Shell Midstream Partners (SHLX) 10-K 20 Feb 20 2019 FY Annual report Financial data

Cover Page

Cover Page - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Feb. 20, 2020	Jun. 28, 2019
Cover page.
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2019
Document Transition Report	false
Entity File Number	001-36710
Entity Registrant Name	Shell Midstream Partners, L.P.
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	46-5223743
Entity Address, Address Line One	150 N. Dairy Ashford
Entity Address, City or Town	Houston
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77079
City Area Code	832
Local Phone Number	337-2034
Title of 12(b) Security	Common Units, Representing Limited Partner Interests
Trading Symbol	SHLX
Security Exchange Name	NYSE
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Public Float			$ 2,564
Entity Common Stock, Shares Outstanding		233,289,537
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	FY
Amendment Flag	false
Entity Central Index Key	0001610466

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Current assets
Cash and cash equivalents	$ 290	$ 208
Accounts receivable – third parties, net	12	19
Accounts receivable – related parties	29	29
Allowance oil	12	13
Prepaid expenses	16	15
Total current assets	359	284
Equity method investments	926	823
Property, plant and equipment, net	726	742
Operating lease right-of-use assets	4	0
Other investments	2	62
Other assets	2	3
Total assets	2,019	1,914
Current liabilities
Accounts payable – third parties	5	4
Accounts payable – related parties	10	9
Deferred revenue – third parties	0	8
Deferred revenue – related party	0	3
Accrued liabilities – third parties	12	13
Accrued liabilities – related parties	19	16
Total current liabilities	46	53
Noncurrent liabilities
Debt payable – related party	2,692	2,091
Operating lease liabilities	4	0
Finance lease liability	24	25
Other unearned income	2	2
Total noncurrent liabilities	2,722	2,118
Total liabilities	2,768	2,171
Commitments and Contingencies (Note 15)
(DEFICIT) EQUITY
Accumulated other comprehensive loss	(8)	0
Total partners’ deficit	(775)	(282)
Noncontrolling interests	26	25
Total deficit	(749)	(257)
Total liabilities and deficit	2,019	1,914
Shell Pipeline Company L P
(DEFICIT) EQUITY
General partner – SPLC (4,761,012 and 4,567,588 units issued and outstanding as of December 31, 2019 and December 31, 2018)	(4,014)	(3,543)
Common units - SPLC | General Public
(DEFICIT) EQUITY
Common and subordinated unitholders	3,450	3,459
Common units - SPLC | Shell Pipeline Company L P
(DEFICIT) EQUITY
Common and subordinated unitholders	$ (203)	$ (198)

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - shares	Dec. 31, 2019	Dec. 31, 2018
Limited partners' capital account, units outstanding (in units)	233,289,537
Shell Pipeline Company L P
General partners' capital account, units issued (in units)	4,761,012	4,567,588
General partners' capital account, units outstanding (in units)	4,761,012	4,567,588
Common unitholders | General Public
Limited partners' capital account, units issued (in units)	123,832,233	12,383,233
Limited partners' capital account, units outstanding (in units)	123,832,233	123,832,233
Common unitholders | Shell Pipeline Company L P
Limited partners' capital account, units issued (in units)	109,457,304	99,979,548
Limited partners' capital account, units outstanding (in units)	109,457,304	99,979,548

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Revenue
Revenue from contract with customer	$ 447	$ 469	$ 414
Total revenue	503	525	470
Costs and expenses
Operations and maintenance – third parties	65	108	104
Operations and maintenance – related parties	59	54	46
Cost of product sold – third parties	5	7	0
Cost of product sold – related parties	31	25	0
Loss (gain) from revision of ARO and disposition of fixed assets	2	(3)	0
General and administrative – third parties	11	8	10
General and administrative – related parties	49	52	48
Depreciation, amortization and accretion	49	46	45
Property and other taxes	17	16	17
Total costs and expenses	288	313	270
Operating income	215	212	200
Income from equity method investments	373	235	187
Dividend income from other investments	14	67	37
Other income	36	31	0
Investment, dividend and other income	423	333	224
Interest expense, net	92	62	32
Income before income taxes	546	483	392
Income tax expense	0	1	0
Net income	546	482	392
Less: Net income attributable to the Parent	0	0	77
Less: Net income attributable to noncontrolling interests	18	18	20
Net income attributable to the Partnership	528	464	295
General partner’s interest in net income attributable to the Partnership	147	134	64
Limited Partners’ interest in net income attributable to the Partnership	$ 381	$ 330	$ 231
Net income per Limited Partner Unit - Basic and Diluted:
Distributions per Limited Partner unit (in dollars per share)	$ 1.7500	$ 1.4950	$ 1.2461
Common
Costs and expenses
Net income attributable to the Partnership	$ 381	$ 330	$ 231
Net income per Limited Partner Unit - Basic and Diluted:
Net income per Limited Partner Unit - Basic and Diluted (in dollars per share)	$ 1.66	$ 1.50	$ 1.28
Weighted average Limited Partner Units outstanding - Basic and Diluted:
Weighted average limited partner units - Basic and Diluted (in units)	229.2	220.3	180.4
Common units - public
Costs and expenses
Net income	$ 204	$ 182	$ 119
Weighted average Limited Partner Units outstanding - Basic and Diluted:
Weighted average limited partner units - Basic and Diluted (in units)	123.8	121.3	91.4
Common units - public | Shell Pipeline Company L P
Costs and expenses
Net income	$ 177	$ 147	$ 112
Common units - SPLC | Shell Pipeline Company L P
Weighted average Limited Partner Units outstanding - Basic and Diluted:
Weighted average limited partner units - Basic and Diluted (in units)	105.4	99	89
Third Parties | Transportation, Terminaling And Storage Services
Revenue
Revenue from contract with customer	$ 143	$ 209	$ 236
Third Parties | Product Revenue
Revenue
Revenue from contract with customer	5	2	0
Related Parties
Revenue
Lease revenue – related parties	56
Lease revenue – related parties	56	56	56
Related Parties | Transportation, Terminaling And Storage Services
Revenue
Revenue from contract with customer	264	229	178
Related Parties | Product Revenue
Revenue
Revenue from contract with customer	$ 35	$ 29	$ 0

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Statement of Comprehensive Income [Abstract]
Net income	$ 546	$ 482	$ 392
Other comprehensive loss, net of tax:
Remeasurements of pension and other postretirement benefits related to equity method investments, net of tax	(2)	0	0
Comprehensive income	544	482	392
Parent	0	0	77
Noncontrolling interests	18	18	20
Comprehensive income attributable to the Partnership	$ 526	$ 464	$ 295

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Cash flows from operating activities
Net income	$ 546	$ 482	$ 392
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation, amortization and accretion	49	46	45
Loss (gain) from revision of ARO and disposition of fixed assets	2	(3)	0
Non-cash interest expense	1	1	0
Allowance oil reduction to net realizable value	1	5	0
Undistributed equity earnings	(6)	(6)	(6)
Changes in operating assets and liabilities
Accounts receivable	7	(7)	(7)
Allowance oil	0	(6)	(3)
Prepaid expenses and other assets	0	(4)	(7)
Accounts payable	2	(7)	8
Deferred revenue and other unearned income	(11)	(4)	6
Accrued liabilities	6	10	4
Net cash provided by operating activities	597	507	432
Cash flows from investing activities
Capital expenditures	(38)	(49)	(58)
Acquisitions from Parent	(90)	(482)	(420)
Third party acquisitions	0	0	(38)
Contributions to investment	(25)	(28)	(12)
Return of investment	66	48	18
April 2017 Divestiture	0	0	1
Net cash used in investing activities	(87)	(511)	(509)
Cash flows from financing activities
Net proceeds from equity offerings	0	973	278
Borrowings under credit facilities	600	1,820	1,693
Repayments of credit facilities	0	(1,573)	(533)
Contributions from general partner	0	20	6
Proceeds from April 2017 Divestiture	0	0	20
Capital distributions to general partner	(510)	(738)	(1,035)
Distributions to noncontrolling interests	(17)	(16)	(19)
Distributions to unitholders and general partner	(519)	(423)	(268)
Net distributions to Parent	0	0	(66)
Other contributions from Parent	19	12	18
Credit facility issuance costs	0	(1)	(2)
Repayment of finance leases	(1)	0	0
Net cash (used in) provided by financing activities	(428)	74	92
Net increase in cash and cash equivalents	82	70	15
Cash and cash equivalents at beginning of the period	208	138	123
Cash and cash equivalents at end of the period	290	208	138
Non-cash investing and financing transactions:
Change in asset retirement obligation	0	2	0
Change in accrued capital expenditures	(3)	2	0
Other non-cash contributions from Parent	0	2	0
Net assets not contributed to the Partnership	$ 0	$ 0	$ (5)

CONSOLIDATED STATEMENTS OF CHAN

CONSOLIDATED STATEMENTS OF CHANGES IN (DEFICIT) EQUITY - USD ($) $ in Millions	Total	Common units - public	Common units - publicShell Pipeline Company L P	Subordinated UnitsShell Pipeline Company L P	General PartnerShell Pipeline Company L P	Accumulated Other Comprehensive Loss	Noncontrolling Interests	Net Parent Investment
Beginning balance at Dec. 31, 2016	$ 534	$ 2,486	$ (124)	$ (390)	$ (1,874)	$ 0	$ 22	$ 414
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	392	119	112	0	65		19	77
Net proceeds from equity offerings	278	278			0
Contributions from general partner	6				6
Other contributions from Parent	17				17			0
Distributions to noncontrolling interests	(19)						(19)
Distributions to unitholders and general partner	(268)	(109)	(87)	(18)	(54)
Acquisitions from Parent	(1,455)				(1,035)			(420)
Net distributions to Parent	(66)							(66)
Proceeds from April 2017 divestiture	20				19		1
Expiration of subordinated period	0		(408)	408
Net assets not contributed to the partnership	(5)							(5)
Ending balance at Dec. 31, 2017	(566)	2,774	(507)	0	(2,856)	0	23	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	482	182	147		135		18
Net proceeds from equity offerings	973	673	300
Contributions from general partner	20				20
Other contributions from Parent	13				13		0
Distributions to noncontrolling interests	(16)						(16)
Distributions to unitholders and general partner	(423)	(169)	(139)		(115)
Acquisitions	(738)				(738)
Ending balance at Dec. 31, 2018	(257)	3,459	(198)	0	(3,543)	0	25	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	546	204	177		147		18
Other contributions from Parent	19				25	(6)
Distributions to noncontrolling interests	(17)						(17)
Other comprehensive loss	(2)					(2)
Distributions to unitholders and general partner	(519)	(209)	(177)		(133)		0
Acquisitions	(510)				(510)
Ending balance at Dec. 31, 2019	$ (749)	$ 3,450	$ (203)	$ 0	$ (4,014)	$ (8)	$ 26	$ 0

Description of Business and Bas

Description of Business and Basis of Presentation	12 Months Ended
	Dec. 31, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Description of Business and Basis of Presentation	Description of Business and Basis of Presentation Shell Midstream Partners, L.P. (“we,” “us,” “our” or “the Partnership”) is a Delaware limited partnership formed by Royal Dutch Shell plc on March 19, 2014 to own and operate pipeline and other midstream assets, including certain assets received from Shell Pipeline Company LP (“SPLC”) and its affiliates. We conduct our operations either through our wholly owned subsidiary Shell Midstream Operating, LLC (“Operating Company”) or through direct ownership. Our general partner is Shell Midstream Partners GP LLC (“general partner” or “sponsor”). References to “RDS”, “Shell” or “Parent” refer collectively to Royal Dutch Shell plc and its controlled affiliates, other than us, our subsidiaries and our general partner. Description of Business We own, operate, develop and acquire pipelines and other midstream assets. As of December 31, 2019, our assets include interests in entities that own crude oil and refined products pipelines and terminals that serve as key infrastructure to (i) transport onshore and offshore crude oil production to Gulf Coast and Midwest refining markets and (ii) deliver refined products from those markets to major demand centers. Our assets also include interests in entities that own natural gas and refinery gas pipelines that transport offshore natural gas to market hubs and deliver refinery gas from refineries and plants to chemical sites along the Gulf Coast. We generate revenue from the transportation, terminaling and storage of crude oil and refined products through our pipelines and storage tanks, and generate income from our equity and other investments. Our operations consist of one reportable segment. The following table reflects our ownership interests as of December 31, 2019: SHLX Ownership Pecten Midstream LLC (“Pecten”) 100.0 % Sand Dollar Pipeline LLC (“Sand Dollar”) 100.0 % Triton West LLC (“Triton”) 100.0 % Zydeco Pipeline Company LLC (“Zydeco”) (1) 92.5 % Amberjack Pipeline Company LLC (“Amberjack”) – Series A/Series B 75.0% / 50.0% Mars Oil Pipeline Company LLC (“Mars”) 71.5 % Odyssey Pipeline L.L.C. (“Odyssey”) 71.0 % Bengal Pipeline Company LLC (“Bengal”) 50.0 % Crestwood Permian Basin LLC (“Permian Basin”) 50.0 % LOCAP LLC (“LOCAP”) 41.48 % Explorer Pipeline Company (“Explorer”) 38.59 % Poseidon Oil Pipeline Company, L.L.C. (“Poseidon”) 36.0 % Colonial Enterprises, Inc. (“Colonial”) (2) 16.125 % Proteus Oil Pipeline Company, LLC (“Proteus”) 10.0 % Endymion Oil Pipeline Company, LLC (“Endymion”) 10.0 % Cleopatra Gas Gathering Company, LLC (“Cleopatra”) 1.0 % (1) SPLC owns the remaining 7.5% ownership interest in Zydeco. (2) On November 12, 2019, Colonial completed a restructuring whereby a new holding company, Colonial Enterprises, Inc. was created as the parent of Colonial Pipeline Company. There is no impact to our ownership interest as a result of the restructuring aside from the entity in which we own an interest. Basis of Presentation Our consolidated financial statements include all subsidiaries required to be consolidated under generally accepted accounting principles in the United States (“GAAP”). Our reporting currency is U.S. dollars, and all references to dollars are U.S. dollars. The accompanying consolidated financial statements and related notes have been prepared under the rules and regulations of the Securities and Exchange Commission (the “SEC”). These rules and regulations conform to the accounting principles contained in the Financial Accounting Standards Board’s (“FASB”) Accounting Standards Codification, the single source of GAAP. Our consolidated subsidiaries include Pecten, Sand Dollar, Triton, Zydeco, Odyssey and the Operating Company. Asset acquisitions of additional interests in previously consolidated subsidiaries and interests in equity method and other investments are included in the financial statements prospectively from the effective date of each acquisition. In cases where these types of acquisitions are considered acquisitions of businesses under common control, the financial statements are retrospectively adjusted. The following businesses were acquired from our Parent and accounted for as acquisitions of businesses under common control. As such, our consolidated financial statements include the financial results of these businesses, which were derived from the financial statements and accounting records of SPLC and Shell for the periods prior to acquisition. Specifically, such businesses are reflected for the following periods prior to the effective date of such acquisitions by us: • May 2017 Acquisition for periods prior to May 10, 2017; and • December 2017 Acquisition for periods prior to December 1, 2017, including the effect of fully consolidating Odyssey. Our consolidated statements of income, cash flows and changes in (deficit) equity for 2017 consist of the combined results of the May 2017 Acquisition and the December 2017 Acquisition prior to the respective acquisition dates, and the consolidated activity of the Partnership. Our consolidated statements of income exclude the results of these businesses from net income attributable to the Partnership for the periods indicated above by allocating these results to our Parent. See Note 3 — Acquisitions and Divestiture for definitions and additional information. Expense Allocations. Our consolidated statements of income also include expense allocations for certain functions performed by SPLC and Shell on behalf of the above businesses prior to their respective dates of acquisition by us. Such costs are included in either general and administrative expenses or operations and maintenance expenses in the accompanying consolidated statements of income, depending on the nature of the employee’s role in our operations. The expense allocations have been determined on a basis that we, SPLC and Shell consider to be a reasonable reflection of the utilization of the services provided or the benefit received during the periods presented. See Note 4 — Related Party Transactions for details of operating agreements impacting expense allocations, as well as details of related party transactions. Cash. For all consolidated subsidiaries, we establish our own cash accounts for the funding of our operating and investing activities, with the exception of the capital expenditures incurred by SPLC on our behalf and then contributed to us. Funds are not commingled with the cash of other entities. Prior to the acquisition of each of these interests, the cash generated and used by our operations was deposited to Shell Treasury Center (West) Inc. (“STCW”), which was commingled with the cash of other entities controlled by Shell. STCW funded our operating activities, and STCW or an affiliate funded investing activities as needed. Accordingly, we did not record any cash and cash equivalents held by SPLC on our behalf for any period prior to the effective date of each acquisition from Shell.

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2019
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	Summary of Significant Accounting Policies Principles of Consolidation Our consolidated financial statements include all subsidiaries where we have control. The assets and liabilities in the accompanying consolidated financial statements have been reflected on a historical basis. All significant intercompany accounts and transactions are eliminated upon consolidation. See Note 1 — Description of the Business and Basis of Presentation for additional details. Regulation Certain businesses are subject to regulation by various authorities including, but not limited to FERC. Regulatory bodies exercise statutory authority over matters such as construction, rates and ratemaking and agreements with customers. Net Parent Investment Net Parent Investment represents Shell’s historical investment in us, our accumulated net earnings through the date which we completed the acquisition, and the net effect of transactions with, and allocations from, SPLC and Shell. Use of Estimates The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the amounts reported of assets, liabilities, revenues and expenses in the accompanying consolidated financial statements and notes. Actual results could differ from those estimates. Common Control Transactions Assets and businesses acquired from our Parent and its subsidiaries are accounted for as common control transactions whereby the net assets acquired are combined with ours at our Parent’s historical carrying value. If any recognized consideration transferred in such a transaction exceeds the carrying value of the net assets acquired, the excess is treated as a capital distribution to our General Partner, similar to a dividend. If the carrying value of the net assets acquired exceeds any recognized consideration transferred including, if applicable, the fair value of any limited partner units issued, then our Parent would record an impairment and our net assets acquired would be recorded at fair value. To the extent that such transactions require prior periods to be retrospectively adjusted, historical net equity amounts prior to the transaction date are reflected in “Net Parent Investment.” Cash consideration up to the carrying value of net assets acquired is presented as an investing activity in our consolidated statement of cash flows. Cash consideration in excess of the carrying value of net assets acquired is presented as a financing activity in our consolidated statement of cash flows. Assets and businesses sold to our Parent are also common control transactions accounted for using historical carrying value with any resulting gain treated as a contribution from Parent. Revenue Recognition Our revenues are primarily generated from the transportation, terminaling and storage of crude oil, refined gas and refined petroleum products through our pipelines, terminals and storage tanks. We recognize revenue when we transfer promised goods or services to customers in an amount that reflects the consideration to which we expect to be entitled in exchange for those goods or services. We recognize revenue through the application of a five-step model, which includes: identification of the contract; identification of the performance obligations; determination of the transaction price; allocation of the transaction price to the performance obligations; and recognition of revenue as the entity satisfies the performance obligations. See Note 12 — Revenue Recognition for information and disclosures related to revenue from contracts with customers. Cash and Cash Equivalents Our cash and cash equivalents includes cash and short-term highly liquid overnight deposits. Accounts Receivable and Allowance for Doubtful Accounts Accounts receivable represent valid claims against customers for products sold or services rendered, net of allowances for doubtful accounts. We assess the creditworthiness of our counterparties on an ongoing basis and require security, including prepayments and other forms of collateral, when appropriate. We establish provisions for losses on accounts receivable due from shippers and operators if we determine that we will not collect all or part of the outstanding balance. Outstanding customer receivables are regularly reviewed for possible nonpayment indicators, and allowances for doubtful accounts are recorded based upon management’s estimate of collectability at each balance sheet date. As of December 31, 2019 and 2018, we did not have any allowance for doubtful accounts. Equity Method Investments We account for investments where we have the ability to exercise significant influence, but not control, under the equity method of accounting. Income from equity method investments represents our proportionate share of net income generated by the equity method investees. Differences in the basis of the investments and the underlying net asset value of the investees, if any, are amortized into net income over the remaining useful lives of the underlying assets. Equity method investments are assessed for impairment whenever changes in the facts and circumstances indicate a loss in value has occurred, if the loss is deemed to be other than temporary. When the loss is deemed to be other than temporary, the carrying value of the equity method investment is written down to fair value. Property, Plant and Equipment Our property, plant and equipment is recorded at its historical cost of construction or, upon acquisition, at either the fair value of the assets acquired or the historical carrying value to the entity that placed the asset in service. Expenditures for major renewals and betterments are capitalized while those minor replacement, maintenance and repairs that do not improve or extend asset life are expensed when incurred. For constructed assets, we capitalize all construction-related direct labor and material costs, as well as indirect construction costs. We capitalize interest on certain projects. For 2019, 2018 and 2017, the total amount of interest capitalized was immaterial. We use the straight-line method to depreciate property, plant and equipment based on the estimated useful life of the asset. We report gains or losses on dispositions of fixed assets as Loss (gain) from revision of ARO and disposition of fixed assets in the accompanying consolidated statements of income. Impairment of Long-lived Assets We evaluate long-lived assets of identifiable business activities for impairment when events or changes in circumstances indicate, in our management’s judgment, that the carrying value of such assets may not be recoverable. These events include a significant decrease in the market value of the asset, changes in the manner in which we intend to use a long-lived asset, decisions to sell an asset and adverse changes in the legal or business environment such as adverse actions by regulators. If an event occurs, which is a determination that involves judgment, we perform an impairment assessment by comparing estimated undiscounted future cash flows associated with the asset to the asset’s net book value. If the net book value exceeds our estimate of undiscounted future cash flows, an impairment is calculated as the amount the net book value exceeds the estimated fair value associated with the asset. We determined that there were no asset impairments in 2019, 2018 or 2017. Income Taxes We are not a taxable entity for U.S. federal income tax purposes or for the majority of states that impose an income tax. Taxes on our net income are generally borne by our partners through the allocation of taxable income. Our income tax expense results from partnership activity in the state of Texas, as conducted by Zydeco, Sand Dollar and Triton. Income tax expense for 2019, 2018 and 2017 was immaterial. Other Investments We account for equity investments in entities where we do not have control or significant influence at fair value with changes in fair value recognized in net income when the fair value is readily determinable. For investments without readily determinable fair values, we carry such investments at cost less impairments, if any. These investments are remeasured at fair value either upon the occurrence of an observable price change or upon identification of impairment. These investments are reported as Other investments in our consolidated balance sheets and dividends received are reported in Dividend income from other investments in our consolidated income statements. Our equity investments which are accounted for at cost as they do not have readily determinable fair values consist of: December 31, 2019 December 31, 2018 Ownership Amount Ownership Amount Colonial (1) 16.125 % $ — 6.0 % $ 11 Explorer (1) 38.59 % — 12.62 % 49 Cleopatra 1.0 % 2 1.0 % 2 $ 2 $ 62 (1) We acquired additional interests in Explorer and Colonial in June 2019. As a result of the June 2019 Acquisition, we now have significant influence over both Explorer and Colonial and account for these investments as equity method investments. The acquisition of these interests has been accounted for prospectively. During the years ended December 31, 2019 and 2018, we did not identify the occurrence of an observable price change or an identification of impairment for these equity investments. Asset Retirement Obligations Asset retirement obligations (“AROs”) represent contractual or regulatory obligations associated with the retirement of long-lived assets that result from the acquisition, construction, development and/or normal use of the asset. Our AROs were zero as of both December 31, 2019 and 2018. Our assets include pipelines and terminals that have contractual or regulatory obligations that will need to be settled at retirement. The settlement date of these obligations will depend mostly on the various supply sources that connect to our systems and the ongoing demand for usage in the markets we serve. We expect these supply sources and market demands to continue for the foreseeable future. As the settlement dates of obligations are indeterminate, there is not sufficient information to make a reasonable estimate of the ARO of our remaining assets as of December 31, 2019 and 2018. We continue to evaluate our AROs and future developments could impact the amounts we record. Pensions and Other Postretirement Benefits We do not have our own employees. Employees that work on our pipelines or terminal are employees of SPLC, and we share employees with other SPLC-controlled and non-controlled entities. For presentation of these accompanying consolidated financial statements, our portion of payroll costs and employee benefit plan costs have been allocated as a charge to us by SPLC and Shell Oil Company. Shell Oil Company sponsors various employee pension and postretirement health and life insurance plans. For purposes of these accompanying consolidated financial statements, we are considered to be participating in the benefit plans of Shell Oil Company. We participate in the following defined benefits plans: Shell Oil Pension Plan, Shell Oil Retiree Health Care Plan, and Pennzoil-Quaker State Retiree Medical & Life Insurance. As a participant in these benefit plans, we recognize as expense in each period an allocation from Shell Oil Company, and we do not recognize any employee benefit plan assets or liabilities. See Note 4 — Related Party Transactions for total pension and benefit expenses under these plans. Legal We are subject to litigation and regulatory proceedings as the result of our business operations and transactions. We use both internal and external counsel in evaluating our potential exposure to adverse outcomes from orders, judgments or settlements. In general, we expense legal costs as incurred. When we identify specific litigation that is expected to continue for a significant period of time, is probable to occur and may require substantial expenditures, we identify a range of possible costs expected to be required to litigate the matter to a conclusion or reach an acceptable settlement, and we accrue for the most probable outcome. To the extent that actual outcomes differ from our estimates, or additional facts and circumstances cause us to revise our estimates, our earnings will be affected. Environmental Matters We are subject to federal, state, and local environmental laws and regulations. Environmental expenditures are expensed or capitalized depending on their economic benefit. We expense costs such as permits, compliance with existing environmental regulations, remedial investigations, soil sampling, testing and monitoring costs to meet applicable environmental laws and regulations where prudently incurred or determined to be reasonably possible in the ordinary course of business. We are permitted to recover such expenditures through tariff rates charged to customers. We also expense costs that relate to an existing condition caused by past environmental incidents, which do not contribute to current or future revenue generation. We record environmental liabilities when environmental assessments and/or remedial efforts are probable and we can reasonably estimate the costs. Generally, our recording of these accruals coincides with our completion of a feasibility study or our commitment to a formal plan of action. We recognize receivables for anticipated associated insurance recoveries when such recoveries are deemed to be probable. For 2019, 2018 and 2017, the environmental cleanup costs incurred were immaterial. At both December 31, 2019 and 2018, the accruals for environmental clean-up costs pursuant to a Consent Decree issued in 1998 by the State of Washington Department of Ecology with respect to our products terminal located in Seattle, Washington were immaterial. The costs relate to ongoing groundwater compliance monitoring and other remedial activities. Refer to Note 4 — Related Party Transactions under the Omnibus Agreement for additional details. We routinely conduct reviews of potential environmental issues and claims that could impact our assets or operations. These reviews assist us in identifying environmental issues and estimating the costs and timing of remediation efforts. In making environmental liability estimations, we consider the material effect of environmental compliance, pending legal actions against us and potential third-party liability claims. Often, as the remediation evaluation and effort progresses, additional information is obtained, requiring revisions to estimated costs. These revisions are reflected in our income statement in the period in which they are probable and reasonably estimable. Other Contingencies We recognize liabilities for other contingencies when we have an exposure that indicates it is both probable that a liability has been incurred and the amount of loss can be reasonably estimated. Where the most likely outcome of a contingency can be reasonably estimated, we accrue a liability for that amount. Where the most likely outcome cannot be estimated, a range of potential losses is established and if no one amount in that range is more likely than any other, the lower end of the range is accrued. Fair Value Estimates We measure assets and liabilities requiring fair value presentation or disclosure using an exit price (i.e., the price that would be received to sell an asset or paid to transfer a liability) and disclose such amounts according to the quality of valuation inputs under the following hierarchy: Level 1: Quoted prices in an active market for identical assets or liabilities. Level 2: Inputs other than quoted prices that are directly or indirectly observable. Level 3: Unobservable inputs that are significant to the fair value of assets or liabilities. We classify the fair value of an asset or liability based on the lowest level of input significant to its measurement. A fair value initially reported as Level 3 will be subsequently reported as Level 2 if the unobservable inputs become inconsequential to its measurement or corroborating market data becomes available. Asset and liability fair values initially reported as Level 2 will be subsequently reported as Level 3 if corroborating market data becomes unavailable. The carrying amounts of our accounts receivable, accounts payable and accrued liabilities approximate their fair values due to their short-term nature. Net income per limited partner unit Net income per unit applicable to common limited partner units, and to subordinated limited partner units in periods prior to the expiration of the subordination period, is computed by dividing the respective limited partners’ interest in net income attributable to the Partnership for the period by the weighted average number of common units and subordinated units, respectively, outstanding for the period. Because we have more than one class of participating securities, we use the two-class method when calculating the net income per unit applicable to limited partners. The classes of participating securities include common units, subordinated units, general partner units and incentive distribution rights (“IDRs”). Basic and diluted net income per unit are the same because we do not have any potentially dilutive units outstanding for the period presented. Our net income includes earnings related to businesses acquired through transactions between entities under common control for periods prior to their acquisition by us. We have allocated these pre-acquisition earnings to our Net Parent Investment. On February 15, 2017, all of the subordinated units converted into common units following the payment of the cash distribution for the fourth quarter of 2016. See Note 11 — (Deficit) Equity for additional information. Recent Accounting Pronouncements Standards Adopted as of January 1, 2019 In May 2014, the FASB issued Accounting Standards Update (“ASU”) 2014-09 to Topic 606, Revenue from Contracts with Customers, which superseded revenue recognition guidance in Topic 605, Revenue Recognition, under GAAP. Under the revenue standard (as defined in Note 12 — Revenue Recognition ), the adoption date for the majority of the equity method investments within the Partnership followed the non-public business entity adoption date of January 1, 2019 for their stand-alone financial statements, with the exception of Mars and Permian Basin, which adopted on January 1, 2018. See Note 5 — Equity Method Investments for additional information. In February 2016, the FASB issued ASU 2016-02 to Topic 842, Leases. As permitted, we adopted the new lease standard (as defined in Note 9 — Leases ) using the modified retrospective approach, effective January 1, 2019, which provides a method for recording existing leases at the beginning of the period of adoption. As such, results and balances prior to January 1, 2019 are not adjusted and continue to be reported in accordance with our historical accounting under previous GAAP. Under the new lease standard, the adoption date for equity method investments within the Partnership will follow the non-public business entity adoption date of January 1, 2020 or 2021 for their stand-alone financial statements, with the exception of Permian Basin, which adopted on January 1, 2019. See Note 9 — Leases for additional information and disclosures required by the new lease standard. Standards Not Adopted as of December 31, 2019 In June 2016, the FASB issued ASU 2016-13 to Topic 326, Financial Instruments — Credit Losses: Measurement of Credit Losses on Financial Instruments, which replaces the current incurred loss impairment method with a method that reflects expected credit losses on financial instruments. The update is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2019 for SEC filers excluding smaller reporting companies. Early adoption is permitted. We do not expect the adoption of this standard to have a material impact on our consolidated financial statements.

