Andeavor Logistics (ANDX) 10-Q 7 Nov 18 2018 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2018	Nov. 02, 2018
Document and Entity Information [Abstract]
Entity Registrant Name	ANDEAVOR LOGISTICS LP
Entity Central Index Key	1,507,615
Document Type	10-Q
Document Period End Date	Sep. 30, 2018
Amendment Flag	false
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	Q3
Current Fiscal Year End Date	--12-31
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Filer Category	Large Accelerated Filer
Limited Partners' Capital Account, Units Issued		245,484,047

Condensed Statements of Consoli

Condensed Statements of Consolidated Operations (unaudited) Statement - USD ($) shares in Millions, $ in Millions		3 Months Ended			9 Months Ended
		Sep. 30, 2018	Sep. 30, 2017		Sep. 30, 2018		Sep. 30, 2017
Revenues: (b)
Revenues		$ 642	$ 1,094	[1],[2],[3]	$ 1,757		$ 2,135	[1],[2],[3]
Costs and Expenses:
Operating expenses (excluding depreciation and amortization)		236	199	[1]	658		512	[1]
Depreciation and amortization expenses		86	85	[1],[2]	268	[4]	222	[1],[2],[4]
General and administrative expenses		31	44	[1]	91		107	[1]
Loss (gain) on asset disposals and impairments		(1)	(1)	[1]	(2)	[4]	25	[1],[4]
Operating Income		215	147	[1],[2]	572		424	[1],[2]
Interest and financing costs, net		(57)	(68)	[1],[2]	(172)		(193)	[1],[2]
Equity in earnings of equity method investments		7	6	[1],[2]	25		13	[1],[2]
Other income, net		1	5	[1],[2]	4		9	[1],[2]
Net Earnings		166	90	[1],[2]	429	[4]	253	[1],[2],[4]
Loss attributable to Predecessors		4	7		28		46
Net Earnings Attributable to Partners		170	97		457		299
Preferred unitholders’ interest in net earnings		(10)	0		(34)		0
General partner’s interest in net earnings, including incentive distribution rights		0	0		0		(79)
Limited Partners’ Interest in Net Earnings		$ 160	$ 97		$ 423		$ 220
Net earnings per limited partner unit
Common - basic	[5]	$ 0.68	$ 0.90		$ 1.91		$ 2.05
Common - diluted	[5]	$ 0.68	$ 0.90		$ 1.91		$ 2.05
Weighted average limited partner units outstanding
Common units - basic		234.4	108		223		107
Common units - diluted	[6]	234.6	108.1		223.2		107.1
Cash distributions paid per unit		$ 1.030	$ 0.971		$ 3.045		$ 2.821
Affiliated Entity
Revenues: (b)
Revenues		$ 415	$ 468		$ 1,131		$ 951
Third Party
Revenues: (b)
Revenues		227	626		626		1,184
Oil and Gas, Purchased
Costs and Expenses:
Cost of Goods and Services Sold	[3]	0	554	[1]	0	[1]	716	[1]
Natural Gas, Midstream
Costs and Expenses:
Cost of Goods and Services Sold		$ 73	$ 64	[1]	$ 166		$ 179	[1]
[1]	Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.
[2]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[3]	Due to the adoption of the revenue recognition standard effective January 1, 2018, the revenues and costs associated with our fuel purchase and supply arrangements with Andeavor for the three and nine months ended September 30, 2018 were netted. See Note 1 for further discussion.
[4]	Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.
[5]	Amounts may not recalculate due to rounding of dollar and unit information.
[6]	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.

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Current Assets
Cash and cash equivalents	$ 30	$ 75	[1]
Receivables, net of allowance for doubtful accounts
Trade and other	250	219	[1]
Affiliate	251	264	[1]
Prepayments and other current assets	81	27	[1]
Total Current Assets	612	585	[1]
Property, Plant and Equipment, Net
Property, plant and equipment, at cost	7,965	7,243	[1]
Accumulated depreciation	(1,215)	(994)	[1]
Property, Plant and Equipment, Net	6,750	6,249	[1]
Acquired Intangibles, Net	1,116	1,154	[1]
Goodwill	988	956	[2]
Equity Method Investments	607	440	[1]
Other Noncurrent Assets, Net	124	121	[1]
Total Assets	10,197	9,505	[1],[3]
Accounts payable
Trade and other	201	186	[1]
Affiliate	254	207	[1]
Accrued interest and financing costs	68	40	[1]
Other current liabilities	81	85	[1]
Total Current Liabilities	604	518	[1]
Debt, Net of Unamortized Issuance Costs	4,829	4,127	[1]
Other Noncurrent Liabilities	77	54	[1]
Total Liabilities	5,510	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	594	589	[1]
Common unitholders; 245,472,743 units issued and outstanding (217,097,057 in 2017)	4,093	2,925	[1]
Total Equity	4,687	4,806	[1]
Total Liabilities and Equity	$ 10,197	$ 9,505	[1]
[1]	Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.
[2]	Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.
[3]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

Condensed Consolidated Balanc_2

Condensed Consolidated Balance Sheets (Unaudited), (Parenthetical) - shares	Sep. 30, 2018	Dec. 31, 2017
Statement of Financial Position [Abstract]
Preferred Units, Outstanding	600,000	600,000
Common units issued (units)	245,472,743	217,097,057

Condensed Statements of Conso_2

Condensed Statements of Consolidated Cash Flows (unaudited) Condensed Statements of Consolidated Cash Flows (unaudited) - USD ($) $ in Millions		9 Months Ended
		Sep. 30, 2018		Sep. 30, 2017
Cash Flows From (Used In) Operating Activities
Net earnings	[1]	$ 429		$ 253	[2],[3]
Adjustments to reconcile net earnings to net cash from operating activities:
Depreciation and amortization expenses	[1]	268		222	[2],[3]
Loss (gain) on asset disposals and impairments	[1]	(2)		25	[2]
Other operating activities	[1]	27		23
Changes in current assets and liabilities	[1]	4		62
Changes in noncurrent assets and liabilities	[1]	11		11
Net cash from operating activities	[1]	719		524
Cash Flows From (Used In) Investing Activities
Capital expenditures	[1]	(566)		(220)
Acquisitions, net of cash	[1]	(379)		(1,230)
Proceeds from sales of assets	[1]	0		46
Net cash used in investing activities	[1]	(945)		(1,404)
Cash Flows From (Used In) Financing Activities
Borrowings under revolving credit agreements	[1]	1,030		319
Repayments under revolving credit agreements	[1]	(333)		(614)
Proceeds from issuance of common units, net of issuance costs	[1]	0		284
Proceeds from issuance of general partner units, net of issuance costs	[1]	0		6
Quarterly distributions to common unitholders	[1]	620		329
Quarterly distributions to general partner	[1]	0		(131)
Distributions to preferred unitholders	[1]	(29)		0
Distributions in connection with acquisitions	[1]	300		5
Sponsor contributions of equity to the Predecessors	[1]	406		678
Capital contributions by affiliate	[1]	27		24
Other financing activities	[1]	0		(2)
Net cash from financing activities	[1]	181		230
Decrease in Cash and Cash Equivalents	[1]	(45)		(650)
Cash and Cash Equivalents, Beginning of Period		75	[4]	688
Cash and Cash Equivalents, End of Period		$ 30		$ 38
[1]	Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.
[2]	Adjusted to include the historical results of the Predecessors. See Note 1 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 Note 1 for further discussion.

Organization and Basis of Prese

Organization and Basis of Presentation (Notes)	9 Months Ended
	Sep. 30, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and Basis of Presentation	Organization and Basis of Presentation Organization Andeavor Logistics LP (“Andeavor Logistics” or the “Partnership”) is a fee-based, growth-oriented Delaware limited partnership formed in December 2010 by Andeavor and its wholly-owned subsidiary, Tesoro Logistics GP, LLC (“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” 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 (“MPC” or “Marathon”), and any of Andeavor’s or Andeavor LLC’s subsidiaries, as applicable, other than Andeavor Logistics, its subsidiaries and its general partner. Marathon Petroleum Corporation Merger On October 1, 2018, MPC completed its acquisition of Andeavor in accordance with the Agreement and Plan of Merger, dated as of April 29, 2018, as amended (the “MPC Merger Agreement”), under which MPC acquired all of Andeavor’s outstanding shares (the “MPC Merger”). Following the MPC Merger, MPC is the beneficial owner of approximately 156 million common units out of approximately 245 million common units outstanding in the Partnership as of October 1, 2018, representing an approximate 64% limited partner interest. MPC is also the beneficial owner of 100% of the equity interests of TLGP. Principles of Consolidation and Basis of Presentation Principles of Consolidation Assets acquired from Andeavor, and the associated liabilities and results of operations, are collectively referred to as the “Predecessors.” See Note 1 of our Annual Report on Form 10-K for the year ended December 31, 2017 and Note 2 for additional information regarding the assets acquired from Andeavor. 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. On August 6, 2018, we acquired Permian, refining logistics and asphalt assets (the “2018 Drop Down”) from Andeavor. See Note 2 for additional information. As an entity under common control with Andeavor, we record the assets that we acquire from Andeavor, on our condensed consolidated balance sheet at Andeavor’s historical basis instead of fair value. Accordingly, the accompanying financial statements and related notes of Andeavor Logistics have been retrospectively adjusted to include the historical results of the assets acquired prior to the effective date of the acquisition. The financial statements of our Predecessors have been prepared from the separate records maintained by Andeavor 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. For the nine months ended September 30, 2018 , the Partnership’s net cash from operating activities includes $40 million and net cash used in investing activities of $446 million from our Predecessors, offset by sponsor contributions of equity to the Predecessors in net cash from financing activities. The Partnership’s operating activities and investing activities for the nine months ended September 30, 2017 include $25 million and $653 million , respectively, of cash used by our Predecessors, offset by sponsor contributions of equity to the Predecessors in net cash from financing activities. We acquired certain logistics assets located in Anacortes, Washington (the “Anacortes Logistics Assets”) in 2017. While this acquisition is a common control transaction, prior periods have not been recast as these assets did not constitute a business in accordance with Accounting Standards Update (“ASU”) 2017-01, “Clarifying the Definition of a Business.” The interim condensed consolidated financial statements and notes thereto have been prepared by management without audit according to the rules and regulations of the Securities and Exchange Commission (“SEC”) and reflect all adjustments that, in the opinion of management, are necessary for a fair presentation of results for the periods presented. Such adjustments are of a normal recurring nature, unless otherwise disclosed. Basis of Presentation We prepare our condensed consolidated financial statements in conformity with accounting principles generally accepted in the United States of America (“U.S. GAAP”). However, certain information and notes normally included in financial statements prepared under U.S. GAAP have been condensed or omitted pursuant to the SEC’s rules and regulations. Management believes that the disclosures presented herein are adequate to present the information fairly. The accompanying interim condensed consolidated financial statements and notes should be read in conjunction with our Annual Report on Form 10-K for the year ended December 31, 2017 . Certain prior year balances have been aggregated or disaggregated in order to conform to the current year presentation, including the adoption of recent accounting standards discussed further below. We are required under U.S. GAAP to make estimates and assumptions that affect the amounts of assets and liabilities and revenues and expenses reported as of and during the periods presented. 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. The results of operations of the Partnership for any interim period are not necessarily indicative of results for the full year. Cost Classifications Natural gas liquids (“NGL”) expense results from the cost of NGL purchases under our percent of proceeds (“POP”) arrangements as well as the non-cash acquisition of replacement dry gas under our keep-whole arrangements. During the three and nine months ended September 30, 2017 , cost of fuel and other included the purchase cost of refined products sold within our Wholesale segment, the cost of inbound transportation and distribution costs incurred to transport product to our customers. Due to the adoption of ASU 2014-09, “Revenue from Contracts with Customers,” and the associated subsequent amendments (collectively, “ASC 606”) on January 1, 2018, the revenues and costs associated with our fuel purchase and supply arrangements were netted, as further described in Note 10 . 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. General and administrative expenses represent costs that are not directly or indirectly related to or otherwise are not allocated to our operations. NGL expense, direct operating expenses, and depreciation and amortization expenses recognized by our Terminalling and Transportation, Gathering and Processing, and Wholesale segments constitute costs of revenue as defined by U.S. GAAP. Financial Instruments 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 borrowings under our amended revolving credit facility (the “Revolving Credit Facility”) and our dropdown credit facility (“Dropdown Credit Facility”), which include a variable interest rate, approximate fair value. The carrying value and fair value of our debt were both $4.9 billion as of September 30, 2018 and were $4.2 billion and $4.3 billion at December 31, 2017 , respectively. These carrying and fair values of our debt exclude the unamortized issuance costs, which are netted against our total debt. We believe the carrying value of our other financial instruments, including cash and cash equivalents, receivables, accounts payable and certain accrued liabilities, approximate 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. New Accounting Standards and Disclosures Revenue Recognition In May 2014, the Financial Accounting Standards Board (“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 $22 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 10 . 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 three and nine months ended September 30, 2018 , we recorded lower revenues of $709 million and $2.0 billion , respectively, and lower costs and expenses of $709 million and $2.0 billion , respectively, 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 with Andeavor, as further described in Note 10 . We recorded lower revenues of $13 million and $10 million associated with minimum volume commitments during the three and nine months ended September 30, 2018 , respectively, as a result of applying the new standard. There were no material impacts during the period to the condensed consolidated balance sheets or condensed 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”), which amends existing accounting standards for lease accounting and adds additional disclosures about leasing arrangements. Under the new guidance, lessees are required to recognize right-of-use assets and lease liabilities on the balance sheet for all leases with terms longer than 12 months. Leases will be classified as either a financing lease or operating lease with classification affecting the pattern of expense recognition in the condensed statements of consolidated operations and presentation of cash flows in the condensed statements of consolidated cash flows. The new standard also requires additional disclosures to help financial statement users better understand the amount, timing, and uncertainty of cash flows arising from leases. ASU 2016-02 is effective for annual reporting periods beginning after December 15, 2018, and interim reporting periods within those annual reporting periods, with early adoption being permitted. In July 2018, the FASB issued ASU 2018-11 , which permits entities with the option to adopt the provisions of ASU 2016-02 prospectively without adjusting comparative periods. We will elect this option and adopt the standard on January 1, 2019 . In addition, we also expect to adopt the package of practical expedients which allows an entity, on the date of adoption, to not reassess expired or existing contracts in whether they are a lease or contain a lease and to not reassess the historical lease classification for expired or existing leases. We continue to progress through our implementation plan, which includes the following activities: testing and implementing a new lease accounting system, finalizing design and implementation of new business processes and related internal controls, the continued extraction of the required accounting and reporting data from our lease agreements as well as the continued assessment and documentation of the accounting impacts related to the new standard. While we are still working through our implementation plan, we do expect that the recognition of right-of-use assets and lease liabilities, which are not currently reflected on our consolidated balance sheets, will have a material impact on total assets and liabilities. However, we do not expect the adoption of the standard to have a material impact on our statement of consolidated operations or liquidity. At this time, we are unable to estimate the full impact of the standard given we are still extracting the accounting data from our lease agreements as well as testing and implementing our new lease accounting system, which will be used to calculate the accounting impacts. 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 and we do not expect the adoption of this standard to have a material impact on our condensed 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 condensed statement of consolidated cash flows for the nine months ended September 30, 2017. See Note 2 for further information regarding restricted cash. 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 condensed statements of consolidated operations since these costs are allocated to the Partnership’s financial statements by Andeavor. The amendments to the presentation of the condensed statements of consolidated 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 $2 million and $6 million , respectively, with a corresponding increase to other income of $2 million and $6 million , respectively, for the three and nine months ended September 30, 2017 with no impact to net earnings. ASU 2017-07 does not impact the condensed consolidated balance sheets or condensed statements of consolidated cash flows. Stock Compensation In June 2018, the FASB issued ASU 2018-07, “Improvements to Nonemployee Share-Based Payment Accounting” (“ASU 2018-07”), 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. While we are still evaluating the impact of ASU 2018-07, we do not expect the adoption of this standard to have a material impact on our condensed consolidated financial statements.

