0001581990-21-000007 | 10-K | XBRL Viewer

Print Document View Excel Document

Cover Page - USD ($) $ in Billions	12 Months Ended
Cover Page - USD ($) $ in Billions	Dec. 31, 2020	Feb. 11, 2021	Jun. 30, 2020
Cover [Abstract]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2020
Current Fiscal Year End Date	--12-31
Document Transition Report	false
Entity File Number	1-36132
Entity Registrant Name	PLAINS GP HOLDINGS LP
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	90-1005472
Entity Address, Address Line One	333 Clay Street
Entity Address, Address Line Two	Suite 1600
Entity Address, City or Town	Houston
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77002
City Area Code	713
Local Phone Number	646-4100
Title of 12(b) Security	Class A Shares, Representing Limited Partner Interests
Trading Symbol	PAGP
Security Exchange Name	NASDAQ
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
ICFR Auditor Attestation Flag	true
Entity Shell Company	false
Entity Public Float			$ 1.6
Entity Common Stock Outstanding (in shares)		194,097,504
Documents Incorporated by Reference	Portions of the registrant’s definitive Proxy Statement to be filed pursuant to Regulation 14A pertaining to the 2021 Annual Meeting of Shareholders are incorporated by reference into Part III hereof. The registrant intends to file such Proxy Statement no later than 120 days after the end of the fiscal year covered by this Form 10-K.
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	FY
Amendment Flag	false
Entity Central Index Key	0001581990

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
CURRENT ASSETS
Cash and cash equivalents	$ 25	$ 47
Restricted cash	38	37
Trade accounts receivable and other receivables, net	2,553	3,614
Inventory	647	604
Other current assets	405	312
Total current assets	3,668	4,614
PROPERTY AND EQUIPMENT	18,620	18,983
Accumulated depreciation	(4,000)	(3,616)
Property and equipment, net	14,620	15,367
OTHER ASSETS
Investments in unconsolidated entities	3,764	3,683
Goodwill	0	2,540
Deferred tax asset	1,444	1,280
Linefill and base gas	982	981
Long-term operating lease right-of-use assets, net	378	466
Long-term inventory	130	182
Other long-term assets, net	965	856
Total assets	25,951	29,969
CURRENT LIABILITIES
Trade accounts payable	2,425	3,687
Short-term debt	831	504
Other current liabilities	999	828
Total current liabilities	4,255	5,019
LONG-TERM LIABILITIES
Senior notes, net	9,071	8,939
Other long-term debt, net	311	248
Long-term operating lease liabilities	317	387
Other long-term liabilities and deferred credits	807	891
Total long-term liabilities	10,506	10,465
COMMITMENTS AND CONTINGENCIES (NOTE 19)
PARTNERS’ CAPITAL
Noncontrolling interests	9,726	12,330
Total partners’ capital	11,190	14,485
Total liabilities and partners’ capital	25,951	29,969
Class A Shares
PARTNERS’ CAPITAL
Class A shareholders (194,051,436 and 182,138,592 shares outstanding, respectively)	$ 1,464	$ 2,155

CONSOLIDATED BALANCE SHEETS (Parenthetical) - shares	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Class A Shares
Shares outstanding (in shares)	194,051,436	182,138,592	159,485,588	156,111,139

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
REVENUES
Total revenues	$ 23,290	$ 33,669	$ 34,055
COSTS AND EXPENSES
Purchases and related costs	20,431	29,452	29,793
Field operating costs	1,076	1,303	1,263
General and administrative expenses	276	302	320
Depreciation and amortization	656	604	521
(Gains)/losses on asset sales and asset impairments, net (Note 6, Note 7)	719	28	(114)
Goodwill impairment losses (Note 8)	2,515	0	0
Total costs and expenses	25,673	31,689	31,783
OPERATING INCOME/(LOSS)	(2,383)	1,980	2,272
OTHER INCOME/(EXPENSE)
Equity earnings in unconsolidated entities	355	388	375
Gain on/(impairment of) investments in unconsolidated entities, net (Note 9)	(182)	271	200
Interest expense (net of capitalized interest of $24, $34 and $30, respectively)	(436)	(425)	(431)
Other income/(expense), net	39	24	(7)
INCOME/(LOSS) BEFORE TAX	(2,607)	2,238	2,409
Current income tax expense	(51)	(112)	(66)
Deferred income tax (expense)/benefit	218	(64)	(236)
NET INCOME/(LOSS)	(2,440)	2,062	2,107
Net (income)/loss attributable to noncontrolling interests	1,872	(1,731)	(1,773)
NET INCOME/(LOSS) ATTRIBUTABLE TO PAGP	(568)	331	334
Supply and Logistics
REVENUES
Total revenues	22,058	32,272	32,819
Transportation
REVENUES
Total revenues	610	788	648
OTHER INCOME/(EXPENSE)
Equity earnings in unconsolidated entities	350	388	375
Facilities
REVENUES
Total revenues	622	609	588
OTHER INCOME/(EXPENSE)
Equity earnings in unconsolidated entities	$ 5	$ 0	$ 0
Class A Shares
OTHER INCOME/(EXPENSE)
BASIC NET INCOME/(LOSS) PER CLASS A SHARE (in dollars per share)	$ (3.06)	$ 1.97	$ 2.12
DILUTED NET INCOME/(LOSS) PER CLASS A SHARE (in dollars per share)	$ (3.07)	$ 1.96	$ 2.11
BASIC WEIGHTED AVERAGE CLASS A SHARES OUTSTANDING (in shares)	186	168	158
DILUTED WEIGHTED AVERAGE CLASS A SHARES OUTSTANDING (in shares)	246	170	282

CONSOLIDATED STATEMENTS OF OPERATIONS (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Income Statement [Abstract]
Capitalized interest	$ 24	$ 34	$ 30

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME/(LOSS) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Statement of Comprehensive Income [Abstract]
Net income/(loss)	$ (2,440)	$ 2,062	$ 2,107
Other comprehensive income/(loss)	15	97	(260)
Comprehensive income/(loss)	(2,425)	2,159	1,847
Comprehensive (income)/loss attributable to noncontrolling interests	1,863	(1,805)	(1,570)
Comprehensive income/(loss) attributable to PAGP	$ (562)	$ 354	$ 277

- Definition

Amount after tax of increase (decrease) in equity from transactions and other events and circumstances from net income (loss) and other comprehensive income (loss), attributable to noncontrolling interests. Excludes changes in equity resulting from investments by owners and distributions to owners.

+ References + Details

- Definition

Amount after tax of increase (decrease) in equity from transactions and other events and circumstances from net income and other comprehensive income. Excludes changes in equity resulting from investments by owners and distributions to owners.