Acquisitions and Divestiture

Acquisitions and Divestiture	12 Months Ended
	Dec. 31, 2019
Business Combinations [Abstract]
Acquisition and Divestiture	Acquisitions and Divestiture 2019 Acquisition On June 6, 2019, we acquired SPLC’s remaining 25.97% ownership interest in Explorer and 10.125% ownership interest in Colonial for consideration valued at $800 million (the “June 2019 Acquisition”). The June 2019 Acquisition increased our ownership interest in Explorer to 38.59% and in Colonial to 16.125%. The June 2019 Acquisition closed pursuant to a Contribution Agreement dated May 10, 2019 (the “May 2019 Contribution Agreement”) between us and SPLC, and is accounted for as a transaction between entities under common control on a prospective basis as an asset acquisition. As such, we recorded the acquired equity interests at SPLC’s historical carrying value of $90 million, which is included in Equity method investments in our consolidated balance sheet. In addition, as a transfer between entities under common control, we recorded Accumulated other comprehensive loss of $6 million related to historical remeasurements of pension and other postretirement benefits provided by Explorer and Colonial to their employees. We recognized $510 million of cash consideration in excess of the historical carrying value of equity interests acquired as a capital distribution to our general partner in accordance with our policy for common control transactions. We funded the June 2019 Acquisition with $600 million in cash consideration from borrowings under our Ten Year Fixed Facility (as defined in Note 8 — Related Party Debt ) with STCW and non-cash equity consideration valued at $200 million. Pursuant to the May 2019 Contribution Agreement, t he number of common units representing the equity consideration was determined by dividing the contribution amount (25% of total consideration of $800 million) by the price per unit of $20.68, which represents the volume weighted average sales prices of the common units calculated for the five trading day period ended on April 30, 2019, less the general partner units issued to the general partner in order to maintain its 2% general partner interest in us. The equity issued consisted of 9,477,756 common units issued to Shell Midstream LP Holdings LLC, an indirect subsidiary of Shell, and 193,424 general partner units issued to the general partner in order to maintain its 2% general partner interest in us. These common and general partner units issued were assigned no book value because the cash consideration exceeded the historical carrying value of equity interests acquired. Accordingly, the units issued had no impact on partner capital accounts, other than changing ownership percentages. As a result of the June 2019 Acquisition, we now have significant influence over both Explorer and Colonial and account for these investments as equity method investments (see Note 5 — Equity Method Investments for further details). 2018 Acquisition On May 11, 2018, we acquired SPLC’s ownership interests in Amberjack, which is comprised of 75% of the issued and outstanding Series A membership interests of Amberjack and 50% of the issued and outstanding Series B membership interests of Amberjack for $1,220 million (the “May 2018 Acquisition”). The May 2018 Acquisition closed pursuant to a Purchase and Sale Agreement dated May 9, 2018 between us and SPLC, and is accounted for as a transaction between entities under common control on a prospective basis as an asset acquisition. We acquired historical carrying value of net assets under common control of $482 million, which is included in Equity method investments in our consolidated balance sheet. We recognized $738 million of consideration in excess of the historical carrying value of net assets acquired as a capital distribution to our general partner in accordance with our policy for common control transactions. We funded the May 2018 Acquisition with $494 million in borrowings under our Five Year Revolver due July 2023 (as defined in Note 8 — Related Party Debt ) and $726 million in borrowings under our Five Note 8 — Related Party Debt ) with STCW. 2017 Acquisitions During 2017, we completed three acquisitions, each as described below. Of these, the December 2017 Acquisition and the May 2017 Acquisition were considered transfers of businesses between entities under common control, and therefore the related acquired assets and liabilities were transferred at historical carrying value. Because these acquisitions were common control transactions in which we acquired businesses, our historical financial statements were recast for the periods of our Parent’s ownership prior to the transactions. December 2017 Acquisition On December 1, 2017, we acquired a 100% interest in Triton, 41.48% of the issued and outstanding membership interest in LOCAP, an additional 22.9% interest in Mars, an additional 22% interest in Odyssey, and an additional 10% interest in Explorer from SPLC and Equilon Enterprises LLC d/b/a Shell Oil Products US (“SOPUS”) for $825 million in cash (the “December 2017 Acquisition”). As part of the December 2017 Acquisition, SOPUS contributed all but the working capital and certain environmental liabilities of Triton. The December 2017 Acquisition closed pursuant to a Purchase and Sale Agreement (the “December 2017 Purchase and Sale Agreement”) among the Operating Company, us, SPLC and SOPUS. SPLC and SOPUS are each wholly owned subsidiaries of Shell. We funded the cash consideration for the December 2017 Acquisition from $825 million in borrowings under the Five Year Revolver due December 2022 and the Five Year Fixed Facility (as defined in Note 8 — Related Party Debt) . Total transaction costs of $1 million were expensed as incurred. The terms of the December 2017 Acquisition were approved by the Board of Directors of our general partner (the “Board”) and by the conflicts committee of the Board, which consists entirely of independent directors. The conflicts committee engaged an independent financial advisor and legal counsel. In connection with the December 2017 Acquisition we acquired the following: Cost investment (1) $ 22 Equity method investments (2) 76 Property, plant and equipment, net (3) 118 Partners’ capital (4) 3 December 2017 Acquisition $ 219 (1) Book value of an additional 10% interest in Explorer contributed by SPLC. (2) Book value of an additional 22.9% interest in Mars and a 41.48% interest in LOCAP contributed by SPLC. (3) Book value of a 100.0% interest in the historical carrying value of property, plant and equipment, net contributed by SOPUS. (4) Book value of an additional 22% interest in Odyssey contributed by SOPUS. We recognized $606 million of consideration in excess of the book value of net assets acquired as a capital distribution to our general partner in accordance with our policy for common control transactions. For the period from closing through December 31, 2017, we recognized $8 million in revenues and $19 million of net earnings related to this acquisition. October 2017 Acquisition On October 17, 2017, we acquired a 50% interest in Permian Basin, which owns the Nautilus gathering system in the Permian Basin, for $50 million consideration and initial capital contributions (the “October 2017 Acquisition”). The October 2017 Acquisition closed pursuant to a Member Interest Purchase Agreement dated October 16, 2017 (the “October 2017 Purchase Agreement”), among the Operating Company and CPB Member LLC (a jointly owned subsidiary of Crestwood Equity Partners LP and First Reserve). We have determined we have significant influence over the financial and operating policies of Permian Basin, and we therefore account for this investment under the equity method. We funded the October 2017 Acquisition with cash on hand. The terms of the October 2017 Acquisition were approved by the Board. May 2017 Acquisition On May 10, 2017, we acquired a 100% interest in Delta, Na Kika and Refinery Gas Pipeline for $630 million in consideration (the “May 2017 Acquisition”). As part of the May 2017 Acquisition, SPLC and Shell GOM Pipeline Company LP (“Shell GOM”) contributed all but the working capital of Delta and Na Kika to Pecten, and Shell Chemical LP (“Shell Chemical”) contributed all but the working capital of Refinery Gas Pipeline to Sand Dollar. The May 2017 Acquisition closed pursuant to a Purchase and Sale Agreement dated May 4, 2017 (the “May 2017 Purchase and Sale Agreement”), among the Operating Company, us, Shell Chemical, Shell GOM and SPLC. Shell Chemical, Shell GOM and SPLC are each wholly owned subsidiaries of Shell. We funded the May 2017 Acquisition with $50 million of cash on hand, $73 million in borrowings under our Five Year Revolver due July 2023, and $507 million in borrowings under our Five Year Fixed Facility. Total transaction costs of $1 million were expensed as incurred. The terms of the May 2017 Acquisition were approved by the Board and by the conflicts committee of the Board. The conflicts committee engaged an independent financial advisor and legal counsel. In accordance with the May 2017 Purchase and Sale Agreement, Shell Chemical has agreed to reimburse us for costs and expenses incurred in connection with the conversion of a section of pipe from the Convent refinery to Sorrento from refinery gas service to butane service. The May 2017 Purchase and Sale Agreement contains other customary representations, warranties and covenants. In connection with the May 2017 Purchase and Sale Agreement, we granted Shell Chemical a purchase option and right of first refusal with respect to Refinery Gas Pipeline and certain other related assets and the ownership interests in Sand Dollar. The purchase option may be triggered by, among other things, (i) a third party obtaining the right to use any or all of Refinery Gas Pipeline; (ii) the loss of all volume on Refinery Gas Pipeline that would result in it being permanently shutdown for two Refinery Gas Pipeline impacted by such event. In addition, in the event that Sand Dollar receives an offer to sell all or a portion of Refinery Gas Pipeline or the ownership interests in Sand Dollar from a third party, Shell Chemical has a right of first refusal with respect to such Refinery Gas Pipeline or ownership interests, as applicable, for so long as the Refinery Gas Pipeline Agreement between Shell Chemical and Sand Dollar is in effect. In connection with the May 2017 Acquisition, we acquired historical carrying value of property, plant and equipment, net and other assets under common control as follows: Delta $ 40 Na Kika 26 Refinery Gas Pipeline 135 May 2017 Acquisition $ 201 We recognized $429 million of consideration in excess of the book value of net assets acquired as a capital distribution to our general partner in accordance with our policy for common control transactions. For the period from closing through December 31, 2017, we recognized $64 million in revenues and $29 million of net earnings related to this acquisition. 2017 Divestiture On April 28, 2017, Zydeco divested a small segment of its pipeline system (the “April 2017 Divestiture”) to SOPUS as part of the Motiva JV separation. The April 2017 Divestiture closed pursuant to a Pipeline Sale and Purchase Agreement (the “April 2017 Pipeline Sale and Purchase Agreement”) dated April 28, 2017 among Zydeco and SOPUS. We received $21 million in cash consideration for this sale, of which $19 million is attributable to the Partnership. The cash consideration represents $1 million for the book value of net assets divested and $20 million in excess proceeds received from our Parent. The April 2017 Pipeline Sale and Purchase Agreement contained customary representations and warranties and indemnification by SOPUS.

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2019
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions Related party transactions include transactions with SPLC and Shell, including those entities in which Shell has an ownership interest but does not have control. Acquisition Agreements Refer to Note 3 — Acquisitions and Divestiture for a description of applicable agreements. Omnibus Agreement On November 3, 2014, we entered into an Omnibus Agreement with SPLC and our general partner concerning our payment of an annual general and administrative services fee to SPLC as well as our reimbursement of certain costs incurred by SPLC on our behalf. On February 19, 2019, we, our general partner, SPLC, the Operating Company and Shell Oil Company terminated the Omnibus Agreement effective as of February 1, 2019, and we, our general partner, SPLC and the Operating Company entered into a new Omnibus Agreement effective February 1, 2019 (the “2019 Omnibus Agreement”). The 2019 Omnibus Agreement addresses, among other things, the following matters: • our payment of an annual general and administrative fee of approximately $11 million for the provision of certain services by SPLC; • our obligation to reimburse SPLC for certain direct or allocated costs and expenses incurred by SPLC on our behalf; and • our obligation to reimburse SPLC for all expenses incurred by SPLC as a result of us becoming and continuing as a publicly traded entity; we will reimburse our general partner for these expenses to the extent the fees relating to such services are not included in the general and administrative fee. Under the 2019 Omnibus Agreement, SPLC agreed to indemnify us against tax liabilities relating to assets acquired at our initial public offering (such offering, the “IPO,” and such assets “initial assets”) that are identified prior to the date that is 60 days after the expiration of the statute of limitations applicable to such liabilities. This obligation has no threshold or cap. We in turn agreed to indemnify SPLC against events and conditions associated with the ownership or operation of our initial assets (other than any liabilities against which SPLC is specifically required to indemnify us as described above). During 2019 and 2018, neither we nor SPLC made any claims for indemnification under the 2019 Omnibus Agreement. Trade Marks License Agreement We, our general partner and SPLC entered into a Trade Marks License Agreement with Shell Trademark Management Inc. effective as of February 1, 2019. The Trade Marks License Agreement grants us the use of certain Shell trademarks and trade names and expires on January 1, 2024 unless earlier terminated by either party upon 360 days’ notice. Tax Sharing Agreement We have entered into a tax sharing agreement with Shell. Pursuant to this agreement, we have agreed to reimburse Shell for state and local income and franchise taxes attributable to any activity of our operating subsidiaries and reported on Shell’s state or local income or franchise tax returns filed on a combined or unitary basis. Reimbursements under this agreement equal the amount of tax our applicable operating subsidiaries would be required to pay with respect to such activity, if such subsidiaries were to file a combined or unitary tax return separate from Shell. Shell will compute and invoice us for the tax reimbursement amount within 15 days of Shell filing its combined or unitary tax return on which such activity is included. We may be required to make prepayments toward the tax reimbursement amount to the extent that Shell is required to make estimated tax payments during the relevant tax year. The tax sharing agreement currently in place is effective for all taxable periods ending on or after December 31, 2017. The current agreement replaced a similar tax sharing agreement between Zydeco and Shell, which was effective for all tax periods ending before December 31, 2017. Reimbursements settled in the years ended December 31, 2019, 2018 and 2017 were not material to our consolidated statements of income. Other Agreements In connection with the IPO and our acquisitions from Shell, we have entered into several customary agreements with SPLC and Shell. These agreements include pipeline operating agreements, reimbursement agreements and services agreements. Pecten Contribution Agreement Maintenance expense and capital expenditures for certain projects associated with the Lockport Terminal were reimbursed by SPLC under the Pecten Contribution Agreement entered into in connection with the acquisition in November 2015. During 2019, 2018 and 2017, we recognized no reimbursement as other contributions from Parent and we do not expect any further reimbursements. Operating Agreements On December 1, 2019, we entered into an Operating and Administrative Management Agreement with SPLC (the “2019 Operating Agreement”). Pursuant to the 2019 Operating Agreement, SPLC provides certain operations, maintenance and administrative services for the assets wholly owned by Pecten, Sand Dollar and Triton (collectively, the “Owners”). The Owners are required to reimburse SPLC for certain costs in connection with the services that SPLC provides pursuant to the 2019 Operating Agreement. SPLC and the Owners each provide standard indemnifications as operator and asset owners, respectively. Upon entering into the 2019 Operating Agreement, certain operating agreements previously entered into between SPLC and each of the Owners were terminated. In connection with the December 2017 Acquisition, we were assigned an operating agreement for Odyssey, whereby SPLC performs physical operations and maintenance services and provides general and administrative services for Odyssey. Odyssey is required to reimburse SPLC for costs and expenses incurred in connection with such services. Also pursuant to the agreement, SPLC and Odyssey agree to standard indemnifications as operator and asset owner, respectively. Beginning July 1, 2014, Zydeco entered into an operating and management agreement with SPLC under which SPLC provides general management and administrative services to us. Therefore, we do not receive allocated corporate expenses from SPLC or Shell under this agreement. We receive direct and allocated field and regional expenses including payroll expenses not covered under this agreement. Partnership Agreement On December 21, 2018, we executed the Second Amendment (the “Second Amendment”) to the Partnership’s First Amended and Restated Agreement of Limited Partnership dated November 3, 2014. Under the Second Amendment, our sponsor agreed to waive $50 million of distributions in 2019 by agreeing to reduce distributions to holders of the incentive distribution rights by: (1) $17 million for the three months ended March 31, 2019, (2) $17 million for the three months ended June 30, 2019 and (3) $16 million for the three months ended September 30, 2019. Noncontrolling Interests For Zydeco, noncontrolling interest consists of SPLC’s 7.5% retained ownership interest as of December 31, 2019, 2018 and 2017. For Odyssey, noncontrolling interest consists of GEL Offshore Pipeline LLC’s (“GEL”) 29.0% retained ownership interest as of December 31, 2019, 2018 and 2017. Other Related Party Balances Other related party balances consist of the following: December 31, 2019 2018 Accounts receivable $ 29 $ 29 Prepaid expenses 15 15 Other assets 2 3 Accounts payable (1) 10 9 Deferred revenue — 3 Accrued liabilities (2) 19 16 Debt payable (3) 2,692 2,091 (1) Accounts payable reflects amounts owed to SPLC for reimbursement of third-party expenses incurred by SPLC for our benefit. (2) As of December 31, 2019, Accrued liabilities reflects $18 million accrued interest and $1 million other accrued liabilities . As of December 31, 2018, Accrued liabilities reflects $14 million accrued interest and $2 million other accrued liabilities. (3) Debt payable reflects borrowings outstanding net of unamortized debt issuance costs of $2 million as of December 31, 2019 and $3 million as of December 31, 2018. Related Party Credit Facilities We have entered into five credit facilities with STCW: the Ten Seven Five Five Five Note 8 — Related Party Debt for definitions and additional information regarding these credit facilities. Related Party Revenues and Expenses We provide crude oil transportation, terminaling and storage services to related parties under long-term contracts. We entered into these contracts in the normal course of our business. Our revenue from related parties for 2019, 2018 and 2017 is disclosed in Note 12 — Revenue Recognition . The following table shows related party expenses, including personnel costs, incurred by Shell and SPLC on our behalf that are reflected in the accompanying consolidated statements of income for the indicated periods. Included in these amounts, and disclosed below, is our share of operating and general corporate expenses, as well as the fees paid to SPLC under certain agreements. 2019 2018 2017 Allocated operating expenses $ 18 $ 15 $ 17 Insurance expense (1) 18 15 8 Other (2) 23 24 21 Operations and maintenance – related parties $ 59 $ 54 $ 46 Allocated general corporate expenses $ 28 $ 33 $ 26 Management Agreement fee 9 9 8 Omnibus Agreement fee 11 9 9 Other 1 1 5 General and administrative – related parties $ 49 $ 52 $ 48 (1) The majority of our insurance coverage is provided by a wholly owned subsidiary of Shell. The remaining coverage is provided by third-party insurers. (2) Other expenses primarily relate to salaries and wages and other payroll expenses. For a discussion of services performed by Shell on our behalf, see Note 1 — Description of Business and Basis of Presentation – Basis of Presentation . Pension and Retirement Savings Plans Employees who directly or indirectly support our operations participate in the pension, postretirement health and life insurance and defined contribution benefit plans sponsored by Shell, which include other Shell subsidiaries. Our share of pension and postretirement health and life insurance costs for 2019, 2018 and 2017 was $6 million, $6 million and $4 million, respectively. Our share of defined contribution benefit plan costs for 2019, 2018 and 2017 was $2 million, $3 million and $2 million, respectively. Pension and defined contribution benefit plan expenses are included in either General and administrative – related parties or Operations and maintenance – related parties in the accompanying consolidated statements of income, depending on the nature of the employee’s role in our operations. Share-based Compensation Certain SPLC and Shell employees supporting our operations as well as other Shell operations were historically granted awards under the Performance Share Plan (“PSP”), Shell’s incentive compensation program. Share-based compensation expense is included in General and administrative – related parties in the accompanying consolidated statements of income. These costs for 2019, 2018 and 2017 were not material. Equity and Other Investments We have equity and other investments in various entities. As of December 31, 2019, SPLC no longer owns an interest in any of these entities. In some cases we may be required to make capital contributions or other payments to these entities. See Note 5 — Equity Method Investments for additional details. Reimbursements from Our General Partner The following table reflects reimbursements from our Parent in 2019, 2018 and 2017: 2019 2018 2017 Cash reimbursements received (1) $ 19 $ 12 $ 16 (1) These reimbursements are included in Other contributions from Parent in the accompanying consolidated statements of cash flows and consolidated statements of (deficit) equity. In 2019, 2018 and 2017, we filed claims for reimbursement from our Parent of $19 million, $12 million and $16 million, respectively. This reflects our proportionate share of Zydeco directional drill project costs and expenses of $10 million, $12 million and $14 million, respectively. Additionally, in 2017 this included reimbursement for the Refinery Gas Pipeline gas to butane service connection project of $2 million. Further, in the fourth quarter of 2019, we received approximately $9 million from SPLC with respect to a Mars storage revenue reimbursement provision contained in the Purchase and Sale Agreement entered into in 2016 that was recognized as an additional capital contribution. See Note 5 — Equity Method Investments for additional details.

Equity Method Investments

Equity Method Investments	12 Months Ended
	Dec. 31, 2019
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	Equity Method Investments For each of the following investments, we have the ability to exercise significant influence over these investments based on certain governance provisions and our participation in the significant activities and decisions that impact the management and economic performance of the investments. Equity method investments comprise the following as of the dates indicated: December 31, 2019 2018 Ownership Amount Ownership Amount Amberjack – Series A / Series B (1) 75.0% / 50.0% $ 426 75.0% / 50.0% $ 458 Mars 71.5% 161 71.5% 169 Bengal 50.0% 88 50.0% 82 Permian Basin 50.0% 91 50.0% 72 LOCAP 41.48% 9 41.48% 8 Explorer (2) 38.59% 88 12.62% — Poseidon 36.0% — 36.0% — Colonial (2) 16.125% 30 6.0% — Proteus 10.0% 15 10.0% 16 Endymion 10.0% 18 10.0% 18 $ 926 $ 823 ( 1 ) We acquired an interest in Amberjack in the May 2018 Acquisition. The acquisition of this interest has been accounted for prospectively. (2) As part of the June 2019 Acquisition, these interests have been accounted for prospectively. See below for additional information. We acquired an additional 25.97% interest in Explorer and an additional 10.125% interest in Colonial in the June 2019 Acquisition. As a result, these investments now qualify for equity method accounting as we have the ability to exercise significant influence over these investments as of the acquisition date. Prior to the acquisition date, Explorer and Colonial were accounted for as Other investments without readily determinable fair values and were therefore carried at cost. Upon acquisition, we added our Parent ’ s historical carrying value of the equity interests transferred as a transaction between entities under common control, totaling $90 million, to the basis of our previously held interests of $60 million as this is the date these investments qualified for equity method accounting. Since the June 2019 Acquisition, we record distributions from these investments as reductions to the respective equity method investment balances for Explorer and Colonial as these amounts are no longer considered dividend income due to the change in the method of accounting. We recognize equity earnings for both Explorer and Colonial prospectively from the date of acquisition. Unamortized differences in the basis of the initial investments and our interest in the separate net assets within the financial statements of the investees are amortized into net income over the remaining useful lives of the underlying assets. As of December 31, 2019, 2018 and 2017, the unamortized basis differences included in our equity method investments are $92 million, $40 million and $41 million, respectively. For the years ended 2019, 2018 and 2017, the net amortization expense was $6 million, $4 million and $4 million, respectively, which is included in Income from equity method investments. During the first quarter of 2018, the investment amount for Poseidon was reduced to zero due to distributions received that were in excess of our investment balance and we, therefore, suspended the equity method of accounting. As we have no commitments to provide further financial support to Poseidon, we have recorded excess distributions of $33 million and $24 million in Other income for the years ended December 31, 2019 and 2018, respectively. Once our cumulative share of equity earnings becomes greater than the cumulative amount of distributions received, we will resume the equity method of accounting as long as the equity method investment balance remains greater than zero. Income from our equity method investments were as follows during the periods indicated: For the Year Ended December 31, 2019 2018 2017 Amberjack (1) $ 125 $ 80 $ — Mars (2) 126 108 122 Bengal 24 21 23 Explorer (3) 41 — — Colonial (3) 40 — — Poseidon (4) — 6 27 Other (5) 17 20 15 $ 373 $ 235 $ 187 (1) We acquired an interest in Amberjack in the May 2018 Acquisition. The acquisition of this interest has been accounted for prospectively. (2) We acquired an additional 22.9% interest in Mars in the December 2017 Acquisition. The acquisition of this interest was retrospectively adjusted for the incremental ownership acquired. (3) As stated above, we acquired additional interests in Explorer and Colonial in the June 2019 Acquisition. The acquisition of these interests has been accounted for prospectively. (4) As stated above, the equity method of accounting has been suspended in 2018 for Poseidon and excess distributions are recorded in Other income. (5) Included in Other is the activity associated with our investments in Permian Basin, LOCAP, Proteus and Endymion. We acquired a 41.48% interest in LOCAP in the December 2017 Acquisition. The adoption of the revenue standard (as defined in Note 12 — Revenue Recognition ) for the majority of our equity method investments followed the non-public business entity adoption date of January 1, 2019 for their stand-alone financial statements, with the exception of Mars and Permian Basin, which both adopted on January 1, 2018. As a result of adopting the revenue standard under the modified retrospective transition method on January 1, 2019 and 2018 by Amberjack and Mars, respectively, we recognized our proportionate share of each investment’s cumulative effect transition adjustment increasing the opening deficit in the amounts of $9 million and $7 million, respectively. The Amberjack adjustment is related to its dedication and transportation agreements, which contain tiered pricing arrangements resulting in a deferral of revenue. The Mars adjustment related to its transportation and dedication agreement and method of recognition as a stand-ready obligation, which resulted in a deferral of the recognition of revenue over the life of the contract, whereas under previous GAAP revenue was recognized upon physical delivery. The adoption of the revenue standard by our other equity method investments was not material. Under the new lease standard (as defined in Note 9 — Leases ), the adoption date for our equity method investments will follow the non-public business entity adoption date of January 1, 2020 or 2021 for their stand-alone financial statements, with the exception of Permian Basin, which adopted on January 1, 2019. On October 23, 2019, we entered into a Settlement Agreement with SPLC (the “Settlement Agreement”) with respect to the storage revenue reimbursement provision contained in the Purchase and Sale Agreement entered into in 2016 under which we acquired an additional 20% interest in Mars. As a result of the Settlement Agreement, we received approximately $9 million during the fourth quarter of 2019 from SPLC that was recognized as an additional capital contribution. Pursuant to the Purchase and Sale Agreement, SPLC agreed to pay us up to $10 million if Mars inventory management fees do not meet certain levels for the calendar years 2017 through 2021. Summarized Financial Information The following tables present aggregated selected balance sheet and income statement data for our equity method investments on a 100% basis. However, during periods in which an acquisition occurs, the selected balance sheet and income statement data reflects activity from the date of the acquisition. For the Year Ended December 31, 2019 Total revenues Total operating expenses Operating income Net income Statements of Income Amberjack 315 73 242 243 Mars 282 104 178 179 Bengal 77 30 47 47 Explorer (1) 258 115 143 111 Colonial (2) 829 449 380 255 Poseidon 132 35 97 87 Other (3) 190 108 82 73 As of December 31, 2019 Current assets Non-current assets Total assets Current liabilities Non-current liabilities Equity (deficit) Total liabilities and equity (deficit) Balance Sheets Amberjack $ 56 $ 804 $ 860 $ 4 $ 32 $ 824 $ 860 Mars 57 173 230 8 22 200 230 Bengal 35 157 192 6 — 186 192 Explorer 93 530 623 44 442 137 623 Colonial 323 2,920 3,243 519 2,873 (149) 3,243 Poseidon 30 190 220 16 246 (42) 220 Other (3) 60 917 977 73 469 435 977 (1) Our interest in Explorer was acquired on June 6, 2019. Explorer total revenues, total operating expenses and operating income (on a 100% basis) was $443 million, $196 million and $247 million, respectively. (2) Our interest in Colonial was acquired on June 6, 2019. Colonial total revenues, total operating expenses and operating income (on a 100% basis) was $1,437 million, $735 million and $702 million, respectively. (3) Included in Other is the activity associated with our investments in Permian Basin, LOCAP, Proteus and Endymion. For the Year Ended December 31, 2018 Total revenues Total operating expenses Operating income Net income Statements of Income Amberjack (1) 204 47 157 157 Mars 241 87 154 154 Bengal 69 28 41 41 Poseidon 116 35 81 73 Other (2) 152 67 85 76 As of December 31, 2018 Current assets Non-current assets Total assets Current liabilities Non-current liabilities Equity (deficit) Total liabilities and equity (deficit) Balance Sheets Amberjack (1) $ 46 $ 846 $ 892 $ 4 $ 4 $ 884 $ 892 Mars 53 178 231 5 18 208 231 Bengal 27 156 183 9 — 174 183 Poseidon 19 203 222 16 243 (37) 222 Other (2) 50 876 926 65 456 405 926 (1) Our interest in Amberjack was acquired on May 11, 2018. Amberjack total revenues, total operating expenses and operating income (on a 100% basis) was $295 million, $74 million and $221 million, respectively. (2) Included in Other is the activity associated with our investments in Permian Basin, LOCAP, Proteus and Endymion. For the Year Ended December 31, 2017 Total revenues Total operating expenses Operating income Net income Statements of Income Mars 256 82 174 174 Bengal 73 28 45 45 Poseidon 117 33 84 79 Other (1) 124 46 78 66 As of December 31, 2017 Current assets Non-current assets Total assets Current liabilities Non-current liabilities Equity (deficit) Total liabilities and equity (deficit) Balance Sheets Mars $ 48 $ 187 $ 235 $ 5 $ — $ 230 $ 235 Bengal 25 157 182 11 — 171 182 Poseidon 19 218 237 18 237 (18) 237 Other (1) 92 625 717 99 245 373 717 (1) Included in Other is the activity associated with our investments in Permian Basin, LOCAP, Proteus and Endymion. Interest in Permian Basin was acquired by us on October 17, 2017 and is pro rated in above table. For the year ended December 31, 2017, Permian Basin total revenue, total operating expenses and operating income (on a 100% basis) was $8 million, $5 million and $3 million, respectively. Capital Contributions We make capital contributions for our pro rata interest in Permian Basin to fund capital and other expenditures. We made capital contributions to Permian Basin of $25 million and $28 million in 2019 and 2018, respectively.