Acquisitions Acquisitions (Note

Acquisitions Acquisitions (Notes)	9 Months Ended
	Sep. 30, 2018
Business Combinations [Abstract]
Condensed Financial Statements [Table Text Block]	The following tables present our unaudited results of operations disaggregated to present results relating to the Partnership and the Predecessors for the assets acquired from Andeavor and the total amounts included in our combined consolidated financial statements for the three and nine months ended September 30, 2018 and 2017 . Reconciliation of Combined Financial Statements (in millions) Three Months Ended September 30, 2018 Nine Months Ended September 30, 2018 Combined Andeavor Logistics LP Predecessors Combined Andeavor Logistics LP Predecessors Revenues Affiliate $ 415 $ 411 $ 4 $ 1,131 $ 1,110 $ 21 Third-party 227 224 3 626 617 9 Total Revenues 642 635 7 1,757 1,727 30 Costs and Expenses NGL expense (exclusive of items shown separately below) 73 73 — 166 166 — Operating expenses (exclusive of depreciation and amortization) 236 227 9 658 618 40 Depreciation and amortization expenses 86 83 3 268 246 22 General and administrative expenses 31 30 1 91 82 9 Loss on asset disposals and impairments 1 1 — 2 2 — Operating Income (Loss) 215 221 (6 ) 572 613 (41 ) Interest and financing costs, net (57 ) (56 ) (1 ) (172 ) (168 ) (4 ) Equity in earnings of equity method investments 7 4 3 25 9 16 Other income, net 1 1 — 4 3 1 Net Earnings (Loss) $ 166 $ 170 $ (4 ) $ 429 $ 457 $ (28 ) Loss attributable to Predecessors 4 — 4 28 — 28 Net Earnings Attributable to Partners 170 170 — 457 457 — Preferred unitholders’ interest in net earnings (10 ) (10 ) — (34 ) (34 ) — Limited Partners’ Interest in Net Earnings $ 160 $ 160 $ — $ 423 $ 423 $ — Reconciliation of Combined Financial Statements (in millions) Three Months Ended September 30, 2017 Nine Months Ended September 30, 2017 Combined Andeavor Logistics LP Predecessors Combined Andeavor Logistics LP Predecessors Revenues Affiliate $ 468 $ 219 $ 249 $ 951 $ 624 $ 327 Third-party 626 225 401 1,184 653 531 Total Revenues 1,094 444 650 2,135 1,277 858 Costs and Expenses Cost of fuel and other (exclusive of items shown separately below) (a) 554 — 554 716 — 716 NGL expense (exclusive of items shown separately below) 64 64 — 179 179 — Operating expenses (exclusive of depreciation and amortization) 199 141 58 512 399 113 Depreciation and amortization expenses 85 60 25 222 178 44 General and administrative expenses 44 27 17 107 78 29 (Gain) loss on asset disposals and impairments 1 1 — (25 ) (24 ) (1 ) Operating Income (Loss) 147 151 (4 ) 424 467 (43 ) Interest and financing costs, net (68 ) (61 ) (7 ) (193 ) (184 ) (9 ) Equity in earnings of equity method investments 6 2 4 13 7 6 Other income, net 5 5 — 9 9 — Net Earnings (Loss) $ 90 $ 97 $ (7 ) $ 253 $ 299 $ (46 ) Loss attributable to Predecessors 7 — 7 46 — 46 Net Earnings Attributable to Partners 97 97 — 299 299 — General partner’s interest in net earnings, including incentive distribution rights — — — (79 ) (79 ) — Limited Partners’ Interest in Net Earnings $ 97 $ 97 $ — $ 220 $ 220 $ —
Mergers, Acquisitions and Dispositions Disclosures	Acquisitions and Divestitures 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, Inc. assets and associated crude terminals; the majority of Andeavor’s remaining refining terminalling, transportation and storage assets; and equity method investments in Andeavor Logistics RIO Pipeline LLC (“ALRP”), Minnesota Pipe Line Company, LLC (“MPL”), and PNAC, LLC (“PNAC”). In addition, the Conan Crude Oil Gathering System and the Los Angeles Refinery Interconnect Pipeline (“LARIP”) were transferred at cost plus incurred interest. In conjunction with the 2018 Drop Down, we entered into additional commercial agreements with Andeavor. 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 Andeavor’s Mandan, Salt Lake City and Los Angeles refineries; • Rail terminals and truck racks at Andeavor’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 TexNewMex 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 Andeavor’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 the Salt Lake City area refineries, including Andeavor’s Salt Lake City refinery. We financed the acquisition using our Revolving Credit Facility. This acquisition is not material to our condensed consolidated financial statements and its operating results are reported in our Terminalling and Transportation segment. Western Refining Logistics, LP Merger Effective October 30, 2017, Andeavor Logistics closed its merger with Western Refining Logistics, LP (“WNRL”) (the “WNRL Merger”), exchanging all outstanding common units of WNRL for units of Andeavor Logistics, representing an equity value of $1.7 billion . Andeavor Logistics accounted for the WNRL Merger as a common control transaction and, accordingly, inherited Andeavor’s basis in WNRL’s net assets. Andeavor 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 Andeavor 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. Prior to the purchase price finalization, we recorded adjustments to the allocation to increase property, plant and equipment and reduce goodwill by $7 million during 2018. Acquisition Date Purchase Price Allocation (in millions) Cash $ 22 Receivables 112 Inventories 11 Prepayments and Other Current Assets 25 Property, Plant and Equipment (a) 1,357 Goodwill 558 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 Andeavor Logistics expects 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 $352 million , $144 million and $62 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 $1.4 billion . This fair value is based on a valuation using a combination of the income, cost and market approaches. The useful lives of acquired assets have been aligned to similar assets at Andeavor Logistics. Acquired Intangible Assets The fair value of the acquired identifiable intangible assets is $130 million . This fair value is based on 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 a weighted average useful life of 15 years. The accumulated amortization of our finite life intangibles acquired from the WNRL Merger was $12 million as of September 30, 2018 . Amortization expense related to the acquired intangible assets is expected to be approximately $9 million per year for the next 15 years. WNRL Revenues and Net Earnings During the nine months ended September 30, 2018 , we recognized $303 million in revenues and $87 million of net earnings related to the business acquired. Pro Forma Financial Information The following 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, the beginning of the earliest period presented. Pro Forma Consolidated Revenues and Consolidated Net Earnings (in millions) Three Months Ended Nine Months Ended September 30, 2017 September 30, 2017 Revenues $ 1,094 $ 3,172 Net earnings (a) 90 258 (a) While many recurring adjustments impact the pro forma figures presented, the pro forma condensed statements of consolidated operations for the three and nine months ended September 30, 2017 includes a significant non-recurring adjustment to recognize the WNRL Merger acquisition and integration costs and reflects these costs in the first quarter of 2017, the period the acquisition was assumed to be completed for pro forma purposes. For the nine months ended September 30, 2017 , we recognized acquisition costs related to the WNRL Merger of $17 million as well as $3 million of severance costs. Post-Acquisition Financial Information The following tables present our unaudited results of operations disaggregated to present results relating to the Partnership and the Predecessors for the assets acquired from Andeavor and the total amounts included in our combined consolidated financial statements for the three and nine months ended September 30, 2018 and 2017 . Reconciliation of Combined Financial Statements (in millions) Three Months Ended September 30, 2018 Nine Months Ended September 30, 2018 Combined Andeavor Logistics LP Predecessors Combined Andeavor Logistics LP Predecessors Revenues Affiliate $ 415 $ 411 $ 4 $ 1,131 $ 1,110 $ 21 Third-party 227 224 3 626 617 9 Total Revenues 642 635 7 1,757 1,727 30 Costs and Expenses NGL expense (exclusive of items shown separately below) 73 73 — 166 166 — Operating expenses (exclusive of depreciation and amortization) 236 227 9 658 618 40 Depreciation and amortization expenses 86 83 3 268 246 22 General and administrative expenses 31 30 1 91 82 9 Loss on asset disposals and impairments 1 1 — 2 2 — Operating Income (Loss) 215 221 (6 ) 572 613 (41 ) Interest and financing costs, net (57 ) (56 ) (1 ) (172 ) (168 ) (4 ) Equity in earnings of equity method investments 7 4 3 25 9 16 Other income, net 1 1 — 4 3 1 Net Earnings (Loss) $ 166 $ 170 $ (4 ) $ 429 $ 457 $ (28 ) Loss attributable to Predecessors 4 — 4 28 — 28 Net Earnings Attributable to Partners 170 170 — 457 457 — Preferred unitholders’ interest in net earnings (10 ) (10 ) — (34 ) (34 ) — Limited Partners’ Interest in Net Earnings $ 160 $ 160 $ — $ 423 $ 423 $ — Reconciliation of Combined Financial Statements (in millions) Three Months Ended September 30, 2017 Nine Months Ended September 30, 2017 Combined Andeavor Logistics LP Predecessors Combined Andeavor Logistics LP Predecessors Revenues Affiliate $ 468 $ 219 $ 249 $ 951 $ 624 $ 327 Third-party 626 225 401 1,184 653 531 Total Revenues 1,094 444 650 2,135 1,277 858 Costs and Expenses Cost of fuel and other (exclusive of items shown separately below) (a) 554 — 554 716 — 716 NGL expense (exclusive of items shown separately below) 64 64 — 179 179 — Operating expenses (exclusive of depreciation and amortization) 199 141 58 512 399 113 Depreciation and amortization expenses 85 60 25 222 178 44 General and administrative expenses 44 27 17 107 78 29 (Gain) loss on asset disposals and impairments 1 1 — (25 ) (24 ) (1 ) Operating Income (Loss) 147 151 (4 ) 424 467 (43 ) Interest and financing costs, net (68 ) (61 ) (7 ) (193 ) (184 ) (9 ) Equity in earnings of equity method investments 6 2 4 13 7 6 Other income, net 5 5 — 9 9 — Net Earnings (Loss) $ 90 $ 97 $ (7 ) $ 253 $ 299 $ (46 ) Loss attributable to Predecessors 7 — 7 46 — 46 Net Earnings Attributable to Partners 97 97 — 299 299 — General partner’s interest in net earnings, including incentive distribution rights — — — (79 ) (79 ) — Limited Partners’ Interest in Net Earnings $ 97 $ 97 $ — $ 220 $ 220 $ — Divestitures Alaska Storage and Terminalling Assets On June 2, 2017, due to Andeavor’s consent decree with the state of Alaska associated with our 2016 acquisition of certain terminalling and storage assets owned by Andeavor, 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 condensed statements of consolidated operations for the nine months ended September 30, 2017. The Alaska Terminal divestiture did not have an impact on our operations. WNRL Lubricant Operations On June 30, 2017, WNRL sold its remaining lubricant operations located in Arizona and Nevada for $14 million . There was no gain or loss resulting from this sale. Due to provisions in WNRL’s senior secured revolving credit facility agreement and senior notes indenture, the proceeds received from the sale of the lubricant operations were restricted to be used in the business or as a prepayment of debt. This cash was used during the third quarter of 2017 to reinvest in assets used in its business and as a payment of debt.

