Andeavor Logistics (ANDX) 10-Q 8 May 18 2018 Q1 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2018	May 03, 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	Mar. 31, 2018
Amendment Flag	false
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	Q1
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Limited Partners' Capital Account, Units Issued		217,187,916

Condensed Statements of Consoli

Condensed Statements of Consolidated Operations (unaudited) Statement - USD ($) shares in Millions, $ in Millions		3 Months Ended
		Mar. 31, 2018	Mar. 31, 2017
Revenues:
Revenue, Net		$ 535	$ 420
Costs and Expenses:
NGL expense (excluding items shown separately below)		48	59
Operating expenses (excluding depreciation and amortization)		190	126
Depreciation and amortization expenses		80	58
General and administrative expenses		27	27
Operating Income		190	150
Interest and financing costs, net		(54)	(62)
Equity in earnings of equity method investments		2	2
Other income, net		1	2
Net Earnings Attributable to Partners		139	92
Preferred unitholders’ interest in net earnings		(14)	0
General partner’s interest in net earnings, including incentive distribution rights		0	(37)
Limited Partners’ Interest in Net Earnings		$ 125	$ 55
Net earnings per limited partner unit
Common - basic		$ 0.59	$ 0.51
Common - diluted		$ 0.59	$ 0.51
Weighted average limited partner units outstanding
Common units - basic		217.2	104.8
Common units - diluted	[1]	217.4	104.9
Cash distributions paid per unit		$ 1	$ 0.910
Affiliated Entity
Revenues:
Revenue, Net		$ 318	$ 203
Third Party
Revenues:
Revenue, Net		$ 217	$ 217
[1]	(e)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	Mar. 31, 2018	Dec. 31, 2017
Current Assets
Cash and cash equivalents	$ 27	$ 75
Receivables, net of allowance for doubtful accounts
Trade and other	198	219
Affiliate	166	184
Prepayments and other current assets	40	27
Total Current Assets	431	505
Property, Plant and Equipment, Net
Property, plant and equipment, at cost	6,381	6,295
Accumulated depreciation	(945)	(882)
Property, Plant and Equipment, Net	5,436	5,413
Acquired Intangibles, Net	1,140	1,153
Goodwill	684	692
Equity Method Investments	312	320
Other Noncurrent Assets, Net	106	86
Total Assets	8,109	8,169
Accounts payable
Trade and other	133	160
Affiliate	198	199
Accrued interest and financing costs	68	40
Other current liabilities	63	75
Total Current Liabilities	462	474
Debt, Net of Unamortized Issuance Costs	4,148	4,127
Other Noncurrent Liabilities	66	54
Total Liabilities	4,676	4,655
Equity
Preferred unitholders; 600,000 units issued and outstanding in 2018 and 2017	594	589
Common unitholders; 217,170,024 units issued and outstanding (217,097,057 in 2017)	2,839	2,925
Total Equity	3,433	3,514
Total Liabilities and Equity	$ 8,109	$ 8,169

Condensed Consolidated Balance4

Condensed Consolidated Balance Sheets (Unaudited), (Parenthetical) - shares	Mar. 31, 2018	Dec. 31, 2017
Equity
Common units issued (units)	217,170,024	217,097,057
Preferred Units, Outstanding	600,000	600,000

Condensed Statements of Consol5

Condensed Statements of Consolidated Cash Flows (unaudited) Condensed Statements of Consolidated Cash Flows (unaudited) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018		Mar. 31, 2017
Cash Flows From (Used In) Operating Activities
Net earnings	$ 139		$ 92
Adjustments to reconcile net earnings to net cash from operating activities:
Depreciation and amortization expenses	80		58
Other operating activities	10		8
Changes in current assets and liabilities	21		54
Changes in noncurrent assets and liabilities	20		5
Net cash from operating activities	230		207
Cash Flows Used In Investing Activities
Capital expenditures	(81)		(49)
Acquisitions	0		(672)
Deposits for acquisitions	(10)		0
Net cash used in investing activities	(91)		(721)
Cash Flows From (Used In) Financing Activities
Borrowings under revolving credit agreements	150		44
Repayments under revolving credit agreements	(130)		(334)
Proceeds from issuance of common units, net of issuance costs	0		281
Proceeds from issuance of general partner units, net of issuance costs	0		6
Quarterly distributions to common unitholders	205	[1]	94
Quarterly distributions to preferred unitholders	(8)		0
Quarterly distributions to general partner	0		(46)
Distributions in connection with acquisitions	0		5
Capital contributions by affiliate	9		9
Other financing activities	(3)		0
Net cash used in financing activities	(187)		(139)
Decrease in Cash and Cash Equivalents	(48)		(653)
Cash and Cash Equivalents, Beginning of Period	75		688
Cash and Cash Equivalents, End of Period	$ 27		$ 35
[1]	(a)This distribution is net of $15 million and $12.5 million waived by TLGP for the three months ended

Organization and Basis of Prese

Organization and Basis of Presentation (Notes)	3 Months Ended
	Mar. 31, 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 and any of its subsidiaries, other than Andeavor Logistics, its subsidiaries and its general partner. Principles of Consolidation and Basis of Presentation Principles of Consolidation Acquired assets 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 for additional information regarding the acquired assets from Andeavor. The acquisition of logistics assets located in Anacortes, Washington in 2017 was immaterial to our condensed consolidated financial statements. While this acquisition is a common control transaction, prior periods have not been recast as these assets do not constitute a business in accordance with ASU 2017-01, “Clarifying the Definition of a Business” (“ASU 2017-01”). 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 gross presentation of replacement dry gas under our keep-whole arrangements. 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 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. 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 approximately $4.2 billion as of March 31, 2018 , and were approximately $4.2 billion and $4.3 billion at December 31, 2017 , respectively. These carrying and fair values of our debt do not consider the unamortized issuance costs, which are netted against our total debt. New Accounting Standards and Disclosures Revenue Recognition In May 2014, the FASB issued Accounting Standards Update (“ASU”) 2014-09, “Revenue from Contracts with Customers” to replace existing revenue recognition rules with a single comprehensive model to use in accounting for revenue arising from contracts with customers. Under this ASU and the associated subsequent amendments (collectively, “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 contain claw-back provisions. 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 7. 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 period ending March 31, 2018, we recorded lower revenue of $566 million and correspondingly $566 million in lower costs and expenses, 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 7 . We recorded an additional $2 million in revenues during the three months ended March 31, 2018 as a result of applying the new standard, associated with minimum volume commitments. 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 new 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. Early adoption is permitted and in the original guidance the modified retrospective application was required, however, in March 2018, the FASB approved another transition method in which the effective date would be the date of initial application of transition. Under this optional transition method, we would recognize a cumulative effect adjustment to the opening balance of partners’ equity in the period of adoption. We expect to elect the optional transition method and will not early adopt the standard. We are progressing through our implementation plan and continue to evaluate the impact of the standard on our business processes, accounting systems, controls and financial statement disclosures. In addition, we continue to assess the impact in certain areas where industry consensus continues to be formed. 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 condensed consolidated balance sheets, to 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 condensed statements of consolidated operations or liquidity. At this time, we are unable to estimate the full impact of the standard until we progress further through our plan and the industry reaches a consensus on certain industry specific issues. 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 the adoption of this standard to have a material impact on our condensed consolidated financial statements. 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 for the three months ended March 31, 2017 of $2 million with a corresponding increase to other income of $2 million with no impact to net earnings. ASU 2017-07 does not impact the condensed consolidated balance sheets or condensed statements of consolidated cash flows.