Property, Plant and Equipment

Property, Plant and Equipment	12 Months Ended
	Dec. 31, 2019
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, Plant and Equipment Property, plant and equipment, net consists of the following as of the dates indicated: December 31, Depreciable Life 2019 2018 Land — $ 11 $ 11 Building and improvements 10 - 40 years 40 39 Pipeline and equipment (1) 10 - 30 years 1,228 1,162 Other 5 - 25 years 33 18 1,312 1,230 Accumulated depreciation and amortization (2) (613) (567) 699 663 Construction in progress 27 79 Property, plant and equipment, net $ 726 $ 742 (1) As of December 31, 2019 and 2018, includes cost of $369 million and $366 million, respectively, related to assets under operating leases (as lessor), which commenced in May 2017 and December 2017. As of both December 31, 2019 and 2018, includes cost of $23 million related to assets under capital lease (as lessee). (2) As of December 31, 2019 and 2018, includes accumulated depreciation of $133 million and $121 million, respectively, related to assets under operating leases (as lessor), which commenced in May 2017 and December 2017. As of December 31, 2019 and 2018, includes accumulated depreciation of $6 million and $5 million, respectively, related to assets under capital lease (as lessee).

Accrued Liabilities - Third Par

Accrued Liabilities - Third Parties	12 Months Ended
	Dec. 31, 2019
Payables and Accruals [Abstract]
Accrued Liabilities – Third Parties	Accrued Liabilities – Third Parties Accrued liabilities – third parties consist of the following as of the dates indicated: December 31, 2019 2018 Project accruals $ 5 $ 7 Property taxes 4 4 Other accrued liabilities 3 2 Total accrued liabilities – third parties $ 12 $ 13 See Note 4 — Related Party Transactions for a discussion of Accrued liabilities – related parties.

Related Party Debt

Related Party Debt	12 Months Ended
	Dec. 31, 2019
Debt Disclosure [Abstract]
Related Party Debt	Related Party Debt Consolidated related party debt obligations comprise the following as of the dates indicated: December 31, 2019 December 31, 2018 Outstanding Balance Total Capacity Available Capacity Outstanding Balance Total Capacity Available Capacity Ten Year Fixed Facility $ 600 $ 600 $ — $ — $ — $ — Seven Year Fixed Facility 600 600 — 600 600 — Five Year Revolver due July 2023 494 760 266 494 760 266 Five Year Revolver due December 2022 400 1,000 600 400 1,000 600 Five Year Fixed Facility 600 600 — 600 600 — 2019 Zydeco Revolver (1) — 30 30 — 30 30 Unamortized debt issuance costs (2) n/a n/a (3) n/a n/a Debt payable – related party $ 2,692 $ 3,590 $ 896 $ 2,091 $ 2,990 $ 896 (1) Effective August 6, 2019, the Zydeco Revolver expired. In its place, Zydeco entered into the 2019 Zydeco Revolver. See below for additional information. Interest and fee expenses associated with our borrowings, net of capitalized interest, were $92 million, $61 million and $29 million for 2019, 2018 and 2017, respectively, of which we paid $88 million, $53 million and $25 million, respectively. Borrowings under our revolving credit facilities approximate fair value as the interest rates are variable and reflective of market rates, which results in Level 2 instruments. The fair value of our fixed rate credit facilities is estimated based on the published market prices for issuances of similar risk and tenor and is categorized as Level 2 within the fair value hierarchy. As of December 31, 2019, the carrying amount and estimated fair value of total debt (before amortization of issuance costs) was $2,694 million and $2,825 million, respectively. As of December 31, 2018, the carrying amount and estimated fair value of total debt (before amortization of issuance costs) was $2,094 million and $2,099 million, respectively. The Ten The Seven Year Fixed Facility was fully drawn on August 1, 2018 and the borrowings were used to partially repay borrowings under the Five Year Revolver due December 2022. On May 11, 2018, we funded the May 2018 Acquisition with $494 million in borrowings under the Five Year Revolver due July 2023 and $726 million in borrowings under the Five Year Revolver due December 2022. On February 6, 2018, we used net proceeds from sales of common units and from our general partner’s proportionate capital contribution to repay $247 million of borrowings outstanding under our Five Year Revolver due July 2023 and $726 million of borrowings outstanding under our Five Year Revolver due December 2022. On December 1, 2017, we borrowed $1,000 million under the Five Year Revolver due December 2022 and $93 million under our Five On September 15, 2017, we used net proceeds from sales of common units to third parties to repay $265 million of borrowings outstanding under our Five Year Revolver due July 2023. On May 10, 2017, we funded the May 2017 Acquisition with $50 million of cash on hand, $73 million in borrowings under our Five Year Revolver due July 2023 and $507 million in borrowings under our Five Year Fixed Facility. Credit Facility Agreements Ten On June 4, 2019, we entered into a ten Ten Ten Seven On July 31, 2018, we entered into a seven Seven Seven The Seven Five On August 1, 2018, we amended and restated the five year revolving credit facility originally due October 2019 such that the facility will now mature on July 31, 2023 (the “Five Year Revolver due July 2023”). The Five a borrowing capacity of $760 million and will continue to bear interest at LIBOR plus a margin and we continue to pay interest of 0.19% on any unused capacity. Commitment fees began to accrue beginning on the date we entered into the agreement. As of December 31, 2019, the annualized weighted average interest rate for the Five The Five Five Year Revolver due December 2022 On December 1, 2017, we entered into a five year revolving credit facility with STCW (the “Five Year Revolver due December 2022”) with a borrowing capacity of $1,000 million and paid an issuance fee of $2 million. Borrowings under the Five Year Revolver due December 2022 bear interest at the three-month LIBOR rate plus a margin, or, in the alternative, the percentage rate per annum which is the rate notified to us by STCW in accordance with the terms of the Five Year Revolver due December 2022 as soon as practicable and in any event before interest is due to be paid in respect of a loan . Additionally, we pay interest of 0.19% on any unused capacity. As of December 31, 2019, the weighted average interest rate for the Five Year Revolver due December 2022 was 3.76%. Commitment fees began to accrue beginning on the date we entered into the agreement. The Five Year Revolver due December 2022 matures on December 1, 2022. Five Year Fixed Facility On March 1, 2017, we entered into a Loan Facility Agreement with STCW with a borrowing capacity of $600 million (the “ Five Five The Five Five Zydeco Revolving Credit Facility Agreement On August 6, 2019, the Zydeco Revolver expired. On August 1, 2019, Zydeco entered into a senior unsecured revolving loan facility agreement with STCW, effective August 6, 2019 (the “2019 Zydeco Revolver”). The 2019 Zydeco Revolver has a borrowing capacity of $30 million and matures on August 6, 2024. Borrowings under the credit facility bear interest at the three-month LIBOR rate plus a margin, or, in certain instances, including if LIBOR is discontinued, STCW may specify another benchmark rate generally accepted in the loan market to apply in relation to the advances in place of LIBOR. No issuance fee was incurred in connection with the 2019 Zydeco Revolver. As of December 31, 2019, the interest rate for the 2019 Zydeco Revolver was 2.59%. Covenants Under the Ten Five • agreed to restrict additional indebtedness not loaned by STCW; • to give the applicable facility pari passu ranking with any new indebtedness; and • to refrain from securing our assets except as agreed with STCW. These facilities also contain customary events of default, such as nonpayment of principal, interest and fees when due and violation of covenants, as well as cross-default provisions under which a default under one credit facility may trigger an event of default in another facility with the same borrower. Any breach of covenants included in our debt agreements which could result in our related party lender demanding payment of the unpaid principal and interest balances will have a material adverse effect upon us and would likely require us to seek to renegotiate these debt arrangements with our related party lender and/or obtain new financing from other sources. As of December 31, 2019, we were in compliance with the covenants contained in the Ten Seven Five Five Five Borrowings and repayments under our credit facilities for 2019, 2018 and 2017 are disclosed in our consolidated statements of cash flows. See Note 3 — Acquisitions and Divestiture for additional information regarding our use of borrowings. See Note 11 — (Deficit) Equity

Leases

Leases	12 Months Ended
	Dec. 31, 2019
Leases [Abstract]
Leases	Leases Adoption of ASC Topic 842 “Leases” On January 1, 2019, we adopted ASC Topic 842 (the “new lease standard”) by applying the modified retrospective approach to all leases on January 1, 2019. We elected the package of practical expedients upon transition that permits us to not reassess (1) whether any contracts entered into prior to adoption are or contain leases, (2) the lease classification of existing leases and (3) initial direct costs for any leases that existed prior to adoption. We also elected the practical expedient to not evaluate existing or expired land easements that were not accounted for as leases under previous guidance. Generally, we account for term-based land easements where we control the use of the land surface as leases. Upon adoption on January 1, 2019, we recognized operating lease right-of-use (“ROU”) assets and corresponding lease liabilities of $5 million. As lessor, the accounting for operating leases has not changed and the adoption did not have an impact on our existing transportation and terminaling services agreements that are considered operating leases. As lessee, the accounting for finance leases (capital leases) was substantially unchanged. Lessee accounting We determine if an arrangement is or contains a lease at inception. Our assessment is based on (1) whether the contract involves the use of a distinct identified asset, (2) whether we obtain the right to substantially all the economic benefit from the use of the asset throughout the period and (3) whether we have the right to direct the use of the asset. Leases are classified as either finance leases or operating leases. A lease is classified as a finance lease if any one of the following criteria are met: the lease transfers ownership of the asset by the end of the lease term, the lease contains an option to purchase the asset that is reasonably certain to be exercised, the lease term is for a major part of the remaining useful life of the asset or the present value of the lease payments equals or exceeds substantially all of the fair value of the asset. A lease is classified as an operating lease if it does not meet any one of these criteria. The lease classification affects the expense recognition in the income statement. Operating lease costs are recorded entirely in operating expenses. Finance lease costs are split, where amortization of the ROU asset is recorded in operating expenses and an implied interest component is recorded in interest expense. Under the new lease standard, operating leases (as lessee) are included in Operating lease right-of-use assets, Accrued liabilities - third parties and Operating lease liabilities in our consolidated balance sheets. Finance leases (as lessee) are included in Property, plant and equipment, Accrued liabilities – third parties and Finance lease liabilities in our consolidated balance sheets. ROU assets and lease liabilities are recognized at commencement date based on the present value of the future minimum lease payments over the lease term. As most of our leases do not provide an implicit interest rate, we use our incremental borrowing rate based on the information available at transition date in determining the present value of future payments. The ROU asset includes any lease payments made but excludes lease incentives and initial direct costs incurred, if any. Lease expense for minimum lease payments is recognized on a straight-line basis over the lease term. We have long-term non-cancelable third-party operating leases for land. Several of the leases provide for renewal terms. We hold cancellable easements or rights-of-way arrangements from landowners permitting the use of land for the construction and operation of our pipeline systems. Obligations under these easements are not material to the results of our operations. In addition, Odyssey has a third-party operating lease for use of offshore platform space at Main Pass 289C. This lease will continue to be in effect until the continued operation of the platform is uneconomic. We are also obligated under two finance leases. We have a terminaling services agreement in which we took possession of certain storage tanks located in Port Neches, Texas and a lease of offshore platform space on the Garden Banks 128 “A” platform. Lease extensions. Many of our leases have options to either extend or terminate the lease. In determining the lease term, we considered all available contract extensions that are reasonably certain of occurring. Significant assumptions and judgments Incremental borrowing rate. We are generally not made aware of the interest rate implicit in a lease due to several reasons, including: (1) uncertainty as to the total amount of the costs incurred by the lessor in negotiating the lease or whether certain costs incurred by the lessor would qualify as initial direct costs and (2) uncertainty as to the lessor’s expectation of the residual value of the asset at the end of the lease. Therefore, we use our incremental borrowing rate (“IBR”) at the commencement of the lease and estimate the IBR for each lease agreement taking into consideration lease contract term, collateral and entity credit ratings, and use sensitivity analyses to evaluate the reasonableness of the rates determined. Lease balances and costs The following tables summarize balance sheet data related to leases at December 31, 2019 and our lease costs as of and for the year ended December 31, 2019 : Leases Classification December 31, 2019 Assets Operating lease assets Operating lease right-of-use assets $ 4 Finance lease assets Property, plant and equipment, net (1) 17 Total lease assets $ 21 Liabilities Current Finance Accrued liabilities - third parties $ 1 Noncurrent Operating Operating lease liabilities 4 Finance Finance lease liabilities 24 Total lease liabilities $ 29 (1) Finance lease assets are recorded net of accumulated amortization of $6 million as of December 31, 2019. Lease cost Classification December 31, 2019 Operating lease cost (1) Operations and maintenance - third parties $ — Finance lease cost (cost resulting from lease payments): Amortization of leased assets Depreciation and amortization 1 Interest on lease liabilities Interest expense, net 4 Total lease cost $ 5 (1) Amounts for the year ended December 31, 2019 were less than $1 million. Other information December 31, 2019 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases (1) $ — Operating cash flows from finance leases (4) Financing cash flows from finance leases (1) (1) Amounts for the year ended December 31, 2019 were less than $1 million. December 31, 2019 Weighted-average remaining lease term (years): Operating leases 20 Finance leases 11 Weighted-average discount rate: Operating leases 5.8 % Finance leases 14.3 % Annual maturity analysis The future annual maturity of lease payments as of December 31, 2019 for the above lease obligations was: Maturity of lease liabilities Operating Leases (1) Finance Leases (2) Total 2020 $ — $ 4 $ 4 2021 1 4 5 2022 — 4 4 2023 1 4 5 2024 — 5 5 Remainder 6 31 37 Total lease payments 8 52 60 Less: Interest (3) (4) (27) (31) Present value of lease liabilities (4) $ 4 $ 25 $ 29 (1) Operating lease payments include $2 million related to options to extend lease terms that are reasonably certain of being exercised. (2) Includes $25 million in principal and excludes $9 million in executory costs. (3) Calculated using the interest rate for each lease. (4) Includes the current portion of $1 million for the finance lease. Lessor accounting We have certain transportation and terminaling services agreements with related parties entered into prior to the adoption date of January 1, 2019 that are considered operating leases and include both lease and non-lease components. Certain of these agreements were entered into for terms of ten years with the option to extend for two additional terms of five years each, and we have additional agreements with an initial term of ten years with the option to extend for up to ten additional one year terms. As is the case with certain of our agreements, when the renewal options are reasonably certain to be exercised, the payments are included in the future maturity of lease payments. Our transportation, terminaling and storage services revenue and lease revenue from related parties for the years ended December 31, 2019 and 2018 are disclosed in Note 12 — Revenue Recognition . Our risk management strategy for the residual assets is mitigated by the long-term nature of the underlying assets and the long-term nature of our lease agreements. Significant assumptions and judgments Lease and non-lease components. Certain of our revenues are accounted for under Topic 842, Leases , as the underlying contracts convey the right to control the use of the identified asset for a period of time. We allocate the arrangement consideration between the lease components that fall within the scope of ASC Topic 842 and any non-lease service components within the scope of ASC Topic 606 based on the relative stand-alone selling price of each component. See Note 12 — Revenue Recognition for additional information regarding the allocation of the consideration in a contract between the lease and non-lease components. Annual maturity analysis As of December 31, 2019, future annual maturity of lease payments to be received under the contract terms of these operating leases, which includes only the lease components of these leases, was estimated to be: Maturity of lease payments Operating leases (1) 2020 $ 56 2021 56 2022 56 2023 56 2024 56 Remainder 551 Total lease payments $ 831 (1) Operating lease payments include $411 million related to options to extend lease terms that are reasonably certain of being exercised. Other As of December 31, 2019 and 2018, we had short-term payment obligations relating to capital expenditures totaling $5 million and $8 million, respectively. These represent unconditional payment obligations to vendors for products and services delivered in connection with capital projects.
Leases	Leases Adoption of ASC Topic 842 “Leases” On January 1, 2019, we adopted ASC Topic 842 (the “new lease standard”) by applying the modified retrospective approach to all leases on January 1, 2019. We elected the package of practical expedients upon transition that permits us to not reassess (1) whether any contracts entered into prior to adoption are or contain leases, (2) the lease classification of existing leases and (3) initial direct costs for any leases that existed prior to adoption. We also elected the practical expedient to not evaluate existing or expired land easements that were not accounted for as leases under previous guidance. Generally, we account for term-based land easements where we control the use of the land surface as leases. Upon adoption on January 1, 2019, we recognized operating lease right-of-use (“ROU”) assets and corresponding lease liabilities of $5 million. As lessor, the accounting for operating leases has not changed and the adoption did not have an impact on our existing transportation and terminaling services agreements that are considered operating leases. As lessee, the accounting for finance leases (capital leases) was substantially unchanged. Lessee accounting We determine if an arrangement is or contains a lease at inception. Our assessment is based on (1) whether the contract involves the use of a distinct identified asset, (2) whether we obtain the right to substantially all the economic benefit from the use of the asset throughout the period and (3) whether we have the right to direct the use of the asset. Leases are classified as either finance leases or operating leases. A lease is classified as a finance lease if any one of the following criteria are met: the lease transfers ownership of the asset by the end of the lease term, the lease contains an option to purchase the asset that is reasonably certain to be exercised, the lease term is for a major part of the remaining useful life of the asset or the present value of the lease payments equals or exceeds substantially all of the fair value of the asset. A lease is classified as an operating lease if it does not meet any one of these criteria. The lease classification affects the expense recognition in the income statement. Operating lease costs are recorded entirely in operating expenses. Finance lease costs are split, where amortization of the ROU asset is recorded in operating expenses and an implied interest component is recorded in interest expense. Under the new lease standard, operating leases (as lessee) are included in Operating lease right-of-use assets, Accrued liabilities - third parties and Operating lease liabilities in our consolidated balance sheets. Finance leases (as lessee) are included in Property, plant and equipment, Accrued liabilities – third parties and Finance lease liabilities in our consolidated balance sheets. ROU assets and lease liabilities are recognized at commencement date based on the present value of the future minimum lease payments over the lease term. As most of our leases do not provide an implicit interest rate, we use our incremental borrowing rate based on the information available at transition date in determining the present value of future payments. The ROU asset includes any lease payments made but excludes lease incentives and initial direct costs incurred, if any. Lease expense for minimum lease payments is recognized on a straight-line basis over the lease term. We have long-term non-cancelable third-party operating leases for land. Several of the leases provide for renewal terms. We hold cancellable easements or rights-of-way arrangements from landowners permitting the use of land for the construction and operation of our pipeline systems. Obligations under these easements are not material to the results of our operations. In addition, Odyssey has a third-party operating lease for use of offshore platform space at Main Pass 289C. This lease will continue to be in effect until the continued operation of the platform is uneconomic. We are also obligated under two finance leases. We have a terminaling services agreement in which we took possession of certain storage tanks located in Port Neches, Texas and a lease of offshore platform space on the Garden Banks 128 “A” platform. Lease extensions. Many of our leases have options to either extend or terminate the lease. In determining the lease term, we considered all available contract extensions that are reasonably certain of occurring. Significant assumptions and judgments Incremental borrowing rate. We are generally not made aware of the interest rate implicit in a lease due to several reasons, including: (1) uncertainty as to the total amount of the costs incurred by the lessor in negotiating the lease or whether certain costs incurred by the lessor would qualify as initial direct costs and (2) uncertainty as to the lessor’s expectation of the residual value of the asset at the end of the lease. Therefore, we use our incremental borrowing rate (“IBR”) at the commencement of the lease and estimate the IBR for each lease agreement taking into consideration lease contract term, collateral and entity credit ratings, and use sensitivity analyses to evaluate the reasonableness of the rates determined. Lease balances and costs The following tables summarize balance sheet data related to leases at December 31, 2019 and our lease costs as of and for the year ended December 31, 2019 : Leases Classification December 31, 2019 Assets Operating lease assets Operating lease right-of-use assets $ 4 Finance lease assets Property, plant and equipment, net (1) 17 Total lease assets $ 21 Liabilities Current Finance Accrued liabilities - third parties $ 1 Noncurrent Operating Operating lease liabilities 4 Finance Finance lease liabilities 24 Total lease liabilities $ 29 (1) Finance lease assets are recorded net of accumulated amortization of $6 million as of December 31, 2019. Lease cost Classification December 31, 2019 Operating lease cost (1) Operations and maintenance - third parties $ — Finance lease cost (cost resulting from lease payments): Amortization of leased assets Depreciation and amortization 1 Interest on lease liabilities Interest expense, net 4 Total lease cost $ 5 (1) Amounts for the year ended December 31, 2019 were less than $1 million. Other information December 31, 2019 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases (1) $ — Operating cash flows from finance leases (4) Financing cash flows from finance leases (1) (1) Amounts for the year ended December 31, 2019 were less than $1 million. December 31, 2019 Weighted-average remaining lease term (years): Operating leases 20 Finance leases 11 Weighted-average discount rate: Operating leases 5.8 % Finance leases 14.3 % Annual maturity analysis The future annual maturity of lease payments as of December 31, 2019 for the above lease obligations was: Maturity of lease liabilities Operating Leases (1) Finance Leases (2) Total 2020 $ — $ 4 $ 4 2021 1 4 5 2022 — 4 4 2023 1 4 5 2024 — 5 5 Remainder 6 31 37 Total lease payments 8 52 60 Less: Interest (3) (4) (27) (31) Present value of lease liabilities (4) $ 4 $ 25 $ 29 (1) Operating lease payments include $2 million related to options to extend lease terms that are reasonably certain of being exercised. (2) Includes $25 million in principal and excludes $9 million in executory costs. (3) Calculated using the interest rate for each lease. (4) Includes the current portion of $1 million for the finance lease. Lessor accounting We have certain transportation and terminaling services agreements with related parties entered into prior to the adoption date of January 1, 2019 that are considered operating leases and include both lease and non-lease components. Certain of these agreements were entered into for terms of ten years with the option to extend for two additional terms of five years each, and we have additional agreements with an initial term of ten years with the option to extend for up to ten additional one year terms. As is the case with certain of our agreements, when the renewal options are reasonably certain to be exercised, the payments are included in the future maturity of lease payments. Our transportation, terminaling and storage services revenue and lease revenue from related parties for the years ended December 31, 2019 and 2018 are disclosed in Note 12 — Revenue Recognition . Our risk management strategy for the residual assets is mitigated by the long-term nature of the underlying assets and the long-term nature of our lease agreements. Significant assumptions and judgments Lease and non-lease components. Certain of our revenues are accounted for under Topic 842, Leases , as the underlying contracts convey the right to control the use of the identified asset for a period of time. We allocate the arrangement consideration between the lease components that fall within the scope of ASC Topic 842 and any non-lease service components within the scope of ASC Topic 606 based on the relative stand-alone selling price of each component. See Note 12 — Revenue Recognition for additional information regarding the allocation of the consideration in a contract between the lease and non-lease components. Annual maturity analysis As of December 31, 2019, future annual maturity of lease payments to be received under the contract terms of these operating leases, which includes only the lease components of these leases, was estimated to be: Maturity of lease payments Operating leases (1) 2020 $ 56 2021 56 2022 56 2023 56 2024 56 Remainder 551 Total lease payments $ 831 (1) Operating lease payments include $411 million related to options to extend lease terms that are reasonably certain of being exercised. Other As of December 31, 2019 and 2018, we had short-term payment obligations relating to capital expenditures totaling $5 million and $8 million, respectively. These represent unconditional payment obligations to vendors for products and services delivered in connection with capital projects.
Leases	Leases Adoption of ASC Topic 842 “Leases” On January 1, 2019, we adopted ASC Topic 842 (the “new lease standard”) by applying the modified retrospective approach to all leases on January 1, 2019. We elected the package of practical expedients upon transition that permits us to not reassess (1) whether any contracts entered into prior to adoption are or contain leases, (2) the lease classification of existing leases and (3) initial direct costs for any leases that existed prior to adoption. We also elected the practical expedient to not evaluate existing or expired land easements that were not accounted for as leases under previous guidance. Generally, we account for term-based land easements where we control the use of the land surface as leases. Upon adoption on January 1, 2019, we recognized operating lease right-of-use (“ROU”) assets and corresponding lease liabilities of $5 million. As lessor, the accounting for operating leases has not changed and the adoption did not have an impact on our existing transportation and terminaling services agreements that are considered operating leases. As lessee, the accounting for finance leases (capital leases) was substantially unchanged. Lessee accounting We determine if an arrangement is or contains a lease at inception. Our assessment is based on (1) whether the contract involves the use of a distinct identified asset, (2) whether we obtain the right to substantially all the economic benefit from the use of the asset throughout the period and (3) whether we have the right to direct the use of the asset. Leases are classified as either finance leases or operating leases. A lease is classified as a finance lease if any one of the following criteria are met: the lease transfers ownership of the asset by the end of the lease term, the lease contains an option to purchase the asset that is reasonably certain to be exercised, the lease term is for a major part of the remaining useful life of the asset or the present value of the lease payments equals or exceeds substantially all of the fair value of the asset. A lease is classified as an operating lease if it does not meet any one of these criteria. The lease classification affects the expense recognition in the income statement. Operating lease costs are recorded entirely in operating expenses. Finance lease costs are split, where amortization of the ROU asset is recorded in operating expenses and an implied interest component is recorded in interest expense. Under the new lease standard, operating leases (as lessee) are included in Operating lease right-of-use assets, Accrued liabilities - third parties and Operating lease liabilities in our consolidated balance sheets. Finance leases (as lessee) are included in Property, plant and equipment, Accrued liabilities – third parties and Finance lease liabilities in our consolidated balance sheets. ROU assets and lease liabilities are recognized at commencement date based on the present value of the future minimum lease payments over the lease term. As most of our leases do not provide an implicit interest rate, we use our incremental borrowing rate based on the information available at transition date in determining the present value of future payments. The ROU asset includes any lease payments made but excludes lease incentives and initial direct costs incurred, if any. Lease expense for minimum lease payments is recognized on a straight-line basis over the lease term. We have long-term non-cancelable third-party operating leases for land. Several of the leases provide for renewal terms. We hold cancellable easements or rights-of-way arrangements from landowners permitting the use of land for the construction and operation of our pipeline systems. Obligations under these easements are not material to the results of our operations. In addition, Odyssey has a third-party operating lease for use of offshore platform space at Main Pass 289C. This lease will continue to be in effect until the continued operation of the platform is uneconomic. We are also obligated under two finance leases. We have a terminaling services agreement in which we took possession of certain storage tanks located in Port Neches, Texas and a lease of offshore platform space on the Garden Banks 128 “A” platform. Lease extensions. Many of our leases have options to either extend or terminate the lease. In determining the lease term, we considered all available contract extensions that are reasonably certain of occurring. Significant assumptions and judgments Incremental borrowing rate. We are generally not made aware of the interest rate implicit in a lease due to several reasons, including: (1) uncertainty as to the total amount of the costs incurred by the lessor in negotiating the lease or whether certain costs incurred by the lessor would qualify as initial direct costs and (2) uncertainty as to the lessor’s expectation of the residual value of the asset at the end of the lease. Therefore, we use our incremental borrowing rate (“IBR”) at the commencement of the lease and estimate the IBR for each lease agreement taking into consideration lease contract term, collateral and entity credit ratings, and use sensitivity analyses to evaluate the reasonableness of the rates determined. Lease balances and costs The following tables summarize balance sheet data related to leases at December 31, 2019 and our lease costs as of and for the year ended December 31, 2019 : Leases Classification December 31, 2019 Assets Operating lease assets Operating lease right-of-use assets $ 4 Finance lease assets Property, plant and equipment, net (1) 17 Total lease assets $ 21 Liabilities Current Finance Accrued liabilities - third parties $ 1 Noncurrent Operating Operating lease liabilities 4 Finance Finance lease liabilities 24 Total lease liabilities $ 29 (1) Finance lease assets are recorded net of accumulated amortization of $6 million as of December 31, 2019. Lease cost Classification December 31, 2019 Operating lease cost (1) Operations and maintenance - third parties $ — Finance lease cost (cost resulting from lease payments): Amortization of leased assets Depreciation and amortization 1 Interest on lease liabilities Interest expense, net 4 Total lease cost $ 5 (1) Amounts for the year ended December 31, 2019 were less than $1 million. Other information December 31, 2019 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases (1) $ — Operating cash flows from finance leases (4) Financing cash flows from finance leases (1) (1) Amounts for the year ended December 31, 2019 were less than $1 million. December 31, 2019 Weighted-average remaining lease term (years): Operating leases 20 Finance leases 11 Weighted-average discount rate: Operating leases 5.8 % Finance leases 14.3 % Annual maturity analysis The future annual maturity of lease payments as of December 31, 2019 for the above lease obligations was: Maturity of lease liabilities Operating Leases (1) Finance Leases (2) Total 2020 $ — $ 4 $ 4 2021 1 4 5 2022 — 4 4 2023 1 4 5 2024 — 5 5 Remainder 6 31 37 Total lease payments 8 52 60 Less: Interest (3) (4) (27) (31) Present value of lease liabilities (4) $ 4 $ 25 $ 29 (1) Operating lease payments include $2 million related to options to extend lease terms that are reasonably certain of being exercised. (2) Includes $25 million in principal and excludes $9 million in executory costs. (3) Calculated using the interest rate for each lease. (4) Includes the current portion of $1 million for the finance lease. Lessor accounting We have certain transportation and terminaling services agreements with related parties entered into prior to the adoption date of January 1, 2019 that are considered operating leases and include both lease and non-lease components. Certain of these agreements were entered into for terms of ten years with the option to extend for two additional terms of five years each, and we have additional agreements with an initial term of ten years with the option to extend for up to ten additional one year terms. As is the case with certain of our agreements, when the renewal options are reasonably certain to be exercised, the payments are included in the future maturity of lease payments. Our transportation, terminaling and storage services revenue and lease revenue from related parties for the years ended December 31, 2019 and 2018 are disclosed in Note 12 — Revenue Recognition . Our risk management strategy for the residual assets is mitigated by the long-term nature of the underlying assets and the long-term nature of our lease agreements. Significant assumptions and judgments Lease and non-lease components. Certain of our revenues are accounted for under Topic 842, Leases , as the underlying contracts convey the right to control the use of the identified asset for a period of time. We allocate the arrangement consideration between the lease components that fall within the scope of ASC Topic 842 and any non-lease service components within the scope of ASC Topic 606 based on the relative stand-alone selling price of each component. See Note 12 — Revenue Recognition for additional information regarding the allocation of the consideration in a contract between the lease and non-lease components. Annual maturity analysis As of December 31, 2019, future annual maturity of lease payments to be received under the contract terms of these operating leases, which includes only the lease components of these leases, was estimated to be: Maturity of lease payments Operating leases (1) 2020 $ 56 2021 56 2022 56 2023 56 2024 56 Remainder 551 Total lease payments $ 831 (1) Operating lease payments include $411 million related to options to extend lease terms that are reasonably certain of being exercised. Other As of December 31, 2019 and 2018, we had short-term payment obligations relating to capital expenditures totaling $5 million and $8 million, respectively. These represent unconditional payment obligations to vendors for products and services delivered in connection with capital projects.