Related-Party Transactions Rela

Related-Party Transactions Related-Party Transactions (Notes)	9 Months Ended
	Sep. 30, 2018
Related Party Transactions [Abstract]
Related Party Transactions Disclosure	Related-Party Transactions Affiliate Agreements The Partnership has various long-term, fee-based commercial agreements with Andeavor, under which we provide terminal distribution, storage services, pipeline transportation, crude oil, natural gas and produced water gathering and processing, wholesale, and trucking services to Andeavor, and Andeavor commits to provide us with minimum monthly throughput volumes of crude oil, refined products and other. If, in any calendar month, Andeavor fails to meet its minimum volume commitments under these agreements, it will be required to pay us a shortfall payment. For the NGLs that we handle under keep-whole agreements, the Partnership transfers the commodity risk exposure associated with these keep-whole agreements to Andeavor pursuant to the Keep-Whole Commodity Fee Agreement, as amended (the “Keep-Whole Commodity Agreement”). Under the Keep-Whole Commodity Agreement, Andeavor pays us a processing fee for NGLs related to the keep-whole agreements and delivers replacement dry gas to the producers on our behalf. We then pay Andeavor a marketing fee in exchange for assuming the commodity risk. The terms and pricing of this agreement are subject to revision each year. In conjunction with the 2018 Drop Down, the Partnership entered into additional commercial agreements with Andeavor. Commercial Agreements with Andeavor Termination Provisions Commercial Agreement Initiation Date Term Renewals Refinery Shutdown Notice Period (a) Force Majeure Transportation Services Agreement (LAR Interconnecting Pipelines) August 2018 10 years 2 x 5 years 12 months Andeavor Logistics can declare (unilateral) Master Terminalling Services Agreement August 2018 10 years 2 x 5 years Master Unloading and Storage Agreement (WNRL) August 2018 10 years 2 x 5 years N/A Asphalt Terminalling, Transportation and Storage Services Agreement August 2018 10 years 2 x 5 years (a) Fixed minimum volumes remain in effect during routine turnarounds. In addition, we have agreements for the provision of various general and administrative services by Andeavor. Under our partnership agreement, we are required to reimburse TLGP and its affiliates for all costs and expenses they incur on our behalf for managing and controlling our business and operations. Except to the extent specified under our amended omnibus agreement (the “Amended Omnibus Agreement”) or our amended secondment agreement (the “Amended Secondment Agreement”), TLGP determines the amount of these expenses. The Amended Omnibus Agreement was most recently amended and restated as of September 28, 2018. Under the terms of the Amended Omnibus Agreement in effect as of September 30, 2018 , we are required to pay Andeavor an annual corporate services fee of approximately $17 million for the provision of various centralized corporate services, including executive management, legal, accounting, treasury, human resources, health, safety and environmental, information technology, certain insurance coverage, administration and other corporate services. Andeavor charged the Partnership $28 million and $6 million pursuant to the Amended Secondment Agreement for the three months ended September 30, 2018 and 2017 , respectively, with $38 million and $16 million for the nine months ended September 30, 2018 and 2017 , respectively, reflecting increased services provided in conjunction with the assets acquired in the 2018 Drop Down. Additionally, pursuant to the Amended Omnibus Agreement and Amended Secondment Agreement, we reimburse Andeavor for any direct costs incurred by Andeavor in providing other operational services with respect to certain of our other assets and operations. In conjunction with the 2018 Drop Down, we entered into a construction service agreement with Andeavor to complete the construction of LARIP (the “Construction Service Agreement”). Andeavor charged the Partnership $11 million pursuant to the Construction Service Agreement during the three and nine months ended September 30, 2018 . Summary of Affiliate Transactions Summary of Revenue and Expense Transactions with Andeavor, Including Predecessors (in millions) Three Months Ended Nine Months Ended 2018 2017 2018 2017 Revenues (a) $ 415 $ 468 $ 1,131 $ 951 Operating expenses (b) 82 67 216 185 General and administrative expenses 31 30 77 77 (a) Andeavor accounted for 65% and 43% of our total revenues for the three months ended September 30, 2018 and 2017 , respectively, and 64% and 45% for the nine months ended September 30, 2018 and 2017 , respectively. (b) Net of reimbursements from Andeavor pursuant to the Amended Omnibus Agreement, the Carson Assets Indemnity Agreement and other affiliate agreements of $2 million and $7 million for the three months ended September 30, 2018 and 2017 respectively, and $12 million for both the nine months ended September 30, 2018 and 2017 . Distributions In accordance with our partnership agreement, the unitholders of our limited partner interests are entitled to receive quarterly distributions of available cash. During the nine months ended September 30, 2018 , we paid quarterly cash distributions of $347 million to Andeavor. On October 26, 2018 , we declared a quarterly cash distribution of $1.03 per unit, which will be paid on November 14, 2018 . The distribution will include a payment of $146 million to Marathon. TLGP’s distribution waivers for 2018 and 2019 remain in effect as instituted in 2017 under the terms of our partnership agreement.

Property, Plant and Equipment (

Property, Plant and Equipment (Notes)	9 Months Ended
	Sep. 30, 2018
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment Disclosure [Text Block]	Property, Plant and Equipment Property, Plant & Equipment (in millions) September 30, December 31, 2017 (a) Terminals and tankage $ 3,595 $ 3,557 Pipelines 3,344 2,825 Land and leasehold improvements 289 282 Buildings and improvements 94 91 Other 142 142 Construction in progress 501 346 Property, Plant and Equipment, at Cost 7,965 7,243 Accumulated Depreciation (1,215 ) (994 ) Property, Plant and Equipment, Net $ 6,750 $ 6,249 (a) 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.

Goodwill (Notes)

Goodwill (Notes)	9 Months Ended
	Sep. 30, 2018
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill Disclosure [Text Block]	Goodwill Goodwill represents the excess of the consideration paid over the fair value of the net assets acquired in a business combination. Goodwill acquired in a business combination is not amortized, but instead tested for impairment at least annually or more frequently should an event occur or circumstances indicate that the carrying amount may be impaired. Goodwill impairment testing is performed at the reporting unit level on November 1 of each year and when circumstances change that might indicate impairment. There were no impairments of goodwill during the three and nine months ended September 30, 2018 and 2017 . Goodwill by Operating Segment (in millions) September 30, December 31, 2017 (a) Terminalling and Transportation (b) $ 231 $ 260 Gathering and Processing (b) 695 607 Wholesale 62 89 Goodwill $ 988 $ 956 (a) Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion. (b) 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.

Equity Method Investments and J

Equity Method Investments and Joint Ventures (Notes)	9 Months Ended
	Sep. 30, 2018
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments and Joint Ventures Disclosure [Text Block]	Equity Method Investments and Joint Ventures For each of the following investments, we have the ability to exercise significant influence over each of these investments 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 investors 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 have 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 have a 78% interest in Rendezvous Gas Services, L.L.C. (“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 Three Rivers Gathering, L.L.C. (“TRG”) located in the southeastern Uinta Basin. TRG was formed with Ute Energy to transport natural gas gathered by Uintah Basin Field Services, L.L.C. (“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, 2017 (b) $ — $ 120 $ — $ 268 $ 37 $ 15 $ 440 Acquired interests 159 — 27 — — — 186 Equity in earnings 4 14 — 4 2 1 25 Cumulative effect of accounting standard adoption — — — — (3 ) — (3 ) Distributions received (4 ) (14 ) — (16 ) (5 ) (2 ) (41 ) Balance at September 30, 2018 (b) $ 159 $ 120 $ 27 $ 256 $ 31 $ 14 $ 607 (a) These equity method investments were included in the 2018 Drop Down. Amounts were adjusted to include the historical results of the Predecessors. See Note 1 for further discussion. (b) The carrying amount of our investments in ALRP, MPL, PNAC, RGS, TRG and UBFS exceeded the underlying equity in net assets by $75 million , $34 million , $17 million , $127 million , $14 million and $6 million , respectively, at September 30, 2018 . The carrying amount of our investments in MPL, RGS, TRG and UBFS exceeded the underlying equity in net assets by $35 million , $130 million , $15 million and $6 million , respectively, at December 31, 2017. 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 (loss). 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.

Debt (Notes)

Debt (Notes)	9 Months Ended
	Sep. 30, 2018
Debt Disclosure [Abstract]
Debt	Debt Debt Balance, Net of Unamortized Issuance Costs (in millions) September 30, December 31, 2017 Total debt $ 4,878 $ 4,182 Unamortized issuance costs (48 ) (54 ) Current maturities (1 ) (1 ) Debt, Net of Current Maturities and Unamortized Issuance Costs $ 4,829 $ 4,127 Available Capacity Under Credit Facilities (in millions) Total Capacity Amount Borrowed as of September 30, 2018 Outstanding Letters of Credit Available Capacity as of September 30, 2018 Weighted Average Interest Rate Expiration Revolving Credit Facility (a) $ 1,100 $ 820 $ — $ 280 3.95 % January 29, 2021 Dropdown Credit Facility 1,000 300 — 700 3.86 % January 29, 2021 Total Credit Facilities (a) $ 2,100 $ 1,120 $ — $ 980 (a) On January 5, 2018, we amended our Revolving Credit Facility to increase the aggregate commitments from $600 million to $1.1 billion and to permit the incurrence of incremental loans. We are allowed to request that the loan availability be increased up to an aggregate of $2.1 billion , subject to receiving increased commitments from the lenders.

Commitments and Contingencies (

Commitments and Contingencies (Notes)	9 Months Ended
	Sep. 30, 2018
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies In the ordinary course of business, we may become party to lawsuits, disputes, 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. While it is not possible to predict the outcome of such proceedings, if one or more of them were decided against us, we believe there would be no material impact on our condensed consolidated financial statements.

Equity (Notes)

Equity (Notes)	9 Months Ended
	Sep. 30, 2018
Equity [Abstract]
Equity	Equity and Net Earnings per Unit We had 89,299,615 common public units and 600,000 6.875% Series A Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Units (the “Preferred Units”) outstanding as of September 30, 2018 . Additionally, Andeavor owned 156,173,128 of our common units, constituting approximately 64% ownership interest in us. Andeavor also held 80,000 Andeavor Logistics TexNew Mex units and all of the outstanding non-economic general partner units as of September 30, 2018 . Changes to Equity (in millions) Equity of Predecessors (a) Partnership Total Common Preferred Balance at December 31, 2017 $ 1,292 $ 2,925 $ 589 $ 4,806 Sponsor contributions of assets to the Predecessors 406 — — 406 Loss attributable to the Predecessors (28 ) — — (28 ) Net assets not assumed by Andeavor Logistics (19 ) — — (19 ) Allocation of net assets acquired by the unitholders (1,651 ) 1,651 — — Distributions to common and preferred unitholders (b) — (620 ) (29 ) (649 ) Distributions to common unitholders related to acquisitions (c) — (300 ) — (300 ) Net earnings attributable to partners — 423 34 457 Cumulative effect of accounting standard adoption — (22 ) — (22 ) Contributions (d) — 34 — 34 Other — 2 — 2 Balance at September 30, 2018 $ — $ 4,093 $ 594 $ 4,687 (a) Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion. (b) Represents cash distributions declared and paid during the nine months ended September 30, 2018 . (c) Distributions to common unitholders include $300 million in cash payments for the 2018 Drop Down. As an entity under common control with Andeavor, we record the assets that we acquire from Andeavor in our consolidated balance sheets at Andeavor’s historical book value instead of fair value, and any excess of cash paid over the historical book value of the assets acquired from Andeavor is recorded within equity. As a result of this accounting treatment, this transaction resulted in a net increase of $1.4 billion in our equity balance during the nine months ended September 30, 2018 . (d) Includes Andeavor and TLGP contributions to the Partnership primarily related to reimbursements for capital spending pursuant predominantly to the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement. Cash Distributions Our partnership agreement, as amended, sets forth the calculation to be used to determine the amount and priority of cash distributions that the limited partner unitholders will receive. Quarterly Distributions on Common Units Quarter Ended Quarterly Distribution Per Common Unit Total Cash Distribution (in millions) Date of Distribution Unitholders Record Date December 31, 2017 (a) $ 1.000 $ 205 February 14, 2018 January 31, 2018 March 31, 2018 (a) 1.015 205 May 15, 2018 May 1, 2018 June 30, 2018 (a) 1.030 209 August 14, 2018 August 3, 2018 September 30, 2018 (a)(b) 1.030 238 November 14, 2018 November 5, 2018 (a) This distribution is net of $15 million waived by TLGP for each of the three months ended September 30, 2018 , June 30, 2018 and March 31, 2018, as well as $12.5 million for the three months ended December 31, 2017. TLGP’s distribution waivers for 2018 and 2019 remain in effect as instituted in 2017 under the terms of our partnership agreement. (b) This distribution was declared on October 26, 2018 and will be paid on the date of distribution. On August 15, 2018 and February 15, 2018, we paid distributions associated with our Preferred Units of $21 million and $8 million , respectively. 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 incentive distribution rights (“IDRs”). Net earnings earned by the Partnership were allocated between the limited and general partners in accordance with our partnership agreement. At the effective time of the WNRL Merger, the IDRs were canceled (the “IDR Exchange”) and the general partner units were converted into a non-economic general partner interest in Andeavor Logistics (together with the IDR Exchange, the “IDR/GP Transaction”). As a result, 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 to equal 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) Three Months Ended Nine Months Ended 2018 2017 2018 2017 Net earnings $ 166 $ 90 $ 429 $ 253 Special allocations of net earnings (“Special Allocations”) (a) — — — 1 Net earnings, including Special Allocations 166 90 429 254 Distributions on Preferred Units (b) (11 ) — (31 ) — Net earnings attributable to common units 155 90 398 254 General partner’s distributions — — — (6 ) General partner’s IDRs (c) — — — (75 ) Limited partners’ distributions on common units (238 ) (201 ) (652 ) (407 ) Distributions on common units greater than earnings $ (83 ) $ (111 ) $ (254 ) $ (234 ) General partner’s earnings: Distributions $ — $ — $ — $ 6 General partner’s IDRs (c) — — — 75 Allocation of distributions greater than earnings (d) (4 ) (8 ) (28 ) (48 ) Total general partner’s earnings $ (4 ) $ (8 ) $ (28 ) $ 33 Limited partners’ earnings on common units: Distributions (e) $ 238 $ 201 $ 652 $ 407 Special Allocations (a) — — — (1 ) Allocation of distributions greater than earnings (79 ) (103 ) (226 ) (186 ) Total limited partners’ earnings on common units $ 159 $ 98 $ 426 $ 220 Weighted average limited partner units outstanding: Common units - basic 234.4 108.0 223.0 107.0 Common units - diluted (f) 234.6 108.1 223.2 107.1 Net earnings per limited partner unit: (g) Common - basic $ 0.68 $ 0.90 $ 1.91 $ 2.05 Common - diluted $ 0.68 $ 0.90 $ 1.91 $ 2.05 (a) 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 Revolving Credit Facility in lieu of using all cash on hand to fund the acquisition of crude oil, natural gas and produced water gathering systems and two natural gas processing facilities from Whiting Oil and Gas Corporation, GBK Investments, LLC and WBI Energy Midstream, LLC (the “North Dakota Gathering and Processing Assets”) during the nine months ended September 30, 2017 . (b) The Preferred Units entitle unitholders to receive preferred distributions on a semi-annually basis. (c) 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 $38 million of IDRs waived by TLGP for the nine months ended September 30, 2017 , respectively. Our general partner no longer holds IDRs as a result of the IDR/GP Transaction. (d) We have revised the historical allocation of general partner earnings to include the Predecessors’ losses of $4 million and $28 million for the three and nine months ended September 30, 2018 , respectively, and losses of $7 million and $46 million for the three and nine months ended September 30, 2017 , respectively. (e) Distributions of earnings for limited partners’ common units for the three and nine months ended September 30, 2018 is net of a $15 million and $45 million waiver, respectively, from Andeavor in connection with the WNRL Merger. (f) 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. (g) Amounts may not recalculate due to rounding of dollar and unit information.
Earnings Per Share	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 incentive distribution rights (“IDRs”). Net earnings earned by the Partnership were allocated between the limited and general partners in accordance with our partnership agreement. At the effective time of the WNRL Merger, the IDRs were canceled (the “IDR Exchange”) and the general partner units were converted into a non-economic general partner interest in Andeavor Logistics (together with the IDR Exchange, the “IDR/GP Transaction”). As a result, 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 to equal 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) Three Months Ended Nine Months Ended 2018 2017 2018 2017 Net earnings $ 166 $ 90 $ 429 $ 253 Special allocations of net earnings (“Special Allocations”) (a) — — — 1 Net earnings, including Special Allocations 166 90 429 254 Distributions on Preferred Units (b) (11 ) — (31 ) — Net earnings attributable to common units 155 90 398 254 General partner’s distributions — — — (6 ) General partner’s IDRs (c) — — — (75 ) Limited partners’ distributions on common units (238 ) (201 ) (652 ) (407 ) Distributions on common units greater than earnings $ (83 ) $ (111 ) $ (254 ) $ (234 ) General partner’s earnings: Distributions $ — $ — $ — $ 6 General partner’s IDRs (c) — — — 75 Allocation of distributions greater than earnings (d) (4 ) (8 ) (28 ) (48 ) Total general partner’s earnings $ (4 ) $ (8 ) $ (28 ) $ 33 Limited partners’ earnings on common units: Distributions (e) $ 238 $ 201 $ 652 $ 407 Special Allocations (a) — — — (1 ) Allocation of distributions greater than earnings (79 ) (103 ) (226 ) (186 ) Total limited partners’ earnings on common units $ 159 $ 98 $ 426 $ 220 Weighted average limited partner units outstanding: Common units - basic 234.4 108.0 223.0 107.0 Common units - diluted (f) 234.6 108.1 223.2 107.1 Net earnings per limited partner unit: (g) Common - basic $ 0.68 $ 0.90 $ 1.91 $ 2.05 Common - diluted $ 0.68 $ 0.90 $ 1.91 $ 2.05 (a) 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 Revolving Credit Facility in lieu of using all cash on hand to fund the acquisition of crude oil, natural gas and produced water gathering systems and two natural gas processing facilities from Whiting Oil and Gas Corporation, GBK Investments, LLC and WBI Energy Midstream, LLC (the “North Dakota Gathering and Processing Assets”) during the nine months ended September 30, 2017 . (b) The Preferred Units entitle unitholders to receive preferred distributions on a semi-annually basis. (c) 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 $38 million of IDRs waived by TLGP for the nine months ended September 30, 2017 , respectively. Our general partner no longer holds IDRs as a result of the IDR/GP Transaction. (d) We have revised the historical allocation of general partner earnings to include the Predecessors’ losses of $4 million and $28 million for the three and nine months ended September 30, 2018 , respectively, and losses of $7 million and $46 million for the three and nine months ended September 30, 2017 , respectively. (e) Distributions of earnings for limited partners’ common units for the three and nine months ended September 30, 2018 is net of a $15 million and $45 million waiver, respectively, from Andeavor in connection with the WNRL Merger. (f) 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. (g) Amounts may not recalculate due to rounding of dollar and unit information.