Acquisitions Acquisitions (Note

Acquisitions Acquisitions (Notes)	3 Months Ended
	Mar. 31, 2018
Business Combinations [Abstract]
Mergers, Acquisitions and Dispositions Disclosures	Acquisitions Wamsutter Pipeline System On May 1, 2018 , we completed our acquisition of 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. 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 with 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. However, we accounted for the WNRL Merger as a reorganization of entities under common control, which requires us to recognize the assets and liabilities acquired using Andeavor’s basis. The purchase price allocation for the WNRL Merger is preliminary and has been allocated based on estimated fair values of the assets acquired and liabilities assumed at the acquisition date, pending the completion of an independent valuation and other information as it becomes available to us. We expect that, as we obtain more information, the preliminary purchase price allocation disclosed below may change. Although the purchase price allocation is substantially complete, adjustments can be made through the end of Andeavor’s measurement period, which is not to exceed one year from the acquisition date. During the three months ended March 31, 2018, we recorded adjustments to our preliminary allocation to increase property, plant and equipment and reduce goodwill by $7 million . Preliminary Acquisition Date Purchase Price Allocation (in millions) Cash $ 22 Receivables 112 Inventories 11 Prepayments and Other Current Assets 25 Property, Plant and Equipment (a) 1,357 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 preliminary 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 have preliminarily allocated $267 million , $202 million and $89 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 preliminary 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 We estimated the fair value of the acquired identifiable intangible assets at $130 million . This fair value is based on a preliminary valuation completed for the business enterprise, along with the related tangible assets, using a combination of the income method, cost method and comparable market transactions. We recognized intangible assets associated with customer relationships of $130 million with third parties, all of which will be amortized on a straight-line basis over an estimated weighted average useful life of 15 years. The accumulated amortization of our finite life intangibles acquired from the WNRL Merger was $7 million as of March 31, 2018 . Amortization expense related to the acquired intangible assets is expected to be approximately $9 million per year for the next five years. Although we have substantially completed our valuation estimate and related evaluation of the useful lives; accordingly, future amortization of intangible assets related to customer relationships, these may be revised during the measurement period. WNRL Revenues and Net Earnings During the three months ended March 31, 2018 , we recognized $92 million in revenues and $45 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 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 Revenues $ 1,024 Net earnings (a) 130 (a) While many recurring adjustments impact the pro forma figures presented, the pro forma condensed statements of consolidated operations for the three months ended March 31, 2017, the period the acquisition was assumed to be completed for pro forma purposes, includes a significant non-recurring adjustment to recognize the WNRL Merger acquisition and integration costs. We recognized acquisition costs related to the WNRL Merger of $17 million as well as $3 million of severance costs.

Related-Party Transactions Rela

Related-Party Transactions Related-Party Transactions (Notes)	3 Months Ended
	Mar. 31, 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 (“Keep-Whole Commodity Agreement”). Under the Keep-Whole Commodity Agreement with Andeavor, 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 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 that 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 and the Amended Secondment Agreement were amended and restated in connection with the WNRL Merger. Under the terms of the Amended Omnibus Agreement in effect as of March 31, 2018 , we are required to pay Andeavor an annual corporate services fee of $13 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 $6 million and $5 million pursuant to the Amended Secondment Agreement for the three months ended March 31, 2018 and 2017 , respectively. 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. Summary of Affiliate Transactions Summary of Revenue and Expense Transactions with Andeavor (in millions) Three Months Ended 2018 2017 Revenues (a) $ 318 $ 203 Operating expenses (b) 51 39 General and administrative expenses 20 20 (a) Andeavor accounted for 59% and 48% of our total revenues for the three months ended March 31, 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 $7 million and $2 million for the three months ended March 31, 2018 and 2017 , respectively. 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 three months ended March 31, 2018 , we paid quarterly cash distributions of $115 million to Andeavor, net of $12.5 million waived by Andeavor and its affiliates. On April 18, 2018 , we declared a quarterly cash distribution of $1.015 per unit, which will be paid on May 15, 2018 . The distribution will include a payment of $115 million to Andeavor, net of $15 million waived by Andeavor and its affiliates. TLGP’s distribution waivers for 2018 and 2019 remain in effect as instituted in 2017 under the terms of our partnership agreement.

Debt (Notes)

Debt (Notes)	3 Months Ended
	Mar. 31, 2018
Debt Disclosure [Abstract]
Debt	Debt Debt Balance, Net of Unamortized Issuance Costs (in millions) March 31, December 31, 2017 Total debt $ 4,201 $ 4,182 Unamortized issuance costs (52 ) (54 ) Current maturities (1 ) (1 ) Debt, Net of Current Maturities and Unamortized Issuance Costs $ 4,148 $ 4,127 Available Capacity Under Credit Facilities (in millions) Total Capacity Amount Borrowed as of March 31, 2018 Outstanding Letters of Credit Available Capacity as of March 31, 2018 Weighted Average Interest Rate Expiration Revolving Credit Facility (a) $ 1,100 $ 443 $ — $ 657 3.59 % January 29, 2021 Dropdown Credit Facility 1,000 — — 1,000 — % January 29, 2021 Total Credit Facilities (a) $ 2,100 $ 443 $ — $ 1,657 (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)	3 Months Ended
	Mar. 31, 2018
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies In the ordinary course of business, we may become party to lawsuits, administrative proceedings and governmental investigations, including environmental, regulatory and other matters. The outcome of these matters cannot always be predicted accurately, but we will accrue liabilities for these matters if the amount is probable and can be reasonably estimated. 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 consolidated financial statements.