Accumulated Other Comprehensive

Accumulated Other Comprehensive Loss	12 Months Ended
	Dec. 31, 2019
Equity [Abstract]
Accumulated Other Comprehensive Loss	Accumulated Other Comprehensive LossAs a result of the June 2019 Acquisition, we recorded an accumulated other comprehensive loss related to pension and other post-retirement benefits provided by Explorer and Colonial to their employees. We are not a sponsor of these benefits plans. The June 2019 Acquisition is accounted for as a transaction between entities under common control on a prospective basis and we have recorded the acquisition on our consolidated balance sheet at SPLC’s historical basis which included accumulated other comprehensive loss. In 2019, we recorded $2 million in other comprehensive loss related to remeasurements related to these pension and other post-retirement benefits.

(Deficit) Equity

(Deficit) Equity	12 Months Ended
	Dec. 31, 2019
Equity [Abstract]
(Deficit) Equity	(Deficit) Equity Our capital accounts are comprised of a 2% general partner interests and 98% limited partner interests. The common units represent limited partner interests in us. The holders of common units, both public and SPLC, are entitled to participate in partnership distributions and have limited rights of ownership as provided for under our partnership agreement. Our general partner participates in our distributions and also currently holds IDRs that entitle it to receive increasing percentages of the cash we distribute from operating surplus. Shelf Registrations We have a universal shelf registration statement on Form S-3 on file with the SEC under which we, as a well-known seasoned issuer, have the ability to issue and sell an indeterminate amount of common units and partnership securities representing limited partner units. We also have on file with the SEC a shelf registration statement on Form S-3 relating to $1,000,000,000 of common units and partnership securities representing limited partner units to be used in connection with the at-the-market equity distribution program, direct sales or other sales consistent with the plan of distribution set forth in the registration statement. Public Offerings and Private Placement On February 6, 2018, we completed the sale of 25,000,000 common units in a registered public offering for $673 million net proceeds ($680 million gross proceeds, or $27.20 per common unit, less $6 million of underwriter’s fees and $1 million of transaction fees). In connection with the issuance of common units, we issued 510,204 general partner units to our general partner for $14 million in order to maintain its 2% general partner interest in us. On February 6, 2018, we also completed the sale of 11,029,412 common units in a private placement with Shell Midstream LP Holdings LLC for an aggregate purchase price of $300 million, or $27.20 per common unit. In connection with the issuance of the common units, we issued 225,091 general partner units to the general partner for $6 million in order to maintain its 2% general partner interest in us. We used net proceeds from these sales to repay $247 million of borrowings outstanding under the Five Five On September 15, 2017, we completed the sale of 5,170,000 common units in a registered public offering for $135 million net proceeds. In connection with the issuance of common units, we issued 105,510 general partner units to our general partner for $3 million in order to maintain its 2% general partner interest in us. We used the net proceeds from these sales of common units and from our general partner’s proportionate capital contribution to repay borrowings outstanding under the Five Year Revolver due July 2023 and for general partnership purposes. At-the-Market Program We have an “at-the-market” equity distribution program pursuant to which we may issue and sell common units for up to $300 million in gross proceeds. During both the years ended December 31, 2019 and 2018, we did not have any sales under this program. During the quarter ended September 30, 2017, we completed the sale of 5,200,000 common units under this program for $140 million net proceeds (an average price of $26.96 per common unit). In connection with the issuance of the common units, we issued 106,122 general partner units to our general partner for $3 million in order to maintain its 2% general partner interest in us. We used the net proceeds from these sales of common units and from our general partner’s proportionate capital contribution to repay borrowings outstanding under the Five During the quarter ended June 30, 2017, we completed the sale of 94,925 common units under this program for $3 million net proceeds (an average price of $31.51 per common unit). In connection with the issuance of the common units, we issued 1,938 general partner units to our general partner in order to maintain its 2% general partner interest in us. We used proceeds from these sales of common units and from our general partner’s proportionate capital contribution for general partnership purposes. Other than as described above, we did not have any other sales under this program during 2019, 2018 or 2017. Units Outstanding As of December 31, 2019, we had 233,289,537 common units outstanding, of which 123,832,233 were publicly owned. SPLC owned 109,457,304 common units representing an aggregate 46% limited partner interest in us, all of the IDRs, and 4,761,012 general partner units, representing a 2% general partner interest in us. The changes in the number of units outstanding from December 31, 2017 through December 31, 2019 are as follows: (in units) Public SPLC General Total Balance as of December 31, 2017 98,832,233 88,950,136 3,832,293 191,614,662 Units issued in connection with equity offerings 25,000,000 11,029,412 735,295 36,764,707 Balance as of December 31, 2018 123,832,233 99,979,548 4,567,588 228,379,369 June 2019 Acquisition — 9,477,756 193,424 9,671,180 Balance as of December 31, 2019 123,832,233 109,457,304 4,761,012 238,050,549 Expiration of Subordination Period On February 15, 2017, all of the subordinated units converted into common units following the payment of the cash distribution for the fourth quarter of 2016. Each of our 67,475,068 outstanding subordinated units converted into one common unit. The converted units will participate pro rata with the other common units in distributions of available cash. The conversion of the subordinated units does not impact the amount of cash distributions paid by us or the total number of outstanding units. Distributions to our Unitholders Under the Second Amendment, our sponsor elected to waive $50 million of IDRs in 2019 to be used for future investment by the Partnership. See Note 4 — Related Party Transactions for terms of the Second Amendment. The following table details the distributions declared and/or paid for the periods presented: Date Paid or to be Paid Three Months Ended Public Common SPLC Common SPLC Subordinated General Partner Distributions per Limited Partner Unit IDRs 2% Total (in millions, except per unit amounts) February 14, 2017 December 31, 2016 $ 25 $ 6 $ 18 $ 9 $ 1 $ 59 $ 0.27700 May 12, 2017 March 31, 2017 26 26 — 11 1 64 0.29100 August 14, 2017 June 30, 2017 27 27 — 13 1 68 0.30410 November 14, 2017 September 30, 2017 31 28 — 16 2 77 0.31800 February 14, 2018 December 31, 2017 33 30 — 18 2 83 0.33300 May 15, 2018 March 31, 2018 43 35 — 26 2 106 0.34800 August 14, 2018 June 30, 2018 46 36 — 29 2 113 0.36500 November 14, 2018 September 30, 2018 47 38 — 33 3 121 0.38200 February 14, 2019 December 31, 2018 49 40 — 37 3 129 0.40000 May 15, 2019 March 30, 2019 (1) 51 42 — 23 3 119 0.41500 August 14, 2019 June 30, 2019 (1) 53 47 — 28 3 131 0.43000 November 14, 2019 September 30, 2019 (1) 56 48 — 33 3 140 0.44500 February 14, 2020 December 31, 2019 (2) 57 50 — 52 3 162 0.46000 (1) Includes the impact of waived distributions to the holders of IDRs. See Note 4 — Related Party Transactions for additional information. (2) See Note 16 — Subsequent Events for additional information. . Distributions to Noncontrolling Interests Distributions to SPLC for its noncontrolling interest in Zydeco were $4 million, $7 million and $9 million in 2019, 2018 and 2017, respectively. Distributions to GEL for its noncontrolling interest in Odyssey were $13 million, $9 million and $10 million in 2019, 2018 and 2017, respectively. See Note 4 — Related Party Transactions for additional details.

Revenue Recognition

Revenue Recognition	12 Months Ended
	Dec. 31, 2019
Revenue from Contract with Customer [Abstract]
Revenue Recognition	Revenue Recognition Adoption of ASC Topic 606 “ Revenue from Contracts with Customers ” On January 1, 2018, we adopted Topic 606 and all related ASUs to this Topic (collectively, the “revenue standard”) by applying the modified retrospective method to all contracts that were not completed on January 1, 2018. Results for reporting periods beginning after January 1, 2018 are presented in accordance with the revenue standard, while prior period amounts are not adjusted and continue to be reported in accordance with our historic accounting under previous GAAP. Upon the adoption of the revenue standard, we recorded a non-cash cumulative effect transition adjustment to decrease opening deficit by $5 million, with the impact primarily due to the earlier recognition of revenue related to deficiency payments under minimum volume commitment contracts. As a result of adopting the revenue standard under the modified retrospective transition method on January 1, 2019 and 2018 by Amberjack and Mars, respectively, we recognized our proportionate share of each investment’s cumulative effect transition adjustment increasing the opening deficit in the amounts of $9 million and $7 million, respectively. See Note 5 — Equity Method Investments for additional information. These adjustments resulted in a total net increase to our total opening deficit of $9 million and $2 million in 2019 and 2018, respectively. Revenue Recognition The revenue standard’s core principle is that a company will recognize revenue when it transfers promised goods or services to customers in an amount that reflects the consideration to which the company expects to be entitled in exchange for those goods or services. The revenue standard requires entities to recognize revenue through the application of a five-step model, which includes: identification of the contract; identification of the performance obligations; determination of the transaction price; allocation of the transaction price to the performance obligations; and recognition of revenue as the entity satisfies the performance obligations. Our revenues are primarily generated from the transportation, terminaling and storage of crude oil, refinery gas and refined petroleum products through our pipelines, terminals and storage tanks. To identify the performance obligations, we considered all the products or services promised in the contracts with customers, whether explicitly stated or implied based on customary business practices. Revenue is recognized when each performance obligation is satisfied under the terms of the contract. Each barrel of product transported or day of services provided is considered a distinct service that represents a performance obligation that would be satisfied over time if it were accounted for separately. The services provided over the contract period are a series of distinct services that are substantially the same, have the same pattern of transfer to the customer, and therefore, qualify as a single performance obligation. Since the customer simultaneously receives and consumes the benefits of services, we recognize revenue over time based on a measure of progress of volumes transported for transportation services contracts or number of days elapsed for storage and terminaling services contracts. Product revenue related to allowance oil sales is recognized at the point in time when the control of the oil transfers to the customer. For all performance obligations, payment is typically due in full within 30 days of the invoice date. Disaggregation of Revenue The following table provides information about disaggregated revenue by service type and customer type: 2019 2018 2017 (1) Transportation services revenue – third parties $ 134 $ 200 $ 227 Transportation services revenue – related parties (2) 210 176 172 Storage services revenue – third parties 9 9 9 Storage services revenue – related parties 7 7 6 Terminaling services revenue – related parties (3) 47 46 — Product revenue – third parties (4) 5 2 — Product revenue – related parties (4) 35 29 — Total Topic 606 revenue 447 469 414 Lease revenue – related parties 56 56 56 Total revenue $ 503 $ 525 $ 470 (1) As noted above, prior period amounts have not been adjusted under the modified retrospective method. (2) Transportation services revenue — related parties for both 2019 and 2018 includes $5 million of non-lease component in our transportation services contract. (3) Terminaling services revenue for 2019 and 2018 is entirely comprised of the non-lease service component in our terminaling services contracts. (4) Product revenue for 2019 and 2018 is comprised of allowance oil sales. Transportation services revenue We have both long-term transportation contracts and month-to-month contracts for spot shippers that make nominations on our pipelines. Some of the long-term contracts entitle the customer to a specified amount of guaranteed capacity on the pipeline. Transportation services are charged at a per barrel rate or other applicable unit of measure. We apply the allocation exception guidance for variable consideration related to market indexing for long-term transportation contracts because (a) the variable payment relates specifically to our efforts to transfer the distinct service and (b) we allocate the variable amount of consideration entirely to the distinct service which is consistent with the allocation objective. Except for guaranteed capacity payments as discussed below, transportation services are billed monthly as services are rendered. Our contracts and tariffs contain terms for the customer to reimburse us for losses from evaporation or other loss in transit in the form of allowance oil. Allowance oil represents the net difference between the tariff PLA volumes and the actual volumetric losses. We obtain control of the excess oil not lost during transportation, if any. Under the revenue standard, we include the excess oil retained during the period, if any, as non-cash consideration and include this amount in the transaction price for transportation services on a net basis. Our allowance oil revenue is valued at the average market price of the relevant type of crude oil during the month product was transported. Gains from pipeline operations that relate to allowance oil are recorded in Operations and maintenance expenses in the accompanying consolidated statements of income. As a result of FERC regulations, revenues we collect may be subject to refund. We establish reserves for these potential refunds based on actual expected refund amounts on the specific facts and circumstances. We had no reserves for potential refunds as of December 31, 2019 and 2018. Deferred revenue Our FERC-approved transportation services agreements on Zydeco entitle the customer to a specified amount of guaranteed capacity on the pipeline. This capacity cannot be pro rated even if the pipeline is oversubscribed. In exchange, the customer makes a specified monthly payment regardless of the volume transported. If the customer does not ship its full guaranteed volume in a given month, it makes the full monthly cash payment (i.e., deficiency payments) and it may ship the unused volume in a later month for no additional cash payment for up to 12 months, subject to availability on the pipeline. The cash payment received is recognized as deferred revenue, a contract liability under the revenue standard. If there is insufficient capacity on the pipeline to allow the unused volume to be shipped, the customer forfeits its right to ship such unused volume. We do not refund any cash payments relating to unused volumes. Prior to January 1, 2018, deferred revenue under these arrangements was previously recognized into revenue once all contingencies or potential performance obligations associated with the related volumes had been satisfied or expired. Under the revenue standard, we are required to estimate the likelihood that unused volumes will be shipped or forfeited at each reporting period based on additional data that becomes available and only to the extent that it is probable that a significant reversal of revenue will not occur. In some cases, this estimate could result in the earlier recognition of revenue. Storage and terminaling services revenue Storage and terminaling services are provided under short-term and long-term contracts, with a fixed price per month for committed storage and terminaling capacity, or under a monthly spot-rate for uncommitted storage or terminaling. Since the customer simultaneously receives and consumes the benefits of services, we recognize revenue over time based on the number of days elapsed. We apply the allocation exception guidance for variable consideration related to market indexing for long-term contracts because (a) the variable payment relates specifically to our efforts to transfer the distinct service and (b) we allocate the variable amount of consideration entirely to the distinct service which is consistent with the allocation objective. Storage and terminaling services are billed monthly as services are rendered. Reimbursements from customers Under certain transportation, terminaling and storage service contracts, we receive reimbursements from customers to recover costs of construction, maintenance or operating costs either under a tariff surcharge per volume shipped or under separate reimbursement payments. Because we consider these amounts as consideration from customers associated with ongoing services to be provided to customers, we defer these payments in deferred revenue and recognize amounts in revenue over the life of the associated revenue contract as performance obligations are satisfied under the contract. We consider these payments to be revenue because control of the long-lived assets does not transfer to our customer upon completion. Our financial statements were not materially impacted by adoption of the revenue standard related to reimbursements from customers. Lease revenue Certain of our long-term transportation and terminaling services contracts with related parties are accounted for as operating leases under Topic 840, Leases. These agreements have both a lease component and an implied operation and maintenance service component (“non-lease service component”). We allocate the arrangement consideration between the lease components that fall within the scope of Topic 840 and any non-lease service components within the scope of the revenue standard based on the relative stand-alone selling price of each component. We estimate the stand-alone selling price of the lease and non-lease service components based on an analysis of service-related and lease-related costs for each contract, adjusted for a representative profit margin. The contracts have a minimum fixed monthly payment for both the lease and non-lease service components. We present the non-lease service components under the revenue standard within Transportation, terminaling and storage services – related parties in the consolidated statement of income. Revenues from the lease components of these agreements are recorded within Lease revenue – related parties in the consolidated statement of income. Certain of these agreements were each entered into for terms of ten years, with the option to extend for two additional five one ten Total Less than 1 year Years 2 to 3 Years 4 to 5 More than 5 years Operating leases $ 838 $ 110 $ 219 $ 219 $ 290 Product revenue We generate revenue by selling accumulated allowance oil inventory to customers. Sale of allowance oil is recorded as product revenue, with specific cost based on a weighted average price per barrel recorded as cost of product sold. Prior to the adoption of the revenue standard, allowance oil received was recorded as revenue on a gross basis with the resulting actual gain or loss recorded in operations and maintenance expenses. The subsequent sale of allowance oil, net of the product cost, was recorded as operations and maintenance expenses. Joint tariff Under a certain joint tariff, revenues were historically recorded on a net basis as an agent prior to the adoption of the revenue standard. However, subsequent to the adoption of the revenue standard, because we control the transportation service before it is transferred to the customer, we are the principal and, therefore, record revenues from these agreements on a gross basis within Transportation, terminaling and storage services – third parties or related parties. Impact of adoption In accordance with the revenue standard, the following tables summarize the impact of adoption on our consolidated financial statements as of and for both the years ended December 31, 2019 and 2018: 2019 Consolidated Statement of Income As Reported Under Topic 606 Amounts Without Adoption of Topic 606 Effect of Change Increase/(Decrease) Revenue Transportation, terminaling and storage services – third parties $ 143 $ 142 $ 1 Transportation, terminaling and storage services – related parties 264 215 49 Product revenue – third parties 5 — 5 Product revenue – related parties 35 — 35 Lease revenue – related parties 56 108 (52) Costs and expenses Operations and maintenance – third parties 65 64 1 Operations and maintenance – related parties 59 58 1 Cost of product sold – third parties 5 — 5 Cost of product sold – related parties 31 — 31 Net income $ 546 $ 546 $ — December 31, 2019 Consolidated Balance Sheet As Reported Under Topic 606 Amounts Without Adoption of Topic 606 Effect of Change Increase/(Decrease) Deferred revenue – related party $ — $ — $ — 2018 Consolidated Statement of Income As Reported Under Topic 606 Amounts Without Adoption of Topic 606 Effect of Change Increase/(Decrease) Revenue Transportation, terminaling and storage services – third parties $ 209 $ 209 $ — Transportation, terminaling and storage services – related parties 229 183 46 Product revenue – third parties 2 — 2 Product revenue – related parties 29 — 29 Lease revenue – related parties 56 107 (51) Costs and expenses Operations and maintenance – third parties 108 107 1 Operations and maintenance – related parties 54 52 2 Cost of product sold – third parties 7 6 1 Cost of product sold – related parties 25 — 25 Net income $ 482 $ 487 $ (5) December 31, 2018 Consolidated Balance Sheet As Reported Under Topic 606 Amounts Without Adoption of Topic 606 Effect of Change Increase/(Decrease) Deferred revenue – related party $ 3 $ 3 $ — Contract Balances We perform our obligations under a contract with a customer by providing services in exchange for consideration from the customer. The timing of our performance may differ from the timing of the customer’s payment, which results in the recognition of a contract asset or a contract liability. Although we did not have any contract assets as of December 31, 2019 and 2018, we recognize a contract asset when we transfer goods or services to a customer and contractually bill an amount which is less than the revenue allocated to the related performance obligation. We recognize deferred revenue (contract liability) when the customer’s payment of consideration precedes our performance. The following table provides information about receivables and contract liabilities from contracts with customers: January 1, 2019 December 31, 2019 Receivables from contracts with customers – third parties $ 19 $ 11 Receivables from contracts with customers – related parties 21 24 Deferred revenue – third parties 8 — Deferred revenue – related party 3 — January 1, 2018 December 31, 2018 Receivables from contracts with customers – third parties $ 17 $ 19 Receivables from contracts with customers – related parties 19 21 Deferred revenue – third parties 6 8 Deferred revenue – related party 9 3 Significant changes in the deferred revenue balances with customers during the period are as follows: December 31, 2018 Transition Adjustment Additions (1) Reductions (2) December 31, 2019 Deferred revenue – third parties $ 8 $ — $ — $ (8) $ — Deferred revenue – related party 3 — — (3) — (1) Contract liability additions resulted from deficiency payments from minimum volume commitment contracts. (2) Contract liability reductions resulted from revenue earned through the actual or estimated use and expiration of deficiency credits. December 31, 2017 Transition Adjustment Additions (1) Reductions (2) December 31, 2018 Deferred revenue – third parties $ 6 $ — $ 10 $ (8) $ 8 Deferred revenue – related party 14 (4) 3 (10) 3 (1) Contract liability additions resulted from deficiency payments from minimum volume commitment contracts. (2) Contract liability reductions resulted from revenue earned through the actual or estimated use and expiration of deficiency credits. We currently have no assets recognized from the costs to obtain or fulfill a contract as of both December 31, 2019 and 2018. Remaining Performance Obligations As of December 31, 2019, contracts with remaining performance obligations primarily include minimum volume commitment contracts, long-term storage contracts and the service component of transportation and terminaling services contracts accounted for as operating leases. The following table includes revenue expected to be recognized in the future related to performance obligations exceeding one year of their initial terms that are unsatisfied or partially unsatisfied as of December 31, 2019: Total 2020 2021 2022 2023 2024 and beyond Revenue expected to be recognized on multi-year committed shipper transportation contracts $ 577 $ 106 $ 63 $ 63 $ 63 $ 282 Revenue expected to be recognized on other multi-year transportation service contracts (1) 40 5 5 5 5 20 Revenue expected to be recognized on multi-year storage service contracts 21 4 4 4 4 5 Revenue expected to be recognized on multi-year terminaling service contracts (1) 378 48 48 48 48 186 Total $ 1,016 $ 163 $ 120 $ 120 $ 120 $ 493 (1) Relates to the non-lease service components of certain of our long-term transportation and terminaling service contracts which are accounted for as operating leases. As an exemption, we do not disclose the amount of remaining performance obligations for contracts with an original expected duration of one year or less or for variable consideration that is allocated entirely to a wholly unsatisfied promise to transfer a distinct service that forms part of a single performance obligation.