Revenues (Notes)

Revenues (Notes)	9 Months Ended
	Sep. 30, 2018
Revenue Recognition [Abstract]
Revenue from Contract with Customer	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 three and nine months ended September 30, 2018 , revenues from contracts with customers were $528 million and $1.5 billion , respectively, which excludes lease revenues of $114 million and $292 million , respectively. 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 replacement dry gas (“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 in service revenue 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 condensed statement of consolidated 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 condensed statement of consolidated operations. We have certain fuel purchase and sale arrangements with Andeavor under which we receive certain minimum guaranteed margins with upside potential on a certain portion of our branded and unbranded fuel sales. Andeavor retains control of fuel and is the principal in these affiliate arrangements. Therefore, we net the purchase and sale of fuel in our condensed 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 Andeavor, 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 generated primarily from contracts with customers. Our payment terms vary by product or service type. The period between invoicing and payment is not significant, and our assets associated with contracts with customers consist primarily of billed accounts receivable, which are included in receivables, net of allowance for doubtful accounts in our condensed 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 condensed consolidated balance sheets. 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 may extend up to 15 years . During the three and nine months ended September 30, 2018 , we recognized $4 million and $24 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) Balance at January 1, 2018 September 30, Receivables from contracts with customers $ 443 $ (34 ) $ 409 $ 437 Other contract assets — 34 34 31 Deferred income, current 23 — 23 22 Deferred income, noncurrent 43 19 62 64 (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 condensed consolidated balance sheets as of January 1, 2018 for the impacts related to our equity method investment in Three Rivers Gathering, LLC. There were no material impacts to this balance during the nine months ended September 30, 2018 due to the adoption. 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 September 30, 2018 , we had $4.1 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 ranges from 1 year to 15 years . We expect approximately 80% 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 11 . Revenue Disaggregation by Type and Product Line (in millions) Three Months Ended September 30, 2018 Nine Months Ended September 30, 2018 Terminalling and Transportation Gathering and Processing Wholesale Terminalling and Transportation Gathering and Processing Wholesale Service Revenues (a) Refined products $ 240 $ — $ 4 $ 650 $ — $ 13 Crude oil and water 39 108 — 108 313 — Natural gas — 100 — — 296 — Other 1 — — 4 — — Total Service Revenues 280 208 4 762 609 13 Product Revenues NGL products — 137 — — 336 — Refined products — — 13 — — 37 Total Product Revenues — 137 13 — 336 37 Total Revenues $ 280 $ 345 $ 17 $ 762 $ 945 $ 50 (a) Includes $114 million and $292 million of lease revenues for the three and nine months ended September 30, 2018 , respectively.

Operating Segments (Notes)

Operating Segments (Notes)	9 Months Ended
	Sep. 30, 2018
Segment Reporting, Disclosure of Entity's Reportable Segments [Abstract]
Segment Disclosures	Operating Segments Our revenues are derived from three operating segments: Terminalling and Transportation, Gathering and Processing and Wholesale. We evaluate the performance of our segments based primarily on segment operating income and net earnings before interest, income taxes, depreciation and amortization expenses (“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 condensed 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 and interest and financing costs are excluded from segment operating income as they are not directly attributable to a specific operating segment. Our Terminalling and Transportation segment consists of pipeline systems, including regulated common carrier refined products pipeline systems and other pipelines, which transport products and crude oil primarily from Andeavor’s refineries to nearby facilities, as well as crude oil and refined products terminals and storage facilities, marine terminals, asphalt terminals, rail-car unloading facilities, an asphalt trucking operation and a petroleum coke handling and storage facility. Our Gathering and Processing segment consists of crude oil, natural gas, NGLs and produced water gathering systems in the Bakken Shale/Williston Basin area of North Dakota and Montana, the Green River Basin, Uinta Basin, and Vermillion Basin in the states of Utah, Colorado and Wyoming, the Delaware Basin in the Permian Basin area of West Texas and Southern New Mexico, and in the San Juan Basin in the Four Corners area of Northwestern New Mexico. It also consists of gas processing and fractionation complexes in the Bakken Shale, Green River Basin, Uinta Basin and Vermillion Basin. 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. Segment Information (in millions) Three Months Ended Nine Months Ended 2018 (a) 2017 (a) 2018 (a) 2017 (a) Revenues Terminalling and Transportation: Terminalling $ 235 $ 189 $ 643 $ 493 Pipeline transportation 44 34 115 97 Other revenues 1 7 4 9 Total Terminalling and Transportation 280 230 762 599 Gathering and Processing: NGL sales 137 90 336 254 Gas gathering and processing 82 85 249 252 Crude oil and water gathering 86 76 241 170 Pass-thru and other 40 44 119 120 Total Gathering and Processing 345 295 945 796 Wholesale: Fuel sales (b) 13 565 37 730 Other wholesale 7 4 25 10 Total Wholesale 20 569 62 740 Intersegment wholesale revenues (3 ) — (12 ) — Total Revenues $ 642 $ 1,094 $ 1,757 $ 2,135 Segment Operating Income Terminalling and Transportation $ 140 $ 103 $ 351 $ 290 Gathering and Processing 80 50 226 158 Wholesale 7 7 22 9 Total Segment Operating Income 227 160 599 457 Unallocated general and administrative expenses (12 ) (13 ) (27 ) (33 ) Operating Income 215 147 572 424 Interest and financing costs, net (57 ) (68 ) (172 ) (193 ) Equity in earnings of equity method investments 7 6 25 13 Other income, net 1 5 4 9 Net Earnings $ 166 $ 90 $ 429 $ 253 Depreciation and Amortization Expenses Terminalling and Transportation $ 35 $ 32 $ 105 $ 85 Gathering and Processing 47 51 154 134 Wholesale 4 2 9 3 Total Depreciation and Amortization Expenses $ 86 $ 85 $ 268 $ 222 Capital Expenditures Terminalling and Transportation $ 76 $ 51 $ 155 $ 127 Gathering and Processing 110 41 368 85 Wholesale — — 1 — Total Capital Expenditures $ 186 $ 92 $ 524 $ 212 (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 in connection with the adoption, the revenues and costs associated with our fuel purchase and supply arrangements with Andeavor were netted. Total Identifiable Assets by Segment (in millions) September 30, December 31, 2017 (a) Terminalling and Transportation $ 3,408 $ 3,045 Gathering and Processing 6,378 6,006 Wholesale 354 342 Other 57 112 Total Identifiable Assets $ 10,197 $ 9,505 (a) Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

Organization and Basis of Pre_2

Organization and Basis of Presentation (Policies)	9 Months Ended
	Sep. 30, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Accounting, Policy	We prepare our condensed consolidated financial statements in conformity with accounting principles generally accepted in the United States of America (“U.S. GAAP”). However, certain information and notes normally included in financial statements prepared under U.S. GAAP have been condensed or omitted pursuant to the SEC’s rules and regulations. Management believes that the disclosures presented herein are adequate to present the information fairly. The accompanying interim condensed consolidated financial statements and notes should be read in conjunction with our Annual Report on Form 10-K for the year ended December 31, 2017 . Certain prior year balances have been aggregated or disaggregated in order to conform to the current year presentation, including the adoption of recent accounting standards discussed further below.
Use of Estimates, Policy	We are required under U.S. GAAP to make estimates and assumptions that affect the amounts of assets and liabilities and revenues and expenses reported as of and during the periods presented. 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. The results of operations of the Partnership for any interim period are not necessarily indicative of results for the full year.
Cost of Sales, Policy	Cost Classifications Natural gas liquids (“NGL”) expense results from the cost of NGL purchases under our percent of proceeds (“POP”) arrangements as well as the non-cash acquisition of replacement dry gas under our keep-whole arrangements. During the three and nine months ended September 30, 2017 , cost of fuel and other included the purchase cost of refined products sold within our Wholesale segment, the cost of inbound transportation and distribution costs incurred to transport product to our customers. Due to the adoption of ASU 2014-09, “Revenue from Contracts with Customers,” and the associated subsequent amendments (collectively, “ASC 606”) on January 1, 2018, the revenues and costs associated with our fuel purchase and supply arrangements were netted, as further described in Note 10 . 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. General and administrative expenses represent costs that are not directly or indirectly related to or otherwise are not allocated to our operations. NGL expense, direct operating expenses, and depreciation and amortization expenses recognized by our Terminalling and Transportation, Gathering and Processing, and Wholesale segments constitute costs of revenue as defined by U.S. GAAP.
Fair Value of Financial Instruments, Policy	Financial Instruments 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 borrowings under our amended revolving credit facility (the “Revolving Credit Facility”) and our dropdown credit facility (“Dropdown Credit Facility”), which include a variable interest rate, approximate fair value. The carrying value and fair value of our debt were both $4.9 billion as of September 30, 2018 and were $4.2 billion and $4.3 billion at December 31, 2017 , respectively. These carrying and fair values of our debt exclude the unamortized issuance costs, which are netted against our total debt. We believe the carrying value of our other financial instruments, including cash and cash equivalents, receivables, accounts payable and certain accrued liabilities, approximate 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.
New Accounting Pronouncement, Policy	New Accounting Standards and Disclosures Revenue Recognition In May 2014, the Financial Accounting Standards Board (“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 $22 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 10 . 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 three and nine months ended September 30, 2018 , we recorded lower revenues of $709 million and $2.0 billion , respectively, and lower costs and expenses of $709 million and $2.0 billion , respectively, 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 with Andeavor, as further described in Note 10 . We recorded lower revenues of $13 million and $10 million associated with minimum volume commitments during the three and nine months ended September 30, 2018 , respectively, as a result of applying the new standard. There were no material impacts during the period to the condensed consolidated balance sheets or condensed 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”), which amends existing accounting standards for lease accounting and adds additional disclosures about leasing arrangements. Under the new guidance, lessees are required to recognize right-of-use assets and lease liabilities on the balance sheet for all leases with terms longer than 12 months. Leases will be classified as either a financing lease or operating lease with classification affecting the pattern of expense recognition in the condensed statements of consolidated operations and presentation of cash flows in the condensed statements of consolidated cash flows. The new standard also requires additional disclosures to help financial statement users better understand the amount, timing, and uncertainty of cash flows arising from leases. ASU 2016-02 is effective for annual reporting periods beginning after December 15, 2018, and interim reporting periods within those annual reporting periods, with early adoption being permitted. In July 2018, the FASB issued ASU 2018-11 , which permits entities with the option to adopt the provisions of ASU 2016-02 prospectively without adjusting comparative periods. We will elect this option and adopt the standard on January 1, 2019 . In addition, we also expect to adopt the package of practical expedients which allows an entity, on the date of adoption, to not reassess expired or existing contracts in whether they are a lease or contain a lease and to not reassess the historical lease classification for expired or existing leases. We continue to progress through our implementation plan, which includes the following activities: testing and implementing a new lease accounting system, finalizing design and implementation of new business processes and related internal controls, the continued extraction of the required accounting and reporting data from our lease agreements as well as the continued assessment and documentation of the accounting impacts related to the new standard. While we are still working through our implementation plan, we do expect that the recognition of right-of-use assets and lease liabilities, which are not currently reflected on our consolidated balance sheets, will have a material impact on total assets and liabilities. However, we do not expect the adoption of the standard to have a material impact on our statement of consolidated operations or liquidity. At this time, we are unable to estimate the full impact of the standard given we are still extracting the accounting data from our lease agreements as well as testing and implementing our new lease accounting system, which will be used to calculate the accounting impacts. 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 and we do not expect the adoption of this standard to have a material impact on our condensed 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 condensed statement of consolidated cash flows for the nine months ended September 30, 2017. See Note 2 for further information regarding restricted cash. 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 condensed statements of consolidated operations since these costs are allocated to the Partnership’s financial statements by Andeavor. The amendments to the presentation of the condensed statements of consolidated 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 $2 million and $6 million , respectively, with a corresponding increase to other income of $2 million and $6 million , respectively, for the three and nine months ended September 30, 2017 with no impact to net earnings. ASU 2017-07 does not impact the condensed consolidated balance sheets or condensed statements of consolidated cash flows. Stock Compensation In June 2018, the FASB issued ASU 2018-07, “Improvements to Nonemployee Share-Based Payment Accounting” (“ASU 2018-07”), 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. While we are still evaluating the impact of ASU 2018-07, we do not expect the adoption of this standard to have a material impact on our condensed consolidated financial statements.

Commitments and Contingencies C

Commitments and Contingencies Contingencies Accrued Liability (Policies)	9 Months Ended
	Sep. 30, 2018
Commitments and Contingencies Disclosure [Abstract]
Contingency Accrued Liabilities, Policy	In the ordinary course of business, we may become party to lawsuits, disputes, 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.

