ 554	[8],[9]	$ 162	[8],[9]	$ 0	[8],[9]	$ 0	[2],[10]	$ 1,244	[2],[8],[9],[10]	$ 316	[2],[10]
[1]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[2]	All periods include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[3]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[4]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[5]	All periods include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[6]	The sum of four quarters may not equal annual results due to rounding or the quarterly number of units outstanding.
[7]	Amounts may not recalculate due to rounding of dollar and unit information.
[8]	Excludes direct operating expenses incurred across our operating segments and depreciation and amortization expenses.
[9]	Due to the adoption of ASC 606 effective January 1, 2018, the revenues and costs associated with our fuel purchase and supply arrangements for the year ended December 31, 2018 were netted. See Note 1 for further discussion.
[10]	Due to the adoption of ASC 606 effective January 1, 2018, the revenues and costs associated with our fuel purchase and supply arrangements for year ended December 31, 2018 were netted. See Note 1 for further discussion.