Net Income Per Limited Partner

Net Income Per Limited Partner Unit	12 Months Ended
	Dec. 31, 2019
Partners' Capital Notes [Abstract]
Net Income Per Limited Partner Unit	Net Income Per Limited Partner Unit Net income per unit applicable to common limited partner units is computed by dividing the respective limited partners’ interest in net income attributable to the Partnership for the period by the weighted average number of common units outstanding for the period. Because we have more than one class of participating securities, we use the two-class method when calculating the net income per unit applicable to limited partners. The classes of participating securities include common units, general partner units and IDRs. Basic and diluted net income per unit are the same because we do not have any potentially dilutive units outstanding for the periods presented. Net income earned by the Partnership is allocated between the limited partners and the general partner (including IDRs) in accordance with our partnership agreement. Earnings are allocated based on actual cash distributions declared to our unitholders, including those attributable to IDRs. To the extent net income attributable to the Partnership exceeds or is less than cash distributions, this difference is allocated based on the unitholders’ respective ownership percentages. Our net income includes earnings related to businesses acquired through transactions between entities under common control for periods prior to their acquisition by us. We have allocated these pre-acquisition earnings to our general partner. The following tables show the allocation of net income attributable to the Partnership to arrive at net income per limited partner unit: 2019 2018 2017 Net income $ 546 $ 482 $ 392 Less: Net income attributable to the Parent — — 77 Net income attributable to noncontrolling interests 18 18 20 Net income attributable to the Partnership 528 464 295 Less: General partner’s distribution declared (1) 148 135 64 Limited partners’ distribution declared on common units 404 334 228 Income (less than)/in excess of distributions $ (24) $ (5) $ 3 (1) For 2019, this includes the impact of waived distributions to the holders of IDRs. See Note 4 — Related Party Transactions for additional information. 2019 General Partner Limited Partners’ Common Units Total (in millions of dollars, except per unit data) Distributions declared (1) $ 148 $ 404 $ 552 Distributions in excess of income (1) (23) (24) Net income attributable to the Partnership $ 147 $ 381 $ 528 Weighted average units outstanding: Basic and diluted 229.2 Net income per limited partner unit: Basic and diluted $ 1.66 (1) This includes the impact of waived distributions to the holders of IDRs. See Note 4 — Related Party Transactions for additional information. 2018 General Partner Limited Partners’ Common Units Total (in millions of dollars, except per unit data) Distributions declared $ 135 $ 334 $ 469 Distributions in excess of income (1) (4) (5) Net income attributable to the Partnership $ 134 $ 330 $ 464 Weighted average units outstanding: Basic and diluted 220.3 Net income per limited partner unit: Basic and diluted $ 1.50 2017 General Partner Limited Partners’ Common Units Total (in millions of dollars, except per unit data) Distributions declared $ 64 $ 228 $ 292 Income in excess of distributions — 3 3 Net income attributable to the Partnership $ 64 $ 231 $ 295 Weighted average units outstanding: Basic and diluted 180.4 Net income per limited partner unit: Basic and diluted $ 1.28

Transactions with Major Custome

Transactions with Major Customers and Concentration of Credit Risk	12 Months Ended
	Dec. 31, 2019
Risks and Uncertainties [Abstract]
Transactions with Major Customers and Concentration of Credit Risk	Transactions with Major Customers and Concentration of Credit Risk Our Parent and its affiliates accounted for approximately 70%, 60% and 50% of our total revenues for 2019, 2018 and 2017, respectively. There is no third party customer that accounted for a 10% or greater share of consolidated revenues or net accounts receivable for the year ended December 31, 2019. We have a concentration of revenues and trade receivables due from customers in the same industry, our Parent’s affiliates, integrated oil companies, marketers, and independent exploration, production and refining companies primarily within the Gulf Coast region of the United States. These concentrations of customers may impact our overall exposure to credit risk as they may be similarly affected by changes in economic, regulatory, regional and other factors. We are potentially exposed to concentration of credit risk primarily through our accounts receivable with our Parent. These receivables have payment terms of 30 days or less, and there has been no history of collectability issues. We monitor the creditworthiness of third-party major customers. We manage our exposure to credit risk through credit analysis, credit limit approvals and monitoring procedures, and for certain transactions, we may request letters of credit, prepayments or guarantees. As of December 31, 2019 and 2018, there were no such arrangements with customers.

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2019
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Environmental Matters We are subject to federal, state and local environmental laws and regulations. We routinely conduct reviews of potential environmental issues and claims that could impact our assets or operations. These reviews assist us in identifying environmental issues and estimating the costs and timing of remediation efforts. In making environmental liability estimations, we consider the material effect of environmental compliance, pending legal actions against us and potential third-party liability claims. Often, as the remediation evaluation and effort progresses, additional information is obtained, requiring revisions to estimated costs. These revisions are reflected in our income in the period in which they are probable and reasonably estimable. For both December 31, 2019 and 2018, these costs and any related liabilities are not material. Proceedings We are named defendants in lawsuits and governmental proceedings that arise in the ordinary course of our business. For each of our outstanding legal matters, we evaluate the merits of the case, our exposure to the matter, possible legal or settlement strategies and the likelihood of an unfavorable outcome. While there are still uncertainties related to the ultimate costs we may incur, based upon our evaluation and experience to date, we do not expect that the ultimate resolution of these matters will have a material adverse effect on our financial position, operating results or cash flows. Indemnification Under the 2019 Omnibus Agreement, certain tax liabilities are indemnified by SPLC. See Note 4 — Related Party Transactions for additional information. Minimum Throughput On September 1, 2016, the in-service date of the capital lease for the Port Neches storage tanks, a joint tariff agreement with a third party became effective. The tariff is reviewed annually and the rate updated based on FERC’s indexing adjustment effective July 1 of each year. Effective July 1, 2019, there was an approximately 4.3% increase to this rate based on FERC indexing adjustment. The initial term of the agreement is ten years with automatic one year renewal terms with the option to cancel prior to each renewal period. Other Commitments Odyssey entered into a tie-in agreement effective January 2012 with a third party, which allowed producers to install the tie-in connection facilities and tying into the system. The agreement will continue to be in effect until the continued operation of the platform is uneconomic. We hold cancellable easements or rights-of-way arrangements from landowners permitting the use of land for the construction and operation of our pipeline systems. Obligations under these easements are not material to the results of our operations. Leases We have operating leases for land, a lease of platform space and finance leases for storage tanks and platform space. See Note 9— Leases for additional information relating to our lease obligations .

Subsequent Events

Subsequent Events	12 Months Ended
	Dec. 31, 2019
Subsequent Events [Abstract]
Subsequent Event(s)	Subsequent Event(s) We have evaluated events that occurred after December 31, 2019 through the issuance of these consolidated financial statements. Any material subsequent events that occurred during this time have been properly recognized or disclosed in the consolidated financial statements and accompanying notes. Distribution On January 22, 2020, the Board declared a cash distribution of $0.4600 per limited partner unit for the three months ended December 31, 2019. The distribution was paid on February 14, 2020 to unitholders of record as of February 3, 2020. 2019 Omnibus Agreement

Selected Quarterly Financial Da

Selected Quarterly Financial Data (Unaudited)	12 Months Ended
	Dec. 31, 2019
Quarterly Financial Information Disclosure [Abstract]
Selected Quarterly Financial Data (Unaudited)	Selected Quarterly Financial Data (Unaudited) (in millions of dollars, except per unit data) Total Revenues Income Before Income Taxes Net Income Net Income Attributable to the Partnership Limited Partners’ Interest in Net Income Attributable to the Partnership Net Income per Common Unit - Basic and Diluted (1) 2019 First $ 131 $ 137 $ 137 $ 132 $ 105 $ 0.47 Second 121 119 119 115 85 0.38 Third 125 146 146 141 105 0.45 Fourth 126 144 144 140 86 0.37 2018 First $ 100 $ 65 $ 65 $ 64 $ 37 $ 0.18 Second 129 115 115 111 79 0.35 Third 153 155 155 149 112 0.50 Fourth 143 148 147 140 102 0.45 (1) The net income per common unit for each of the quarterly periods in the applicable year may not equal the year-to-date net income per common unit as the calculations of each are performed independently.

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2019
Accounting Policies [Abstract]
Description of Business	Description of Business We own, operate, develop and acquire pipelines and other midstream assets. As of December 31, 2019, our assets include interests in entities that own crude oil and refined products pipelines and terminals that serve as key infrastructure to (i) transport onshore and offshore crude oil production to Gulf Coast and Midwest refining markets and (ii) deliver refined products from those markets to major demand centers. Our assets also include interests in entities that own natural gas and refinery gas pipelines that transport offshore natural gas to market hubs and deliver refinery gas from refineries and plants to chemical sites along the Gulf Coast.
Basis of Presentation	Basis of Presentation Our consolidated financial statements include all subsidiaries required to be consolidated under generally accepted accounting principles in the United States (“GAAP”). Our reporting currency is U.S. dollars, and all references to dollars are U.S. dollars. The accompanying consolidated financial statements and related notes have been prepared under the rules and regulations of the Securities and Exchange Commission (the “SEC”). These rules and regulations conform to the accounting principles contained in the Financial Accounting Standards Board’s (“FASB”) Accounting Standards Codification, the single source of GAAP. Our consolidated subsidiaries include Pecten, Sand Dollar, Triton, Zydeco, Odyssey and the Operating Company. Asset acquisitions of additional interests in previously consolidated subsidiaries and interests in equity method and other investments are included in the financial statements prospectively from the effective date of each acquisition. In cases where these types of acquisitions are considered acquisitions of businesses under common control, the financial statements are retrospectively adjusted. The following businesses were acquired from our Parent and accounted for as acquisitions of businesses under common control. As such, our consolidated financial statements include the financial results of these businesses, which were derived from the financial statements and accounting records of SPLC and Shell for the periods prior to acquisition. Specifically, such businesses are reflected for the following periods prior to the effective date of such acquisitions by us: • May 2017 Acquisition for periods prior to May 10, 2017; and • December 2017 Acquisition for periods prior to December 1, 2017, including the effect of fully consolidating Odyssey. Our consolidated statements of income, cash flows and changes in (deficit) equity for 2017 consist of the combined results of the May 2017 Acquisition and the December 2017 Acquisition prior to the respective acquisition dates, and the consolidated activity of the Partnership. Our consolidated statements of income exclude the results of these businesses from net income attributable to the Partnership for the periods indicated above by allocating these results to our Parent. See Note 3 — Acquisitions and Divestiture for definitions and additional information. Expense Allocations. Our consolidated statements of income also include expense allocations for certain functions performed by SPLC and Shell on behalf of the above businesses prior to their respective dates of acquisition by us. Such costs are included in either general and administrative expenses or operations and maintenance expenses in the accompanying consolidated statements of income, depending on the nature of the employee’s role in our operations. The expense allocations have been determined on a basis that we, SPLC and Shell consider to be a reasonable reflection of the utilization of the services provided or the benefit received during the periods presented. See Note 4 — Related Party Transactions for details of operating agreements impacting expense allocations, as well as details of related party transactions. Cash. For all consolidated subsidiaries, we establish our own cash accounts for the funding of our operating and investing activities, with the exception of the capital expenditures incurred by SPLC on our behalf and then contributed to us. Funds are not commingled with the cash of other entities. Prior to the acquisition of each of these interests, the cash generated and used by our operations was deposited to Shell Treasury Center (West) Inc. (“STCW”), which was commingled with the cash of other entities controlled by Shell. STCW funded our operating activities, and STCW or an affiliate funded investing activities as needed. Accordingly, we did not record any cash and cash equivalents held by SPLC on our behalf for any period prior to the effective date of each acquisition from Shell.
Principles of Consolidation	Principles of Consolidation Our consolidated financial statements include all subsidiaries where we have control.  The assets and liabilities in the accompanying consolidated financial statements have been reflected on a historical basis. All significant intercompany accounts and transactions are eliminated upon consolidation.
Regulation	Regulation Certain businesses are subject to regulation by various authorities including, but not limited to FERC. Regulatory bodies exercise statutory authority over matters such as construction, rates and ratemaking and agreements with customers.
Net Parent Investment	Net Parent Investment Net Parent Investment represents Shell’s historical investment in us, our accumulated net earnings through the date which we completed the acquisition, and the net effect of transactions with, and allocations from, SPLC and Shell.
Use of Estimates	Use of Estimates The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the amounts reported of assets, liabilities, revenues and expenses in the accompanying consolidated financial statements and notes. Actual results could differ from those estimates.
Common Control Transactions	Common Control Transactions Assets and businesses acquired from our Parent and its subsidiaries are accounted for as common control transactions whereby the net assets acquired are combined with ours at our Parent’s historical carrying value. If any recognized consideration transferred in such a transaction exceeds the carrying value of the net assets acquired, the excess is treated as a capital distribution to our General Partner, similar to a dividend. If the carrying value of the net assets acquired exceeds any recognized consideration transferred including, if applicable, the fair value of any limited partner units issued, then our Parent would record an impairment and our net assets acquired would be recorded at fair value. To the extent that such transactions require prior periods to be retrospectively adjusted, historical net equity amounts prior to the transaction date are reflected in “Net Parent Investment.” Cash consideration up to the carrying value of net assets acquired is presented as an investing activity in our consolidated statement of cash flows. Cash consideration in excess of the carrying value of net assets acquired is presented as a financing activity in our consolidated statement of cash flows. Assets and businesses sold to our Parent are also common control transactions accounted for using historical carrying value with any resulting gain treated as a contribution from Parent.
Revenue Recognition	Revenue Recognition Our revenues are primarily generated from the transportation, terminaling and storage of crude oil, refined gas and refined petroleum products through our pipelines, terminals and storage tanks. We recognize revenue when we transfer promised goods or services to customers in an amount that reflects the consideration to which we expect to be entitled in exchange for those goods or services. We recognize revenue through the application of a five-step model, which includes: identification of the contract; identification of the performance obligations; determination of the transaction price; allocation of the transaction price to the performance obligations; and recognition of revenue as the entity satisfies the performance obligations.
Cash and Cash Equivalents	Cash and Cash Equivalents Our cash and cash equivalents includes cash and short-term highly liquid overnight deposits.
Accounts Receivable and Allowance for Doubtful Accounts	Accounts Receivable and Allowance for Doubtful Accounts Accounts receivable represent valid claims against customers for products sold or services rendered, net of allowances for doubtful accounts. We assess the creditworthiness of our counterparties on an ongoing basis and require security, including prepayments and other forms of collateral, when appropriate. We establish provisions for losses on accounts receivable due from shippers and operators if we determine that we will not collect all or part of the outstanding balance. Outstanding customer receivables are regularly reviewed for possible nonpayment indicators, and allowances for doubtful accounts are
Other Investments	Equity Method Investments We account for investments where we have the ability to exercise significant influence, but not control, under the equity method of accounting. Income from equity method investments represents our proportionate share of net income generated by the equity method investees. Differences in the basis of the investments and the underlying net asset value of the investees, if any, are amortized into net income over the remaining useful lives of the underlying assets. Equity method investments are assessed for impairment whenever changes in the facts and circumstances indicate a loss in value has occurred, if the loss is deemed to be other than temporary. When the loss is deemed to be other than temporary, the carrying value of the equity method investment is written down to fair value.
Property, Plant and Equipment	Property, Plant and Equipment Our property, plant and equipment is recorded at its historical cost of construction or, upon acquisition, at either the fair value of the assets acquired or the historical carrying value to the entity that placed the asset in service. Expenditures for major renewals and betterments are capitalized while those minor replacement, maintenance and repairs that do not improve or extend asset life are expensed when incurred. For constructed assets, we capitalize all construction-related direct labor and material
Impairment of Long-lived Assets	Impairment of Long-lived Assets We evaluate long-lived assets of identifiable business activities for impairment when events or changes in circumstances indicate, in our management’s judgment, that the carrying value of such assets may not be recoverable. These events include a significant decrease in the market value of the asset, changes in the manner in which we intend to use a long-lived asset, decisions to sell an asset and adverse changes in the legal or business environment such as adverse actions by regulators. If an event occurs, which is a determination that involves judgment, we perform an impairment assessment by comparing estimated undiscounted future cash flows associated with the asset to the asset’s net book value. If the net book value exceeds our estimate of undiscounted future cash flows, an impairment is calculated as the amount the net book value exceeds the estimated fair value associated with the asset.
Income Taxes	Income Taxes We are not a taxable entity for U.S. federal income tax purposes or for the majority of states that impose an income tax. Taxes on our net income are generally borne by our partners through the allocation of taxable income. Our income tax expense results from partnership activity in the state of Texas, as conducted by Zydeco, Sand Dollar and Triton. Income tax expense for 2019, 2018 and 2017 was immaterial.
Other Investments	Other InvestmentsWe account for equity investments in entities where we do not have control or significant influence at fair value with changes in fair value recognized in net income when the fair value is readily determinable. For investments without readily determinable fair values, we carry such investments at cost less impairments, if any. These investments are remeasured at fair value either upon the occurrence of an observable price change or upon identification of impairment. These investments are reported as Other investments in our consolidated balance sheets and dividends received are reported in Dividend income from other investments in our consolidated income statements.
Asset Retirement Obligations	Asset Retirement Obligations Asset retirement obligations (“AROs”) represent contractual or regulatory obligations associated with the retirement of long-lived assets that result from the acquisition, construction, development and/or normal use of the asset. Our AROs were zero as of both December 31, 2019 and 2018. Our assets include pipelines and terminals that have contractual or regulatory obligations that will need to be settled at retirement. The settlement date of these obligations will depend mostly on the various supply sources that connect to our systems and the ongoing demand for usage in the markets we serve. We expect these supply sources and market demands to continue for the foreseeable future. As the settlement dates of obligations are indeterminate, there is not sufficient information to make a reasonable estimate of the ARO of our remaining assets as of December 31, 2019 and 2018. We continue to evaluate our AROs and future developments could impact the amounts we record.
Pensions and Other Postretirement Benefits	Pensions and Other Postretirement Benefits We do not have our own employees. Employees that work on our pipelines or terminal are employees of SPLC, and we share employees with other SPLC-controlled and non-controlled entities. For presentation of these accompanying consolidated financial statements, our portion of payroll costs and employee benefit plan costs have been allocated as a charge to us by SPLC and Shell Oil Company. Shell Oil Company sponsors various employee pension and postretirement health and life insurance plans. For purposes of these accompanying consolidated financial statements, we are considered to be participating in the benefit plans of Shell Oil Company. We participate in the following defined benefits plans: Shell Oil Pension Plan, Shell Oil Retiree Health Care Plan, and Pennzoil-Quaker State Retiree Medical & Life Insurance. As a participant in these benefit plans, we recognize as expense in each period an allocation from Shell Oil Company, and we do not recognize any employee benefit plan assets or liabilities. See Note 4 — Related Party Transactions
Legal	Legal We are subject to litigation and regulatory proceedings as the result of our business operations and transactions. We use both internal and external counsel in evaluating our potential exposure to adverse outcomes from orders, judgments or settlements. In general, we expense legal costs as incurred. When we identify specific litigation that is expected to continue for a significant period of time, is probable to occur and may require substantial expenditures, we identify a range of possible costs expected to be required to litigate the matter to a conclusion or reach an acceptable settlement, and we accrue for the most probable outcome. To the extent that actual outcomes differ from our estimates, or additional facts and circumstances cause us to revise our estimates, our earnings will be affected.
Environmental Matters	Environmental Matters We are subject to federal, state, and local environmental laws and regulations. Environmental expenditures are expensed or capitalized depending on their economic benefit. We expense costs such as permits, compliance with existing environmental regulations, remedial investigations, soil sampling, testing and monitoring costs to meet applicable environmental laws and regulations where prudently incurred or determined to be reasonably possible in the ordinary course of business. We are permitted to recover such expenditures through tariff rates charged to customers. We also expense costs that relate to an existing condition caused by past environmental incidents, which do not contribute to current or future revenue generation. We record environmental liabilities when environmental assessments and/or remedial efforts are probable and we can reasonably estimate the costs. Generally, our recording of these accruals coincides with our completion of a feasibility study or our commitment to a formal plan of action. We recognize receivables for anticipated associated insurance recoveries when such recoveries are deemed to be probable. For 2019, 2018 and 2017, the environmental cleanup costs incurred were immaterial. At both December 31, 2019 and 2018, the accruals for environmental clean-up costs pursuant to a Consent Decree issued in 1998 by the State of Washington Department of Ecology with respect to our products terminal located in Seattle, Washington were immaterial. The costs relate to ongoing groundwater compliance monitoring and other remedial activities. Refer to Note 4 — Related Party Transactions under the Omnibus Agreement for additional details.
Other Contingencies	Other Contingencies We recognize liabilities for other contingencies when we have an exposure that indicates it is both probable that a liability has been incurred and the amount of loss can be reasonably estimated. Where the most likely outcome of a contingency can be reasonably estimated, we accrue a liability for that amount. Where the most likely outcome cannot be estimated, a range of potential losses is established and if no one amount in that range is more likely than any other, the lower end of the range is accrued.
Fair Value Estimates	Fair Value Estimates We measure assets and liabilities requiring fair value presentation or disclosure using an exit price (i.e., the price that would be received to sell an asset or paid to transfer a liability) and disclose such amounts according to the quality of valuation inputs under the following hierarchy: Level 1: Quoted prices in an active market for identical assets or liabilities. Level 2: Inputs other than quoted prices that are directly or indirectly observable. Level 3: Unobservable inputs that are significant to the fair value of assets or liabilities. We classify the fair value of an asset or liability based on the lowest level of input significant to its measurement. A fair value initially reported as Level 3 will be subsequently reported as Level 2 if the unobservable inputs become inconsequential to its measurement or corroborating market data becomes available. Asset and liability fair values initially reported as Level 2 will be subsequently reported as Level 3 if corroborating market data becomes unavailable.
Net Income per Limited Partner Unit	Net income per limited partner unit Net income per unit applicable to common limited partner units, and to subordinated limited partner units in periods prior to the expiration of the subordination period, is computed by dividing the respective limited partners’ interest in net income attributable to the Partnership for the period by the weighted average number of common units and subordinated units, respectively, outstanding for the period. Because we have more than one class of participating securities, we use the two-class method when calculating the net income per unit applicable to limited partners. The classes of participating securities include common units, subordinated units, general partner units and incentive distribution rights (“IDRs”). Basic and diluted net income per unit are the same because we do not have any potentially dilutive units outstanding for the period presented.
Recent Accounting Pronouncements	Recent Accounting Pronouncements Standards Adopted as of January 1, 2019 In May 2014, the FASB issued Accounting Standards Update (“ASU”) 2014-09 to Topic 606, Revenue from Contracts with Customers, which superseded revenue recognition guidance in Topic 605, Revenue Recognition, under GAAP. Under the revenue standard (as defined in Note 12 — Revenue Recognition ), the adoption date for the majority of the equity method investments within the Partnership followed the non-public business entity adoption date of January 1, 2019 for their stand-alone financial statements, with the exception of Mars and Permian Basin, which adopted on January 1, 2018. See Note 5 — Equity Method Investments for additional information. In February 2016, the FASB issued ASU 2016-02 to Topic 842, Leases. As permitted, we adopted the new lease standard (as defined in Note 9 — Leases ) using the modified retrospective approach, effective January 1, 2019, which provides a method for recording existing leases at the beginning of the period of adoption. As such, results and balances prior to January 1, 2019 are not adjusted and continue to be reported in accordance with our historical accounting under previous GAAP. Under the new lease standard, the adoption date for equity method investments within the Partnership will follow the non-public business entity adoption date of January 1, 2020 or 2021 for their stand-alone financial statements, with the exception of Permian Basin, which adopted on January 1, 2019. See Note 9 — Leases for additional information and disclosures required by the new lease standard. Standards Not Adopted as of December 31, 2019 In June 2016, the FASB issued ASU 2016-13 to Topic 326, Financial Instruments — Credit Losses: Measurement of Credit Losses on Financial Instruments, which replaces the current incurred loss impairment method with a method that reflects expected credit losses on financial instruments. The update is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2019 for SEC filers excluding smaller reporting companies. Early adoption is permitted. We do not expect the adoption of this standard to have a material impact on our consolidated financial statements.

Description of Business and B_2

Description of Business and Basis of Presentation (Tables)	12 Months Ended
	Dec. 31, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Schedule of Ownership Percentage	The following table reflects our ownership interests as of December 31, 2019: SHLX Ownership Pecten Midstream LLC (“Pecten”) 100.0 % Sand Dollar Pipeline LLC (“Sand Dollar”) 100.0 % Triton West LLC (“Triton”) 100.0 % Zydeco Pipeline Company LLC (“Zydeco”) (1) 92.5 % Amberjack Pipeline Company LLC (“Amberjack”) – Series A/Series B 75.0% / 50.0% Mars Oil Pipeline Company LLC (“Mars”) 71.5 % Odyssey Pipeline L.L.C. (“Odyssey”) 71.0 % Bengal Pipeline Company LLC (“Bengal”) 50.0 % Crestwood Permian Basin LLC (“Permian Basin”) 50.0 % LOCAP LLC (“LOCAP”) 41.48 % Explorer Pipeline Company (“Explorer”) 38.59 % Poseidon Oil Pipeline Company, L.L.C. (“Poseidon”) 36.0 % Colonial Enterprises, Inc. (“Colonial”) (2) 16.125 % Proteus Oil Pipeline Company, LLC (“Proteus”) 10.0 % Endymion Oil Pipeline Company, LLC (“Endymion”) 10.0 % Cleopatra Gas Gathering Company, LLC (“Cleopatra”) 1.0 % (1) SPLC owns the remaining 7.5% ownership interest in Zydeco.

Summary of Significant Accoun_3

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2019
Accounting Policies [Abstract]
Schedule of Cost Method Investments	Our equity investments which are accounted for at cost as they do not have readily determinable fair values consist of: December 31, 2019 December 31, 2018 Ownership Amount Ownership Amount Colonial (1) 16.125 % $ — 6.0 % $ 11 Explorer (1) 38.59 % — 12.62 % 49 Cleopatra 1.0 % 2 1.0 % 2 $ 2 $ 62 (1) We acquired additional interests in Explorer and Colonial in June 2019. As a result of the June 2019 Acquisition, we now have significant influence over both Explorer and Colonial and account for these investments as equity method investments. The acquisition of these interests has been accounted for prospectively.

Acquisitions and Divestiture (T

Acquisitions and Divestiture (Tables)	12 Months Ended
	Dec. 31, 2019
May 2017 Acquisition
Asset Acquisition [Line Items]
Schedule of Net Assets Acquired	In connection with the May 2017 Acquisition, we acquired historical carrying value of property, plant and equipment, net and other assets under common control as follows: Delta $ 40 Na Kika 26 Refinery Gas Pipeline 135 May 2017 Acquisition $ 201
December 2017 Acquisition
Asset Acquisition [Line Items]
Schedule of Net Assets Acquired	In connection with the December 2017 Acquisition we acquired the following: Cost investment (1) $ 22 Equity method investments (2) 76 Property, plant and equipment, net (3) 118 Partners’ capital (4) 3 December 2017 Acquisition $ 219 (1) Book value of an additional 10% interest in Explorer contributed by SPLC. (2) Book value of an additional 22.9% interest in Mars and a 41.48% interest in LOCAP contributed by SPLC. (3) Book value of a 100.0% interest in the historical carrying value of property, plant and equipment, net contributed by SOPUS. (4) Book value of an additional 22% interest in Odyssey contributed by SOPUS.

Related Party Transactions (Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2019
Related Party Transactions [Abstract]
Schedule of Other Related Party Balances	Other related party balances consist of the following: December 31, 2019 2018 Accounts receivable $ 29 $ 29 Prepaid expenses 15 15 Other assets 2 3 Accounts payable (1) 10 9 Deferred revenue — 3 Accrued liabilities (2) 19 16 Debt payable (3) 2,692 2,091 (1) Accounts payable reflects amounts owed to SPLC for reimbursement of third-party expenses incurred by SPLC for our benefit. (2) As of December 31, 2019, Accrued liabilities reflects $18 million accrued interest and $1 million other accrued liabilities . As of December 31, 2018, Accrued liabilities reflects $14 million accrued interest and $2 million other accrued liabilities. (3) Debt payable reflects borrowings outstanding net of unamortized debt issuance costs of $2 million as of December 31, 2019 and $3 million as of December 31, 2018.
Schedule of Related Party Expenses Including Personnel Costs	The following table shows related party expenses, including personnel costs, incurred by Shell and SPLC on our behalf that are reflected in the accompanying consolidated statements of income for the indicated periods. Included in these amounts, and disclosed below, is our share of operating and general corporate expenses, as well as the fees paid to SPLC under certain agreements. 2019 2018 2017 Allocated operating expenses $ 18 $ 15 $ 17 Insurance expense (1) 18 15 8 Other (2) 23 24 21 Operations and maintenance – related parties $ 59 $ 54 $ 46 Allocated general corporate expenses $ 28 $ 33 $ 26 Management Agreement fee 9 9 8 Omnibus Agreement fee 11 9 9 Other 1 1 5 General and administrative – related parties $ 49 $ 52 $ 48 (1) The majority of our insurance coverage is provided by a wholly owned subsidiary of Shell. The remaining coverage is provided by third-party insurers. (2) Other expenses primarily relate to salaries and wages and other payroll expenses.
Schedule of Reimbursements from Parent	The following table reflects reimbursements from our Parent in 2019, 2018 and 2017: 2019 2018 2017 Cash reimbursements received (1) $ 19 $ 12 $ 16 (1) These reimbursements are included in Other contributions from Parent in the accompanying consolidated statements of cash flows and consolidated statements of (deficit) equity.