Equity Earnings Per Unit (Polic

Equity Earnings Per Unit (Policies)	9 Months Ended
	Sep. 30, 2018
Earnings Per Share [Abstract]
Earnings Per Share, Policy	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 incentive distribution rights (“IDRs”). Net earnings earned by the Partnership were allocated between the limited and general partners in accordance with our partnership agreement. At the effective time of the WNRL Merger, the IDRs were canceled (the “IDR Exchange”) and the general partner units were converted into a non-economic general partner interest in Andeavor Logistics (together with the IDR Exchange, the “IDR/GP Transaction”). As a result, 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 to equal 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.

Revenues (Policies)

Revenues (Policies)	9 Months Ended
	Sep. 30, 2018
Revenue Recognition [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 three and nine months ended September 30, 2018 , revenues from contracts with customers were $528 million and $1.5 billion , respectively, which excludes lease revenues of $114 million and $292 million , respectively. 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, Policy	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 replacement dry gas (“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 in service revenue 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 condensed statement of consolidated operations.
Revenue Recognition, Sales of Goods, Policy	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 condensed statement of consolidated operations. We have certain fuel purchase and sale arrangements with Andeavor under which we receive certain minimum guaranteed margins with upside potential on a certain portion of our branded and unbranded fuel sales. Andeavor retains control of fuel and is the principal in these affiliate arrangements. Therefore, we net the purchase and sale of fuel in our condensed 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.

Acquisitions Business Combinati

Acquisitions Business Combinations (Tables)	9 Months Ended
	Sep. 30, 2018
Business Combinations [Abstract]
Schedule of Business Acquisitions, by Acquisition	Acquisition Date Purchase Price Allocation (in millions) Cash $ 22 Receivables 112 Inventories 11 Prepayments and Other Current Assets 25 Property, Plant and Equipment (a) 1,357 Goodwill 558 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.
Business Acquisition, Pro Forma Information	Pro Forma Consolidated Revenues and Consolidated Net Earnings (in millions) Three Months Ended Nine Months Ended September 30, 2017 September 30, 2017 Revenues $ 1,094 $ 3,172 Net earnings (a) 90 258 (a) While many recurring adjustments impact the pro forma figures presented, the pro forma condensed statements of consolidated operations for the three and nine months ended September 30, 2017 includes a significant non-recurring adjustment to recognize the WNRL Merger acquisition and integration costs and reflects these costs in the first quarter of 2017, the period the acquisition was assumed to be completed for pro forma purposes. For the nine months ended September 30, 2017 , we recognized acquisition costs related to the WNRL Merger of $17 million as well as $3 million of severance costs.

Related-Party Transactions Re_2

Related-Party Transactions Related-Party Transactions (Tables)	9 Months Ended
	Sep. 30, 2018
Related Party Transactions [Abstract]
Schedule of Related Party Transactions	Summary of Revenue and Expense Transactions with Andeavor, Including Predecessors (in millions) Three Months Ended Nine Months Ended 2018 2017 2018 2017 Revenues (a) $ 415 $ 468 $ 1,131 $ 951 Operating expenses (b) 82 67 216 185 General and administrative expenses 31 30 77 77 (a) Andeavor accounted for 65% and 43% of our total revenues for the three months ended September 30, 2018 and 2017 , respectively, and 64% and 45% for the nine months ended September 30, 2018 and 2017 , respectively. (b) Net of reimbursements from Andeavor pursuant to the Amended Omnibus Agreement, the Carson Assets Indemnity Agreement and other affiliate agreements of $2 million and $7 million for the three months ended September 30, 2018 and 2017 respectively, and $12 million for both the nine months ended September 30, 2018 and 2017 .

Property, Plant and Equipment_2

Property, Plant and Equipment (Tables)	9 Months Ended
	Sep. 30, 2018
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment [Table Text Block]	Property, Plant & Equipment (in millions) September 30, December 31, 2017 (a) Terminals and tankage $ 3,595 $ 3,557 Pipelines 3,344 2,825 Land and leasehold improvements 289 282 Buildings and improvements 94 91 Other 142 142 Construction in progress 501 346 Property, Plant and Equipment, at Cost 7,965 7,243 Accumulated Depreciation (1,215 ) (994 ) Property, Plant and Equipment, Net $ 6,750 $ 6,249 (a) 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.

Goodwill (Tables)

Goodwill (Tables)	9 Months Ended
	Sep. 30, 2018
Goodwill and Intangible Assets Disclosure [Abstract]
Schedule of Goodwill [Table Text Block]	Goodwill by Operating Segment (in millions) September 30, December 31, 2017 (a) Terminalling and Transportation (b) $ 231 $ 260 Gathering and Processing (b) 695 607 Wholesale 62 89 Goodwill $ 988 $ 956 (a) Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion. (b) 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.

Equity Method Investments and_2

Equity Method Investments and Joint Ventures (Tables)	9 Months Ended
	Sep. 30, 2018
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments [Table Text Block]	Equity Method Investments (in millions) ALRP (a) MPL (a) PNAC (a) RGS TRG UBFS Total Balance at December 31, 2017 (b) $ — $ 120 $ — $ 268 $ 37 $ 15 $ 440 Acquired interests 159 — 27 — — — 186 Equity in earnings 4 14 — 4 2 1 25 Cumulative effect of accounting standard adoption — — — — (3 ) — (3 ) Distributions received (4 ) (14 ) — (16 ) (5 ) (2 ) (41 ) Balance at September 30, 2018 (b) $ 159 $ 120 $ 27 $ 256 $ 31 $ 14 $ 607 (a) These equity method investments were included in the 2018 Drop Down. Amounts were adjusted to include the historical results of the Predecessors. See Note 1 for further discussion. (b) The carrying amount of our investments in ALRP, MPL, PNAC, RGS, TRG and UBFS exceeded the underlying equity in net assets by $75 million , $34 million , $17 million , $127 million , $14 million and $6 million , respectively, at September 30, 2018 . The carrying amount of our investments in MPL, RGS, TRG and UBFS exceeded the underlying equity in net assets by $35 million , $130 million , $15 million and $6 million , respectively, at December 31, 2017. 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 (loss).

Debt (Tables)

Debt (Tables)	9 Months Ended
	Sep. 30, 2018
Debt Disclosure [Abstract]
Schedule of Debt	Debt Balance, Net of Unamortized Issuance Costs (in millions) September 30, December 31, 2017 Total debt $ 4,878 $ 4,182 Unamortized issuance costs (48 ) (54 ) Current maturities (1 ) (1 ) Debt, Net of Current Maturities and Unamortized Issuance Costs $ 4,829 $ 4,127
Schedule of Line of Credit Facilities	Available Capacity Under Credit Facilities (in millions) Total Capacity Amount Borrowed as of September 30, 2018 Outstanding Letters of Credit Available Capacity as of September 30, 2018 Weighted Average Interest Rate Expiration Revolving Credit Facility (a) $ 1,100 $ 820 $ — $ 280 3.95 % January 29, 2021 Dropdown Credit Facility 1,000 300 — 700 3.86 % January 29, 2021 Total Credit Facilities (a) $ 2,100 $ 1,120 $ — $ 980 (a) On January 5, 2018, we amended our Revolving Credit Facility to increase the aggregate commitments from $600 million to $1.1 billion and to permit the incurrence of incremental loans. We are allowed to request that the loan availability be increased up to an aggregate of $2.1 billion , subject to receiving increased commitments from the lenders.

Equity (Tables)

Equity (Tables)	9 Months Ended
	Sep. 30, 2018
Equity [Abstract]
Schedule of partners' capital	Changes to Equity (in millions) Equity of Predecessors (a) Partnership Total Common Preferred Balance at December 31, 2017 $ 1,292 $ 2,925 $ 589 $ 4,806 Sponsor contributions of assets to the Predecessors 406 — — 406 Loss attributable to the Predecessors (28 ) — — (28 ) Net assets not assumed by Andeavor Logistics (19 ) — — (19 ) Allocation of net assets acquired by the unitholders (1,651 ) 1,651 — — Distributions to common and preferred unitholders (b) — (620 ) (29 ) (649 ) Distributions to common unitholders related to acquisitions (c) — (300 ) — (300 ) Net earnings attributable to partners — 423 34 457 Cumulative effect of accounting standard adoption — (22 ) — (22 ) Contributions (d) — 34 — 34 Other — 2 — 2 Balance at September 30, 2018 $ — $ 4,093 $ 594 $ 4,687 (a) Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion. (b) Represents cash distributions declared and paid during the nine months ended September 30, 2018 . (c) Distributions to common unitholders include $300 million in cash payments for the 2018 Drop Down. As an entity under common control with Andeavor, we record the assets that we acquire from Andeavor in our consolidated balance sheets at Andeavor’s historical book value instead of fair value, and any excess of cash paid over the historical book value of the assets acquired from Andeavor is recorded within equity. As a result of this accounting treatment, this transaction resulted in a net increase of $1.4 billion in our equity balance during the nine months ended September 30, 2018 . (d) Includes Andeavor and TLGP contributions to the Partnership primarily related to reimbursements for capital spending pursuant predominantly to the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement.
Schedule of quarterly distributions	Quarterly Distributions on Common Units Quarter Ended Quarterly Distribution Per Common Unit Total Cash Distribution (in millions) Date of Distribution Unitholders Record Date December 31, 2017 (a) $ 1.000 $ 205 February 14, 2018 January 31, 2018 March 31, 2018 (a) 1.015 205 May 15, 2018 May 1, 2018 June 30, 2018 (a) 1.030 209 August 14, 2018 August 3, 2018 September 30, 2018 (a)(b) 1.030 238 November 14, 2018 November 5, 2018 (a) This distribution is net of $15 million waived by TLGP for each of the three months ended September 30, 2018 , June 30, 2018 and March 31, 2018, as well as $12.5 million for the three months ended December 31, 2017. TLGP’s distribution waivers for 2018 and 2019 remain in effect as instituted in 2017 under the terms of our partnership agreement. (b) This distribution was declared on October 26, 2018 and will be paid on the date of distribution.

Equity Net Earnings per Unit (T

Equity Net Earnings per Unit (Tables)	9 Months Ended
	Sep. 30, 2018
Earnings Per Share [Abstract]
Earnings Per Share	Net Earnings per Unit (in millions, except per unit amounts) Three Months Ended Nine Months Ended 2018 2017 2018 2017 Net earnings $ 166 $ 90 $ 429 $ 253 Special allocations of net earnings (“Special Allocations”) (a) — — — 1 Net earnings, including Special Allocations 166 90 429 254 Distributions on Preferred Units (b) (11 ) — (31 ) — Net earnings attributable to common units 155 90 398 254 General partner’s distributions — — — (6 ) General partner’s IDRs (c) — — — (75 ) Limited partners’ distributions on common units (238 ) (201 ) (652 ) (407 ) Distributions on common units greater than earnings $ (83 ) $ (111 ) $ (254 ) $ (234 ) General partner’s earnings: Distributions $ — $ — $ — $ 6 General partner’s IDRs (c) — — — 75 Allocation of distributions greater than earnings (d) (4 ) (8 ) (28 ) (48 ) Total general partner’s earnings $ (4 ) $ (8 ) $ (28 ) $ 33 Limited partners’ earnings on common units: Distributions (e) $ 238 $ 201 $ 652 $ 407 Special Allocations (a) — — — (1 ) Allocation of distributions greater than earnings (79 ) (103 ) (226 ) (186 ) Total limited partners’ earnings on common units $ 159 $ 98 $ 426 $ 220 Weighted average limited partner units outstanding: Common units - basic 234.4 108.0 223.0 107.0 Common units - diluted (f) 234.6 108.1 223.2 107.1 Net earnings per limited partner unit: (g) Common - basic $ 0.68 $ 0.90 $ 1.91 $ 2.05 Common - diluted $ 0.68 $ 0.90 $ 1.91 $ 2.05 (a) 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 Revolving Credit Facility in lieu of using all cash on hand to fund the acquisition of crude oil, natural gas and produced water gathering systems and two natural gas processing facilities from Whiting Oil and Gas Corporation, GBK Investments, LLC and WBI Energy Midstream, LLC (the “North Dakota Gathering and Processing Assets”) during the nine months ended September 30, 2017 . (b) The Preferred Units entitle unitholders to receive preferred distributions on a semi-annually basis. (c) 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 $38 million of IDRs waived by TLGP for the nine months ended September 30, 2017 , respectively. Our general partner no longer holds IDRs as a result of the IDR/GP Transaction. (d) We have revised the historical allocation of general partner earnings to include the Predecessors’ losses of $4 million and $28 million for the three and nine months ended September 30, 2018 , respectively, and losses of $7 million and $46 million for the three and nine months ended September 30, 2017 , respectively. (e) Distributions of earnings for limited partners’ common units for the three and nine months ended September 30, 2018 is net of a $15 million and $45 million waiver, respectively, from Andeavor in connection with the WNRL Merger. (f) 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. (g) Amounts may not recalculate due to rounding of dollar and unit information.

Revenues (Tables)

Revenues (Tables)	9 Months Ended
	Sep. 30, 2018
Revenue Recognition [Abstract]
Contract with Customer, Asset and Liability	Summary of Customer Contract Assets and Liabilities (in millions) December 31, 2017 (a) Adjustments for ASC 606 (b) Balance at January 1, 2018 September 30, Receivables from contracts with customers $ 443 $ (34 ) $ 409 $ 437 Other contract assets — 34 34 31 Deferred income, current 23 — 23 22 Deferred income, noncurrent 43 19 62 64 (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 condensed consolidated balance sheets as of January 1, 2018 for the impacts related to our equity method investment in Three Rivers Gathering, LLC. There were no material impacts to this balance during the nine months ended September 30, 2018 due to the adoption.
Disaggregation of Revenue	Revenue Disaggregation by Type and Product Line (in millions) Three Months Ended September 30, 2018 Nine Months Ended September 30, 2018 Terminalling and Transportation Gathering and Processing Wholesale Terminalling and Transportation Gathering and Processing Wholesale Service Revenues (a) Refined products $ 240 $ — $ 4 $ 650 $ — $ 13 Crude oil and water 39 108 — 108 313 — Natural gas — 100 — — 296 — Other 1 — — 4 — — Total Service Revenues 280 208 4 762 609 13 Product Revenues NGL products — 137 — — 336 — Refined products — — 13 — — 37 Total Product Revenues — 137 13 — 336 37 Total Revenues $ 280 $ 345 $ 17 $ 762 $ 945 $ 50 (a) Includes $114 million and $292 million of lease revenues for the three and nine months ended September 30, 2018 , respectively.