Equity (Notes)

Equity (Notes)	3 Months Ended
	Mar. 31, 2018
Equity [Abstract]
Equity	Equity and Net Earnings per Unit We had 89,280,638 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 March 31, 2018 . Additionally, Andeavor owned 127,889,386 of our common units, constituting approximately 59% ownership interest in us. Andeavor also held 80,000 Andeavor Logistics TexNew Mex units and 2,202,880 non-economic general partner units as of March 31, 2018 . Andeavor and Marathon Petroleum Corporation (“MPC”) entered into an Agreement and Plan of Merger, dated as of April 29, 2018 (the “MPC Merger Agreement”), under which MPC will acquire all outstanding shares of Andeavor. The MPC Merger Agreement contains customary representations, warranties and covenants. As a subsidiary of Andeavor, the MPC Merger Agreement limits our ability to issue additional common or preferred units, with certain exceptions as outlined in the MPC Merger Agreement, and from incurring any additional indebtedness outside the ordinary course of business. However, the MPC Merger Agreement allows us to continue paying the regular quarterly distributions on our common units including regular increases consistent with our past practices. Additionally, the MPC Merger Agreement allows us to continue paying the scheduled distribution on our Preferred Units. The transaction was unanimously approved by the boards of directors of both companies and is subject to regulatory and other customary closing conditions, including approvals from the shareholders of each company. Changes to Equity (in millions) Partnership Total Common Preferred Balance at December 31, 2017 $ 2,925 $ 589 $ 3,514 Distributions to common and preferred unitholders (a) (205 ) (8 ) (213 ) Net earnings attributable to partners 125 14 139 Cumulative effect of accounting standard adoption (22 ) — (22 ) Contributions (b) 16 — 16 Other — (1 ) (1 ) Balance at March 31, 2018 $ 2,839 $ 594 $ 3,433 (a) Represents cash distributions declared and paid during the three months ended March 31, 2018 . (b) 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)(b)(c) 1.015 205 May 15, 2018 May 1, 2018 (a) This distribution is net of $15 million and $12.5 million waived by TLGP for the three months ended March 31, 2018 and December 31, 2017, respectively. 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 April 18, 2018 and will be paid on the date of distribution. (c) On February 15, 2018, we paid distributions associated with our Preferred Units of $8 million . 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 2018 2017 Net earnings $ 139 $ 92 Special allocations of net earnings (“Special Allocations”) (a) — 1 Net earnings, including Special Allocations 139 93 Distributions on Preferred Units (b) (10 ) — Net earnings attributable to common units 129 93 General partner’s distributions — (3 ) General partner’s IDRs (c) — (36 ) Limited partners’ distributions on common units (205 ) (101 ) Distributions on common units greater than earnings $ (76 ) $ (47 ) General partner’s earnings: Distributions $ — $ 3 General partner’s IDRs (c) — 36 Allocation of distributions greater than earnings — (1 ) Total general partner’s earnings $ — $ 38 Limited partners’ earnings on common units: Distributions (d) $ 205 $ 101 Special Allocations (a) — (1 ) Allocation of distributions greater than earnings (76 ) (46 ) Total limited partners’ earnings on common units $ 129 $ 54 Weighted average limited partner units outstanding: Common units - basic 217.2 104.8 Common units - diluted (e) 217.4 104.9 Net earnings per limited partner unit: Common - basic $ 0.59 $ 0.51 Common - diluted $ 0.59 $ 0.51 (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 three months ended March 31, 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 $12.5 million of IDRs waived by TLGP for the three months ended March 31, 2017 . Our general partner no longer receives IDRs as a result of the IDR/GP Transaction. (d) Distributions of earnings for limited partners’ common units for the three months ended March 31, 2018 is net of a $15.0 million waiver from Andeavor in connection with the WNRL Merger. (e) 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.
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 2018 2017 Net earnings $ 139 $ 92 Special allocations of net earnings (“Special Allocations”) (a) — 1 Net earnings, including Special Allocations 139 93 Distributions on Preferred Units (b) (10 ) — Net earnings attributable to common units 129 93 General partner’s distributions — (3 ) General partner’s IDRs (c) — (36 ) Limited partners’ distributions on common units (205 ) (101 ) Distributions on common units greater than earnings $ (76 ) $ (47 ) General partner’s earnings: Distributions $ — $ 3 General partner’s IDRs (c) — 36 Allocation of distributions greater than earnings — (1 ) Total general partner’s earnings $ — $ 38 Limited partners’ earnings on common units: Distributions (d) $ 205 $ 101 Special Allocations (a) — (1 ) Allocation of distributions greater than earnings (76 ) (46 ) Total limited partners’ earnings on common units $ 129 $ 54 Weighted average limited partner units outstanding: Common units - basic 217.2 104.8 Common units - diluted (e) 217.4 104.9 Net earnings per limited partner unit: Common - basic $ 0.59 $ 0.51 Common - diluted $ 0.59 $ 0.51 (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 three months ended March 31, 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 $12.5 million of IDRs waived by TLGP for the three months ended March 31, 2017 . Our general partner no longer receives IDRs as a result of the IDR/GP Transaction. (d) Distributions of earnings for limited partners’ common units for the three months ended March 31, 2018 is net of a $15.0 million waiver from Andeavor in connection with the WNRL Merger. (e) 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.

Revenues (Notes)

Revenues (Notes)	3 Months Ended
	Mar. 31, 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 months ended March 31, 2018 , revenues from contracts with customers were $454 million , which excludes lease revenues of $81 million . Upon adoption of ASC 606, revenue is recognized net of amounts collected from customers for taxes assessed by governmental authorities on, and concurrent with, specific revenue-producing transactions. Service Revenue We generate service revenue for gathering and transporting crude oil, natural gas and water; processing and fractionating natural gas and NGLs; and terminalling, transporting, and storing crude oil and refined products. We perform these services under various contractual arrangements with our customers. Under fee-based arrangements, we receive a fixed rate per volumetric unit for services we provide. For many of these fee-based arrangements, customers are required to make deficiency payments when they do not meet their minimum throughput volume commitments. Some of these contracts allow our customers to claw-back all or a portion of prior deficiency payments against excess volumes in future periods. Under keep-whole arrangements, we gather and process natural gas from producer-customers, retain and sell extracted NGLs, and return to the producer 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 costs. 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, and NGL expense for shrink gas we provide back to our customers. We obtain control of the NGLs we receive from our customers and we bear the inventory risk, 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 monthly average published price of underlying commodity adjusted for location differences 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. Losses in excess of the stated percentage are recorded in operating expenses. When losses are lower than the stated percentage, proceeds from the sale of the retained NGLs are recorded in service revenue. 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. 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 primarily with 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 months ended March 31, 2018 , we recognized $14 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 Adjustments for ASC 606 (a) Balance at January 1, 2018 March 31, 2018 Receivables from contracts with customers $ 363 $ (34 ) $ 329 $ 325 Other contract assets — 34 34 13 Deferred income, current 23 — 23 21 Deferred income, noncurrent 43 19 62 56 (a) 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 three months ended March 31, 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 consist primarily of arrangements for which the customer has agreed to fixed consideration based on minimum throughput volume commitments or capacity utilization. As of March 31, 2018 , we had $4.2 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 primarily range from 1 year to 15 years . We expect approximately 80% of our total remaining obligations to be recognized within 5 years . Disaggregation Revenue Disaggregation by Type and Product Line (in millions) March 31, 2018 Terminalling and Transportation Gathering and Processing Wholesale Service Revenues (a) Refined products $ 203 $ — $ 6 Crude oil and water 26 87 — Natural gas — 98 — Other 2 — — Total Service Revenues 231 185 6 Product Revenues NGL products — 104 — Refined products — — 9 Total Product Revenues — 104 9 Total Revenues $ 231 $ 289 $ 15 (a) Includes $81 million of lease revenues for the three months ended March 31, 2018 .