Equity Method Investments (Tabl

Equity Method Investments (Tables)	12 Months Ended
	Dec. 31, 2019
Equity Method Investments and Joint Ventures [Abstract]
Schedule of Equity Investments in Affiliates	Equity method investments comprise the following as of the dates indicated: December 31, 2019 2018 Ownership Amount Ownership Amount Amberjack – Series A / Series B (1) 75.0% / 50.0% $ 426 75.0% / 50.0% $ 458 Mars 71.5% 161 71.5% 169 Bengal 50.0% 88 50.0% 82 Permian Basin 50.0% 91 50.0% 72 LOCAP 41.48% 9 41.48% 8 Explorer (2) 38.59% 88 12.62% — Poseidon 36.0% — 36.0% — Colonial (2) 16.125% 30 6.0% — Proteus 10.0% 15 10.0% 16 Endymion 10.0% 18 10.0% 18 $ 926 $ 823 ( 1 ) We acquired an interest in Amberjack in the May 2018 Acquisition. The acquisition of this interest has been accounted for prospectively. (2) As part of the June 2019 Acquisition, these interests have been accounted for prospectively. See below for additional information.
Schedule Of Equity Investments In Affiliates Balance Affected Table	Income from our equity method investments were as follows during the periods indicated: For the Year Ended December 31, 2019 2018 2017 Amberjack (1) $ 125 $ 80 $ — Mars (2) 126 108 122 Bengal 24 21 23 Explorer (3) 41 — — Colonial (3) 40 — — Poseidon (4) — 6 27 Other (5) 17 20 15 $ 373 $ 235 $ 187 (1) We acquired an interest in Amberjack in the May 2018 Acquisition. The acquisition of this interest has been accounted for prospectively. (2) We acquired an additional 22.9% interest in Mars in the December 2017 Acquisition. The acquisition of this interest was retrospectively adjusted for the incremental ownership acquired. (3) As stated above, we acquired additional interests in Explorer and Colonial in the June 2019 Acquisition. The acquisition of these interests has been accounted for prospectively. (4) As stated above, the equity method of accounting has been suspended in 2018 for Poseidon and excess distributions are recorded in Other income. (5)
Summary of Balance Sheet and Income Statement Data for Equity Method Investments	The following tables present aggregated selected balance sheet and income statement data for our equity method investments on a 100% basis. However, during periods in which an acquisition occurs, the selected balance sheet and income statement data reflects activity from the date of the acquisition. For the Year Ended December 31, 2019 Total revenues Total operating expenses Operating income Net income Statements of Income Amberjack 315 73 242 243 Mars 282 104 178 179 Bengal 77 30 47 47 Explorer (1) 258 115 143 111 Colonial (2) 829 449 380 255 Poseidon 132 35 97 87 Other (3) 190 108 82 73 As of December 31, 2019 Current assets Non-current assets Total assets Current liabilities Non-current liabilities Equity (deficit) Total liabilities and equity (deficit) Balance Sheets Amberjack $ 56 $ 804 $ 860 $ 4 $ 32 $ 824 $ 860 Mars 57 173 230 8 22 200 230 Bengal 35 157 192 6 — 186 192 Explorer 93 530 623 44 442 137 623 Colonial 323 2,920 3,243 519 2,873 (149) 3,243 Poseidon 30 190 220 16 246 (42) 220 Other (3) 60 917 977 73 469 435 977 (1) Our interest in Explorer was acquired on June 6, 2019. Explorer total revenues, total operating expenses and operating income (on a 100% basis) was $443 million, $196 million and $247 million, respectively. (2) Our interest in Colonial was acquired on June 6, 2019. Colonial total revenues, total operating expenses and operating income (on a 100% basis) was $1,437 million, $735 million and $702 million, respectively. (3) Included in Other is the activity associated with our investments in Permian Basin, LOCAP, Proteus and Endymion. For the Year Ended December 31, 2018 Total revenues Total operating expenses Operating income Net income Statements of Income Amberjack (1) 204 47 157 157 Mars 241 87 154 154 Bengal 69 28 41 41 Poseidon 116 35 81 73 Other (2) 152 67 85 76 As of December 31, 2018 Current assets Non-current assets Total assets Current liabilities Non-current liabilities Equity (deficit) Total liabilities and equity (deficit) Balance Sheets Amberjack (1) $ 46 $ 846 $ 892 $ 4 $ 4 $ 884 $ 892 Mars 53 178 231 5 18 208 231 Bengal 27 156 183 9 — 174 183 Poseidon 19 203 222 16 243 (37) 222 Other (2) 50 876 926 65 456 405 926 (1) Our interest in Amberjack was acquired on May 11, 2018. Amberjack total revenues, total operating expenses and operating income (on a 100% basis) was $295 million, $74 million and $221 million, respectively. (2) Included in Other is the activity associated with our investments in Permian Basin, LOCAP, Proteus and Endymion. For the Year Ended December 31, 2017 Total revenues Total operating expenses Operating income Net income Statements of Income Mars 256 82 174 174 Bengal 73 28 45 45 Poseidon 117 33 84 79 Other (1) 124 46 78 66 As of December 31, 2017 Current assets Non-current assets Total assets Current liabilities Non-current liabilities Equity (deficit) Total liabilities and equity (deficit) Balance Sheets Mars $ 48 $ 187 $ 235 $ 5 $ — $ 230 $ 235 Bengal 25 157 182 11 — 171 182 Poseidon 19 218 237 18 237 (18) 237 Other (1) 92 625 717 99 245 373 717 (1) Included in Other is the activity associated with our investments in Permian Basin, LOCAP, Proteus and Endymion. Interest in Permian Basin was acquired by us on October 17, 2017 and is pro rated in above table. For the year ended December 31, 2017, Permian Basin total revenue, total operating expenses and operating income (on a 100% basis) was $8 million, $5 million and $3 million, respectively.

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2019
Property, Plant and Equipment [Abstract]
Components of Property, Plant and Equipment	Property, plant and equipment, net consists of the following as of the dates indicated: December 31, Depreciable Life 2019 2018 Land — $ 11 $ 11 Building and improvements 10 - 40 years 40 39 Pipeline and equipment (1) 10 - 30 years 1,228 1,162 Other 5 - 25 years 33 18 1,312 1,230 Accumulated depreciation and amortization (2) (613) (567) 699 663 Construction in progress 27 79 Property, plant and equipment, net $ 726 $ 742 (1) As of December 31, 2019 and 2018, includes cost of $369 million and $366 million, respectively, related to assets under operating leases (as lessor), which commenced in May 2017 and December 2017. As of both December 31, 2019 and 2018, includes cost of $23 million related to assets under capital lease (as lessee). (2) As of December 31, 2019 and 2018, includes accumulated depreciation of $133 million and $121 million, respectively, related to assets under operating leases (as lessor), which commenced in May 2017 and December 2017. As of December 31, 2019 and 2018, includes accumulated depreciation of $6 million and $5 million, respectively, related to assets under capital lease (as lessee).

Accrued Liabilities - Third P_2

Accrued Liabilities - Third Parties (Tables)	12 Months Ended
	Dec. 31, 2019
Payables and Accruals [Abstract]
Schedule of Accrued Liabilities - Third Parties	Accrued liabilities – third parties consist of the following as of the dates indicated: December 31, 2019 2018 Project accruals $ 5 $ 7 Property taxes 4 4 Other accrued liabilities 3 2 Total accrued liabilities – third parties $ 12 $ 13

Related Party Debt (Tables)

Related Party Debt (Tables)	12 Months Ended
	Dec. 31, 2019
Debt Disclosure [Abstract]
Schedule of Consolidated Related Party Debt Obligations	Consolidated related party debt obligations comprise the following as of the dates indicated: December 31, 2019 December 31, 2018 Outstanding Balance Total Capacity Available Capacity Outstanding Balance Total Capacity Available Capacity Ten Year Fixed Facility $ 600 $ 600 $ — $ — $ — $ — Seven Year Fixed Facility 600 600 — 600 600 — Five Year Revolver due July 2023 494 760 266 494 760 266 Five Year Revolver due December 2022 400 1,000 600 400 1,000 600 Five Year Fixed Facility 600 600 — 600 600 — 2019 Zydeco Revolver (1) — 30 30 — 30 30 Unamortized debt issuance costs (2) n/a n/a (3) n/a n/a Debt payable – related party $ 2,692 $ 3,590 $ 896 $ 2,091 $ 2,990 $ 896 (1) Effective August 6, 2019, the Zydeco Revolver expired. In its place, Zydeco entered into the 2019 Zydeco Revolver. See below for additional information.

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2019
Leases [Abstract]
Assets And Liabilities, Lessee	The following tables summarize balance sheet data related to leases at December 31, 2019 and our lease costs as of and for the year ended December 31, 2019 : Leases Classification December 31, 2019 Assets Operating lease assets Operating lease right-of-use assets $ 4 Finance lease assets Property, plant and equipment, net (1) 17 Total lease assets $ 21 Liabilities Current Finance Accrued liabilities - third parties $ 1 Noncurrent Operating Operating lease liabilities 4 Finance Finance lease liabilities 24 Total lease liabilities $ 29 (1) Finance lease assets are recorded net of accumulated amortization of $6 million as of December 31, 2019.
Lease, Cost	Lease cost Classification December 31, 2019 Operating lease cost (1) Operations and maintenance - third parties $ — Finance lease cost (cost resulting from lease payments): Amortization of leased assets Depreciation and amortization 1 Interest on lease liabilities Interest expense, net 4 Total lease cost $ 5 (1) Amounts for the year ended December 31, 2019 were less than $1 million.
Supplemental Cash Flows, Lessee	December 31, 2019 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases (1) $ — Operating cash flows from finance leases (4) Financing cash flows from finance leases (1) (1) Amounts for the year ended December 31, 2019 were less than $1 million. December 31, 2019 Weighted-average remaining lease term (years): Operating leases 20 Finance leases 11 Weighted-average discount rate: Operating leases 5.8 % Finance leases 14.3 %
Lessee, Operating Lease, Liability, Maturity	The future annual maturity of lease payments as of December 31, 2019 for the above lease obligations was: Maturity of lease liabilities Operating Leases (1) Finance Leases (2) Total 2020 $ — $ 4 $ 4 2021 1 4 5 2022 — 4 4 2023 1 4 5 2024 — 5 5 Remainder 6 31 37 Total lease payments 8 52 60 Less: Interest (3) (4) (27) (31) Present value of lease liabilities (4) $ 4 $ 25 $ 29 (1) Operating lease payments include $2 million related to options to extend lease terms that are reasonably certain of being exercised. (2) Includes $25 million in principal and excludes $9 million in executory costs. (3) Calculated using the interest rate for each lease. (4) Includes the current portion of $1 million for the finance lease.
Finance Lease, Liability, Maturity	The future annual maturity of lease payments as of December 31, 2019 for the above lease obligations was: Maturity of lease liabilities Operating Leases (1) Finance Leases (2) Total 2020 $ — $ 4 $ 4 2021 1 4 5 2022 — 4 4 2023 1 4 5 2024 — 5 5 Remainder 6 31 37 Total lease payments 8 52 60 Less: Interest (3) (4) (27) (31) Present value of lease liabilities (4) $ 4 $ 25 $ 29 (1) Operating lease payments include $2 million related to options to extend lease terms that are reasonably certain of being exercised. (2) Includes $25 million in principal and excludes $9 million in executory costs. (3) Calculated using the interest rate for each lease. (4) Includes the current portion of $1 million for the finance lease.
Lessor, Operating Lease, Payments to be Received, Maturity	As of December 31, 2019, future annual maturity of lease payments to be received under the contract terms of these operating leases, which includes only the lease components of these leases, was estimated to be: Maturity of lease payments Operating leases (1) 2020 $ 56 2021 56 2022 56 2023 56 2024 56 Remainder 551 Total lease payments $ 831 (1) Operating lease payments include $411 million related to options to extend lease terms that are reasonably certain of being exercised.

(Deficit) Equity (Tables)

(Deficit) Equity (Tables)	12 Months Ended
	Dec. 31, 2019
Equity [Abstract]
Schedule of Number of Units Outstanding	The changes in the number of units outstanding from December 31, 2017 through December 31, 2019 are as follows: (in units) Public SPLC General Total Balance as of December 31, 2017 98,832,233 88,950,136 3,832,293 191,614,662 Units issued in connection with equity offerings 25,000,000 11,029,412 735,295 36,764,707 Balance as of December 31, 2018 123,832,233 99,979,548 4,567,588 228,379,369 June 2019 Acquisition — 9,477,756 193,424 9,671,180 Balance as of December 31, 2019 123,832,233 109,457,304 4,761,012 238,050,549
Schedule of Distributions Declared and/or Paid	The following table details the distributions declared and/or paid for the periods presented: Date Paid or to be Paid Three Months Ended Public Common SPLC Common SPLC Subordinated General Partner Distributions per Limited Partner Unit IDRs 2% Total (in millions, except per unit amounts) February 14, 2017 December 31, 2016 $ 25 $ 6 $ 18 $ 9 $ 1 $ 59 $ 0.27700 May 12, 2017 March 31, 2017 26 26 — 11 1 64 0.29100 August 14, 2017 June 30, 2017 27 27 — 13 1 68 0.30410 November 14, 2017 September 30, 2017 31 28 — 16 2 77 0.31800 February 14, 2018 December 31, 2017 33 30 — 18 2 83 0.33300 May 15, 2018 March 31, 2018 43 35 — 26 2 106 0.34800 August 14, 2018 June 30, 2018 46 36 — 29 2 113 0.36500 November 14, 2018 September 30, 2018 47 38 — 33 3 121 0.38200 February 14, 2019 December 31, 2018 49 40 — 37 3 129 0.40000 May 15, 2019 March 30, 2019 (1) 51 42 — 23 3 119 0.41500 August 14, 2019 June 30, 2019 (1) 53 47 — 28 3 131 0.43000 November 14, 2019 September 30, 2019 (1) 56 48 — 33 3 140 0.44500 February 14, 2020 December 31, 2019 (2) 57 50 — 52 3 162 0.46000 (1) Includes the impact of waived distributions to the holders of IDRs. See Note 4 — Related Party Transactions for additional information. (2) See Note 16 — Subsequent Events for additional information. .

Revenue Recognition (Tables)

Revenue Recognition (Tables)	12 Months Ended
	Dec. 31, 2019
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	The following table provides information about disaggregated revenue by service type and customer type: 2019 2018 2017 (1) Transportation services revenue – third parties $ 134 $ 200 $ 227 Transportation services revenue – related parties (2) 210 176 172 Storage services revenue – third parties 9 9 9 Storage services revenue – related parties 7 7 6 Terminaling services revenue – related parties (3) 47 46 — Product revenue – third parties (4) 5 2 — Product revenue – related parties (4) 35 29 — Total Topic 606 revenue 447 469 414 Lease revenue – related parties 56 56 56 Total revenue $ 503 $ 525 $ 470 (1) As noted above, prior period amounts have not been adjusted under the modified retrospective method. (2) Transportation services revenue — related parties for both 2019 and 2018 includes $5 million of non-lease component in our transportation services contract. (3) Terminaling services revenue for 2019 and 2018 is entirely comprised of the non-lease service component in our terminaling services contracts. (4) Product revenue for 2019 and 2018 is comprised of allowance oil sales.
Operating Lease, Lease Income	As of December 31, 2019, future minimum payments to be received under the ten Total Less than 1 year Years 2 to 3 Years 4 to 5 More than 5 years Operating leases $ 838 $ 110 $ 219 $ 219 $ 290
Schedule of New Accounting Pronouncements and Changes in Accounting Principles	Impact of adoption In accordance with the revenue standard, the following tables summarize the impact of adoption on our consolidated financial statements as of and for both the years ended December 31, 2019 and 2018: 2019 Consolidated Statement of Income As Reported Under Topic 606 Amounts Without Adoption of Topic 606 Effect of Change Increase/(Decrease) Revenue Transportation, terminaling and storage services – third parties $ 143 $ 142 $ 1 Transportation, terminaling and storage services – related parties 264 215 49 Product revenue – third parties 5 — 5 Product revenue – related parties 35 — 35 Lease revenue – related parties 56 108 (52) Costs and expenses Operations and maintenance – third parties 65 64 1 Operations and maintenance – related parties 59 58 1 Cost of product sold – third parties 5 — 5 Cost of product sold – related parties 31 — 31 Net income $ 546 $ 546 $ — December 31, 2019 Consolidated Balance Sheet As Reported Under Topic 606 Amounts Without Adoption of Topic 606 Effect of Change Increase/(Decrease) Deferred revenue – related party $ — $ — $ — 2018 Consolidated Statement of Income As Reported Under Topic 606 Amounts Without Adoption of Topic 606 Effect of Change Increase/(Decrease) Revenue Transportation, terminaling and storage services – third parties $ 209 $ 209 $ — Transportation, terminaling and storage services – related parties 229 183 46 Product revenue – third parties 2 — 2 Product revenue – related parties 29 — 29 Lease revenue – related parties 56 107 (51) Costs and expenses Operations and maintenance – third parties 108 107 1 Operations and maintenance – related parties 54 52 2 Cost of product sold – third parties 7 6 1 Cost of product sold – related parties 25 — 25 Net income $ 482 $ 487 $ (5) December 31, 2018 Consolidated Balance Sheet As Reported Under Topic 606 Amounts Without Adoption of Topic 606 Effect of Change Increase/(Decrease) Deferred revenue – related party $ 3 $ 3 $ —
Contract with Customer, Asset and Liability	The following table provides information about receivables and contract liabilities from contracts with customers: January 1, 2019 December 31, 2019 Receivables from contracts with customers – third parties $ 19 $ 11 Receivables from contracts with customers – related parties 21 24 Deferred revenue – third parties 8 — Deferred revenue – related party 3 — January 1, 2018 December 31, 2018 Receivables from contracts with customers – third parties $ 17 $ 19 Receivables from contracts with customers – related parties 19 21 Deferred revenue – third parties 6 8 Deferred revenue – related party 9 3 Significant changes in the deferred revenue balances with customers during the period are as follows: December 31, 2018 Transition Adjustment Additions (1) Reductions (2) December 31, 2019 Deferred revenue – third parties $ 8 $ — $ — $ (8) $ — Deferred revenue – related party 3 — — (3) — (1) Contract liability additions resulted from deficiency payments from minimum volume commitment contracts. (2) Contract liability reductions resulted from revenue earned through the actual or estimated use and expiration of deficiency credits. December 31, 2017 Transition Adjustment Additions (1) Reductions (2) December 31, 2018 Deferred revenue – third parties $ 6 $ — $ 10 $ (8) $ 8 Deferred revenue – related party 14 (4) 3 (10) 3 (1) Contract liability additions resulted from deficiency payments from minimum volume commitment contracts.
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction	The following table includes revenue expected to be recognized in the future related to performance obligations exceeding one year of their initial terms that are unsatisfied or partially unsatisfied as of December 31, 2019: Total 2020 2021 2022 2023 2024 and beyond Revenue expected to be recognized on multi-year committed shipper transportation contracts $ 577 $ 106 $ 63 $ 63 $ 63 $ 282 Revenue expected to be recognized on other multi-year transportation service contracts (1) 40 5 5 5 5 20 Revenue expected to be recognized on multi-year storage service contracts 21 4 4 4 4 5 Revenue expected to be recognized on multi-year terminaling service contracts (1) 378 48 48 48 48 186 Total $ 1,016 $ 163 $ 120 $ 120 $ 120 $ 493 (1) Relates to the non-lease service components of certain of our long-term transportation and terminaling service contracts which are accounted for as operating leases.

Net Income Per Limited Partne_2

Net Income Per Limited Partner Unit (Tables)	12 Months Ended
	Dec. 31, 2019
Partners' Capital Notes [Abstract]
Schedule of Allocation of Net Income to Arrive at Net Income Per Limited Partner Unit	The following tables show the allocation of net income attributable to the Partnership to arrive at net income per limited partner unit: 2019 2018 2017 Net income $ 546 $ 482 $ 392 Less: Net income attributable to the Parent — — 77 Net income attributable to noncontrolling interests 18 18 20 Net income attributable to the Partnership 528 464 295 Less: General partner’s distribution declared (1) 148 135 64 Limited partners’ distribution declared on common units 404 334 228 Income (less than)/in excess of distributions $ (24) $ (5) $ 3 (1) For 2019, this includes the impact of waived distributions to the holders of IDRs. See Note 4 — Related Party Transactions for additional information.
Schedule of Basic and Diluted Net Income Per Unit	2019 General Partner Limited Partners’ Common Units Total (in millions of dollars, except per unit data) Distributions declared (1) $ 148 $ 404 $ 552 Distributions in excess of income (1) (23) (24) Net income attributable to the Partnership $ 147 $ 381 $ 528 Weighted average units outstanding: Basic and diluted 229.2 Net income per limited partner unit: Basic and diluted $ 1.66 (1) This includes the impact of waived distributions to the holders of IDRs. See Note 4 — Related Party Transactions for additional information. 2018 General Partner Limited Partners’ Common Units Total (in millions of dollars, except per unit data) Distributions declared $ 135 $ 334 $ 469 Distributions in excess of income (1) (4) (5) Net income attributable to the Partnership $ 134 $ 330 $ 464 Weighted average units outstanding: Basic and diluted 220.3 Net income per limited partner unit: Basic and diluted $ 1.50 2017 General Partner Limited Partners’ Common Units Total (in millions of dollars, except per unit data) Distributions declared $ 64 $ 228 $ 292 Income in excess of distributions — 3 3 Net income attributable to the Partnership $ 64 $ 231 $ 295 Weighted average units outstanding: Basic and diluted 180.4 Net income per limited partner unit: Basic and diluted $ 1.28

Selected Quarterly Financial _2

Selected Quarterly Financial Data (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2019
Quarterly Financial Information Disclosure [Abstract]
Selected Quarterly Financial Data (Unaudited)	(in millions of dollars, except per unit data) Total Revenues Income Before Income Taxes Net Income Net Income Attributable to the Partnership Limited Partners’ Interest in Net Income Attributable to the Partnership Net Income per Common Unit - Basic and Diluted (1) 2019 First $ 131 $ 137 $ 137 $ 132 $ 105 $ 0.47 Second 121 119 119 115 85 0.38 Third 125 146 146 141 105 0.45 Fourth 126 144 144 140 86 0.37 2018 First $ 100 $ 65 $ 65 $ 64 $ 37 $ 0.18 Second 129 115 115 111 79 0.35 Third 153 155 155 149 112 0.50 Fourth 143 148 147 140 102 0.45 (1) The net income per common unit for each of the quarterly periods in the applicable year may not equal the year-to-date net income per common unit as the calculations of each are performed independently.

Description of Business and B_3

Description of Business and Basis of Presentation (Details) - segment	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Schedule of Equity Method Investments [Line Items]
Number of segments	1
Pecten Midstream LLC (“Pecten”)
Schedule of Equity Method Investments [Line Items]
Ownership	100.00%
Sand Dollar Pipeline LLC (“Sand Dollar”)
Schedule of Equity Method Investments [Line Items]
Ownership	100.00%
Triton West LLC (“Triton”)
Schedule of Equity Method Investments [Line Items]
Ownership	100.00%
Zydeco Pipeline Company LLC (“Zydeco”)
Schedule of Equity Method Investments [Line Items]
Ownership	92.50%
Zydeco Pipeline Company LLC (“Zydeco”) | Zydeco Pipeline Company LLC (“Zydeco”)
Schedule of Equity Method Investments [Line Items]
Shell's Retained Ownership	7.50%
Amberjack Pipeline Company LLC - Series A
Schedule of Equity Method Investments [Line Items]
Ownership	75.00%	75.00%
Amberjack Pipeline Company LLC - Series B
Schedule of Equity Method Investments [Line Items]
Ownership	50.00%	50.00%
Mars Oil Pipeline Company LLC (“Mars”)
Schedule of Equity Method Investments [Line Items]
Ownership	71.50%	71.50%
Odyssey Pipeline L.L.C. (“Odyssey”)
Schedule of Equity Method Investments [Line Items]
Ownership	71.00%
Bengal Pipeline Company LLC (“Bengal”)
Schedule of Equity Method Investments [Line Items]
Ownership	50.00%	50.00%
Crestwood Permian Basin LLC (“Permian Basin”)
Schedule of Equity Method Investments [Line Items]
Ownership	50.00%
LOCAP LLC (“LOCAP”)
Schedule of Equity Method Investments [Line Items]
Ownership	41.48%	41.48%
Explorer Pipeline Company (“Explorer”)
Schedule of Equity Method Investments [Line Items]
Ownership	38.59%	12.62%
Poseidon Oil Pipeline Company, L.L.C. (“Poseidon”)
Schedule of Equity Method Investments [Line Items]
Ownership	36.00%	36.00%
Colonial Enterprises, Inc. (“Colonial”) (2)
Schedule of Equity Method Investments [Line Items]
Ownership	16.125%	6.00%
Proteus Oil Pipeline Company, LLC (“Proteus”)
Schedule of Equity Method Investments [Line Items]
Ownership	10.00%	10.00%
Endymion Oil Pipeline Company, LLC (“Endymion”)
Schedule of Equity Method Investments [Line Items]
Ownership	10.00%	10.00%
Cleopatra Gas Gathering Company, LLC (“Cleopatra”)
Schedule of Equity Method Investments [Line Items]
Ownership	1.00%

Summary of Significant Accoun_4

Summary of Significant Accounting Policies - Additional Information (Details) - USD ($)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Accounting Policies [Abstract]
Allowance for doubtful accounts	$ 0	$ 0
Asset retirement obligation	0	0
Asset impairments	$ 0	$ 0	$ 0
Potentially dilutive units outstanding (in units)	0	0

Summary of Significant Accoun_5

Summary of Significant Accounting Policies - Investments (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Schedule of Equity Method Investments [Line Items]
Other investments	$ 2	$ 62
Colonial
Schedule of Equity Method Investments [Line Items]
Ownership	16.125%	6.00%
Other investments	$ 0	$ 11
Explorer
Schedule of Equity Method Investments [Line Items]
Ownership	38.59%	12.62%
Other investments	$ 0	$ 49
Cleopatra
Schedule of Equity Method Investments [Line Items]
Ownership	1.00%	1.00%
Other investments	$ 2	$ 2

Acquisitions and Divestiture -

Acquisitions and Divestiture - June 2019 Acquisitions (Details) - USD ($) $ / shares in Units, $ in Millions	Jun. 06, 2019	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Asset Acquisition [Line Items]
Remeasurements of pension and other postretirement benefits related to equity method investments, net of tax		$ 2	$ 0	$ 0
June 2019 Acquisition
Asset Acquisition [Line Items]
Consideration transferred	$ 800
Equity method investment, aggregate cost	90
Remeasurements of pension and other postretirement benefits related to equity method investments, net of tax	6
Capital distribution to general partner	510
Non-cash equity consideration	$ 200
Common units, weighted average sales price (in dollars per share)	$ 20.68
General partners' capital account, units issued (in units)	193,424
General Partner | June 2019 Acquisition | Shell Midstream Partners L.P.
Asset Acquisition [Line Items]
Noncontrolling interest	2.00%
Subsidiary | Shell Midstream LP Holdings LLC | June 2019 Acquisition
Asset Acquisition [Line Items]
Common units issued (in shares)	9,477,756
Revolving Credit Facility | Ten Year Fixed Facility
Asset Acquisition [Line Items]
Debt instrument term		10 years
Revolving Credit Facility | Shell Treasury Center West Inc | Ten Year Fixed Facility
Asset Acquisition [Line Items]
Debt instrument term		10 years
Revolving Credit Facility | Shell Treasury Center West Inc | Ten Year Fixed Facility | June 2019 Acquisition
Asset Acquisition [Line Items]
Consideration, cash on hand	$ 600
Explorer
Asset Acquisition [Line Items]
Ownership		38.59%	12.62%
Explorer | June 2019 Acquisition
Asset Acquisition [Line Items]
Equity method investments, ownership interest acquired	25.97%
Ownership		38.59%
Colonial
Asset Acquisition [Line Items]
Ownership		16.125%	6.00%
Colonial | June 2019 Acquisition
Asset Acquisition [Line Items]
Equity method investments, ownership interest acquired	10.125%
Ownership		16.125%

Acquisitions and Divestiture _2

Acquisitions and Divestiture - May 2018 Acquisitions (Details) - USD ($) $ in Millions	May 11, 2018	Dec. 31, 2019
May 2018 Acquisition
Asset Acquisition [Line Items]
Consideration transferred	$ 1,220
Consideration in excess of book value of net assets acquired	738
Equity method investment, aggregate cost	482
Five Year Revolver due July 2023
Asset Acquisition [Line Items]
Debt instrument term		5 years
Five Year Revolver Due December 2022
Asset Acquisition [Line Items]
Debt instrument term		5 years
Revolving Credit Facility | Five Year Revolver due July 2023
Asset Acquisition [Line Items]
Debt instrument term		5 years
Shell Treasury Center West Inc | Revolving Credit Facility | Five Year Revolver due July 2023
Asset Acquisition [Line Items]
Debt instrument term		5 years
Shell Treasury Center West Inc | Revolving Credit Facility | Five Year Revolver due July 2023 | May 2018 Acquisition
Asset Acquisition [Line Items]
Consideration transferred	494
Shell Treasury Center West Inc | Revolving Credit Facility | Five Year Revolver Due December 2022
Asset Acquisition [Line Items]
Debt instrument term		5 years
Shell Treasury Center West Inc | Revolving Credit Facility | Five Year Revolver Due December 2022 | May 2018 Acquisition
Asset Acquisition [Line Items]
Consideration transferred	$ 726
Debt instrument term	5 years
Amberjack Pipeline Company LLC - Series A | May 2018 Acquisition
Asset Acquisition [Line Items]
Voting interest acquired	75.00%
Amberjack Pipeline Company LLC - Series B | May 2018 Acquisition
Asset Acquisition [Line Items]
Voting interest acquired	50.00%