Operating Segments (Tables)

Operating Segments (Tables)	9 Months Ended
	Sep. 30, 2018
Segment Reporting, Disclosure of Entity's Reportable Segments [Abstract]
Schedule of segment reporting information, by segment	Segment Information (in millions) Three Months Ended Nine Months Ended 2018 (a) 2017 (a) 2018 (a) 2017 (a) Revenues Terminalling and Transportation: Terminalling $ 235 $ 189 $ 643 $ 493 Pipeline transportation 44 34 115 97 Other revenues 1 7 4 9 Total Terminalling and Transportation 280 230 762 599 Gathering and Processing: NGL sales 137 90 336 254 Gas gathering and processing 82 85 249 252 Crude oil and water gathering 86 76 241 170 Pass-thru and other 40 44 119 120 Total Gathering and Processing 345 295 945 796 Wholesale: Fuel sales (b) 13 565 37 730 Other wholesale 7 4 25 10 Total Wholesale 20 569 62 740 Intersegment wholesale revenues (3 ) — (12 ) — Total Revenues $ 642 $ 1,094 $ 1,757 $ 2,135 Segment Operating Income Terminalling and Transportation $ 140 $ 103 $ 351 $ 290 Gathering and Processing 80 50 226 158 Wholesale 7 7 22 9 Total Segment Operating Income 227 160 599 457 Unallocated general and administrative expenses (12 ) (13 ) (27 ) (33 ) Operating Income 215 147 572 424 Interest and financing costs, net (57 ) (68 ) (172 ) (193 ) Equity in earnings of equity method investments 7 6 25 13 Other income, net 1 5 4 9 Net Earnings $ 166 $ 90 $ 429 $ 253 Depreciation and Amortization Expenses Terminalling and Transportation $ 35 $ 32 $ 105 $ 85 Gathering and Processing 47 51 154 134 Wholesale 4 2 9 3 Total Depreciation and Amortization Expenses $ 86 $ 85 $ 268 $ 222 Capital Expenditures Terminalling and Transportation $ 76 $ 51 $ 155 $ 127 Gathering and Processing 110 41 368 85 Wholesale — — 1 — Total Capital Expenditures $ 186 $ 92 $ 524 $ 212 (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 in connection with the adoption, the revenues and costs associated with our fuel purchase and supply arrangements with Andeavor were netted. Total Identifiable Assets by Segment (in millions) September 30, December 31, 2017 (a) Terminalling and Transportation $ 3,408 $ 3,045 Gathering and Processing 6,378 6,006 Wholesale 354 342 Other 57 112 Total Identifiable Assets $ 10,197 $ 9,505 (a) Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

Organization and Basis of Pre_3

Organization and Basis of Presentation, Fair Value (Details) - USD ($) $ in Millions		9 Months Ended
		Sep. 30, 2018	Sep. 30, 2017	Dec. 31, 2017
Limited Partners' Capital Account, Units Outstanding		245,000,000
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage		64.00%
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest		100.00%
Net Cash Provided by (Used in) Operating Activities, Continuing Operations	[1]	$ 719	$ 524
Net Cash Provided by (Used in) Investing Activities	[1]	(945)	(1,404)
Debt, carrying value		4,900		$ 4,200
Debt, fair value		4,900		$ 4,300
Predecessor [Member]
Net Cash Provided by (Used in) Operating Activities, Continuing Operations		40	25
Net Cash Provided by (Used in) Investing Activities		$ 446	$ 653
Limited Partner Units, Affiliate [Member]
Limited Partners' Capital Account, Units Outstanding		156,173,128
[1]	Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.

Organization and Basis of Pre_4

Organization and Basis of Presentation New Accounting Standards and Disclosures (Details) - USD ($) $ in Millions		3 Months Ended				9 Months Ended
		Sep. 30, 2018	Sep. 30, 2017		Jun. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Revenues		$ 642	$ 1,094	[1],[2],[3]		$ 1,757	$ 2,135	[1],[2],[3]
Interest and Debt Expense		57	68	[1],[2]		172	193	[1],[2]
Other income, net		1	5	[1],[2]		4	9	[1],[2]
Net Income (Loss) Allocated to Limited Partners		160	97			423	220
Accounting Standards Update 2016-18 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cash and cash equivalents					$ 14
Accounting Standards Update 2017-07
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Interest and Debt Expense			2				6
Other income, net			$ 2				6
Net Income (Loss) Allocated to Limited Partners					$ 0		$ 0
Difference between Revenue Guidance in Effect before and after Topic 606 | Accounting Standards Update 2014-09
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Retained Earnings (Accumulated Deficit)		22				22
Wholesale | Difference between Revenue Guidance in Effect before and after Topic 606 | Accounting Standards Update 2014-09
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Revenues	[1],[3]	709				2,000
Cost of Goods and Services Sold	[1],[3]	709				2,000
Gathering and Processing | Difference between Revenue Guidance in Effect before and after Topic 606 | Accounting Standards Update 2014-09
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Revenues	[1],[3]	$ 13				$ 10
[1]	Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.
[2]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[3]	Due to the adoption of the revenue recognition standard effective January 1, 2018, the revenues and costs associated with our fuel purchase and supply arrangements with Andeavor for the three and nine months ended September 30, 2018 were netted. See Note 1 for further discussion.

Acquisitions Dropdown (Details)

Acquisitions Dropdown (Details) - USD ($) $ in Millions		Aug. 06, 2018	Sep. 30, 2018	Sep. 30, 2018	Sep. 30, 2017
Distributions in connection with acquisitions	[1]			$ 300	$ 5
Common Unit, Issued			28,283,742
Business Acquisition, Equity Interest Issued or Issuable, Value Assigned			$ 1,250	$ 1,250
Logistics Assets Drop Down and Asset Transfer [Member]
Business Combination, Consideration Transferred		$ 1,550
Rangeland RIO Pipeline, LLC [Member]
Equity Method Investment, Ownership Percentage			67.00%	67.00%
[1]	Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.

Acquisitions DropDown - Reconci

Acquisitions DropDown - Reconciliation of Combined Financial Statements (Details) - USD ($) $ in Millions		Jun. 02, 2017	Sep. 30, 2018	Sep. 30, 2017		Sep. 30, 2018		Sep. 30, 2017
Revenues			$ 642	$ 1,094	[1],[2],[3]	$ 1,757		$ 2,135	[1],[2],[3]
Operating expenses (excluding depreciation and amortization)			236	199	[1]	658		512	[1]
Depreciation and amortization expenses			86	85	[1],[2]	268	[4]	222	[1],[2],[4]
General and administrative expenses			31	44	[1]	91		107	[1]
Gain (Loss) on Disposition of Property Plant Equipment		$ (28)	1	1	[1]	2	[4]	(25)	[1],[4]
Operating Income			215	147	[1],[2]	572		424	[1],[2]
Interest and Debt Expense			(57)	(68)	[1],[2]	(172)		(193)	[1],[2]
Equity in earnings of equity method investments			7	6	[1],[2]	25		13	[1],[2]
Other income, net			1	5	[1],[2]	4		9	[1],[2]
Net Earnings			166	90	[1],[2]	429	[4]	253	[1],[2],[4]
Loss attributable to Predecessors			4	7		28		46
Net Income (Loss) Attributable to Parent			170	97		457		299
Preferred unitholders’ interest in net earnings			(10)	0		(34)		0
General partner’s interest in net earnings, including incentive distribution rights			0	0		0		(79)
Net Income (Loss) Allocated to Limited Partners			160	97		423		220
Oil and Gas, Purchased
Cost of Goods and Services Sold	[3]		0	554	[1]	0	[1]	716	[1]
Natural Gas, Midstream
Cost of Goods and Services Sold			73	64	[1]	166		179	[1]
Third Party
Revenues			227	626		626		1,184
Affiliated Entity
Revenues			415	468		1,131		951
Predecessor [Member]
Revenues			7	650		30		858
Operating expenses (excluding depreciation and amortization)			9	58		40		113
Depreciation and amortization expenses			3	25		22		44
General and administrative expenses			1	17		9		29
Gain (Loss) on Disposition of Property Plant Equipment			0	0		0		(1)
Operating Income			(6)	(4)		(41)		(43)
Interest and Debt Expense			(1)	(7)		(4)		(9)
Equity in earnings of equity method investments			3	4		16		6
Other income, net			0	0		1		0
Net Earnings			(4)	(7)		(28)		(46)
Loss attributable to Predecessors			4	7		28		46
Net Income (Loss) Attributable to Parent			0	0		0		0
Preferred unitholders’ interest in net earnings			0			0
General partner’s interest in net earnings, including incentive distribution rights				0				0
Net Income (Loss) Allocated to Limited Partners			0	0		0		0
Predecessor [Member] | Oil and Gas, Purchased
Cost of Goods and Services Sold				554				716
Predecessor [Member] | Natural Gas, Midstream
Cost of Goods and Services Sold			0	0		0		0
Predecessor [Member] | Third Party
Revenues			3	401		9		531
Predecessor [Member] | Affiliated Entity
Revenues			4	249		21		327
Successor [Member]
Revenues			635	444		1,727		1,277
Operating expenses (excluding depreciation and amortization)			227	141		618		399
Depreciation and amortization expenses			83	60		246		178
General and administrative expenses			30	27		82		78
Gain (Loss) on Disposition of Property Plant Equipment			1	1		2		(24)
Operating Income			221	151		613		467
Interest and Debt Expense			(56)	(61)		(168)		(184)
Equity in earnings of equity method investments			4	2		9		7
Other income, net			1	5		3		9
Net Earnings			170	97		457		299
Loss attributable to Predecessors			0	0		0		0
Net Income (Loss) Attributable to Parent			170	97		457		299
Preferred unitholders’ interest in net earnings			(10)			(34)
General partner’s interest in net earnings, including incentive distribution rights				0				(79)
Net Income (Loss) Allocated to Limited Partners			160	97		423		220
Successor [Member] | Oil and Gas, Purchased
Cost of Goods and Services Sold				0				0
Successor [Member] | Natural Gas, Midstream
Cost of Goods and Services Sold			73	64		166		179
Successor [Member] | Third Party
Revenues			224	225		617		653
Successor [Member] | Affiliated Entity
Revenues			$ 411	$ 219		$ 1,110		$ 624
[1]	Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.
[2]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[3]	Due to the adoption of the revenue recognition standard effective January 1, 2018, the revenues and costs associated with our fuel purchase and supply arrangements with Andeavor for the three and nine months ended September 30, 2018 were netted. See Note 1 for further discussion.
[4]	Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.

Acquisitions Acquisitions (Deta

Acquisitions Acquisitions (Details) - USD ($) $ in Millions		May 01, 2018	Sep. 30, 2018	Sep. 30, 2017
Acquisition and Divestitures
Distributions in connection with acquisitions	[1]		$ 300	$ 5
Wamsutter Pipeline System
Acquisition and Divestitures
Distributions in connection with acquisitions		$ 180
WNRL Merger
Acquisition and Divestitures
Total purchase price			1,662
Goodwill, Purchase Accounting Adjustments			$ (7)
[1]	Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.

Acquisitions Purchase Price All

Acquisitions Purchase Price Allocation Table (Details) - USD ($) $ in Millions		9 Months Ended
		Sep. 30, 2018	Dec. 31, 2017	[1]
Business Acquisition [Line Items]
Goodwill		$ 988	$ 956
WNRL Merger
Business Acquisition [Line Items]
Cash		22
Receivables		112
Inventories		11
Prepayments and Other Current Assets		25
Property, Plant and Equipment (a)	[2]	1,357
Goodwill		558
Acquired Intangibles		130
Other Noncurrent Assets		2
Accounts Payable		(167)
Accrued Liabilities		(41)
Debt		(347)
Total purchase price		$ 1,662
Minimum | WNRL Merger
Business Acquisition [Line Items]
Property, Plant and Equipment, Useful Life		3 years
Maximum | WNRL Merger
Business Acquisition [Line Items]
Property, Plant and Equipment, Useful Life		22 years
[1]	Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.
[2]	Estimated useful lives ranging from 3 to 22 years have been assumed based on the valuation.

Acquisitions Additional Acquisi

Acquisitions Additional Acquisition information (Details) - USD ($) $ in Millions		3 Months Ended			9 Months Ended
		Sep. 30, 2018	Sep. 30, 2017		Sep. 30, 2018	Sep. 30, 2017		Jun. 30, 2018	Dec. 31, 2017	[1]
Goodwill		$ 988			$ 988				$ 956
Revenues		642	$ 1,094	[2],[3],[4]	1,757	$ 2,135	[2],[3],[4]
Net Income (Loss) Attributable to Parent		170	97		457	299
WNRL Merger
Finite-Lived Intangible Assets, Amortization Expense, Year Two								$ 9
Business Acquisition, Transaction Costs			17			17
Business Acquisition, Pro Forma Revenue			1,094			3,172
Goodwill		558			558
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment	[5]	1,357			1,357
Acquired Intangibles		130			$ 130
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life					15 years
Finite-Lived Intangible Assets, Accumulated Amortization		12			$ 12
Finite-Lived Intangible Assets, Amortization Expense, Next Twelve Months		9			9
Revenues					303
Net Income (Loss) Attributable to Parent					87
Business Acquisition, Pro Forma Net Income (Loss)	[6]		$ 90			258
Business Combination, Integration Related Costs						$ 3
Finite-Lived Intangible Assets, Amortization Expense, Year Three								9
Finite-Lived Intangible Assets, Amortization Expense, Year Four								9
Finite-Lived Intangible Assets, Amortization Expense, Year Five								$ 9
WNRL Merger | Gathering and Processing
Goodwill		352			352
WNRL Merger | Terminalling and Transportation
Goodwill		144			144
WNRL Merger | Wholesale Segment
Goodwill		$ 62			$ 62
[1]	Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.
[2]	Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.
[3]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[4]	Due to the adoption of the revenue recognition standard effective January 1, 2018, the revenues and costs associated with our fuel purchase and supply arrangements with Andeavor for the three and nine months ended September 30, 2018 were netted. See Note 1 for further discussion.
[5]	Estimated useful lives ranging from 3 to 22 years have been assumed based on the valuation.
[6]	While many recurring adjustments impact the pro forma figures presented, the pro forma condensed statements of consolidated operations for the three and nine months ended September 30, 2017 includes a significant non-recurring adjustment to recognize the WNRL Merger acquisition and integration costs and reflects these costs in the first quarter of 2017, the period the acquisition was assumed to be completed for pro forma purposes. For the nine months ended September 30, 2017, we recognized acquisition costs related to the WNRL Merger of $17 million as well as $3 million of severance costs.