+ References + Details

- Definition

Amount after tax and reclassification adjustments of other comprehensive income (loss).

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 1A
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=121641772&loc=SL7669619-108580

Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=109259400&loc=d3e21463-112644

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 830
-SubTopic 30
-Section 45
-Paragraph 17
-URI http://asc.fasb.org/extlink&oid=118261656&loc=d3e32136-110900

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section S99
-Paragraph 2
-Subparagraph (SX 210.5-03(21))
-URI http://asc.fasb.org/extlink&oid=120395209&loc=SL114868664-224227

Reference 5: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 55
-Paragraph 15
-URI http://asc.fasb.org/extlink&oid=121640130&loc=d3e1436-108581

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 830
-SubTopic 30
-Section 45
-Paragraph 20
-URI http://asc.fasb.org/extlink&oid=118261656&loc=d3e32211-110900

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 830
-SubTopic 30
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6450520&loc=d3e32583-110901

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 1B
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=121641772&loc=SL7669625-108580

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 942
-SubTopic 220
-Section S99
-Paragraph 1
-Subparagraph (SX 210.9-04(23))
-URI http://asc.fasb.org/extlink&oid=120399700&loc=SL114874048-224260

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 944
-SubTopic 220
-Section S99
-Paragraph 1
-Subparagraph (SX 210.7-04(19))
-URI http://asc.fasb.org/extlink&oid=120400993&loc=SL114874131-224263

+ Details

- Definition

The consolidated profit or loss for the period, net of income taxes, including the portion attributable to the noncontrolling interest.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08(g)(1)(ii))
-URI http://asc.fasb.org/extlink&oid=120395691&loc=d3e23780-122690

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 1A
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=121641772&loc=SL7669619-108580

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 7
-URI http://asc.fasb.org/extlink&oid=109222650&loc=SL51721683-107760

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 250
-SubTopic 10
-Section 50
-Paragraph 1
-Subparagraph (b)(2)
-URI http://asc.fasb.org/extlink&oid=109234566&loc=d3e22499-107794

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 50
-Paragraph 28
-Subparagraph (f)
-URI http://asc.fasb.org/extlink&oid=75031198&loc=d3e14064-108612

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 50
-Paragraph 1A
-Subparagraph (a)(1)
-URI http://asc.fasb.org/extlink&oid=109239629&loc=SL4573702-111684

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 942
-SubTopic 235
-Section S99
-Paragraph 1
-Subparagraph (SX 210.9-05(b)(2))
-URI http://asc.fasb.org/extlink&oid=120399901&loc=d3e537907-122884

Reference 8: http://www.xbrl.org/2003/role/exampleRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 31
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8924-108599

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 1B
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=121641772&loc=SL7669625-108580

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 250
-SubTopic 10
-Section 50
-Paragraph 9
-URI http://asc.fasb.org/extlink&oid=109234566&loc=d3e22663-107794

Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 22
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8736-108599

Reference 12: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 32
-Subparagraph (c)
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8933-108599

Reference 13: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 50
-Paragraph 1A
-Subparagraph (c)(1)
-URI http://asc.fasb.org/extlink&oid=109239629&loc=SL4573702-111684

Reference 14: http://www.xbrl.org/2003/role/exampleRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 55
-Paragraph 4J
-URI http://asc.fasb.org/extlink&oid=120409616&loc=SL4591551-111686

Reference 15: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 30
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8906-108599

Reference 16: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 230
-SubTopic 10
-Section 45
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=121586364&loc=d3e3000-108585

Reference 17: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 45
-Paragraph 19
-URI http://asc.fasb.org/extlink&oid=108774443&loc=SL4569616-111683

Reference 18: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 323
-SubTopic 10
-Section 50
-Paragraph 3
-Subparagraph (c)
-URI http://asc.fasb.org/extlink&oid=114001798&loc=d3e33918-111571

Reference 19: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 32
-Subparagraph (f)
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8933-108599

Reference 20: http://www.xbrl.org/2003/role/exampleRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 55
-Paragraph 4K
-URI http://asc.fasb.org/extlink&oid=120409616&loc=SL4591552-111686

Reference 21: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 250
-SubTopic 10
-Section 50
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=109234566&loc=d3e22658-107794

+ Details

CONSOLIDATED STATEMENTS OF CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Total period activity	$ 15	$ 97	$ (260)
Derivative Instruments
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(259)	(177)	(223)
Reclassification adjustments	11	9	8
Unrealized gain/(loss) on hedges	(10)	(91)	38
Total period activity	1	(82)	46
Ending balance	(258)	(259)	(177)
Translation Adjustments
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(674)	(853)	(548)
Currency translation adjustments	17	179	(305)
Total period activity	17	179	(305)
Ending balance	(657)	(674)	(853)
Other
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance			1
Other	(3)		(1)
Total period activity	(3)		(1)
Ending balance	(3)
Total
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(933)	(1,030)	(770)
Reclassification adjustments	11	9	8
Unrealized gain/(loss) on hedges	(10)	(91)	38
Currency translation adjustments	17	179	(305)
Other	(3)		(1)
Total period activity	15	97	(260)
Ending balance	$ (918)	$ (933)	$ (1,030)