Operating Segments (Notes)

Operating Segments (Notes)	3 Months Ended
	Mar. 31, 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 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 2018 2017 Revenues Terminalling and Transportation: Terminalling $ 198 $ 145 Pipeline transportation 31 30 Other revenues 2 — Total Terminalling and Transportation 231 175 Gathering and Processing: NGL sales 104 83 Gas gathering and processing 85 80 Crude oil and water gathering 65 39 Pass-thru and other 35 43 Total Gathering and Processing 289 245 Wholesale: Fuel sales 9 — Other wholesale 8 — Total Wholesale 17 — Intersegment wholesale revenues (2 ) — Total Revenues $ 535 $ 420 Segment Operating Income Terminalling and Transportation $ 120 $ 98 Gathering and Processing 74 62 Wholesale 4 — Total Segment Operating Income 198 160 Unallocated general and administrative expenses (8 ) (10 ) Operating Income 190 150 Interest and financing costs, net (54 ) (62 ) Equity in earnings of equity method investments 2 2 Other income, net 1 2 Net Earnings $ 139 $ 92 Depreciation and Amortization Expenses Terminalling and Transportation $ 29 $ 21 Gathering and Processing 48 37 Wholesale 3 — Total Depreciation and Amortization Expenses $ 80 $ 58 Capital Expenditures Terminalling and Transportation $ 27 $ 27 Gathering and Processing 55 18 Wholesale 1 — Total Capital Expenditures $ 83 $ 45

Organization and Basis of Pre14

Organization and Basis of Presentation (Policies)	3 Months Ended
	Mar. 31, 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 .
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 gross presentation of replacement dry gas under our keep-whole arrangements. 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 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. 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 approximately $4.2 billion as of March 31, 2018 , and were approximately $4.2 billion and $4.3 billion at December 31, 2017 , respectively. These carrying and fair values of our debt do not consider the unamortized issuance costs, which are netted against our total debt.
New Accounting Pronouncement, Policy	New Accounting Standards and Disclosures Revenue Recognition In May 2014, the FASB issued Accounting Standards Update (“ASU”) 2014-09, “Revenue from Contracts with Customers” to replace existing revenue recognition rules with a single comprehensive model to use in accounting for revenue arising from contracts with customers. Under this ASU and the associated subsequent amendments (collectively, “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 contain claw-back provisions. 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 7. 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 period ending March 31, 2018, we recorded lower revenue of $566 million and correspondingly $566 million in lower costs and expenses, 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 7 . We recorded an additional $2 million in revenues during the three months ended March 31, 2018 as a result of applying the new standard, associated with minimum volume commitments. 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 new 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. Early adoption is permitted and in the original guidance the modified retrospective application was required, however, in March 2018, the FASB approved another transition method in which the effective date would be the date of initial application of transition. Under this optional transition method, we would recognize a cumulative effect adjustment to the opening balance of partners’ equity in the period of adoption. We expect to elect the optional transition method and will not early adopt the standard. We are progressing through our implementation plan and continue to evaluate the impact of the standard on our business processes, accounting systems, controls and financial statement disclosures. In addition, we continue to assess the impact in certain areas where industry consensus continues to be formed. 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 condensed consolidated balance sheets, to 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 condensed statements of consolidated operations or liquidity. At this time, we are unable to estimate the full impact of the standard until we progress further through our plan and the industry reaches a consensus on certain industry specific issues. 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 the adoption of this standard to have a material impact on our condensed consolidated financial statements. 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 for the three months ended March 31, 2017 of $2 million with a corresponding increase to other income of $2 million with no impact to net earnings. ASU 2017-07 does not impact the condensed consolidated balance sheets or condensed statements of consolidated cash flows.

Commitments and Contingencies C

Commitments and Contingencies Contingencies Accrued Liability (Policies)	3 Months Ended
	Mar. 31, 2018
Commitments and Contingencies Disclosure [Abstract]
Contingency Accrued Liabilities, Policy	In the ordinary course of business, we may become party to lawsuits, administrative proceedings and governmental investigations, including environmental, regulatory and other matters. The outcome of these matters cannot always be predicted accurately, but we will accrue liabilities for these matters if the amount is probable and can be reasonably estimated.

Equity Earnings Per Unit (Polic

Equity Earnings Per Unit (Policies)	3 Months Ended
	Mar. 31, 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)	3 Months Ended
	Mar. 31, 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 months ended March 31, 2018 , revenues from contracts with customers were $454 million , which excludes lease revenues of $81 million . Upon adoption of ASC 606, revenue is recognized net of amounts collected from customers for taxes assessed by governmental authorities on, and concurrent with, specific revenue-producing transactions.
Revenue Recognition, Sales of Services, 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 costs. 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, and NGL expense for shrink gas we provide back to our customers. We obtain control of the NGLs we receive from our customers and we bear the inventory risk, 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 monthly average published price of underlying commodity adjusted for location differences 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. Losses in excess of the stated percentage are recorded in operating expenses. When losses are lower than the stated percentage, proceeds from the sale of the retained NGLs are recorded in service revenue. 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. 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)	3 Months Ended
	Mar. 31, 2018
Business Combinations [Abstract]
Schedule of Business Acquisitions, by Acquisition	Preliminary Acquisition Date Purchase Price Allocation (in millions) Cash $ 22 Receivables 112 Inventories 11 Prepayments and Other Current Assets 25 Property, Plant and Equipment (a) 1,357 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 preliminary valuation.
Business Acquisition, Pro Forma Information	Pro Forma Consolidated Revenues and Consolidated Net Earnings (in millions) Three Months Ended Revenues $ 1,024 Net earnings (a) 130 (a) While many recurring adjustments impact the pro forma figures presented, the pro forma condensed statements of consolidated operations for the three months ended March 31, 2017, the period the acquisition was assumed to be completed for pro forma purposes, includes a significant non-recurring adjustment to recognize the WNRL Merger acquisition and integration costs. We recognized acquisition costs related to the WNRL Merger of $17 million as well as $3 million of severance costs.