Acquisitions Divestitures (Deta

Acquisitions Divestitures (Details) - USD ($) $ in Millions	Jun. 02, 2017	Sep. 30, 2018	Sep. 30, 2017	[1]	Jun. 30, 2017	Sep. 30, 2018	[2]	Sep. 30, 2017	[1],[2]
Property, Plant and Equipment [Line Items]
Proceeds from Sales of Business, Affiliate and Productive Assets					$ 14
Loss (gain) on asset disposals and impairments	$ 28	$ (1)	$ (1)			$ (2)		$ 25
Alaska Terminal [Member]
Property, Plant and Equipment [Line Items]
Loss (gain) on asset disposals and impairments					25
WNRL Lubricant Operations [Member]
Property, Plant and Equipment [Line Items]
Loss (gain) on asset disposals and impairments					$ 0
[1]	Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.
[2]	Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.

Related-Party Transactions Re_3

Related-Party Transactions Related-Party Transactions, Summary of Transactions Narrative (Details) - USD ($) $ in Millions		2 Months Ended	3 Months Ended		9 Months Ended
		Nov. 30, 2018	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Revenue from Related Parties	[1]		$ 415	$ 468	$ 1,131	$ 951
Related Party Transaction, Expenses from Transactions with Related Party	[2]		82	67	216	185
Related Party Transaction, Selling, General and Administrative Expenses from Transactions with Related Party			$ 31	$ 30	$ 77	$ 77
Concentration Risk, Percentage			65.00%	43.00%	64.00%	45.00%
Payments of Distributions to Affiliates					$ 347
Partner to Andeavor | Omnibus Agreement
Payment for Administrative Fees					17
Andeavor to Partner | Secondment and Logistics Services Agreement
Long-term Purchase Commitment, Amount			$ 28	$ 6	38	$ 16
Andeavor to Partner | Construction Contracts [Member]
Long-term Purchase Commitment, Amount					$ 11
Subsequent Event
Payments of Distributions to Affiliates		$ 146
[1]	Andeavor accounted for 65% and 43% of our total revenues for the three months ended September 30, 2018 and 2017, respectively, and 64% and 45% for the nine months ended September 30, 2018 and 2017, respectively.
[2]	Net of reimbursements from Andeavor pursuant to the Amended Omnibus Agreement, the Carson Assets Indemnity Agreement and other affiliate agreements of $2 million and $7 million for the three months ended September 30, 2018 and 2017 respectively, and $12 million for both the nine months ended September 30, 2018 and 2017.

Related-Party Transactions Re_4

Related-Party Transactions Related-Party Transactions, Summary of Affiliate Transactions (Details) - USD ($) $ / shares in Units, $ in Millions		2 Months Ended	3 Months Ended					9 Months Ended
		Nov. 30, 2018	Sep. 30, 2018		Jun. 30, 2018	Mar. 31, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Revenue from Related Parties	[1]		$ 415				$ 468	$ 1,131	$ 951
Concentration Risk, Percentage			65.00%				43.00%	64.00%	45.00%
Distribution Made to Limited Partner, Distributions Declared, Per Unit	[2]		$ 1.030	[3]	$ 1.015	$ 1
Distribution Made to Limited Partner, Distribution Date	[2]		Aug. 14, 2018	[3]	May 15, 2018	Feb. 14, 2018
Related Party Transaction, Expenses from Transactions with Related Party	[4]		$ 82				$ 67	$ 216	$ 185
Related Party Transaction, Selling, General and Administrative Expenses from Transactions with Related Party			31				30	77	77
Recovery of Direct Costs			$ 2				$ 7	$ 12	$ 12
Subsequent Event
Distribution Made to Limited Partner, Declaration Date		Oct. 26, 2018
Distribution Made to Limited Partner, Distributions Declared, Per Unit	[2]	$ 1.030
Distribution Made to Limited Partner, Distribution Date	[2],[3]	Nov. 14, 2018
[1]	Andeavor accounted for 65% and 43% of our total revenues for the three months ended September 30, 2018 and 2017, respectively, and 64% and 45% for the nine months ended September 30, 2018 and 2017, respectively.
[2]	This distribution is net of $15 million waived by TLGP for each of the three months ended September 30, 2018, June 30, 2018 and March 31, 2018, as well as $12.5 million for the three months ended December 31, 2017. TLGP’s distribution waivers for 2018 and 2019 remain in effect as instituted in 2017 under the terms of our partnership agreement.
[3]	This distribution was declared on October 26, 2018 and will be paid on the date of distribution.
[4]	Net of reimbursements from Andeavor pursuant to the Amended Omnibus Agreement, the Carson Assets Indemnity Agreement and other affiliate agreements of $2 million and $7 million for the three months ended September 30, 2018 and 2017 respectively, and $12 million for both the nine months ended September 30, 2018 and 2017.

Property, Plant and Equipment_3

Property, Plant and Equipment (Details) - USD ($) $ in Millions		Sep. 30, 2018	Dec. 31, 2017
Property, Plant and Equipment [Line Items]
Property, plant and equipment, at cost		$ 7,965	$ 7,243	[1]
Accumulated depreciation		1,215	994	[1]
Property, Plant and Equipment, Net		6,750	6,249	[1]
Terminals and tankage
Property, Plant and Equipment [Line Items]
Property, plant and equipment, at cost		3,595	3,557
Pipelines
Property, Plant and Equipment [Line Items]
Property, plant and equipment, at cost		3,344	2,825
Land and leasehold improvements
Property, Plant and Equipment [Line Items]
Property, plant and equipment, at cost		289	282
Buildings and improvements
Property, Plant and Equipment [Line Items]
Property, plant and equipment, at cost		94	91
Other
Property, Plant and Equipment [Line Items]
Property, plant and equipment, at cost		142	142
Construction in progress
Property, Plant and Equipment [Line Items]
Property, plant and equipment, at cost		$ 501	346
Predecessor [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, at cost	[1],[2]		948
Accumulated depreciation	[1],[2]		$ 112
[1]	Adjusted to include the historical results of the Predecessors. See Note 1 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.

Goodwill (Details)

Goodwill (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017	Dec. 31, 2017
Goodwill [Line Items]
Goodwill		$ 988		$ 988		$ 956	[1]
Goodwill, Impairment Loss		0	$ 0	0	$ 0
Operating Segments | Terminalling and Transportation
Goodwill [Line Items]
Goodwill		231		231		260	[1],[2]
Operating Segments | Gathering and Processing
Goodwill [Line Items]
Goodwill		695		695		607	[1],[2]
Operating Segments | Wholesale
Goodwill [Line Items]
Goodwill		$ 62		$ 62		89	[1]
Predecessor [Member] | Operating Segments | Terminalling and Transportation
Goodwill [Line Items]
Goodwill	[1],[2]					39
Predecessor [Member] | Operating Segments | Gathering and Processing
Goodwill [Line Items]
Goodwill	[1],[2]					$ 225
[1]	Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.
[2]	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.

Equity Method Investments and_3

Equity Method Investments and Joint Ventures (Details) - USD ($) $ in Millions		3 Months Ended			9 Months Ended
		Sep. 30, 2018	Sep. 30, 2017	[2],[3]	Sep. 30, 2018	Sep. 30, 2017	[2],[3]	Dec. 31, 2017
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Equity Method Investments	[1]				$ 440
Payments to Acquire Equity Method Investments					186
Equity in earnings of equity method investments		$ 7	$ 6		25	$ 13
Cumulative Effect of New Accounting Principle in Period of Adoption		(3)			(3)
Proceeds from Equity Method Investment, Distribution					41
Equity Method Investments		$ 607			$ 607
Minnesota Pipe Line Company, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		17.00%			17.00%
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity		$ 34			$ 34			$ 35
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Equity Method Investments	[4],[5]				120
Payments to Acquire Equity Method Investments	[5]				0
Equity in earnings of equity method investments	[5]				14
Cumulative Effect of New Accounting Principle in Period of Adoption	[5]	0			0
Proceeds from Equity Method Investment, Distribution	[5]				14
Equity Method Investments	[4],[5]	$ 120			$ 120
PNAC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		50.00%			50.00%
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity		$ 17			$ 17
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Equity Method Investments	[4],[5]				0
Payments to Acquire Equity Method Investments	[5]				27
Equity in earnings of equity method investments	[5]				0
Cumulative Effect of New Accounting Principle in Period of Adoption	[5]	0			0
Proceeds from Equity Method Investment, Distribution	[5]				0
Equity Method Investments	[4],[5]	$ 27			$ 27
Rendezvous Gas Services, L.L.C. [Domain]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		78.00%			78.00%
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity		$ 127			$ 127			130
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Equity Method Investments	[4]				268
Payments to Acquire Equity Method Investments					0
Equity in earnings of equity method investments					4
Cumulative Effect of New Accounting Principle in Period of Adoption		0			0
Proceeds from Equity Method Investment, Distribution					16
Equity Method Investments	[4]	$ 256			$ 256
Rangeland RIO Pipeline, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		67.00%			67.00%
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity		$ 75			$ 75
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Equity Method Investments	[4],[5]				0
Payments to Acquire Equity Method Investments	[5]				159
Equity in earnings of equity method investments	[5]				4
Cumulative Effect of New Accounting Principle in Period of Adoption	[5]	0			0
Proceeds from Equity Method Investment, Distribution	[5]				4
Equity Method Investments	[4],[5]	$ 159			$ 159
Three Rivers Gathering, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		50.00%			50.00%
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity		$ 14			$ 14			15
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Equity Method Investments	[4]				37
Payments to Acquire Equity Method Investments					0
Equity in earnings of equity method investments					2
Cumulative Effect of New Accounting Principle in Period of Adoption		(3)			(3)
Proceeds from Equity Method Investment, Distribution					5
Equity Method Investments	[4]	$ 31			$ 31
Uintah Basin Field Services, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		38.00%			38.00%
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity		$ 6			$ 6			$ 6
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Equity Method Investments	[4]				15
Payments to Acquire Equity Method Investments					0
Equity in earnings of equity method investments					1
Cumulative Effect of New Accounting Principle in Period of Adoption		0			0
Proceeds from Equity Method Investment, Distribution					2
Equity Method Investments	[4]	$ 14			$ 14
[1]	Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.
[2]	Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.
[3]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[4]	The carrying amount of our investments in ALRP, MPL, PNAC, RGS, TRG and UBFS exceeded the underlying equity in net assets by $75 million, $34 million, $17 million, $127 million, $14 million and $6 million, respectively, at September 30, 2018. The carrying amount of our investments in MPL, RGS, TRG and UBFS exceeded the underlying equity in net assets by $35 million, $130 million, $15 million and $6 million, respectively, at December 31, 2017. 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 (loss).
[5]	These equity method investments were included in the 2018 Drop Down. Amounts were adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.

Debt Total Debt (Details)

Debt Total Debt (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Debt Disclosure [Abstract]
Total debt	$ 4,878	$ 4,182
Unamortized issuance costs	(48)	(54)
Current maturities	(1)	(1)
Debt, Net of Current Maturities and Unamortized Issuance Costs	$ 4,829	$ 4,127	[1]
[1]	Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.

Debt Credit Facilities (Details

Debt Credit Facilities (Details) - USD ($) $ in Millions		9 Months Ended
		Sep. 30, 2018		Jan. 05, 2018	Dec. 31, 2017
Line of Credit Facility [Line Items]
Total Capacity	[1]	$ 2,100
Amount Borrowed as of September 30, 2018	[1]	1,120
Outstanding Letters of Credit	[1]	0
Available Capacity as of September 30, 2018	[1]	980
Line of Credit Facility, Maximum Borrowing Capacity				$ 2,100
Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Total Capacity		1,100	[1]		$ 600
Amount Borrowed as of September 30, 2018	[1]	820
Outstanding Letters of Credit	[1]	0
Available Capacity as of September 30, 2018	[1]	$ 280
Expiration	[1]	Jan. 29, 2021
Weighted Average Interest Rate	[1]	3.95%
Dropdown Credit Facility
Line of Credit Facility [Line Items]
Total Capacity		$ 1,000
Amount Borrowed as of September 30, 2018		300
Outstanding Letters of Credit		0
Available Capacity as of September 30, 2018		$ 700
Expiration		Jan. 29, 2021
Weighted Average Interest Rate		3.86%
[1]	On January 5, 2018, we amended our Revolving Credit Facility to increase the aggregate commitments from $600 million to $1.1 billion and to permit the incurrence of incremental loans. We are allowed to request that the loan availability be increased up to an aggregate of $2.1 billion, subject to receiving increased commitments from the lenders.

Equity Equity, Narrative (Detai

Equity Equity, Narrative (Details) - shares	9 Months Ended
	Sep. 30, 2018	Dec. 31, 2017
Limited Partners' Capital Account, Units Outstanding	245,000,000
Preferred Units, Outstanding	600,000	600,000
Preferred Stock, Dividend Rate, Percentage	6.875%
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage	64.00%
Public common units
Limited Partners' Capital Account, Units Outstanding	89,299,615
Limited Partner Units, Affiliate [Member]
Limited Partners' Capital Account, Units Outstanding	156,173,128
TexNew Mex Units
Limited Partners' Capital Account, Units Outstanding	80,000

Equity, Equity Activity (Detail

Equity, Equity Activity (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Changes in carrying amount of Equity
Balance at December 31, 2017	[1]			$ 4,806
Partners Capital Contribution Other				406
Loss attributable to Predecessors		$ 4	$ 7	28	$ 46
Net assets not assumed by Andeavor Logistics		(19)		(19)
Stockholders' Equity, Change in Reporting Entity				0
Distributions to common unitholders related to acquisitions (c)				649
Net earnings attributable to partners		170	$ 97	457	$ 299
Cumulative effect of accounting standard adoption				(22)
Contributions (d)	[2]			34
Other				2
Balance at September 30, 2018		4,687		4,687
Predecessor Equity [Member]
Changes in carrying amount of Equity
Balance at December 31, 2017	[3]			1,292
Partners Capital Contribution Other	[3]			406
Loss attributable to Predecessors	[3]			28
Net assets not assumed by Andeavor Logistics	[3]	(19)		(19)
Stockholders' Equity, Change in Reporting Entity	[3]			(1,651)
Distributions to common unitholders related to acquisitions (c)				0
Distributions to common unitholders related to acquisitions (c)				0
Cumulative effect of accounting standard adoption				0
Contributions (d)				0
Other				0
Balance at September 30, 2018		0		0
Common
Changes in carrying amount of Equity
Balance at December 31, 2017				2,925
Partners Capital Contribution Other				0
Net assets not assumed by Andeavor Logistics		0		0
Stockholders' Equity, Change in Reporting Entity				1,651
Distributions to common unitholders related to acquisitions (c)	[2]			(620)
Distributions to common unitholders related to acquisitions (c)	[4]			300
Net earnings attributable to partners				423
Cumulative effect of accounting standard adoption				(22)
Contributions (d)	[5]			34
Other				2
Balance at September 30, 2018		4,093		4,093
Preferred Partner
Changes in carrying amount of Equity
Balance at December 31, 2017				589
Partners Capital Contribution Other				0
Net assets not assumed by Andeavor Logistics		0		0
Stockholders' Equity, Change in Reporting Entity				0
Distributions to common unitholders related to acquisitions (c)	[2]			(29)
Distributions to common unitholders related to acquisitions (c)				0
Net earnings attributable to partners				34
Cumulative effect of accounting standard adoption				0
Contributions (d)				0
Other				0
Balance at September 30, 2018		$ 594		$ 594
[1]	Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.
[2]	Represents cash distributions declared and paid during the nine months ended September 30, 2018.
[3]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[4]	Distributions to common unitholders include $300 million in cash payments for the 2018 Drop Down. As an entity under common control with Andeavor, we record the assets that we acquire from Andeavor in our consolidated balance sheets at Andeavor’s historical book value instead of fair value, and any excess of cash paid over the historical book value of the assets acquired from Andeavor is recorded within equity. As a result of this accounting treatment, this transaction resulted in a net increase of $1.4 billion in our equity balance during the nine months ended September 30, 2018.
[5]	Includes Andeavor and TLGP contributions to the Partnership primarily related to reimbursements for capital spending pursuant predominantly to the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement.