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
CASH FLOWS FROM OPERATING ACTIVITIES
Net income/(loss)	$ (2,440)	$ 2,062	$ 2,107
Reconciliation of net income/(loss) to net cash provided by operating activities:
Depreciation and amortization	656	604	521
(Gains)/losses on asset sales and asset impairments, net (Note 6, Note 7)	719	28	(114)
Goodwill impairment losses (Note 8)	2,515	0	0
Equity-indexed compensation expense	16	35	79
Inventory valuation adjustments (Note 5)	233	11	8
Deferred income tax expense/(benefit)	(218)	64	236
Settlement of terminated interest rate hedging instruments	(100)	(55)	14
Equity earnings in unconsolidated entities	(355)	(388)	(375)
Distributions on earnings from unconsolidated entities	472	401	422
(Gain on)/impairment of investments in unconsolidated entities, net (Note 9)	182	(271)	(200)
Other	(12)	21	39
Changes in assets and liabilities, net of acquisitions:
Trade accounts receivable and other	1,432	(1,158)	309
Inventory	(304)	(5)	(75)
Trade accounts payable and other	(1,286)	1,151	(367)
Net cash provided by operating activities	1,510	2,500	2,604
CASH FLOWS FROM INVESTING ACTIVITIES
Cash paid in connection with acquisitions, net of cash acquired (Note 7)	(310)	(50)
Investments in unconsolidated entities (Note 9)	(461)	(524)	(468)
Additions to property, equipment and other	(738)	(1,181)	(1,634)
Proceeds from sales of assets (Note 7)	429	77	1,334
Cash paid for purchases of linefill and base gas	(14)	(74)	(45)
Other investing activities	1	(13)
Net cash used in investing activities	(1,093)	(1,765)	(813)
CASH FLOWS FROM FINANCING ACTIVITIES
Net borrowings/(repayments) under PAA commercial paper program (Note 11)	456	93	(123)
Net borrowings/(repayments) under PAA senior secured hedged inventory facility (Note 11)	(160)	325	(778)
Proceeds from PAA GO Zone term loans (Note 11)			200
Proceeds from the issuance of PAA senior notes (Note 11)	748	998
Repayments of PAA senior notes (Note 11)	(617)	(1,000)
Repurchase of common units by a subsidiary (Note 12)	(50)
Distributions paid to Class A shareholders (Note 12)	(166)	(231)	(189)
Distributions paid to noncontrolling interests (Note 12)	(697)	(977)	(843)
Sale of noncontrolling interest in a subsidiary (Note 12)		128
Other financing activities	56	(53)	(20)
Net cash used in financing activities	(430)	(717)	(1,753)
Effect of translation adjustment	(8)	(3)	(9)
Net increase/(decrease) in cash and cash equivalents and restricted cash	(21)	15	29
Cash and cash equivalents and restricted cash, beginning of period	84	69	40
Cash and cash equivalents and restricted cash, end of period	63	84	69
Cash paid for:
Interest, net of amounts capitalized	428	397	400
Income taxes, net of amounts refunded	$ 111	$ 136	$ 21

CONSOLIDATED STATEMENTS OF CHANGES IN PARTNERS' CAPITAL - USD ($) $ in Millions	Total	Cumulative Effect, Period of Adoption, Adjustment	Cumulative Effect, Period of Adoption, Adjusted Balance	Noncontrolling Interests	Noncontrolling Interests Cumulative Effect, Period of Adoption, Adjustment	Noncontrolling Interests Cumulative Effect, Period of Adoption, Adjusted Balance	Class A Shares Limited Partners	Class A Shares Limited Partners Cumulative Effect, Period of Adoption, Adjustment	Class A Shares Limited Partners Cumulative Effect, Period of Adoption, Adjusted Balance
Balance, beginning of period at Dec. 31, 2017	$ 12,358	$ 113		$ 10,663	$ 89		$ 1,695	$ 24
Increase (Decrease) in Partners' Capital
Accounting Standards Update [Extensible List]	us-gaap:AccountingStandardsUpdate201705Member
Net income/(loss)	$ 2,107			1,773			334
Distributions (Note 12)	(1,069)			(880)			(189)
Deferred tax asset (Note 15)	22			0			22
Change in ownership interest in connection with Exchange Right exercises (Note 12)	0			(7)			7
Other comprehensive income/(loss)	(260)			(203)			(57)
Equity-indexed compensation expense	56			46			10
Other	(8)			(8)			0
Balance, end of period at Dec. 31, 2018	13,319		$ 12,471	11,473		$ 10,752	1,846		$ 1,719
Increase (Decrease) in Partners' Capital
Net income/(loss)	2,062			1,731			331
Distributions (Note 12)	(1,208)			(977)			(231)
Deferred tax asset (Note 15)	86			0			86
Change in ownership interest in connection with Exchange Right exercises (Note 12)	0			(101)			101
Other comprehensive income/(loss)	97			74			23
Equity-indexed compensation expense	18			13			5
Sale of noncontrolling interest in a subsidiary (Note 12)	128			128			0
Other	(17)			(11)			(6)
Balance, end of period at Dec. 31, 2019	14,485			12,330			2,155
Increase (Decrease) in Partners' Capital
Net income/(loss)	(2,440)			(1,872)			(568)
Distributions (Note 12)	(863)			(697)			(166)
Deferred tax asset (Note 15)	16			0			16
Change in ownership interest in connection with Exchange Right exercises (Note 12)	0			(10)			10
Other comprehensive income/(loss)	15			9			6
Equity-indexed compensation expense	20			14			6
Repurchase of common units by a subsidiary (Note 12)	(50)			(54)			4
Contributions from noncontrolling interests (Note 12)	12			12			0
Other	(5)			(6)			1
Balance, end of period at Dec. 31, 2020	$ 11,190			$ 9,726			$ 1,464

Organization and Basis of Consolidation and Presentation

12 Months Ended

Dec. 31, 2020

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Organization and Basis of Consolidation and Presentation

Organization

Plains GP Holdings, L.P. (“PAGP”) is a Delaware limited partnership formed in 2013 that has elected to be taxed as a corporation for United States federal income tax purposes. PAGP does not directly own any operating assets; as of December 31, 2020, its principal sources of cash flow are derived from an indirect investment in Plains All American Pipeline, L.P. (“PAA”), a publicly traded Delaware limited partnership. As used in this Form 10-K and unless the context indicates otherwise (taking into account the fact that PAGP has no operating activities apart from those conducted by PAA and its subsidiaries), the terms “Partnership,” “we,” “us,” “our,” “ours” and similar terms refer to PAGP and its subsidiaries.

As of December 31, 2020, PAGP owned (i) a 100% managing member interest in Plains All American GP LLC (“GP LLC”), an entity that has also elected to be taxed as a corporation for United States federal income tax purposes and (ii) an approximate 79% limited partner interest in Plains AAP, L.P. (“AAP”) through our direct ownership of approximately 193.1 million Class A units of AAP (“AAP units”) and indirect ownership of approximately 1.0 million AAP units through GP LLC. GP LLC is a Delaware limited liability company that also holds the non-economic general partner interest in AAP. AAP is a Delaware limited partnership that, as of December 31, 2020, directly owned a limited partner interest in PAA through its ownership of approximately 245.8 million PAA common units (approximately 31% of PAA’s total outstanding common units and Series A preferred units combined). AAP is the sole member of PAA GP LLC (“PAA GP”), a Delaware limited liability company that directly holds the non-economic general partner interest in PAA.

PAA is a publicly traded master limited partnership. PAA’s business model integrates large-scale supply aggregation capabilities with the ownership and operation of critical midstream infrastructure systems that connect major producing regions to key demand centers and export terminals. As one of the largest midstream service providers in North America, PAA owns an extensive network of pipeline transportation, terminalling, storage and gathering assets in key crude oil and natural gas liquids (“NGL”) producing basins (including the Permian Basin) and transportation corridors and at major market hubs in the United States and Canada. PAA’s assets and the services it provides are primarily focused on crude oil, NGL and natural gas. Our business activities are conducted through three operating segments: Transportation, Facilities and Supply and Logistics. See Note 21 for further discussion of our operating segments.