Related-Party Transactions Re19

Related-Party Transactions Related-Party Transactions (Tables)	3 Months Ended
	Mar. 31, 2018
Related Party Transactions [Abstract]
Schedule of Related Party Transactions	Summary of Revenue and Expense Transactions with Andeavor (in millions) Three Months Ended 2018 2017 Revenues (a) $ 318 $ 203 Operating expenses (b) 51 39 General and administrative expenses 20 20 (a) Andeavor accounted for 59% and 48% of our total revenues for the three months ended March 31, 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 $7 million and $2 million for the three months ended March 31, 2018 and 2017 , respectively.

Debt (Tables)

Debt (Tables)	3 Months Ended
	Mar. 31, 2018
Debt Disclosure [Abstract]
Schedule of Debt	Debt Balance, Net of Unamortized Issuance Costs (in millions) March 31, December 31, 2017 Total debt $ 4,201 $ 4,182 Unamortized issuance costs (52 ) (54 ) Current maturities (1 ) (1 ) Debt, Net of Current Maturities and Unamortized Issuance Costs $ 4,148 $ 4,127
Schedule of Line of Credit Facilities	Available Capacity Under Credit Facilities (in millions) Total Capacity Amount Borrowed as of March 31, 2018 Outstanding Letters of Credit Available Capacity as of March 31, 2018 Weighted Average Interest Rate Expiration Revolving Credit Facility (a) $ 1,100 $ 443 $ — $ 657 3.59 % January 29, 2021 Dropdown Credit Facility 1,000 — — 1,000 — % January 29, 2021 Total Credit Facilities (a) $ 2,100 $ 443 $ — $ 1,657 (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)	3 Months Ended
	Mar. 31, 2018
Equity [Abstract]
Schedule of partners' capital	Changes to Equity (in millions) Partnership Total Common Preferred Balance at December 31, 2017 $ 2,925 $ 589 $ 3,514 Distributions to common and preferred unitholders (a) (205 ) (8 ) (213 ) Net earnings attributable to partners 125 14 139 Cumulative effect of accounting standard adoption (22 ) — (22 ) Contributions (b) 16 — 16 Other — (1 ) (1 ) Balance at March 31, 2018 $ 2,839 $ 594 $ 3,433 (a) Represents cash distributions declared and paid during the three months ended March 31, 2018 . (b) 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)(b)(c) 1.015 205 May 15, 2018 May 1, 2018 (a) This distribution is net of $15 million and $12.5 million waived by TLGP for the three months ended March 31, 2018 and December 31, 2017, respectively. 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 April 18, 2018 and will be paid on the date of distribution. (c) On February 15, 2018, we paid distributions associated with our Preferred Units of $8 million .

Equity Net Earnings per Unit (T

Equity Net Earnings per Unit (Tables)	3 Months Ended
	Mar. 31, 2018
Earnings Per Share [Abstract]
Earnings Per Share	Net Earnings per Unit (in millions, except per unit amounts) Three Months Ended 2018 2017 Net earnings $ 139 $ 92 Special allocations of net earnings (“Special Allocations”) (a) — 1 Net earnings, including Special Allocations 139 93 Distributions on Preferred Units (b) (10 ) — Net earnings attributable to common units 129 93 General partner’s distributions — (3 ) General partner’s IDRs (c) — (36 ) Limited partners’ distributions on common units (205 ) (101 ) Distributions on common units greater than earnings $ (76 ) $ (47 ) General partner’s earnings: Distributions $ — $ 3 General partner’s IDRs (c) — 36 Allocation of distributions greater than earnings — (1 ) Total general partner’s earnings $ — $ 38 Limited partners’ earnings on common units: Distributions (d) $ 205 $ 101 Special Allocations (a) — (1 ) Allocation of distributions greater than earnings (76 ) (46 ) Total limited partners’ earnings on common units $ 129 $ 54 Weighted average limited partner units outstanding: Common units - basic 217.2 104.8 Common units - diluted (e) 217.4 104.9 Net earnings per limited partner unit: Common - basic $ 0.59 $ 0.51 Common - diluted $ 0.59 $ 0.51 (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 three months ended March 31, 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 $12.5 million of IDRs waived by TLGP for the three months ended March 31, 2017 . Our general partner no longer receives IDRs as a result of the IDR/GP Transaction. (d) Distributions of earnings for limited partners’ common units for the three months ended March 31, 2018 is net of a $15.0 million waiver from Andeavor in connection with the WNRL Merger. (e) 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.

Revenues (Tables)

Revenues (Tables)	3 Months Ended
	Mar. 31, 2018
Revenue Recognition [Abstract]
Contract with Customer, Asset and Liability	Summary of Customer Contract Assets and Liabilities (in millions) December 31, 2017 Adjustments for ASC 606 (a) Balance at January 1, 2018 March 31, 2018 Receivables from contracts with customers $ 363 $ (34 ) $ 329 $ 325 Other contract assets — 34 34 13 Deferred income, current 23 — 23 21 Deferred income, noncurrent 43 19 62 56 (a) 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 three months ended March 31, 2018 due to the adoption.
Disaggregation of Revenue	Disaggregation Revenue Disaggregation by Type and Product Line (in millions) March 31, 2018 Terminalling and Transportation Gathering and Processing Wholesale Service Revenues (a) Refined products $ 203 $ — $ 6 Crude oil and water 26 87 — Natural gas — 98 — Other 2 — — Total Service Revenues 231 185 6 Product Revenues NGL products — 104 — Refined products — — 9 Total Product Revenues — 104 9 Total Revenues $ 231 $ 289 $ 15 (a) Includes $81 million of lease revenues for the three months ended March 31, 2018 .