Acquisitions and Divestiture _3

Acquisitions and Divestiture - 2017 Acquisitions (Details) - USD ($) $ in Millions	Dec. 01, 2017	Oct. 17, 2017	May 10, 2017	Dec. 31, 2017
December 2017 Acquisition
Business Acquisition [Line Items]
Consideration transferred	$ 825
Transaction costs	1
Cost investment	22
Equity method investments	76
Property, plant and equipment, net	118
Partners' capital	3
Book value of net assets	219
Contribution in excess of book value of net assets acquired	$ 606
Revenue related to acquisition				$ 8
Net earnings related to acquisition				$ 19
Odyssey Pipeline L.L.C. (“Odyssey”) | December 2017 Acquisition
Business Acquisition [Line Items]
Equity method investments, ownership interest acquired	22.00%
Triton | December 2017 Acquisition
Business Acquisition [Line Items]
Equity method investments, ownership interest acquired	100.00%
Mars Oil Pipeline Company LLC (“Mars”) | December 2017 Acquisition
Business Acquisition [Line Items]
Equity method investments, ownership interest acquired				22.90%
Explorer | December 2017 Acquisition
Business Acquisition [Line Items]
Equity method investments, ownership interest acquired	10.00%
Crestwood Permian Basin LLC (“Permian Basin”) | October 2017 Acquisitions
Business Acquisition [Line Items]
Equity method investments, ownership interest acquired		50.00%
Consideration transferred		$ 50
Delta | May 2017 Acquisition
Business Acquisition [Line Items]
Book value of net assets			$ 40
Delta, Na Kika And Refinery Gas Pipeline | May 2017 Acquisition
Business Acquisition [Line Items]
Equity method investments, ownership interest acquired			100.00%
Consideration, cash on hand			$ 50
Consideration transferred			630
Transaction costs			1
Book value of net assets			201
Revenue related to acquisition			64
Net earnings related to acquisition			$ 29
Shutdown period			2 years
Consideration in excess of book value of net assets acquired			$ 429
Delta, Na Kika And Refinery Gas Pipeline | Shell Treasury Center West Inc | May 2017 Acquisition | Five Year Revolver due July 2023 | Revolving Credit Facility
Business Acquisition [Line Items]
Consideration transferred			73
Delta, Na Kika And Refinery Gas Pipeline | Shell Treasury Center West Inc | May 2017 Acquisition | Five Year Fixed Facility | Revolving Credit Facility
Business Acquisition [Line Items]
Consideration transferred			507
Refinery Gas Pipeline | May 2017 Acquisition
Business Acquisition [Line Items]
Book value of net assets			135
Na Kika | May 2017 Acquisition
Business Acquisition [Line Items]
Book value of net assets			$ 26
LOCAP LLC (“LOCAP”) | December 2017 Acquisition
Business Acquisition [Line Items]
Equity method investments, ownership interest acquired	41.48%

Acquisitions and Divestiture _4

Acquisitions and Divestiture - 2017 Divestiture (Details) - USD ($) $ in Millions	Apr. 28, 2017	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Business Acquisition [Line Items]
Divestiture cash consideration		$ 0	$ 0	$ 1
Excess proceeds from divestiture from Parent				$ 20
Disposal Group, Held-for-sale or Disposed of by Sale, Not Discontinued Operations | Zydeco
Business Acquisition [Line Items]
Divestiture cash consideration	$ 21
Book value of net assets divested	1
Excess proceeds from divestiture from Parent	20
Shell Pipeline Company L P | Disposal Group, Held-for-sale or Disposed of by Sale, Not Discontinued Operations | Zydeco
Business Acquisition [Line Items]
Divestiture cash consideration	$ 19

Related Party Transactions - Ad

Related Party Transactions - Additional Information (Details) $ in Millions	Nov. 03, 2014USD ($)	Sep. 30, 2019USD ($)	Jun. 30, 2019USD ($)	Mar. 31, 2019USD ($)	Dec. 31, 2019USD ($)credit_facility	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)
Related Party Transaction [Line Items]
Number of days within combined tax filing submission					15 days
Distribution to holders of incentive distribution rights waived		$ 16	$ 17	$ 17	$ 50
Pension and postretirement health and life insurance					6	$ 6	$ 4
Defined contribution benefit plan costs					2	3	2
Other assets					2	3
Accounts payable					10	9
Accrued liabilities – related parties					19	16
Debt payable – related party					2,692	2,091
Allocated general corporate expenses					28	33	26
Management Agreement fee					9	9	8
Omnibus Agreement fee					11	9	9
General and administrative – related parties					$ 49	$ 52	$ 48
Five Year Fixed Facility | Revolving Credit Facility
Related Party Transaction [Line Items]
Debt instrument term					5 years
Five Year Revolver Due December 2022
Related Party Transaction [Line Items]
Debt instrument term					5 years
Five Year Revolver due July 2023
Related Party Transaction [Line Items]
Debt instrument term					5 years
Five Year Revolver due July 2023 | Revolving Credit Facility
Related Party Transaction [Line Items]
Debt instrument term					5 years
Ten Year Fixed Facility | Revolving Credit Facility
Related Party Transaction [Line Items]
Debt instrument term					10 years
Seven Year Fixed Facility | Revolving Credit Facility
Related Party Transaction [Line Items]
Debt instrument term					7 years
Omnibus Agreement
Related Party Transaction [Line Items]
Statute of limitations expirations, number of days					60 days
Shell Treasury Center West Inc
Related Party Transaction [Line Items]
Number of revolving credit facilities | credit_facility					5
Shell Treasury Center West Inc | Five Year Fixed Facility | Revolving Credit Facility
Related Party Transaction [Line Items]
Debt instrument term					5 years
Shell Treasury Center West Inc | Five Year Revolver Due December 2022 | Revolving Credit Facility
Related Party Transaction [Line Items]
Debt instrument term					5 years
Shell Treasury Center West Inc | Five Year Revolver due July 2023 | Revolving Credit Facility
Related Party Transaction [Line Items]
Debt instrument term					5 years
Shell Treasury Center West Inc | Ten Year Fixed Facility | Revolving Credit Facility
Related Party Transaction [Line Items]
Debt instrument term					10 years
Shell Treasury Center West Inc | Seven Year Fixed Facility | Revolving Credit Facility
Related Party Transaction [Line Items]
Debt instrument term					7 years
Shell Pipeline Company L P | Omnibus Agreement
Related Party Transaction [Line Items]
Payment of general and administrative fee	$ 11
Zydeco Pipeline Company LLC (“Zydeco”) | Shell Pipeline Company L P
Related Party Transaction [Line Items]
Noncontrolling interest					7.50%	7.50%	7.50%
Odyssey Pipeline L.L.C. | GEL Offshore Pipeline LLC
Related Party Transaction [Line Items]
Noncontrolling interest					29.00%	29.00%	29.00%

Related Party Transactions - Sc

Related Party Transactions - Schedule of Other Related Party Balances (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Related Party Transaction [Line Items]
Accounts receivable	$ 29	$ 29
Prepaid expenses	15	15
Other assets	2	3
Accounts payable	10	9
Deferred revenue	0	3
Accrued liabilities	19	16
Debt payable	2,692	2,091
Accrued interest, related parties	18	14
Other accrued liabilities, related parties	1	2
Unamortized debt issuance expense	2	3
Affiliated Entity
Related Party Transaction [Line Items]
Unamortized debt issuance expense	$ 2	$ 3

Related Party Transactions - _2

Related Party Transactions - Schedule of Condensed Combined Statement of Operations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Related Party Transactions [Abstract]
Allocated operating expenses	$ 18	$ 15	$ 17
Insurance Expense, Related Parties	18	15	8
Other Operating Expenses, Related Parties	23	24	21
Operations and maintenance – related parties	59	54	46
Allocated general corporate expenses	28	33	26
Management Agreement fee	9	9	8
Omnibus Agreement fee	11	9	9
Other	1	1	5
General and administrative – related parties	$ 49	$ 52	$ 48

Related Party Transactions - _3

Related Party Transactions - Schedule of Reimbursement from Parent (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Shell Pipeline Company L P
Related Party Transaction [Line Items]
Cash received		$ 19	$ 12	$ 16
Reimbursement related to cost and expenses for maintenance projects		19	12	16
Zydeco Pipeline Company LLC (“Zydeco”)
Related Party Transaction [Line Items]
Reimbursement related to cost and expenses for maintenance projects		$ 10	$ 12	14
Refinery Gas Pipeline
Related Party Transaction [Line Items]
Reimbursement related to cost and expenses for maintenance projects				$ 2
Mars | Shell Pipeline Company L P
Related Party Transaction [Line Items]
Cash received	$ 9

Equity Method Investments - Sch

Equity Method Investments - Schedule of Equity Investments in Affiliates (Details) - USD ($)	Dec. 31, 2019	Dec. 31, 2018	Jun. 30, 2018
Schedule of Equity Method Investments [Line Items]
Equity method investments	$ 926,000,000	$ 823,000,000
Amberjack
Schedule of Equity Method Investments [Line Items]
Equity method investments	$ 426,000,000	$ 458,000,000
Amberjack Pipeline Company LLC - Series A
Schedule of Equity Method Investments [Line Items]
Ownership interest (in percentage)	75.00%	75.00%
Amberjack Pipeline Company LLC - Series B
Schedule of Equity Method Investments [Line Items]
Ownership interest (in percentage)	50.00%	50.00%
Mars
Schedule of Equity Method Investments [Line Items]
Ownership interest (in percentage)	71.50%	71.50%
Equity method investments	$ 161,000,000	$ 169,000,000
Bengal Pipeline Company LLC (“Bengal”)
Schedule of Equity Method Investments [Line Items]
Ownership interest (in percentage)	50.00%	50.00%
Equity method investments	$ 88,000,000	$ 82,000,000
Permian Basin
Schedule of Equity Method Investments [Line Items]
Ownership interest (in percentage)	50.00%	50.00%
Equity method investments	$ 91,000,000	$ 72,000,000
LOCAP
Schedule of Equity Method Investments [Line Items]
Ownership interest (in percentage)	41.48%	41.48%
Equity method investments	$ 9,000,000	$ 8,000,000
Explorer
Schedule of Equity Method Investments [Line Items]
Ownership interest (in percentage)	38.59%	12.62%
Equity method investments	$ 88,000,000	$ 0
Poseidon Oil Pipeline Company, L.L.C. (“Poseidon”)
Schedule of Equity Method Investments [Line Items]
Ownership interest (in percentage)	36.00%	36.00%
Equity method investments	$ 0	$ 0	$ 0
Colonial
Schedule of Equity Method Investments [Line Items]
Ownership interest (in percentage)	16.125%	6.00%
Equity method investments	$ 30,000,000	$ 0
Proteus
Schedule of Equity Method Investments [Line Items]
Ownership interest (in percentage)	10.00%	10.00%
Equity method investments	$ 15,000,000	$ 16,000,000
Endymion Oil Pipeline Company, LLC (“Endymion”)
Schedule of Equity Method Investments [Line Items]
Ownership interest (in percentage)	10.00%	10.00%
Equity method investments	$ 18,000,000	$ 18,000,000

Equity Method Investments - Add

Equity Method Investments - Additional Information (Details) - USD ($)	3 Months Ended	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Jun. 06, 2019	Jun. 05, 2019	Jan. 01, 2019	Jun. 30, 2018	Jan. 01, 2018	Dec. 01, 2017	Dec. 31, 2016
Schedule of Equity Method Investments [Line Items]
Equity method investments	$ 926,000,000	$ 926,000,000	$ 823,000,000
Unamortized basis differences included in equity investments	92,000,000	92,000,000	40,000,000	$ 41,000,000
Amortization expense		6,000,000	4,000,000	4,000,000
Income from equity method investments		373,000,000	235,000,000	187,000,000
Impact of changes in accounting policy							$ (9,000,000)		$ (2,000,000)
Shell Pipeline Company L P
Schedule of Equity Method Investments [Line Items]
Cash received		19,000,000	12,000,000	16,000,000
Mars Oil Pipeline Company LLC (“Mars”) | Shell Pipeline Company L P
Schedule of Equity Method Investments [Line Items]
Equity method investments, ownership interest acquired											20.00%
Consideration to be received if inventory management fees do now meet certain levels											$ 10,000,000
June 2019 Acquisition
Schedule of Equity Method Investments [Line Items]
Equity method investments					$ 90,000,000
Poseidon Oil Pipeline Company, L.L.C. (“Poseidon”)
Schedule of Equity Method Investments [Line Items]
Equity method investments	0	0	0					$ 0
Investment, excess distribution		33,000,000	24,000,000
Income from equity method investments		0	6,000,000	27,000,000
Mars Oil Pipeline Company LLC (“Mars”)
Schedule of Equity Method Investments [Line Items]
Equity method investments	161,000,000	161,000,000	169,000,000
Income from equity method investments		126,000,000	108,000,000	$ 122,000,000
Mars Oil Pipeline Company LLC (“Mars”) | Shell Pipeline Company L P
Schedule of Equity Method Investments [Line Items]
Cash received	9,000,000
Mars Oil Pipeline Company LLC (“Mars”) | Accounting Standards Update 2014-09
Schedule of Equity Method Investments [Line Items]
Impact of changes in accounting policy							$ (9,000,000)		$ (7,000,000)
Mars Oil Pipeline Company LLC (“Mars”) | December 2017 Acquisition
Schedule of Equity Method Investments [Line Items]
Equity method investments, ownership interest acquired				22.90%
Amberjack
Schedule of Equity Method Investments [Line Items]
Equity method investments	426,000,000	426,000,000	458,000,000
Income from equity method investments		125,000,000	80,000,000	$ 0
Explorer
Schedule of Equity Method Investments [Line Items]
Equity method investments	88,000,000	88,000,000	0
Income from equity method investments		41,000,000	0	0
Explorer | June 2019 Acquisition
Schedule of Equity Method Investments [Line Items]
Equity method investments, ownership interest acquired					25.97%
Explorer | December 2017 Acquisition
Schedule of Equity Method Investments [Line Items]
Equity method investments, ownership interest acquired										10.00%
Colonial
Schedule of Equity Method Investments [Line Items]
Equity method investments	30,000,000	30,000,000	0
Income from equity method investments		40,000,000	0	0
Colonial | June 2019 Acquisition
Schedule of Equity Method Investments [Line Items]
Equity method investments, ownership interest acquired					10.125%
Permian Basin
Schedule of Equity Method Investments [Line Items]
Equity method investments	91,000,000	91,000,000	72,000,000
Capital contribution		25,000,000	28,000,000
Other
Schedule of Equity Method Investments [Line Items]
Income from equity method investments		17,000,000	20,000,000	15,000,000
Explorer And Colonial
Schedule of Equity Method Investments [Line Items]
Other Investments						$ 60,000,000
Bengal
Schedule of Equity Method Investments [Line Items]
Equity method investments	$ 88,000,000	88,000,000	82,000,000
Income from equity method investments		$ 24,000,000	$ 21,000,000	$ 23,000,000

Equity Method Investments - Sum

Equity Method Investments - Summary of Balance Sheet and Income Statement Data for Equity Method Investments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Balance Sheets
Outstanding Balance	$ 2,692	$ 2,091
Total Capacity	3,590	2,990
Available Capacity	896	896
Amberjack
Statements of Income
Total revenues	315	204
Total operating expenses	73	47
Operating income	242	157
Net income	243	157
Balance Sheets
Current assets	56	46
Non-current assets	804	846
Total assets	860	892
Current liabilities	4	4
Non-current liabilities	32	4
Equity (Deficit)	824	884
Total liabilities and equity (deficit)	860	892
Mars
Statements of Income
Total revenues	282	241	$ 256
Total operating expenses	104	87	82
Operating income	178	154	174
Net income	179	154	174
Balance Sheets
Current assets	57	53	48
Non-current assets	173	178	187
Total assets	230	231	235
Current liabilities	8	5	5
Non-current liabilities	22	18	0
Equity (Deficit)	200	208	230
Total liabilities and equity (deficit)	230	231	235
Bengal
Statements of Income
Total revenues	77	69	73
Total operating expenses	30	28	28
Operating income	47	41	45
Net income	47	41	45
Balance Sheets
Current assets	35	27	25
Non-current assets	157	156	157
Total assets	192	183	182
Current liabilities	6	9	11
Non-current liabilities	0	0	0
Equity (Deficit)	186	174	171
Total liabilities and equity (deficit)	192	183	182
Explorer
Statements of Income
Total revenues	258
Total operating expenses	115
Operating income	143
Net income	111
Balance Sheets
Current assets	93
Non-current assets	530
Total assets	623
Current liabilities	44
Non-current liabilities	442
Equity (Deficit)	137
Total liabilities and equity (deficit)	623
Colonial
Statements of Income
Total revenues	829
Total operating expenses	449
Operating income	380
Net income	255
Balance Sheets
Current assets	323
Non-current assets	2,920
Total assets	3,243
Current liabilities	519
Non-current liabilities	2,873
Equity (Deficit)	(149)
Total liabilities and equity (deficit)	3,243
Poseidon
Statements of Income
Total revenues	132	116	117
Total operating expenses	35	35	33
Operating income	97	81	84
Net income	87	73	79
Balance Sheets
Current assets	30	19	19
Non-current assets	190	203	218
Total assets	220	222	237
Current liabilities	16	16	18
Non-current liabilities	246	243	237
Equity (Deficit)	(42)	(37)	(18)
Total liabilities and equity (deficit)	220	222	237
Other
Statements of Income
Total revenues	190	152	124
Total operating expenses	108	67	46
Operating income	82	85	78
Net income	73	76	66
Balance Sheets
Current assets	60	50	92
Non-current assets	917	876	625
Total assets	977	926	717
Current liabilities	73	65	99
Non-current liabilities	469	456	245
Equity (Deficit)	435	405	373
Total liabilities and equity (deficit)	977	926	717
May 2018 Acquisition | Amberjack
Statements of Income
Total revenues		295
Total operating expenses		74
Operating income		$ 221
June 2019 Acquisition | Explorer
Statements of Income
Total revenues	443
Total operating expenses	196
Operating income	247
June 2019 Acquisition | Colonial
Statements of Income
Total revenues	1,437
Total operating expenses	735
Operating income	$ 702
October 2017 Acquisitions | Permian Basin
Statements of Income
Total revenues			8
Total operating expenses			5
Operating income			$ 3

Property, Plant and Equipment -

Property, Plant and Equipment - Components of Property, Plant and Equipment (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Property Plant And Equipment [Line Items]
Land	$ 11	$ 11
Building and improvements	40	39
Pipeline and equipment	1,228	1,162
Other	33	18
Property, plant and equipment, gross	1,312	1,230
Accumulated depreciation, and amortization	(613)	(567)
Property plant and equipment excluding construction in progress	699	663
Construction in progress	27	79
Property, plant and equipment, net	726	742
Operating lease cost	0
Accumulated depreciation related to assets under operating leases	133	121
Accumulated depreciation related to assets under capital lease	6	5
Building and Improvements | Minimum
Property Plant And Equipment [Line Items]
Property, plant and equipment, depreciable life			10 years
Building and Improvements | Maximum
Property Plant And Equipment [Line Items]
Property, plant and equipment, depreciable life			40 years
Pipeline and Equipment
Property Plant And Equipment [Line Items]
Operating lease cost	369	366
Finance lease cost	$ 23	$ 23
Pipeline and Equipment | Minimum
Property Plant And Equipment [Line Items]
Property, plant and equipment, depreciable life			10 years
Pipeline and Equipment | Maximum
Property Plant And Equipment [Line Items]
Property, plant and equipment, depreciable life			30 years
Other | Minimum
Property Plant And Equipment [Line Items]
Property, plant and equipment, depreciable life			5 years
Other | Maximum
Property Plant And Equipment [Line Items]
Property, plant and equipment, depreciable life			25 years

Property, Plant and Equipment_2

Property, Plant and Equipment - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Property, Plant and Equipment [Abstract]
Depreciation, amortization and accretion	$ 49	$ 46	$ 45

Accrued Liabilities - Third P_3

Accrued Liabilities - Third Parties (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Payables and Accruals [Abstract]
Project accruals	$ 5	$ 7
Property taxes	4	4
Other accrued liabilities	3	2
Accrued liabilities - third parties	$ 12	$ 13

Related Party Debt - Schedule o

Related Party Debt - Schedule of Consolidated Related Party Debt Obligations (Details) - USD ($)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Aug. 01, 2018
Line Of Credit Facility [Line Items]
Outstanding Balance	$ 2,692,000,000	$ 2,091,000,000
Total Capacity	3,590,000,000	2,990,000,000
Available Capacity	896,000,000	896,000,000
Unamortized debt issuance costs	$ (2,000,000)	(3,000,000)
Five Year Revolver due July 2023
Line Of Credit Facility [Line Items]
Debt instrument term	5 years
Revolving Credit Facility | Ten Year Fixed Facility
Line Of Credit Facility [Line Items]
Debt instrument term	10 years
Outstanding Balance	$ 600,000,000	0
Total Capacity	600,000,000	0
Available Capacity	$ 0	0
Revolving Credit Facility | Seven Year Fixed Facility
Line Of Credit Facility [Line Items]
Debt instrument term	7 years
Outstanding Balance	$ 600,000,000	600,000,000
Total Capacity	600,000,000	600,000,000
Available Capacity	$ 0	0
Revolving Credit Facility | Five Year Revolver due July 2023
Line Of Credit Facility [Line Items]
Debt instrument term	5 years
Outstanding Balance	$ 494,000,000	494,000,000
Total Capacity	760,000,000	760,000,000	$ 760,000,000
Available Capacity	$ 266,000,000	266,000,000
Revolving Credit Facility | Five Year Revolver due December 2022
Line Of Credit Facility [Line Items]
Debt instrument term	5 years
Outstanding Balance	$ 400,000,000	400,000,000
Total Capacity	1,000,000,000	1,000,000,000
Available Capacity	$ 600,000,000	600,000,000
Revolving Credit Facility | Five Year Fixed Facility
Line Of Credit Facility [Line Items]
Debt instrument term	5 years
Outstanding Balance	$ 600,000,000	600,000,000
Total Capacity	600,000,000	600,000,000
Available Capacity	0	0
Revolving Credit Facility | 2019 Zydeco Revolver
Line Of Credit Facility [Line Items]
Outstanding Balance	0	0
Total Capacity	30,000,000	30,000,000
Available Capacity	$ 30,000,000	$ 30,000,000

Related Party Debt - Additional

Related Party Debt - Additional Information (Details) - USD ($)

May 11, 2018

Feb. 06, 2018

Dec. 01, 2017

Sep. 15, 2017

May 10, 2017

Dec. 31, 2019

Dec. 31, 2018

Dec. 31, 2017

Aug. 06, 2019

Aug. 01, 2018

Jul. 31, 2018

Mar. 01, 2017

Line Of Credit Facility [Line Items]

Interest and fee expenses associated with borrowings

$ 92,000,000

$ 61,000,000

$ 29,000,000

Interest paid

88,000,000

53,000,000

25,000,000

Long-term debt, carrying value

2,694,000,000

2,094,000,000

Long-term debt, fair value

2,825,000,000

2,099,000,000

Repayments of credit facilities

0

1,573,000,000

$ 533,000,000

Maximum borrowing capacity

$ 3,590,000,000

2,990,000,000

Seven Year Fixed Facility | Revolving Credit Facility

Line Of Credit Facility [Line Items]

Debt instrument term

7 years

Maximum borrowing capacity

$ 600,000,000

600,000,000

Fixed interest rate

4.06%

Debt issuance costs

$ 1,000,000

Five Year Revolver due July 2023

Line Of Credit Facility [Line Items]

Debt instrument term

5 years

Five Year Revolver due July 2023 | Revolving Credit Facility

Line Of Credit Facility [Line Items]

Interest paid

$ 1,000,000

Debt instrument term

5 years

Repayments of credit facilities

$ 247,000,000

268,000,000

$ 265,000,000

Maximum borrowing capacity

$ 760,000,000

760,000,000

$ 760,000,000

Fixed interest rate

0.19%

Weighted average interest rate

3.57%

Five Year Revolver due December 2022 | Revolving Credit Facility

Line Of Credit Facility [Line Items]

Debt instrument term

5 years

Borrowings under credit facilities

$ 1,000,000,000

Repayments of credit facilities

$ 726,000,000

Maximum borrowing capacity

$ 1,000,000,000

1,000,000,000

Five Year Revolver due December 2022 | Revolving Credit Facility | Affiliated Entity | Shell Treasury Center West Inc

Line Of Credit Facility [Line Items]

Unused capacity commitment fee percentage

0.19%

Maximum borrowing capacity

$ 1,000,000,000

Debt issuance costs

2,000,000

Weighted average interest rate

3.76%

2019 Zydeco Revolver | Revolving Credit Facility

Line Of Credit Facility [Line Items]

Maximum borrowing capacity

$ 30,000,000

30,000,000

2019 Zydeco Revolver | Revolving Credit Facility | Affiliated Entity | Shell Treasury Center West Inc

Line Of Credit Facility [Line Items]

Maximum borrowing capacity

$ 30,000,000

Fixed interest rate

2.59%

Five Year Fixed Facility | Revolving Credit Facility

Line Of Credit Facility [Line Items]

Debt instrument term

5 years

Borrowings under credit facilities

93,000,000

Maximum borrowing capacity

$ 600,000,000

600,000,000

Five Year Fixed Facility | Revolving Credit Facility | Affiliated Entity | Shell Treasury Center West Inc

Line Of Credit Facility [Line Items]

Maximum borrowing capacity

$ 600,000,000

Fixed interest rate

3.23%

Debt issuance costs

$ 1,000,000

Ten Year Fixed Facility | Revolving Credit Facility

Line Of Credit Facility [Line Items]

Debt instrument term

10 years

Maximum borrowing capacity

$ 600,000,000

$ 0

Ten Year Fixed Facility | Revolving Credit Facility | Affiliated Entity | Shell Treasury Center West Inc

Line Of Credit Facility [Line Items]

Maximum borrowing capacity

$ 600,000,000

Fixed interest rate

4.18%

December 2017 Acquisition

Line Of Credit Facility [Line Items]

Consideration transferred

825,000,000

December 2017 Acquisition | Five Year Fixed Facility

Line Of Credit Facility [Line Items]

Consideration, funded with borrowings

$ 825,000,000

May 2017 Acquisition

Line Of Credit Facility [Line Items]

Consideration, cash on hand

$ 50,000,000

May 2017 Acquisition | Five Year Revolver due July 2023 | Revolving Credit Facility

Line Of Credit Facility [Line Items]

Consideration, funded with borrowings

73,000,000

May 2017 Acquisition | Five Year Fixed Facility | Revolving Credit Facility

Line Of Credit Facility [Line Items]

Consideration, funded with borrowings

$ 507,000,000

May 2018 Acquisition

Line Of Credit Facility [Line Items]

Consideration transferred

$ 1,220,000,000

May 2018 Acquisition | Five Year Revolver due July 2023 | Revolving Credit Facility | Affiliated Entity | Shell Treasury Center West Inc

Line Of Credit Facility [Line Items]

Consideration transferred

494,000,000

May 2018 Acquisition | Five Year Revolver due December 2022 | Revolving Credit Facility | Affiliated Entity | Shell Treasury Center West Inc

Line Of Credit Facility [Line Items]

Consideration transferred

$ 726,000,000

Leases - Additional Information

Leases - Additional Information (Details) $ in Millions	12 Months Ended
	Dec. 31, 2019USD ($)renewal_optionlease	Jan. 01, 2019USD ($)	Dec. 31, 2018USD ($)
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Operating lease right-of-use assets	$ 4		$ 0
Number of finance leases | lease	2
Present value of lease liabilities	$ 4
Unconditional payment obligations	$ 5		$ 8
Accounting Standards Update 2016-02
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Operating lease right-of-use assets		$ 5
Present value of lease liabilities		$ 5
Ten Year Agreement, Five Year Renewal Option
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Lease revenue related party agreements, term	10 years
Lease revenue related party agreements, renewal term	5 years
Number of renewal options | renewal_option	2
Ten Year Agreement, One Year Renewal Option
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Lease revenue related party agreements, renewal term	1 year
Number of renewal options | renewal_option	10