PAA GP Holdings LLC, a Delaware limited liability company, is our general partner. Our general partner manages our operations and activities and is responsible for exercising on our behalf any rights we have as the sole and managing member of GP LLC, including responsibility for conducting the business and managing the operations of AAP and PAA. GP LLC employs our domestic officers and personnel involved in the operation and management of AAP and PAA. PAA’s Canadian officers and personnel are employed by our subsidiary, Plains Midstream Canada ULC.

References to the “Plains Entities” include us, our general partner, GP LLC, AAP, PAA GP and PAA and its subsidiaries.

Definitions

Additional defined terms are used in the following notes and shall have the meanings indicated below:


AOCI	=	Accumulated other comprehensive income/(loss)
ASC	=	Accounting Standards Codification
ASU	=	Accounting Standards Update
Bcf	=	Billion cubic feet
CAD	=	Canadian dollar
CODM	=	Chief Operating Decision Maker
DERs	=	Distribution equivalent rights
EBITDA	=	Earnings before interest, taxes, depreciation and amortization
EPA	=	United States Environmental Protection Agency
FASB	=	Financial Accounting Standards Board


GAAP	=	Generally accepted accounting principles in the United States
ICE	=	Intercontinental Exchange
ISDA	=	International Swaps and Derivatives Association
LIBOR	=	London Interbank Offered Rate
LTIP	=	Long-term incentive plan
Mcf	=	Thousand cubic feet
MMbls	=	Million barrels
NGL	=	Natural gas liquids, including ethane, propane and butane
NYMEX	=	New York Mercantile Exchange
Oxy	=	Occidental Petroleum Corporation or its subsidiaries
SEC	=	United States Securities and Exchange Commission
TWh	=	Terawatt hour
U.S.	=	United States
USD	=	United States dollar
WTI	=	West Texas Intermediate

Basis of Consolidation and Presentation

The accompanying financial statements and related notes present and discuss our consolidated financial position as of December 31, 2020 and 2019, and the consolidated results of our operations, cash flows, changes in partners’ capital, comprehensive income and changes in accumulated other comprehensive income/(loss) for the years ended December 31, 2020, 2019 and 2018. All significant intercompany transactions have been eliminated in consolidation, and certain reclassifications have been made to information from previous years to conform to the current presentation.

The accompanying consolidated financial statements include the accounts of PAGP and all of its wholly owned subsidiaries and those entities that it controls. Investments in entities over which we have significant influence but not control are accounted for by the equity method. We apply proportionate consolidation for pipelines and other assets in which we own undivided joint interests.

Management judgment is required to evaluate whether PAGP controls an entity. Key areas of that evaluation include (i) determining whether an entity is a variable interest entity (“VIE”); (ii) determining whether PAGP is the primary beneficiary of a VIE, including evaluating which activities of the VIE most significantly impact its economic performance and the degree of power that PAGP and its related parties have over those activities through variable interests; and (iii) identifying events that require reconsideration of whether an entity is a VIE and continuously evaluating whether PAGP is a VIE’s primary beneficiary.

We have determined that our subsidiaries, PAA and AAP, are VIEs and should be consolidated by PAGP because:

•The limited partners of PAA and AAP lack (i) substantive “kick-out rights” (i.e., the right to remove the general partner) based on a simple majority or lower vote and (ii) substantive participation rights and thus lack the ability to block actions of the general partner that most significantly impact the economic performance of PAA and AAP, respectively.

•AAP is the primary beneficiary of PAA because it has the power to direct the activities that most significantly impact PAA’s performance and the right to receive benefits, and obligation to absorb losses, that could be significant to PAA.

•PAGP is the primary beneficiary of AAP because it has the power to direct the activities that most significantly impact AAP’s performance and the right to receive benefits, and obligation to absorb losses, that could be significant to AAP.

With the exception of a deferred tax asset of $1.444 billion and $1.280 billion as of December 31, 2020 and 2019, respectively, substantially all assets and liabilities presented on PAGP’s Consolidated Balance Sheets are those of PAA. Only the assets of each respective VIE can be used to settle the obligations of that individual VIE, and the creditors of each/either of those VIEs do not have recourse against the general credit of PAGP. PAGP did not provide any financial support to PAA or AAP during the years ended December 31, 2020, 2019 or 2018. See Note 17 for information regarding the Omnibus Agreement entered into by the Plains Entities on November 15, 2016.

Subsequent events have been evaluated through the financial statements issuance date and have been included in the following footnotes where applicable.

COVID-19

During 2020, the novel coronavirus (“COVID-19”) pandemic resulted in a swift and material decline in global crude oil demand, which contributed to an oversupply of crude oil that was exacerbated by increases in production from certain suppliers in the global oil markets. These macroeconomic and industry specific challenges resulted in a number of impairment charges recognized during 2020. See Note 6, Note 8 and Note 9 for further discussion of these impairments.

Many uncertainties remain with respect to COVID-19, including uncertainty regarding the length of time the pandemic will continue, as well as the timing, pace and extent of an economic recovery in the United States, Canada and elsewhere, and how such uncertainties will impact the energy industry and our business. As a result, these matters may affect our estimates and assumptions on amounts reported in the financial statements and accompanying notes in the near term.

Summary of Significant Accounting Policies

12 Months Ended

Dec. 31, 2020

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

Use of Estimates

The preparation of financial statements in conformity with GAAP requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities, as well as the disclosure of contingent assets and liabilities at the date of the financial statements. Such estimates and assumptions also affect the reported amounts of revenues and expenses during the reporting period. We make significant estimates with respect to (i) estimated fair value of assets and liabilities acquired and identification of associated goodwill and intangible assets, (ii) impairment assessments of goodwill and intangible assets, (iii) fair value of derivatives, (iv) accruals and contingent liabilities, (v) property and equipment, depreciation and amortization expense and asset retirement obligations, (vi) impairment assessments of property and equipment and investments in unconsolidated entities and (vii) inventory valuations. Although we believe these estimates are reasonable, actual results could differ from these estimates.

Purchases and Related Costs

Purchases and related costs include (i) the weighted average cost of crude oil, NGL and natural gas sold to customers, (ii) fees incurred for storage and transportation, whether by pipeline, truck or rail and (iii) performance-related bonus costs. These costs are recognized when incurred except in the case of products sold, which are recognized at the time title transfers to our customers. Inventory exchanges under buy/sell transactions are presented net in “Purchases and related costs” in our Consolidated Statements of Operations.