Operating Segments (Tables)

Operating Segments (Tables)	3 Months Ended
	Mar. 31, 2018
Segment Reporting, Disclosure of Entity's Reportable Segments [Abstract]
Schedule of segment reporting information, by segment	Segment Information (in millions) Three Months Ended 2018 2017 Revenues Terminalling and Transportation: Terminalling $ 198 $ 145 Pipeline transportation 31 30 Other revenues 2 — Total Terminalling and Transportation 231 175 Gathering and Processing: NGL sales 104 83 Gas gathering and processing 85 80 Crude oil and water gathering 65 39 Pass-thru and other 35 43 Total Gathering and Processing 289 245 Wholesale: Fuel sales 9 — Other wholesale 8 — Total Wholesale 17 — Intersegment wholesale revenues (2 ) — Total Revenues $ 535 $ 420 Segment Operating Income Terminalling and Transportation $ 120 $ 98 Gathering and Processing 74 62 Wholesale 4 — Total Segment Operating Income 198 160 Unallocated general and administrative expenses (8 ) (10 ) Operating Income 190 150 Interest and financing costs, net (54 ) (62 ) Equity in earnings of equity method investments 2 2 Other income, net 1 2 Net Earnings $ 139 $ 92 Depreciation and Amortization Expenses Terminalling and Transportation $ 29 $ 21 Gathering and Processing 48 37 Wholesale 3 — Total Depreciation and Amortization Expenses $ 80 $ 58 Capital Expenditures Terminalling and Transportation $ 27 $ 27 Gathering and Processing 55 18 Wholesale 1 — Total Capital Expenditures $ 83 $ 45

Organization and Basis of Pre25

Organization and Basis of Presentation, Fair Value (Details) - USD ($) $ in Billions	Mar. 31, 2018	Dec. 31, 2017
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Debt, carrying value	$ 4.2	$ 4.2
Debt, fair value		$ 4.3

Organization and Basis of Pre26

Organization and Basis of Presentation New Accounting Standards and Disclosures (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Revenue, Net	$ (535)	$ (420)
Interest and Debt Expense	54	62
Other income, net	1	2
Net Income (Loss) Allocated to Limited Partners	125	55
Accounting Standards Update 2017-07
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Interest and Debt Expense		(2)
Other income, net		2
Net Income (Loss) Allocated to Limited Partners		$ 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
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]
Revenue, Net	566
Cost of Purchased Oil and Gas	566
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]
Revenue, Net	$ 2

Acquisitions Acquisitions (Deta

Acquisitions Acquisitions (Details) - USD ($) $ in Millions		3 Months Ended
		Jun. 30, 2018	Mar. 31, 2018	Mar. 31, 2017	Dec. 31, 2017
Acquisition and Divestitures
Business Combination, Provisional Information, Initial Accounting Incomplete, Adjustment, Property, Plant, and Equipment			$ 7
Distributions in connection with acquisitions			0	$ 5
Goodwill			684		$ 692
Business Acquisition, Net Earnings			139	92
WNRL Merger
Acquisition and Divestitures
Finite-Lived Intangible Assets, Amortization Expense, Year Two			9
Inventory			11
Property, plant and equipment	[1]		1,357
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill			130
Goodwill			$ 558
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life			15 years
Business Acquisition, Revenue			$ 92
Business Acquisition, Net Earnings			45
Finite-Lived Intangible Assets, Accumulated Amortization			7
Finite-Lived Intangible Assets, Amortization Expense, Next Twelve Months			9
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
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Less Noncontrolling Interest			1,662		$ 1,700
Business Acquisition, Transaction Costs				17
Business Combination, Integration Related Costs				3
Goodwill, Purchase Accounting Adjustments			7
Business Acquisition, Pro Forma Revenue				1,024
Business Acquisition, Pro Forma Net Income (Loss)				$ 130
Gathering and Processing | WNRL Merger
Acquisition and Divestitures
Goodwill			267
Terminalling and Transportation | WNRL Merger
Acquisition and Divestitures
Goodwill			202
Wholesale Segment | WNRL Merger
Acquisition and Divestitures
Goodwill			$ 89
Subsequent Event | Wamsutter Pipeline System
Acquisition and Divestitures
Distributions in connection with acquisitions		$ 180
[1]	Estimated useful lives ranging from 3 to 22 years have been assumed based on the preliminary valuation.

Acquisitions PPA table (Details

Acquisitions PPA table (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2018	Dec. 31, 2017
Business Acquisition [Line Items]
Goodwill		$ 684	$ 692
WNRL Merger
Business Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Cash and Equivalents		22
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Receivables		112
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Inventory		11
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Prepaid Expense and Other Assets		25
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment	[1]	1,357
Goodwill		558
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets		2
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Accounts Payable		(167)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Other		(41)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-term Debt		(347)
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Less Noncontrolling Interest		$ 1,662	$ 1,700
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]	Estimated useful lives ranging from 3 to 22 years have been assumed based on the preliminary valuation.

Related-Party Transactions Re29

Related-Party Transactions Related-Party Transactions, Summary of Transactions Narrative (Details) - USD ($) $ in Millions		May 15, 2018	Jun. 30, 2018	[1],[4],[5]	Mar. 31, 2018		Mar. 31, 2017
Quarterly distributions to common unitholders					$ 205	[1]	$ 94
Revenue from Related Parties	[2]				318		203
Related Party Transaction, Expenses from Transactions with Related Party	[3]				51		39
Related Party Transaction, Selling, General and Administrative Expenses from Transactions with Related Party					$ 20		$ 20
Concentration Risk, Percentage					59.00%		48.00%
Cost of Reimbursable Expense					$ 7		$ 2
Payments of Distributions to Affiliates					(115)
Distribution to Partner, Waived Distribution					12.5		12.5
Partner to Andeavor | Omnibus Agreement
Payment for Administrative Fees					13
Andeavor to Partner | Secondment and Logistics Services Agreement
Long-term Purchase Commitment, Amount					$ 6		$ 5
Subsequent Event
Quarterly distributions to common unitholders		$ 115	$ 205
Distribution to Partner, Waived Distribution		$ 15
[1]	(a)This distribution is net of $15 million and $12.5 million waived by TLGP for the three months ended
[2]	Andeavor accounted for 59% and 48% of our total revenues for the three months ended March 31, 2018 and 2017, respectively.
[3]	Net of reimbursements from Andeavor pursuant to the Amended Omnibus Agreement, the Carson Assets Indemnity Agreement and other affiliate agreements of $7 million and $2 million for the three months ended March 31, 2018 and 2017, respectively.
[4]	(b)This distribution was declared on April 18, 2018 and will be paid on the date of distribution.
[5]	(c)On February 15, 2018, we paid distributions associated with our Preferred Units of $8 million.

Related-Party Transactions Re30

Related-Party Transactions Related-Party Transactions, Summary of Affiliate Transactions (Details) - USD ($) $ / shares in Units, $ in Millions		May 15, 2018	Apr. 18, 2018	Jun. 30, 2018		Mar. 31, 2018		Mar. 31, 2017
Revenues	[1]					$ 318		$ 203
Cost of Reimbursable Expense						$ 7		$ 2
Concentration Risk, Percentage						59.00%		48.00%
Distribution Made to Limited Partner, Distributions Declared, Per Unit	[2]					$ 1
Distribution Made to Limited Partner, Distribution Date	[2]					Feb. 14, 2018
Quarterly distributions to common unitholders						$ 205	[2]	$ 94
Subsequent Event
Distribution Made to Limited Partner, Declaration Date			Apr. 18, 2018
Distribution Made to Limited Partner, Distributions Declared, Per Unit	[2],[3],[4]			$ 1.015
Distribution Made to Limited Partner, Distribution Date	[2],[3],[4]	May 15, 2018
Quarterly distributions to common unitholders		$ 115		$ 205	[2],[3],[4]
[1]	Andeavor accounted for 59% and 48% of our total revenues for the three months ended March 31, 2018 and 2017, respectively.
[2]	(a)This distribution is net of $15 million and $12.5 million waived by TLGP for the three months ended
[3]	(b)This distribution was declared on April 18, 2018 and will be paid on the date of distribution.
[4]	(c)On February 15, 2018, we paid distributions associated with our Preferred Units of $8 million.