Leases - Assets and Liabilities

Leases - Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Leases [Abstract]
Operating lease right-of-use assets	$ 4	$ 0
Finance lease assets	17
Total lease assets	21
Current finance lease liabilities	1
Operating lease liabilities	4	0
Finance lease liability	24	$ 25
Total lease liabilities	29
Finance lease, right of use asset, accumulated depreciation	$ 6

Leases - Lease Cost (Details)

Leases - Lease Cost (Details) $ in Millions	12 Months Ended
	Dec. 31, 2019USD ($)
Leases [Abstract]
Operating lease cost	$ 0
Finance lease cost, amortization of leased assets	1
Finance lease cost, interest on lease liabilities	4
Total lease cost	$ 5

Leases - Supplemental Cash Flow

Leases - Supplemental Cash Flows (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Leases [Abstract]
Operating cash flows from operating leases	$ 0
Operating cash flows from finance leases	(4)
Financing cash flows from finance leases	$ (1)	$ 0	$ 0
Weighted-average remaining lease term - operating leases	20 years
Weighted-average remaining lease term - finance leases	11 years
Weighted-average discount rate - operating leases	5.80%
Weighted-average discount rate - finance leases	14.30%

Leases - Maturities of Operatin

Leases - Maturities of Operating and Financing Lease Liabilities (Details) $ in Millions	Dec. 31, 2019USD ($)
Lessee, Operating Lease, Liability, Payment, Due [Abstract]
2020	$ 0
2021	1
2022	0
2023	1
2024	0
Remainder	6
Total lease payments	8
Less: Interest	(4)
Present value of lease liabilities	4
Operating lease, payments due, related to options to extend	2
Finance Lease, Liability, Payment, Due [Abstract]
2020	4
2021	4
2022	4
2023	4
2024	5
Remainder	31
Total lease payments	52
Less: Interest	(27)
Present value of lease liabilities	25
Finance lease, liability, payments due, principal amounts	25
Finance lease, liability, payments due, executory costs	9
Current finance lease liabilities	1
Operating And Finance Lease, Liabilities, Payments Due [Abstract]
2020	4
2021	5
2022	4
2023	5
2024	5
Remainder	37
Total lease payments	60
Less: Interest	(31)
Present value of lease liabilities	$ 29

Leases - Maturity of Lease Paym

Leases - Maturity of Lease Payments to be Received (Details) $ in Millions	Dec. 31, 2019USD ($)
Leases [Abstract]
2020	$ 56
2021	56
2022	56
2023	56
2024	56
Remainder	551
Total lease payments	831
Operating lease, payments to be received, related to options to extend	$ 411

Accumulated Other Comprehensi_2

Accumulated Other Comprehensive Loss (Details) $ in Millions	12 Months Ended
	Dec. 31, 2019USD ($)
Equity [Abstract]
Other comprehensive loss	$ (2)

(Deficit) Equity - Additional I

(Deficit) Equity - Additional Information (Details) - USD ($) $ / shares in Units, $ in Millions	Feb. 06, 2018	Sep. 15, 2017	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Class of Stock [Line Items]
Distributions declared and/or paid			$ 162	$ 140	$ 131	$ 119	$ 129	$ 121	$ 113	$ 106	$ 83	$ 77	$ 68	$ 64	$ 59
Distributions per Limited Partner unit (in dollars per share)			$ 0.46000	$ 0.44500	$ 0.43000	$ 0.41500	$ 0.40000	$ 0.38200	$ 0.36500	$ 0.34800	$ 0.33300	$ 0.31800	$ 0.30410	$ 0.29100	$ 0.27700	$ 1.7500	$ 1.4950	$ 1.2461
General Partner
Class of Stock [Line Items]
Distributions declared and/or paid			$ 3	$ 3	$ 3	$ 3	$ 3	$ 3	$ 2	$ 2	$ 2	$ 2	$ 1	$ 1	$ 1
General Partner | General Partner Interest
Class of Stock [Line Items]
Aggregate percentage of interest																2.00%
General Partner | Shell Pipeline Company L P | General Partner Interest
Class of Stock [Line Items]
Aggregate percentage of interest	2.00%	2.00%														2.00%
Limited Partner | Shell Pipeline Company L P | Limited Partner Interest
Class of Stock [Line Items]
Aggregate percentage of interest																98.00%

(Deficit) Equity - Public Offer

(Deficit) Equity - Public Offerings and Private Placement (Details) - USD ($) $ / shares in Units, $ in Millions	Feb. 06, 2018	Sep. 15, 2017	Sep. 30, 2017	Jun. 30, 2017	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Class of Stock [Line Items]
Units issued in connection with public offering (in units)						36,764,707
Net proceeds from equity offerings						$ 973	$ 278
Contributions from general partner	$ 14	$ 3				20	6
Consideration for units issued in connection with private placement					$ 0	$ 20	6
Five Year Revolver Due December 2022
Class of Stock [Line Items]
Debt instrument term					5 years
Repayments of Debt					$ 726
Five Year Revolver due July 2023
Class of Stock [Line Items]
Debt instrument term					5 years
Repayments of Debt					$ 247
Common units - SPLC
Class of Stock [Line Items]
Units issued in connection with private placement (in units)	11,029,412		5,200,000	94,925	1,000,000,000
Common units per share (in units per share)	$ 27.20		$ 26.96	$ 31.51
Net proceeds from private equity placement	$ 300		$ 140	$ 3
Consideration for units issued in connection with private placement	$ 6
Common units - SPLC | General Public
Class of Stock [Line Items]
Units issued in connection with public offering (in units)	25,000,000	5,170,000				25,000,000
Net proceeds from equity offerings	$ 673	$ 135
Gross proceeds from public offering	$ 680
Common units per share (in units per share)	$ 27.20
Underwriter fees	$ 6
Placement fees	$ 1
Common units - SPLC | Shell Pipeline Company L P
Class of Stock [Line Items]
Units issued in connection with public offering (in units)						11,029,412
General Partner
Class of Stock [Line Items]
Units issued in connection with private placement (in units)	225,091		106,122	1,938
Units issued in connection with public offering (in units)	510,204	105,510				735,295
Consideration for units issued in connection with private placement			$ 3
General Partner | General Partner Interest
Class of Stock [Line Items]
Aggregate percentage of interest					2.00%
General Partner | Shell Pipeline Company L P
Class of Stock [Line Items]
Net proceeds from equity offerings							0
Contributions from general partner						$ 20	$ 6
General Partner | Shell Pipeline Company L P | General Partner Interest
Class of Stock [Line Items]
Aggregate percentage of interest	2.00%	2.00%			2.00%

(Deficit) Equity - At-the-Marke

(Deficit) Equity - At-the-Market Program (Details) - USD ($)	Feb. 06, 2018	Sep. 15, 2017	Sep. 30, 2017	Jun. 30, 2017	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Class of Stock [Line Items]
Issuance of common units, maximum (in units)					$ 300,000,000
Consideration for units issued in connection with private placement					$ 0	$ 20,000,000	$ 6,000,000
Five Year Revolver due July 2023
Class of Stock [Line Items]
Debt instrument term					5 years
Five Year Revolver due July 2023 | Revolving Credit Facility
Class of Stock [Line Items]
Debt instrument term					5 years
Common units - SPLC
Class of Stock [Line Items]
Units issued in connection with private placement (in units)	11,029,412		5,200,000	94,925	1,000,000,000
Net proceeds from private equity placement	$ 300,000,000		$ 140,000,000	$ 3,000,000
Common units per share (in units per share)	$ 27.20		$ 26.96	$ 31.51
Consideration for units issued in connection with private placement	$ 6,000,000
General Partner
Class of Stock [Line Items]
Units issued in connection with private placement (in units)	225,091		106,122	1,938
Consideration for units issued in connection with private placement			$ 3,000,000
General Partner | General Partner Interest
Class of Stock [Line Items]
Aggregate percentage of interest					2.00%
Shell Pipeline Company L P | General Partner | General Partner Interest
Class of Stock [Line Items]
Aggregate percentage of interest	2.00%	2.00%			2.00%

(Deficit) Equity - Units Outsta

(Deficit) Equity - Units Outstanding (Details) - shares	Feb. 06, 2018	Sep. 15, 2017	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Class of Stock [Line Items]
Limited partners' capital account, units outstanding (in units)			233,289,537
Capital units, publicly owned (in units)			238,050,549	228,379,369	191,614,662
General Partner
Class of Stock [Line Items]
Capital units, publicly owned (in units)				4,567,588	3,832,293
General Partner | General Partner Interest
Class of Stock [Line Items]
Aggregate percentage of interest			2.00%
General Public | Common units - SPLC
Class of Stock [Line Items]
Limited partners' capital account, units outstanding (in units)			123,832,233	123,832,233
Capital units, publicly owned (in units)			123,832,233	123,832,233	98,832,233
Shell Pipeline Company L P
Class of Stock [Line Items]
General partners' capital account, units outstanding (in units)			4,761,012	4,567,588
Shell Pipeline Company L P | Common units - SPLC
Class of Stock [Line Items]
Limited partners' capital account, units outstanding (in units)			109,457,304	99,979,548
Capital units, publicly owned (in units)			109,457,304	99,979,548	88,950,136
Shell Pipeline Company L P | Limited Partner | Limited Partner Interest
Class of Stock [Line Items]
Ownership interest (in percentage)			46.00%
Aggregate percentage of interest			98.00%
Shell Pipeline Company L P | General Partner
Class of Stock [Line Items]
Capital units, publicly owned (in units)			4,761,012
Shell Pipeline Company L P | General Partner | General Partner Interest
Class of Stock [Line Items]
Aggregate percentage of interest	2.00%	2.00%	2.00%

(Deficit) Equity - Schedule of

(Deficit) Equity - Schedule of Number of Units Outstanding (Details) - shares	Feb. 06, 2018	Sep. 15, 2017	Dec. 31, 2019	Dec. 31, 2018
Increase (Decrease) in Partners' Capital [Roll Forward]
Beginning balance (in units)			228,379,369	191,614,662
Units issued in connection with public offering (in units)				36,764,707
June 2019 Acquisition (in units)			9,671,180
Ending balance (in units)			238,050,549	228,379,369
General Partner
Increase (Decrease) in Partners' Capital [Roll Forward]
Beginning balance (in units)			4,567,588	3,832,293
Units issued in connection with public offering (in units)	510,204	105,510		735,295
June 2019 Acquisition (in units)			193,424
Ending balance (in units)				4,567,588
General Public | Common units - SPLC
Increase (Decrease) in Partners' Capital [Roll Forward]
Beginning balance (in units)			123,832,233	98,832,233
Units issued in connection with public offering (in units)	25,000,000	5,170,000		25,000,000
June 2019 Acquisition (in units)			0
Ending balance (in units)			123,832,233	123,832,233
Shell Pipeline Company L P | Common units - SPLC
Increase (Decrease) in Partners' Capital [Roll Forward]
Beginning balance (in units)			99,979,548	88,950,136
Units issued in connection with public offering (in units)				11,029,412
June 2019 Acquisition (in units)			9,477,756
Ending balance (in units)			109,457,304	99,979,548
Shell Pipeline Company L P | General Partner
Increase (Decrease) in Partners' Capital [Roll Forward]
Ending balance (in units)			4,761,012

(Deficit) Equity - Expiration o

(Deficit) Equity - Expiration of Subordination Period (Details)	Feb. 15, 2017shares
Common units
Class of Stock [Line Items]
Shares converted (in shares)	67,475,068

(Deficit) Equity - Schedule o_2

(Deficit) Equity - Schedule of Distributions Declared and/or Paid (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended													12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Distribution Made To Limited Partner [Line Items]
Distribution to holders of incentive distribution rights waived		$ 16	$ 17	$ 17										$ 50
Distributions declared and/or paid	$ 162	$ 140	$ 131	$ 119	$ 129	$ 121	$ 113	$ 106	$ 83	$ 77	$ 68	$ 64	$ 59
Distributions per Limited Partner unit (in dollars per share)	$ 0.46000	$ 0.44500	$ 0.43000	$ 0.41500	$ 0.40000	$ 0.38200	$ 0.36500	$ 0.34800	$ 0.33300	$ 0.31800	$ 0.30410	$ 0.29100	$ 0.27700	$ 1.7500	$ 1.4950	$ 1.2461
Shell Midstream Partners L.P.
Distribution Made To Limited Partner [Line Items]
Aggregate percentage of interest														200.00%
Common units - SPLC | General Public
Distribution Made To Limited Partner [Line Items]
Distributions declared and/or paid	$ 57	$ 56	$ 53	$ 51	$ 49	$ 47	$ 46	$ 43	$ 33	$ 31	$ 27	$ 26	$ 25
Common units - SPLC | Shell Pipeline Company L P
Distribution Made To Limited Partner [Line Items]
Distributions declared and/or paid	50	48	47	42	40	38	36	35	30	28	27	26	6
Subordinated Units | Shell Pipeline Company L P
Distribution Made To Limited Partner [Line Items]
Distributions declared and/or paid	0	0	0	0	0	0	0	0	0	0	0	0	18
General Partner
Distribution Made To Limited Partner [Line Items]
Distributions declared and/or paid	3	3	3	3	3	3	2	2	2	2	1	1	1
General Partner | General Partner IDR's
Distribution Made To Limited Partner [Line Items]
Distributions declared and/or paid	$ 52	$ 33	$ 28	$ 23	$ 37	$ 33	$ 29	$ 26	$ 18	$ 16	$ 13	$ 11	$ 9

(Deficit) Equity - Distribution

(Deficit) Equity - Distributions to Noncontroling Interest (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Zydeco Pipeline Company LLC (“Zydeco”)
Class of Stock [Line Items]
Distributions to noncontrolling interest	$ 4	$ 7	$ 9
Odyssey Pipeline L.L.C.
Class of Stock [Line Items]
Distributions to noncontrolling interest	$ 13	$ 9	$ 10

Revenue Recognition - Additiona

Revenue Recognition - Additional Information (Details) $ in Millions	12 Months Ended
	Dec. 31, 2019term	Jan. 01, 2019USD ($)	Jan. 01, 2018USD ($)
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Impact of changes in accounting policy		$ (9)	$ (2)
Transportation Services Operating Leases Five Year Terms
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Lease revenue related party agreements, term	10 years
Lessor, number of renewal terms | term	2
Lease revenue related party agreements, renewal term	5 years
Transportation Services Operating Leases One Year Terms
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Lease revenue related party agreements, term	10 years
Lessor, number of renewal terms | term	10
Lease revenue related party agreements, renewal term	1 year
Transportation Services Operating Leases
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Lease revenue related party agreements, term	10 years
Accounting Standards Update 2014-09
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Cumulative effect transition adjustment resulting from earlier recognition of revenue			(2)
Accounting Standards Update 2014-09 | Difference between Revenue Guidance in Effect before and after Topic 606
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Cumulative effect transition adjustment resulting from earlier recognition of revenue			5
Mars Oil Pipeline Company LLC (“Mars”) | Accounting Standards Update 2014-09
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Impact of changes in accounting policy		$ (9)	$ (7)

Revenue Recognition - Disaggreg

Revenue Recognition - Disaggregated Revenue (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Revenue Recognition, Multiple-deliverable Arrangements [Line Items]
Revenue from contract with customer									$ 447	$ 469	$ 414
Total revenue	$ 126	$ 125	$ 121	$ 131	$ 143	$ 153	$ 129	$ 100	503	525	470
Third Parties | Transportation Services
Revenue Recognition, Multiple-deliverable Arrangements [Line Items]
Revenue from contract with customer									134	200	227
Third Parties | Storage Services
Revenue Recognition, Multiple-deliverable Arrangements [Line Items]
Revenue from contract with customer									9	9	9
Third Parties | Product Revenue
Revenue Recognition, Multiple-deliverable Arrangements [Line Items]
Revenue from contract with customer									5	2	0
Related Parties
Revenue Recognition, Multiple-deliverable Arrangements [Line Items]
Lease revenue – related parties									56	56	56
Related Parties | Transportation Services
Revenue Recognition, Multiple-deliverable Arrangements [Line Items]
Revenue from contract with customer									210	176	172
Related Parties | Storage Services
Revenue Recognition, Multiple-deliverable Arrangements [Line Items]
Revenue from contract with customer									7	7	6
Related Parties | Terminaling Services
Revenue Recognition, Multiple-deliverable Arrangements [Line Items]
Revenue from contract with customer									47	46	0
Related Parties | Product Revenue
Revenue Recognition, Multiple-deliverable Arrangements [Line Items]
Revenue from contract with customer									35	$ 29	$ 0
Related Parties | Transportation Services Nonlease Service
Revenue Recognition, Multiple-deliverable Arrangements [Line Items]
Revenue from contract with customer									$ 5

Revenue Recognition - Future Mi

Revenue Recognition - Future Minimum Payments Receivable (Details) $ in Millions	Dec. 31, 2019USD ($)
Revenue Recognition, Multiple-deliverable Arrangements [Line Items]
Total lease payments	$ 831
Less than 1 year	56
More than 5 years	551
Transportation Services Operating Leases
Revenue Recognition, Multiple-deliverable Arrangements [Line Items]
Total lease payments	838
Less than 1 year	110
Years 2 to 3	219
Years 4 to 5	219
More than 5 years	$ 290

Revenue Recognition - Impact of

Revenue Recognition - Impact of Adoption (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Revenue from contract with customer									$ 447	$ 469	$ 414
Lease revenue – related parties									56	56
Operations and maintenance – third parties									65	108	104
Costs and Expenses, Related Party									59	54	46
Cost of product sold – third parties									5	7	0
Cost of product sold – related parties									31	25	0
Net income	$ 144	$ 146	$ 119	$ 137	$ 147	$ 155	$ 115	$ 65	546	482	392
Deferred revenue – related party	0				3				0	3
Third Parties | Transportation, Terminaling And Storage Services
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Revenue from contract with customer									143	209	236
Third Parties | Product Revenue
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Revenue from contract with customer									5	2	0
Related Parties | Transportation, Terminaling And Storage Services
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Revenue from contract with customer									264	229	178
Related Parties | Product Revenue
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Revenue from contract with customer									35	29	$ 0
Calculated under Revenue Guidance in Effect before Topic 606
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Lease revenue – related parties									108	107
Operations and maintenance – third parties									64	107
Costs and Expenses, Related Party									58	52
Cost of product sold – third parties									0	6
Cost of product sold – related parties									0	0
Net income									546	487
Calculated under Revenue Guidance in Effect before Topic 606 | Third Parties | Transportation, Terminaling And Storage Services
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Revenue from contract with customer									142	209
Calculated under Revenue Guidance in Effect before Topic 606 | Third Parties | Product Revenue
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Revenue from contract with customer									0	0
Calculated under Revenue Guidance in Effect before Topic 606 | Related Parties | Transportation, Terminaling And Storage Services
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Revenue from contract with customer									215	183
Calculated under Revenue Guidance in Effect before Topic 606 | Related Parties | Product Revenue
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Revenue from contract with customer									0	0
Difference between Revenue Guidance in Effect before and after Topic 606
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Deferred revenue – related party	0				3				0	3
Accounting Standards Update 2014-09 | Difference between Revenue Guidance in Effect before and after Topic 606
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Lease revenue – related parties									(52)	(51)
Operations and maintenance – third parties									1	1
Costs and Expenses, Related Party									1	2
Cost of product sold – third parties									5	1
Cost of product sold – related parties									31	25
Net income									0	(5)
Deferred revenue – related party	$ 0				$ 0				0	0
Accounting Standards Update 2014-09 | Difference between Revenue Guidance in Effect before and after Topic 606 | Third Parties | Transportation, Terminaling And Storage Services
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Revenue from contract with customer									1	0
Accounting Standards Update 2014-09 | Difference between Revenue Guidance in Effect before and after Topic 606 | Third Parties | Product Revenue
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Revenue from contract with customer									5	2
Accounting Standards Update 2014-09 | Difference between Revenue Guidance in Effect before and after Topic 606 | Related Parties | Transportation, Terminaling And Storage Services
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Revenue from contract with customer									49	46
Accounting Standards Update 2014-09 | Difference between Revenue Guidance in Effect before and after Topic 606 | Related Parties | Product Revenue
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Revenue from contract with customer									$ 35	$ 29

Revenue Recognition - Receivabl

Revenue Recognition - Receivables and Contract Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2019	Jan. 01, 2019	Dec. 31, 2018	Jan. 01, 2018	Dec. 31, 2017
Disaggregation of Revenue [Line Items]
Accounts receivable – third parties, net	$ 12		$ 19
Deferred revenue	0		8
Third Parties
Disaggregation of Revenue [Line Items]
Accounts receivable – third parties, net	11	$ 19	19	$ 17
Deferred revenue	0	8	8	6	$ 6
Related Parties
Disaggregation of Revenue [Line Items]
Accounts receivable – third parties, net	24	21	21	19
Deferred revenue	$ 0	$ 3	$ 3	$ 9	$ 14

Revenue Recognition - Contract

Revenue Recognition - Contract Balances (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Movement in Deferred Revenue [Roll Forward]
Beginning balance	$ 8
Ending balance	0	$ 8
Third Parties
Movement in Deferred Revenue [Roll Forward]
Beginning balance	8	6
Transition Adjustment	0	0
Additions	0	10
Reductions	(8)	(8)
Ending balance	0	8
Related Parties
Movement in Deferred Revenue [Roll Forward]
Beginning balance	3	14
Transition Adjustment	0	(4)
Additions	0	3
Reductions	(3)	(10)
Ending balance	$ 0	$ 3

Revenue Recognition - Remaining

Revenue Recognition - Remaining Performance Obligations (Details) $ in Millions	Dec. 31, 2019USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	$ 1,016
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	$ 163
Remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	$ 120
Remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	$ 120
Remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	$ 120
Remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	$ 493
Remaining performance obligation, expected timing of satisfaction, period
Transportation Services
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	$ 577
Transportation Services | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	106
Transportation Services | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	63
Transportation Services | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	63
Transportation Services | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	63
Transportation Services | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	282
Transportation Services Nonlease Services
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	40
Transportation Services Nonlease Services | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	5
Transportation Services Nonlease Services | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	5
Transportation Services Nonlease Services | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	5
Transportation Services Nonlease Services | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	5
Transportation Services Nonlease Services | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	20
Storage Services
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	21
Storage Services | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	4
Storage Services | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	4
Storage Services | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	4
Storage Services | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	4
Storage Services | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	5
Terminaling Services
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	378
Terminaling Services | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	48
Terminaling Services | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	48
Terminaling Services | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	48
Terminaling Services | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	48
Terminaling Services | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, amount	$ 186

Net Income Per Limited Partne_3

Net Income Per Limited Partner Unit - Schedule of Allocation of Net Income to Arrive at Net Income Per Limited Partner Unit (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Limited Partners Capital Account [Line Items]
Net income	$ 144	$ 146	$ 119	$ 137	$ 147	$ 155	$ 115	$ 65	$ 546	$ 482	$ 392
Net income attributable to the Parent									0	0	77
Net income attributable to noncontrolling interests									18	18	20
Net income attributable to the Partnership	$ 140	$ 141	$ 115	$ 132	$ 140	$ 149	$ 111	$ 64	528	464	295
Partner distribution declared									552	469	292
Income (less than)/in excess of distributions									(24)	(5)	3
General Partner
Limited Partners Capital Account [Line Items]
Net income attributable to the Partnership									147	134	64
Partner distribution declared									148	135	64
Income (less than)/in excess of distributions									(1)	(1)	0
Common
Limited Partners Capital Account [Line Items]
Net income attributable to the Partnership									381	330	231
Partner distribution declared									404	334	228
Income (less than)/in excess of distributions									$ (23)	$ (4)	$ 3

Net Income Per Limited Partne_4

Net Income Per Limited Partner Unit - Schedule of Basic and Diluted Net Income Per Unit (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Distribution Made To Limited Partner [Line Items]
Distributions declared									$ 552	$ 469	$ 292
Income (less than)/in excess of distributions									(24)	(5)	3
Net income attributable to the Partnership	$ 140	$ 141	$ 115	$ 132	$ 140	$ 149	$ 111	$ 64	528	464	295
Net income per limited partner unit:
Basic and diluted (in dollars per share)	$ 0.37	$ 0.45	$ 0.38	$ 0.47	$ 0.45	$ 0.50	$ 0.35	$ 0.18
General Partner
Distribution Made To Limited Partner [Line Items]
Distributions declared									148	135	64
Income (less than)/in excess of distributions									(1)	(1)	0
Net income attributable to the Partnership									147	134	64
Common
Distribution Made To Limited Partner [Line Items]
Distributions declared									404	334	228
Income (less than)/in excess of distributions									(23)	(4)	3
Net income attributable to the Partnership									$ 381	$ 330	$ 231
Weighted average units outstanding:
Basic and diluted (in shares)									229.2	220.3	180.4
Net income per limited partner unit:
Basic and diluted (in dollars per share)									$ 1.66	$ 1.50	$ 1.28

Transactions with Major Custo_2

Transactions with Major Customers and Concentration of Credit Risk - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Concentration Risk [Line Items]
Cash and cash equivalents in excess of FDIC limits	$ 289	$ 207
Maximum
Concentration Risk [Line Items]
Receivables payment terms	30 days
Sales Revenue Net | Parent and Affiliates
Concentration Risk [Line Items]
Revenue with parent as percentage of total revenues	70.00%	60.00%	50.00%

Commitments and Contingencies (

Commitments and Contingencies (Details)	Jul. 01, 2019	Sep. 01, 2016
Commitments and Contingencies Disclosure [Abstract]
Traffic rate increase	4.30%
Initial term of contract		10 years
Renewal term		1 year

Subsequent Events (Details)

Subsequent Events (Details) - USD ($) $ / shares in Units, $ in Millions	Feb. 18, 2020	Jan. 22, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Subsequent Event [Line Items]
Distributions per Limited Partner unit (in dollars per share)			$ 0.46000	$ 0.44500	$ 0.43000	$ 0.41500	$ 0.40000	$ 0.38200	$ 0.36500	$ 0.34800	$ 0.33300	$ 0.31800	$ 0.30410	$ 0.29100	$ 0.27700	$ 1.7500	$ 1.4950	$ 1.2461
Subsequent Event
Subsequent Event [Line Items]
Distributions per Limited Partner unit (in dollars per share)		$ 0.4600
General and administrative fee, percent increase	3.00%
Administrative fee payable	$ 11

Selected Quarterly Financial _3

Selected Quarterly Financial Data (Unaudited) (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Quarterly Financial Information Disclosure [Abstract]
Total Revenues	$ 126	$ 125	$ 121	$ 131	$ 143	$ 153	$ 129	$ 100	$ 503	$ 525	$ 470
Income Before Income Taxes	144	146	119	137	148	155	115	65	546	483	392
Net income	144	146	119	137	147	155	115	65	546	482	392
Net Income Attributable to the Partnership	140	141	115	132	140	149	111	64	528	464	295
Limited Partners’ Interest in Net Income Attributable to the Partnership	$ 86	$ 105	$ 85	$ 105	$ 102	$ 112	$ 79	$ 37	$ 381	$ 330	$ 231
Net income per Limited Partner Unit - Basic and Diluted (in dollars per share)	$ 0.37	$ 0.45	$ 0.38	$ 0.47	$ 0.45	$ 0.50	$ 0.35	$ 0.18

Uncategorized Items - shlx-2019

Label	Element	Value
Common Units Public [Member]
Cumulative Effect of New Accounting Principle in Period of Adoption	us-gaap_CumulativeEffectOfNewAccountingPrincipleInPeriodOfAdoption	$ (4,000,000)
Cumulative Effect of New Accounting Principle in Period of Adoption	us-gaap_CumulativeEffectOfNewAccountingPrincipleInPeriodOfAdoption	(1,000,000)
Shell Pipeline Company L P [Member] | Common Units Public [Member]
Cumulative Effect of New Accounting Principle in Period of Adoption	us-gaap_CumulativeEffectOfNewAccountingPrincipleInPeriodOfAdoption	1,000,000
Cumulative Effect of New Accounting Principle in Period of Adoption	us-gaap_CumulativeEffectOfNewAccountingPrincipleInPeriodOfAdoption	(5,000,000)
Shell Pipeline Company L P [Member] | General Partner [Member]
Cumulative Effect of New Accounting Principle in Period of Adoption	us-gaap_CumulativeEffectOfNewAccountingPrincipleInPeriodOfAdoption	(2,000,000)
Noncontrolling Interest [Member]
Cumulative Effect of New Accounting Principle in Period of Adoption	us-gaap_CumulativeEffectOfNewAccountingPrincipleInPeriodOfAdoption	$ 0