Field Operating Costs and General and Administrative Expenses

Field operating costs consist of various field operating expenses, including payroll, compensation and benefits costs for operations personnel; fuel and power costs (including the impact of gains and losses from derivative related activities); third-party trucking transportation costs for our U.S. crude oil operations; maintenance and integrity management costs; regulatory compliance; environmental remediation; insurance; costs for usage of third-party owned pipeline, rail and storage assets; vehicle leases; and property taxes. General and administrative expenses consist primarily of payroll, compensation and benefits costs; certain information systems and legal costs; office rent; contract and consultant costs; and audit and tax fees.

Foreign Currency Transactions/Translation

Certain of our subsidiaries use the Canadian dollar as their functional currency. Assets and liabilities of subsidiaries with a Canadian dollar functional currency are translated at period-end rates of exchange, and revenues and expenses are translated at average exchange rates prevailing for each month. The resulting translation adjustments are made directly to a separate component of other comprehensive income, which is reflected in Partners’ Capital on our Consolidated Balance Sheets.

Certain of our subsidiaries also enter into transactions and have monetary assets and liabilities that are denominated in a currency other than the entities’ respective functional currencies. Gains and losses from the revaluation of foreign currency transactions and monetary assets and liabilities are generally included in the Consolidated Statements of Operations. However, gains and losses arising from intercompany foreign currency transactions that are of a long-term investment nature are reported in the same manner as translation adjustments. For the years ended December 31, 2020, 2019 and 2018, the revaluation of foreign currency transactions and monetary assets and liabilities resulted in the recognitions of net gains of $16 million, $1 million and $1 million, respectively, in our Consolidated Statements of Operations.

Cash and Cash Equivalents and Restricted Cash

Cash and cash equivalents consist of all unrestricted demand deposits and funds invested in highly liquid instruments with original maturities of three months or less and typically exceed federally insured limits. We periodically assess the financial condition of the institutions where these funds are held and believe that our credit risk is minimal.

In accordance with our policy, unless they may be covered by funds on deposit, outstanding checks are classified as trade accounts payable rather than negative cash. As of December 31, 2020 and 2019, trade accounts payable included $27 million and $39 million, respectively, of outstanding checks that were reclassified from cash and cash equivalents.

Restricted cash includes cash held by us that is unavailable for general use and is comprised of amounts advanced to us by certain equity method investees related to the construction of fixed assets where we serve as construction manager. The following table presents a reconciliation of cash and cash equivalents and restricted cash reported on our Consolidated Balance Sheets that sum to the total of the amount shown on our Consolidated Statements of Cash Flows (in millions):


	December 31,
	2020		2019
Cash and cash equivalents	$	25	$	47
Restricted cash	38		37
Total cash and cash equivalents and restricted cash	$	63	$	84

Noncontrolling Interests

Noncontrolling interest represents the portion of assets and liabilities in a consolidated subsidiary that is owned by a third party. FASB guidance requires all entities to report noncontrolling interests in subsidiaries as a component of equity in the consolidated financial statements. See Note 12 for additional discussion regarding our noncontrolling interests.

Asset Retirement Obligations

FASB guidance establishes accounting requirements for retirement obligations associated with tangible long-lived assets, including estimates related to (i) the time of the liability recognition, (ii) initial measurement of the liability, (iii) allocation of asset retirement cost to expense, (iv) subsequent measurement of the liability and (v) financial statement disclosures. FASB guidance also requires that the cost for asset retirement should be capitalized as part of the cost of the related long-lived asset and subsequently allocated to expense using a systematic and rational method.

Some of our assets, primarily related to our Transportation and Facilities segments, have contractual or regulatory obligations to perform remediation and, in some instances, dismantlement and removal activities when the assets are abandoned. These obligations include varying levels of activity including disconnecting inactive assets from active assets, cleaning and purging assets, and in some cases, completely removing the assets and returning the land to its original state. These assets have been in existence for many years and with regular maintenance will continue to be in service for many years to come. It is not possible to predict when demand for these transportation or storage services will cease, and we do not believe that such demand will cease for the foreseeable future. Accordingly, we believe the date when these assets will be abandoned is indeterminate. With no reasonably determinable abandonment date, we cannot reasonably estimate the fair value of the associated asset retirement obligations. We will record asset retirement obligations for these assets in the period in which sufficient information becomes available for us to reasonably determine the settlement dates.

A small portion of our contractual or regulatory obligations is related to assets that are inactive or that we plan to take out of service and, although the ultimate timing and costs to settle these obligations are not known with certainty, we have recorded a reasonable estimate of these obligations. The following table presents the change in the liability for asset retirement obligations, substantially all of which is reflected in “Other long-term liabilities and deferred credits” on our Consolidated Balance Sheets as of December 31, 2020, 2019 and 2018 (in millions):


	December 31,
	2020		2019		2018
Beginning balance	$	137	$	109	$	103
Liabilities incurred	12		3		3
Liabilities settled	(1)		(3)		(3)
Accretion expense	5		5		4
Revisions in estimated cash flows	(18)		23		2
Ending balance	$	135	$	137	$	109

Fair Value Measurements

Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment, which affects the placement of assets and liabilities within the fair value hierarchy levels. The determination of the fair values includes not only the credit standing of the counterparties involved and the impact of credit enhancements (such as cash deposits and letters of credit) but also the impact of our nonperformance risk on our liabilities. The fair value of our commodity derivatives, interest rate derivatives and foreign currency derivatives includes adjustments for credit risk. Our credit adjustment methodology uses market observable inputs and requires judgment. There were no changes to any of our valuation techniques during the period. See Note 13 for further discussion.

Other Significant Accounting Policies

See the respective footnotes for our accounting policies regarding (i) revenues and accounts receivable, (ii) net income/(loss) per Class A share, (iii) inventory, linefill and base gas and long-term inventory, (iv) property and equipment, (v) acquisitions, (vi) goodwill, (vii) investments in unconsolidated entities, (viii) other long-term assets, net, (ix) derivatives and risk management activities, (x) leases, (xi) income taxes, (xii) equity-indexed compensation and (xiii) legal and environmental matters.

Recent Accounting Pronouncements

In August 2020, the FASB issued ASU 2020-06, Debt—Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging—Contracts in Entity’s Own Equity (Subtopic 815-40): Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity, which simplifies accounting for certain financial instruments with characteristics of liabilities and equity, including convertible instruments and contracts on an entity’s own equity, by eliminating two of the three models that require separate accounting for embedded conversion features and the settlement assessment that entities are required to perform to determine whether a contract qualifies for equity classification. This guidance is effective for interim and annual periods beginning after December 15, 2021, with early adoption permitted. We are currently evaluating the effect that this guidance will have on our financial position, results of operations and cash flows.