Equity, Cash Distributions (Det

Equity, Cash Distributions (Details) - USD ($) $ / shares in Units, $ in Millions

2 Months Ended

3 Months Ended

9 Months Ended

12 Months Ended

Nov. 30, 2018

Sep. 30, 2018

Jun. 30, 2018

Mar. 31, 2018

Dec. 31, 2017

Sep. 30, 2017

Sep. 30, 2018

Sep. 30, 2017

Dec. 31, 2017

Distribution Made to Member or Limited Partner

Distributions to common unitholders related to acquisitions (c)

$ 649

Payments of Ordinary Dividends, Preferred Stock and Preference Stock

[1]

$ 21

$ 8

29

$ 0

Distribution to Partner, Waived Distribution

15

$ 12.5

38

Loss attributable to Predecessors

$ 4

$ 7

28

46

Distribution Made to Limited Partner, Distributions Declared, Per Unit

[2]

$ 1.030

[3]

$ 1.015

$ 1

Quarterly distributions to common unitholders

$ 209

[2],[3]

$ 205

[2]

$ 205

[2]

$ 620

[1]

$ 329

[1]

Distribution Made to Limited Partner, Distribution Date

[2]

Aug. 14, 2018

[3]

May 15, 2018

Feb. 14, 2018

Distribution Made to Limited Partner, Date of Record

[2]

Aug. 3, 2018

[3]

May 1, 2018

Jan. 31, 2018

Increase (Decrease) In Equity Balance Due To Acquisitions

$ (1,400)

Subsequent Event

Distribution Made to Member or Limited Partner

Distribution Made to Limited Partner, Declaration Date

Oct. 26, 2018

Distribution Made to Limited Partner, Distributions Declared, Per Unit

[2]

$ 1.030

Quarterly distributions to common unitholders

[2],[3]

$ 238

Distribution Made to Limited Partner, Distribution Date

[2],[3]

Nov. 14, 2018

Distribution Made to Limited Partner, Date of Record

[2],[3]

Nov. 5, 2018

[1]

Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.

[2]

This distribution is net of $15 million waived by TLGP for each of the three months ended September 30, 2018, June 30, 2018 and March 31, 2018, as well as $12.5 million for the three months ended December 31, 2017. TLGP’s distribution waivers for 2018 and 2019 remain in effect as instituted in 2017 under the terms of our partnership agreement.

[3]

This distribution was declared on October 26, 2018 and will be paid on the date of distribution.

Equity Equity, Earnings Per Uni

Equity Equity, Earnings Per Unit (Details) $ / shares in Units, shares in Millions, $ in Millions		3 Months Ended				9 Months Ended
		Sep. 30, 2018USD ($)$ / sharesshares	Dec. 31, 2017USD ($)	Sep. 30, 2017USD ($)$ / sharesshares		Sep. 30, 2018USD ($)$ / sharesshares		Sep. 30, 2017USD ($)$ / sharesshares
Net earnings		$ 166		$ 90	[1],[2]	$ 429	[3]	$ 253	[1],[2],[3]
Special allocations of net earnings (“Special Allocations”) (a)	[4]	0		0		0		(1)
Net earnings, including Special Allocations		166		90		429		254
Distributions on Preferred Units (b)	[5]	(11)		0		(31)		0
Net earnings attributable to common units		155		90		398		254
Distributions on common units greater than earnings		$ (83)		$ (111)		$ (254)		$ (234)
Common units - basic | shares		234.4		108		223		107
Common units - diluted | shares	[6]	234.6		108.1		223.2		107.1
Common - basic | $ / shares	[7]	$ 0.68		$ 0.90		$ 1.91		$ 2.05
Common - diluted | $ / shares	[7]	$ 0.68		$ 0.90		$ 1.91		$ 2.05
Incentive Distribution, Distribution Split Marginal Percentage								50.00%
Incentive Distribution, Minimum Distribution Level | $ / shares								0.3881
Distribution to Partner, Waived Distribution		$ 15	$ 12.5					$ 38
Incentive Distribution, Distribution						$ 45
Common
Special allocations of net earnings (“Special Allocations”) (a)	[4]	0		$ 0		0		(1)
Limited partners’ distributions on common units	[8]	(238)		(201)		(652)		(407)
Distributions on common units greater than earnings		(79)		(103)		(226)		(186)
Participating Securities, Distributed and Undistributed Earnings (Loss), Basic		159		98		426		220
General Partner
General partner’s distributions		0		0		0		(6)
General partner’s IDRs (c)	[9]	0		0		0		(75)
Distributions on common units greater than earnings	[10]	4		8		28		48
Participating Securities, Distributed and Undistributed Earnings (Loss), Basic		$ (4)		$ (8)		$ (28)		$ 33
[1]	Adjusted to include the historical results of the Predecessors. See Note 1 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 Note 1 for further discussion.
[4]	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 Revolving Credit Facility in lieu of using all cash on hand to fund the acquisition of crude oil, natural gas and produced water gathering systems and two natural gas processing facilities from Whiting Oil and Gas Corporation, GBK Investments, LLC and WBI Energy Midstream, LLC (the “North Dakota Gathering and Processing Assets”) during the nine months ended September 30, 2017.
[5]	The Preferred Units entitle unitholders to receive preferred distributions on a semi-annually basis.
[6]	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.
[7]	Amounts may not recalculate due to rounding of dollar and unit information.
[8]	Distributions of earnings for limited partners’ common units for the three and nine months ended September 30, 2018 is net of a $15 million and $45 million waiver, respectively, from Andeavor in connection with the WNRL Merger
[9]	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 $38 million of IDRs waived by TLGP for the nine months ended September 30, 2017, respectively. Our general partner no longer holds IDRs as a result of the IDR/GP Transaction.
[10]	We have revised the historical allocation of general partner earnings to include the Predecessors’ losses of $4 million and $28 million for the three and nine months ended September 30, 2018, respectively, and losses of $7 million and $46 million for the three and nine months ended September 30, 2017, respectively.

Revenues Revenue Recognition, N

Revenues Revenue Recognition, Narrative (Details) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2018USD ($)	Sep. 30, 2018USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 4,100	$ 4,100
Contract with Customer, Liability, Revenue Recognized	4	24
Revenue from Contract with Customer, Including Assessed Tax	528	1,500
Operating Leases, Income Statement, Lease Revenue	$ 114	$ 292
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	5 years	5 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Percent	80.00%	80.00%
Minimum
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year	1 year
Maximum
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	15 years	15 years

Revenues Contract Assets and Li

Revenues Contract Assets and Liabilities (Details) - USD ($) $ in Millions		3 Months Ended	9 Months Ended
		Sep. 30, 2018	Sep. 30, 2018	Jan. 01, 2018	Dec. 31, 2017
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Contract with Customer, Liability, Revenue Recognized		$ 4	$ 24
Accounts Receivable, Net		437	437	$ 409	$ 443	[1]
Contract with Customer, Asset, Net		31	31	34	0	[1]
Deferred Revenue, Current		22	22	23	23	[1]
Deferred Revenue, Noncurrent		64	64	62	43	[1]
Equity Method Investments		$ 607	$ 607		$ 440	[2]
Difference between Revenue Guidance in Effect before and after Topic 606 | Accounting Standards Update 2014-09
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Accounts Receivable, Net	[3]			(34)
Contract with Customer, Asset, Net	[3]			34
Deferred Revenue, Current	[3]			0
Deferred Revenue, Noncurrent	[3]			19
Equity Method Investments				$ 3
[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 Note 1 for further discussion.
[3]	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 condensed consolidated balance sheets as of January 1, 2018 for the impacts related to our equity method investment in Three Rivers Gathering, LLC. There were no material impacts to this balance during the nine months ended September 30, 2018 due to the adoption.

Revenues Revenue Disaggregation

Revenues Revenue Disaggregation (Details) - USD ($) $ in Millions		3 Months Ended	9 Months Ended
		Sep. 30, 2018	Sep. 30, 2018
Terminalling and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		$ 280	$ 762
Terminalling and Transportation | Refined Products
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	240	650
Terminalling and Transportation | Crude oil and water gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	39	108
Terminalling and Transportation | Natural Gas
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	0	0
Terminalling and Transportation | Other Services
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	1	4
Terminalling and Transportation | Service Revenues
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	280	762
Terminalling and Transportation | Natural Gas Liquids
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0
Terminalling and Transportation | Crude Oil Refined Products And Blending Products
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0
Terminalling and Transportation | Product Revenues
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0
Gathering and Processing
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		345	945
Gathering and Processing | Refined Products
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	0	0
Gathering and Processing | Crude oil and water gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	108	313
Gathering and Processing | Natural Gas
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	100	296
Gathering and Processing | Other Services
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	0	0
Gathering and Processing | Service Revenues
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	208	609
Gathering and Processing | Natural Gas Liquids
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		137	336
Gathering and Processing | Crude Oil Refined Products And Blending Products
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0
Gathering and Processing | Product Revenues
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		137	336
Wholesale
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		17	50
Wholesale | Refined Products
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	4	13
Wholesale | Crude oil and water gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	0	0
Wholesale | Natural Gas
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	0	0
Wholesale | Other Services
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	0	0
Wholesale | Service Revenues
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	4	13
Wholesale | Natural Gas Liquids
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0
Wholesale | Crude Oil Refined Products And Blending Products
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		13	37
Wholesale | Product Revenues
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		$ 13	$ 37
[1]	Includes $114 million and $292 million of lease revenues for the three and nine months ended September 30, 2018, respectively.

Operating Segments Operating Se

Operating Segments Operating Segments, Results (Details) $ in Millions		3 Months Ended			9 Months Ended
		Sep. 30, 2018USD ($)	Sep. 30, 2017USD ($)	[2]	Sep. 30, 2018USD ($)segments		Sep. 30, 2017USD ($)	[2]	Dec. 31, 2017USD ($)	[6]
Segment Reporting Information [Line Items]
Number of Reportable Segments | segments					3
Revenues		$ 642	$ 1,094	[1],[3]	$ 1,757		$ 2,135	[1],[3]
Operating Income		215	147	[1]	572		424	[1]
Segment Reporting Operating Income		227	160		599		457
Unallocated general and administrative expenses		(12)	(13)		(27)		(33)
Interest and financing costs, net		(57)	(68)	[1]	(172)		(193)	[1]
Equity in earnings of equity method investments		7	6	[1]	25		13	[1]
Other income, net		1	5	[1]	4		9	[1]
Net Earnings		166	90	[1]	429	[4]	253	[1],[4]
Depreciation and amortization expenses		86	85	[1]	268	[4]	222	[1],[4]
Additions to Other Assets, Amount		186	92		524		212
Assets		10,197			10,197				$ 9,505	[5]
Operating Segments | Terminalling and Transportation
Segment Reporting Information [Line Items]
Revenues		280	230		762		599
Operating Income		140	103		351		290
Depreciation and amortization expenses		35	32		105		85
Additions to Other Assets, Amount		76	51		155		127
Assets		3,408			3,408				3,045
Operating Segments | Gathering and Processing
Segment Reporting Information [Line Items]
Revenues		345	295		945		796
Operating Income		80	50		226		158
Depreciation and amortization expenses		47	51		154		134
Additions to Other Assets, Amount		110	41		368		85
Assets		6,378			6,378				6,006
Operating Segments | Wholesale Segment
Segment Reporting Information [Line Items]
Revenues		20	569		62		740
Operating Income		7	7		22		9
Depreciation and amortization expenses		4	2		9		3
Additions to Other Assets, Amount		0	0		1		0
Assets		354			354				342
Intersegment Eliminations
Segment Reporting Information [Line Items]
Revenues		(3)	0		(12)		0
Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
Assets		57			57				$ 112
Terminalling revenues | Operating Segments | Terminalling and Transportation
Segment Reporting Information [Line Items]
Revenues		235	189		643		493
Pipeline transportation revenues | Operating Segments | Terminalling and Transportation
Segment Reporting Information [Line Items]
Revenues		44	34		115		97
Other Terminalling and Transportation Revenue | Operating Segments | Terminalling and Transportation
Segment Reporting Information [Line Items]
Revenues		1	7		4		9
Sales of natural gas, NGLS and condensate | Operating Segments | Gathering and Processing
Segment Reporting Information [Line Items]
Revenues		137	90		336		254
Gas gathering and processing | Operating Segments | Gathering and Processing
Segment Reporting Information [Line Items]
Revenues		82	85		249		252
Crude oil and water gathering | Operating Segments | Gathering and Processing
Segment Reporting Information [Line Items]
Revenues		86	76		241		170
Pass-thru and other revenue | Operating Segments | Gathering and Processing
Segment Reporting Information [Line Items]
Revenues		40	44		119		120
Fuel Sales | Operating Segments | Wholesale Segment
Segment Reporting Information [Line Items]
Revenues	[7]	13	565		37		730
Other Non-fuel | Operating Segments | Wholesale Segment
Segment Reporting Information [Line Items]
Revenues		$ 7	$ 4		$ 25		$ 10
[1]	Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.
[2]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[3]	Due to the adoption of the revenue recognition standard effective January 1, 2018, the revenues and costs associated with our fuel purchase and supply arrangements with Andeavor for the three and nine months ended September 30, 2018 were netted. See Note 1 for further discussion.
[4]	Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.
[5]	Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.
[6]	Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
[7]	The presentation of wholesale fuel sales was impacted by adoption of ASC 606 on January 1, 2018. Beginning January 1, 2018 in connection with the adoption, the revenues and costs associated with our fuel purchase and supply arrangements with Andeavor were netted.