Debt Total Debt (Details)

Debt Total Debt (Details) - USD ($) $ in Millions	Mar. 31, 2018	Dec. 31, 2017
Debt Disclosure [Abstract]
Total debt	$ 4,201	$ 4,182
Unamortized issuance costs	(52)	(54)
Current maturities	(1)	(1)
Debt, Net of Current Maturities and Unamortized Issuance Costs	$ 4,148	$ 4,127

Debt Credit Facilities (Details

Debt Credit Facilities (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2018	Jan. 05, 2018	Dec. 31, 2017
Line of Credit Facility [Line Items]
Line of Credit Facility, Current Borrowing Capacity	[1]	$ 2,100
Long-term Line of Credit	[1]	443
Letters of Credit Outstanding, Amount	[1]	0
Line of Credit Facility, Remaining Borrowing Capacity	[1]	1,657
Line of Credit Facility, Maximum Borrowing Capacity			$ 2,100
Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Current Borrowing Capacity		1,100		$ 600
Long-term Line of Credit		443
Letters of Credit Outstanding, Amount		0
Line of Credit Facility, Remaining Borrowing Capacity		$ 657
Line of Credit Facility, Expiration Date		Jan. 29, 2021
Dropdown Credit Facility
Line of Credit Facility [Line Items]
Line of Credit Facility, Current Borrowing Capacity		$ 1,000
Long-term Line of Credit		0
Letters of Credit Outstanding, Amount		0
Line of Credit Facility, Remaining Borrowing Capacity		$ 1,000
Line of Credit Facility, Expiration Date		Jan. 29, 2021
Revolving Credit Facility [Member] | Andeavor Logistics Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Debt, Weighted Average Interest Rate		3.59%
Revolving Credit Facility [Member] | Dropdown Credit Facility
Line of Credit Facility [Line Items]
Debt, Weighted Average Interest Rate		0.00%
[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	3 Months Ended
	Mar. 31, 2018	Dec. 31, 2017
Preferred Units, Outstanding	600,000	600,000
Preferred Stock, Dividend Rate, Percentage	6.875%
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage	59.00%
General Partners' Capital Account, Units Outstanding	2,202,880
Public common units
Limited Partners' Capital Account, Units Outstanding	89,280,638
Andeavor common units
Limited Partners' Capital Account, Units Outstanding	127,889,386
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
		Mar. 31, 2018	Mar. 31, 2017
Changes in carrying amount of Equity
Partners' Capital		$ 3,514
Partners' Capital Account, Distributions	[1]	213
Net Income (Loss) Attributable to Parent		139	$ 92
Partners' Capital Account, Exchanges and Conversions		(22)
Other		(1)
Partners' Capital		3,433
Partners' Capital Account, Contributions	[2]	16
Common
Changes in carrying amount of Equity
Partners' Capital		2,925
Partners' Capital Account, Distributions	[1]	205
Net Income (Loss) Attributable to Parent		125
Partners' Capital Account, Exchanges and Conversions		(22)
Other		0
Partners' Capital		2,839
Partners' Capital Account, Contributions	[2]	16
Preferred Partner
Changes in carrying amount of Equity
Partners' Capital		589
Partners' Capital Account, Distributions	[1]	8
Net Income (Loss) Attributable to Parent		14
Partners' Capital Account, Exchanges and Conversions		0
Other		(1)
Partners' Capital		594
Partners' Capital Account, Contributions	[2]	$ 0
[1]	(a)Represents cash distributions declared and paid during the three months ended March 31, 2018.
[2]	(b)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 Equity, Earnings Per Uni

Equity Equity, Earnings Per Unit (Details) $ / shares in Units, shares in Millions, $ in Millions		3 Months Ended
		Mar. 31, 2018USD ($)$ / sharesshares	Mar. 31, 2017USD ($)$ / sharesshares
Net Income (Loss) Attributable To Partners Excluding Special Allocation		$ 139	$ 93
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable	[1]	10	0
Net earnings attributable to common units		129	93
Net earnings		139	92
Special allocations of net earnings (“Special Allocations”) (a)	[2]	0	(1)
Distributions on common units greater than earnings		$ 76	$ 47
Common units - basic | shares		217.2	104.8
Common units - diluted | shares	[3]	217.4	104.9
Common - basic | $ / shares		$ 0.59	$ 0.51
Common - diluted | $ / shares		$ 0.59	$ 0.51
Incentive Distribution, Distribution Split Marginal Percentage			50.00%
Incentive Distribution, Minimum Distribution Level | $ / shares			0.3881
Distribution to Partner, Waived Distribution		$ 12.5	$ 12.5
Common
Special allocations of net earnings (“Special Allocations”) (a)	[2]	0	(1)
Limited partners’ distributions on common units	[4]	(205)	(101)
Distributions on common units greater than earnings		76	46
Participating Securities, Distributed and Undistributed Earnings (Loss), Basic		129	54
General Partner
General partner’s distributions		0	(3)
General partner’s IDRs (c)	[5]	0	(36)
Distributions on common units greater than earnings		0	(1)
Participating Securities, Distributed and Undistributed Earnings (Loss), Basic		$ 0	$ 38
[1]	(b)The Preferred Units entitle unitholders to receive preferred distributions on a semi-annually basis.
[2]	(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 three months ended March 31, 2017.
[3]	(e)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.
[4]	(d)Distributions of earnings for limited partners’ common units for the three months ended March 31, 2018 is net of a $15.0 million waiver from Andeavor in connection with the WNRL Merger.
[5]	(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 $12.5 million of IDRs waived by TLGP for the three months ended March 31, 2017. Our general partner no longer receives IDRs as a result of the IDR/GP Transaction.