In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting, which provides optional expedients and exceptions for applying GAAP to contracts, hedging relationships and other transactions that reference LIBOR or another reference rate expected to be discontinued because of reference rate reform. This guidance is effective prospectively upon issuance through December 31, 2022 and may be applied from the beginning of an interim period that includes the issuance date of this ASU. We will apply applicable expedients and exceptions to contract modifications through December 31, 2022.

In December 2019, the FASB issued ASU 2019-12, Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes, to simplify the accounting for income taxes based on changes suggested by stakeholders as part of the FASB’s simplification initiative. This guidance is effective for interim and annual periods beginning after December 15, 2020, with early adoption permitted. We will adopt this guidance effective January 1, 2021, and do not anticipate that the adoption will have a material impact on our financial position, results of operations or cash flows.

In April 2019, the FASB issued ASU 2019-04, Codification Improvements to Topic 326, Financial Instruments—Credit Losses, Topic 815, Derivatives and Hedging, and Topic 825, Financial Instruments, which clarifies certain aspects of accounting for credit losses, hedging activities and financial instruments. We adopted this guidance effective January 1, 2020, and our adoption did not have a material impact on our financial position, results of operations or cash flows.

In October 2018, the FASB issued ASU 2018-17, Consolidation (Topic 810): Targeted Improvements to Related Party Guidance for Variable Interest Entities, in response to stakeholder observations that improvements could be made by requiring reporting entities to consider indirect interests held through related parties under common control on a proportional basis rather than as the equivalent of a direct interest in its entirety as currently required in GAAP. This guidance is effective for interim and annual periods beginning after December 15, 2019, with early adoption permitted. We adopted this guidance effective January 1, 2020, and our adoption did not have a material impact on our financial position, results of operations or cash flows.

In August 2018, the FASB issued ASU 2018-15, Intangibles—Goodwill and Other—Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract (a consensus of the FASB Emerging Issues Task Force), to address the accounting for implementation costs of a hosting arrangement that is a service contract and to align the accounting for implementation costs for hosting arrangements, regardless of whether they convey a license to the hosted software. This guidance is effective for interim and annual periods beginning after December 15, 2019, with early adoption permitted. We adopted this guidance effective January 1, 2020, and our adoption did not have a material impact on our financial position, results of operations or cash flows.

In August 2018, the FASB issued ASU 2018-13, Fair Value Measurement (Topic 820): Disclosure Framework—Changes to the Disclosure Requirements for Fair Value Measurement, modifying the disclosure requirements on fair value measurements in Topic 820. This guidance is effective for interim and annual periods beginning after December 15, 2019, with early adoption permitted. We adopted this guidance effective January 1, 2020, and our adoption did not have a material impact on our financial position, results of operations or cash flows.

In June 2016, the FASB issued ASU 2016-13, Financial Instruments—Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments (followed by a series of related accounting standard updates), which amends guidance on the impairment of financial instruments and adds an impairment model (known as the current expected credit loss (or CECL) model) that is based on expected losses rather than incurred losses. This guidance became effective for interim and annual periods beginning after December 15, 2019, with early adoption permitted by one year. We adopted this guidance effective January 1, 2020, and our adoption did not have a material impact on our financial position, results of operations or cash flows.

Revenues and Accounts Receivable

12 Months Ended

Dec. 31, 2020

Revenue from Contract with Customer [Abstract]

Revenues and Accounts Receivable

Revenue Recognition

We disaggregate our revenues by segment and type of activity. These categories depict how the nature, amount, timing and uncertainty of revenues and cash flows are affected by economic factors.

Supply and Logistics Segment Revenues from Contracts with Customers. The following table presents our Supply and Logistics segment revenues from contracts with customers disaggregated by type of activity (in millions):


	Year Ended December 31,
	2020		2019		2018
Supply and Logistics segment revenues from contracts with customers
Crude oil transactions	$	21,202	$	30,082	$	29,592
NGL and other transactions	1,149		1,884		3,108
Total Supply and Logistics segment revenues from contracts with customers	$	22,351	$	31,966	$	32,700

Revenues from sales of crude oil, NGL and natural gas are recognized at the time title to the product sold transfers to the purchaser, which occurs upon delivery of the product to the purchaser or its designee. Sales of crude oil and NGL consist of outright sales contracts. The consideration received under these contracts is variable based on commodity prices. Inventory exchanges under buy/sell transactions are excluded from Supply and Logistics segment revenues in our Consolidated Statements of Operations. Revenues recognized by our Supply and Logistics segment primarily represent margin based activities.

In addition, we have certain crude oil sales agreements that are entered into in conjunction with storage arrangements and future inventory exchanges. The revenues under these agreements are deferred until all performance obligations associated with the related agreements are completed. The inventory that has been sold under these crude oil sales agreements is reflected in “Other current assets” on our Consolidated Balance Sheet until all of our performance obligations are complete. At that time, the inventory that has been sold is removed from our Consolidated Balance Sheet and recorded as “Purchases and related costs” in our Consolidated Statement of Operations. See “Contract Balances” below for further discussion of contract liabilities associated with these agreements. The following table presents amounts in Other current assets and deferred revenue associated with these agreements (in millions):


	December 31,
	2020		2019
Other current assets	$	229	$	142
Deferred revenue (1)	$	361	$	155

(1)Included in “Other current liabilities” on our Consolidated Balance Sheet.

We may also utilize derivatives in connection with the transactions described above. Derivative revenue is not included as a component of revenue from contracts with customers, but is included in other items in revenue. The change in the fair value of derivatives that are not designated or do not qualify for hedge accounting is recognized in revenues each period.

Transportation Segment Revenues from Contracts with Customers. The following table presents our Transportation segment revenues from contracts with customers disaggregated by type of activity (in millions):


	Year Ended December 31,
	2020		2019		2018
Transportation segment revenues from contracts with customers
Tariff activities:
Crude oil pipelines	$	1,805	$	2,039	$	1,724
NGL pipelines	101		99		103
Total tariff activities	1,906		2,138		1,827
Trucking	99		145		149
Total Transportation segment revenues from contracts with customers	$	2,005	$	2,283	$	1,976

Our Transportation segment operations generally consist of fee-based activities associated with transporting crude oil and NGL on pipelines and trucks. Revenues from pipeline tariffs and fees are associated with the transportation of crude oil and NGL at a published tariff. We primarily recognize pipeline tariff and fee revenues over time as services are rendered, based on the volumes transported. As is common in the pipeline transportation industry, our tariffs incorporate a loss allowance factor. We recognize the allowance volumes collected as part of the transaction price and record this non-cash consideration at fair value, measured as of the contract inception date.

Facilities Segment Revenues from Contracts with Customers. The following table presents our Facilities segment revenues from contracts with customers disaggregated by type of activity (in millions):


	Year Ended December 31,
	2020		2019		2018
Facilities segment revenues from contracts with customers
Crude oil, NGL and other terminalling and storage	$	704	$	697	$	688
NGL and natural gas processing and fractionation	350		349		364
Rail load / unload	45		76		84
Total Facilities segment revenues from contracts with customers	$	1,099	$	1,122	$	1,136

Our Facilities segment operations generally consist of fee-based activities associated with providing storage, terminalling and throughput services primarily for crude oil, NGL and natural gas, as well as NGL fractionation and isomerization services and natural gas and condensate processing services. Revenues generated in this segment include (i) fees that are generated when we receive liquids from one connecting source and deliver the applicable product to another connecting carrier, fees from storage capacity agreements and fees associated with natural gas storage related activities (collectively “Crude oil, NGL and other terminalling and storage”), (ii) fees from natural gas and condensate processing services and from NGL fractionation and isomerization services (collectively, “NGL and natural gas processing and fractionation”) and (iii) loading and unloading fees at our rail terminals.

We generate revenue through a combination of month-to-month and multi-year agreements and processing arrangements. Storage fees are typically recognized in revenue ratably over the term of the contract regardless of the actual storage capacity utilized as our performance obligation is to make available storage capacity for a period of time. Terminal fees (including throughput and rail fees) are recognized as the liquids enter or exit the terminal and are received from or delivered to the connecting carrier or third-party terminal, as applicable. Fees from NGL fractionation and isomerization services and gas processing services are recognized in the period when the services are performed. Natural gas storage related activities fees are recognized in the period the natural gas moves across our header system. We recognize rail loading and unloading fees when the volumes are delivered or received.


Year Ended December 31, 2020	Transportation		Facilities		Supply and Logistics		Total
Revenues from contracts with customers	$	2,005	$	1,099	$	22,351	$	25,455
Other items in revenues	15		39		(292)		(238)
Total revenues of reportable segments	$	2,020	$	1,138	$	22,059	$	25,217
Intersegment revenues							(1,927)
Total revenues							$	23,290


Year Ended December 31, 2019	Transportation		Facilities		Supply and Logistics		Total
Revenues from contracts with customers	$	2,283	$	1,122	$	31,966	$	35,371
Other items in revenues	37		49		310		396
Total revenues of reportable segments	$	2,320	$	1,171	$	32,276	$	35,767
Intersegment revenues							(2,098)
Total revenues							$	33,669


Year Ended December 31, 2018	Transportation		Facilities		Supply and Logistics		Total
Revenues from contracts with customers	$	1,976	$	1,136	$	32,700	$	35,812
Other items in revenues	14		25		122		161
Total revenues of reportable segments	$	1,990	$	1,161	$	32,822	$	35,973
Intersegment revenues							(1,918)
Total revenues							$	34,055

Minimum Volume Commitments. We have certain agreements that require counterparties to transport or throughput a minimum volume over an agreed upon period. Some of these agreements include make-up rights if the minimum volume is not met. We record a receivable from the counterparty in the period that services are provided or when the transaction occurs, including amounts for deficiency obligations from counterparties associated with minimum volume commitments. If a counterparty has a make-up right associated with a deficiency, we defer the revenue attributable to the counterparty’s make-up right as a contract liability and subsequently recognize the revenue at the earlier of when the deficiency volume is delivered or shipped, when the make-up right expires or when it is determined that the counterparty’s ability to utilize the make-up right is remote.

The following table presents counterparty deficiencies associated with contracts with customers and buy/sell arrangements that include minimum volume commitments for which we had remaining performance obligations and the customers still had the ability to meet their obligations (in millions):


		December 31,
Counterparty deficiencies	Financial Statement Classification	2020		2019
Billed and collected	Liability	$	73	$	22
Unbilled (1)	N/A	4		20
Total		$	77	$	42

(1)Amounts were related to deficiencies for which the counterparties had not met their contractual minimum commitments and are not reflected in our Consolidated Financial Statements as we had not yet billed or collected such amounts.

Contract Balances. Our contract balances consist of amounts received associated with services or sales for which we have not yet completed the related performance obligation. The following table presents the changes in the liability balance associated with contracts with customers (in millions):


	Contract Liabilities
Balance at December 31, 2018	$	338
Amounts recognized as revenue	(227)

Additions (1)	244
Other	(1)
Balance at December 31, 2019	$	354
Amounts recognized as revenue (1)	(246)
Additions (2)	393

Balance at December 31, 2020	$	501

(1)Includes approximately $155 million associated with crude oil sales agreements that are entered into in conjunction with storage arrangements and future inventory exchanges. Such amount was recognized as revenue in the first quarter of 2020.

(2)Includes approximately $361 million, as discussed above, associated with crude oil sales agreements that are entered into in conjunction with storage arrangements and future inventory exchanges. Such amount is expected to be recognized as revenue in the first quarter of 2021.

Remaining Performance Obligations. The information below includes the amount of consideration allocated to partially and wholly unsatisfied performance obligations under contracts that exist as of the end of the periods and the timing of revenue recognition of those remaining performance obligations. Certain contracts meet the requirements for the presentation as remaining performance obligations. These arrangements include a fixed minimum level of service, typically a set volume of service, and do not contain any variability other than expected timing within a limited range. The following table presents the amount of consideration associated with remaining performance obligations for the population of contracts with external customers meeting the presentation requirements as of December 31, 2020 (in millions):


	2021		2022		2023		2024		2025		2026 and Thereafter
Pipeline revenues supported by minimum volume commitments and capacity agreements (1)	$	174	$	166	$	170	$	142	$	125	$	455
Storage, terminalling and throughput agreement revenues	340		273		206		173		114		328
Total	$	514	$	439	$	376	$	315	$	239	$	783

(1)Calculated as volumes committed under contracts multiplied by the current applicable tariff rate.

The presentation above does not include (i) expected revenues from legacy shippers not underpinned by minimum volume commitments, including pipelines where there are no or limited alternative pipeline transportation options, (ii) intersegment revenues and (iii) the amount of consideration associated with certain income generating contracts, which include a fixed minimum level of service, that are either not within the scope of ASC 606 or do not meet the requirements for presentation as remaining performance obligations. The following are examples of contracts that are not included in the table above because they are not within the scope of ASC 606 or do not meet the requirements for presentation:

•Minimum volume commitments on certain of our joint venture pipeline systems;

•Acreage dedications;

•Supply and Logistics buy/sell arrangements with future committed volumes;

•All other Supply and Logistics contracts, due to the election of practical expedients related to variable consideration and short-term contracts, as discussed below;

•Transportation and Facilities contracts that are short-term, as discussed below;

•Contracts within the scope of ASC Topic 842, Leases; and

•Contracts within the scope of ASC Topic 815, Derivatives and Hedging.