Equity, Cash Distributions (Det

Equity, Cash Distributions (Details) - USD ($) $ / shares in Units, $ in Millions		May 15, 2018	May 05, 2018	Jun. 30, 2018		Mar. 31, 2018		Mar. 31, 2017
Distribution Made to Member or Limited Partner
Distribution to Partner, Waived Distribution						$ 12.5		$ 12.5
Distribution Made to Limited Partner, Distributions Declared, Per Unit	[1]					$ 1
Quarterly distributions to common unitholders						$ 205	[1]	$ 94
Distribution Made to Limited Partner, Distribution Date	[1]					Feb. 14, 2018
Distribution Made to Limited Partner, Date of Record	[1]					Jan. 31, 2018
Subsequent Event
Distribution Made to Member or Limited Partner
Distribution to Partner, Waived Distribution		$ 15
Distribution Made to Limited Partner, Distributions Declared, Per Unit	[1],[2],[3]			$ 1.015
Quarterly distributions to common unitholders		$ 115		$ 205	[1],[2],[3]
Distribution Made to Limited Partner, Distribution Date	[1],[2],[3]	May 15, 2018
Distribution Made to Limited Partner, Date of Record	[1],[2],[3]		May 1, 2018
[1]	(a)This distribution is net of $15 million and $12.5 million waived by TLGP for the three months ended
[2]	(b)This distribution was declared on April 18, 2018 and will be paid on the date of distribution.
[3]	(c)On February 15, 2018, we paid distributions associated with our Preferred Units of $8 million.

Equity Equity, Net Earnings (De

Equity Equity, Net Earnings (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
General Partner
Schedule of Capitalization, Equity [Line Items]
Participating Securities, Distributed and Undistributed Earnings (Loss), Basic	$ 0	$ 38
Common
Schedule of Capitalization, Equity [Line Items]
Participating Securities, Distributed and Undistributed Earnings (Loss), Basic	$ 129	$ 54

Revenues Revenue Recognition, N

Revenues Revenue Recognition, Narrative (Details) $ in Millions	3 Months Ended
	Mar. 31, 2018USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	$ 4,200
Contract with Customer, Liability, Revenue Recognized	14
Revenue from Contract with Customer, Including Assessed Tax	454
Operating Leases, Income Statement, Lease Revenue	$ 81
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	5 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Percent	80.00%
Minimum
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Maximum
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	15 years

Revenues Contract Assets and Li

Revenues Contract Assets and Liabilities (Details) - USD ($) $ in Millions	Mar. 31, 2018	Jan. 01, 2018	Dec. 31, 2017
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Accounts Receivable, Net	$ 325	$ 329	$ 363
Contract with Customer, Asset, Net	13	34	0
Deferred Revenue, Current	21	23	23
Deferred Revenue, Noncurrent	56	62	43
Equity Method Investments	$ 312		$ 320
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		(34)
Contract with Customer, Asset, Net		34
Deferred Revenue, Current		0
Deferred Revenue, Noncurrent		19
Equity Method Investments		$ 3

Revenues Revenue Disaggregation

Revenues Revenue Disaggregation (Details) $ in Millions	3 Months Ended
	Mar. 31, 2018USD ($)
Terminalling and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 231
Terminalling and Transportation | Refined Products
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	203
Terminalling and Transportation | Crude oil and water gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	26
Terminalling and Transportation | Natural Gas
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Terminalling and Transportation | Other Services
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2
Terminalling and Transportation | Service Revenues
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	231
Terminalling and Transportation | Natural Gas Liquids
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	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
Terminalling and Transportation | Product Revenues
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Gathering and Processing
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	289
Gathering and Processing | Refined Products
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Gathering and Processing | Crude oil and water gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	87
Gathering and Processing | Natural Gas
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	98
Gathering and Processing | Other Services
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Gathering and Processing | Service Revenues
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	185
Gathering and Processing | Natural Gas Liquids
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	104
Gathering and Processing | Crude Oil Refined Products And Blending Products
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Gathering and Processing | Product Revenues
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	104
Wholesale
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	15
Wholesale | Refined Products
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	6
Wholesale | Crude oil and water gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Wholesale | Natural Gas
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Wholesale | Other Services
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Wholesale | Service Revenues
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	6
Wholesale | Natural Gas Liquids
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Wholesale | Crude Oil Refined Products And Blending Products
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	9
Wholesale | Product Revenues
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 9

Operating Segments Operating Se

Operating Segments Operating Segments, Results (Details) $ in Millions	3 Months Ended
	Mar. 31, 2018USD ($)segments	Mar. 31, 2017USD ($)
Segment Reporting Information [Line Items]
Number of Reportable Segments | segments	3
Revenue, Net	$ 535	$ 420
Operating Income	190	150
Segment Reporting Operating Income	198	160
Unallocated general and administrative expenses	(8)	(10)
Interest and financing costs, net	(54)	(62)
Equity in earnings of equity method investments	2	2
Other income, net	1	2
Net Earnings	139	92
Additions to Other Assets, Amount	83	45
Depreciation and amortization expenses	80	58
Operating Segments | Terminalling and Transportation
Segment Reporting Information [Line Items]
Refining and Marketing Revenue	231	175
Operating Income	120	98
Additions to Other Assets, Amount	27	27
Depreciation and amortization expenses	29	21
Operating Segments | Gathering and Processing
Segment Reporting Information [Line Items]
Refining and Marketing Revenue	289	245
Operating Income	74	62
Additions to Other Assets, Amount	55	18
Depreciation and amortization expenses	48	37
Operating Segments | Wholesale Segment
Segment Reporting Information [Line Items]
Refining and Marketing Revenue	17	0
Operating Income	4	0
Additions to Other Assets, Amount	1	0
Depreciation and amortization expenses	3	0
Intersegment Eliminations
Segment Reporting Information [Line Items]
Revenue, Net	(2)	0
Terminalling revenues | Operating Segments | Terminalling and Transportation
Segment Reporting Information [Line Items]
Revenue, Net	198	145
Pipeline transportation revenues | Operating Segments | Terminalling and Transportation
Segment Reporting Information [Line Items]
Revenue, Net	31	30
Other Terminalling and Transportation Revenue | Operating Segments | Terminalling and Transportation
Segment Reporting Information [Line Items]
Revenue, Net	2	0
Sales of natural gas, NGLS and condensate | Operating Segments | Gathering and Processing
Segment Reporting Information [Line Items]
Revenue, Net	104	83
Gas gathering and processing | Operating Segments | Gathering and Processing
Segment Reporting Information [Line Items]
Revenue, Net	85	80
Crude oil and water gathering | Operating Segments | Gathering and Processing
Segment Reporting Information [Line Items]
Revenue, Net	65	39
Pass-thru and other revenue | Operating Segments | Gathering and Processing
Segment Reporting Information [Line Items]
Revenue, Net	35	43
Fuel Sales | Operating Segments | Wholesale Segment
Segment Reporting Information [Line Items]
Revenue, Net	9	0
Other Non-fuel | Operating Segments | Wholesale Segment
Segment Reporting Information [Line Items]
Revenue, Net	$ 8	$ 0