We have elected practical expedients to exclude the presentation of remaining performance obligations for variable consideration which relates to wholly unsatisfied performance obligations. Certain contracts do not meet the requirements for presentation of remaining performance obligations due to variability in amount of performance obligation remaining, variability in the timing of recognition or variability in consideration. Acreage dedications do require us to perform future services but do not contain a minimum level of services and are therefore excluded from this presentation. Long-term supply and logistics arrangements contain variable timing, volumes and/or consideration and are excluded from this presentation. The duration of these contracts varies across the periods presented above.

Additionally, we have elected practical expedients to exclude contracts with terms of one year or less, and therefore exclude the presentation of remaining performance obligations for short-term transportation, storage and processing services, supply and logistics arrangements, including the non-cancelable period of evergreen arrangements, and any other types of arrangements with terms of one year or less.

Trade Accounts Receivable and Other Receivables, Net

Our accounts receivable are primarily from purchasers and shippers of crude oil and, to a lesser extent, purchasers of NGL. These purchasers include, but are not limited to, refiners, producers, marketing and trading companies and financial institutions. The majority of our accounts receivable relate to our crude oil supply and logistics activities that can generally be described as high volume and low margin activities, in many cases involving exchanges of crude oil volumes.

During 2020, macroeconomic and geopolitical conditions including the collapse of oil prices driven by both the decrease in demand caused by the COVID-19 pandemic and excess supply has caused liquidity issues impacting many energy companies, which in turn has increased the potential credit risks associated with certain counterparties with which we do business. To mitigate credit risk related to our accounts receivable, we utilize a rigorous credit review process. We closely monitor market conditions and perform credit reviews of each customer to make a determination with respect to the amount, if any, of open credit to be extended to any given customer and the form and amount of financial performance assurances we require. Such financial assurances are commonly provided to us in the form of advance cash payments, standby letters of credit, credit insurance or parental guarantees. Additionally, in an effort to mitigate credit risk, a significant portion of our transactions with counterparties are settled on a net-cash basis. For a majority of these net-cash arrangements, we also enter into netting agreements (contractual agreements that allow us to offset receivables and payables with those counterparties against each other on our balance sheet).

Accounts receivable from the sale of crude oil are generally settled with counterparties on the industry settlement date, which is typically in the month following the month in which the title transfers. Otherwise, we generally invoice customers within 30 days of when the products or services were provided and generally require payment within 30 days of the invoice date. We review all outstanding accounts receivable balances on a monthly basis and record our receivables net of expected credit losses. We do not write-off accounts receivable balances until we have exhausted substantially all collection efforts. At December 31, 2020 and 2019, substantially all of our trade accounts receivable were less than 30 days past their scheduled invoice date. Our expected credit losses are immaterial. Although we consider our credit procedures to be adequate to mitigate any significant credit losses, given the sharp decline in demand for crude oil and the drop in prices, the actual amount of current and future credit losses could vary significantly from estimated amounts.

The following is a reconciliation of trade accounts receivable from revenues from contracts with customers to total Trade accounts receivable and other receivables, net as presented on our Consolidated Balance Sheets (in millions):


	December 31,
	2020		2019
Trade accounts receivable arising from revenues from contracts with customers	$	2,317	$	3,381
Other trade accounts receivables and other receivables (1)	2,818		3,576
Impact due to contractual rights of offset with counterparties	(2,582)		(3,343)
Trade accounts receivable and other receivables, net	$	2,553	$	3,614

(1) The balance is comprised primarily of accounts receivable associated with buy/sell arrangements that are not within the scope of ASC 606.

- Definition

The entire disclosure of revenue from contract with customer to transfer good or service and to transfer nonfinancial asset. Includes, but is not limited to, disaggregation of revenue, credit loss recognized from contract with customer, judgment and change in judgment related to contract with customer, and asset recognized from cost incurred to obtain or fulfill contract with customer. Excludes insurance and lease contracts.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-URI http://asc.fasb.org/topic&trid=49130388

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 10
-URI http://asc.fasb.org/extlink&oid=121604090&loc=SL49130551-203045

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 13
-Subparagraph (b)(2)
-URI http://asc.fasb.org/extlink&oid=121604090&loc=SL49130556-203045

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 12
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=121604090&loc=SL49130554-203045

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 9
-URI http://asc.fasb.org/extlink&oid=121604090&loc=SL49130550-203045

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 12
-Subparagraph (e)
-URI http://asc.fasb.org/extlink&oid=121604090&loc=SL49130554-203045

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 12
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=121604090&loc=SL49130554-203045

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 12
-Subparagraph (d)
-URI http://asc.fasb.org/extlink&oid=121604090&loc=SL49130554-203045

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 15
-URI http://asc.fasb.org/extlink&oid=121604090&loc=SL49130558-203045

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 12
-Subparagraph (c)
-URI http://asc.fasb.org/extlink&oid=121604090&loc=SL49130554-203045

+ Details

Net Income/(Loss) Per Class A Share

12 Months Ended

Dec. 31, 2020

Earnings Per Share [Abstract]

Net Income/(Loss) Per Class A Share

Net Income/(Loss) Per Class A ShareBasic net income/(loss) per Class A share is determined by dividing net income/(loss) attributable to PAGP by the weighted average number of Class A shares outstanding during the period. Our Class B and Class C shares do not share in the earnings of the Partnership; accordingly, basic and diluted net income/(loss) per Class B and Class C share has not been presented.

Diluted net income/(loss) per Class A share is determined by dividing net income/(loss) attributable to PAGP by the diluted weighted average number of Class A shares outstanding during the period. For purposes of calculating diluted net income/(loss) per Class A share, both the net income/(loss) attributable to PAGP and the diluted weighted average number of Class A shares outstanding consider the impact of possible future exchanges of (i) AAP units and the associated Class B shares into our Class A shares and (ii) certain Class B units of AAP (referred to herein as “AAP Management Units”) into our Class A shares. In addition, the calculation of the diluted weighted average number of Class A shares outstanding considers the effect of potentially dilutive awards under the Plains GP Holdings, L.P. Long-Term Incentive Plan (the “PAGP LTIP”).

All AAP Management Units that have satisfied the applicable performance conditions are considered potentially dilutive. Exchanges of potentially dilutive AAP units and AAP Management Units are assumed to have occurred at the beginning of the period and the incremental income attributable to PAGP resulting from the assumed exchanges is representative of the incremental income that would have been attributable to PAGP if the assumed exchanges occurred on that date. See Note 12 for information regarding exchanges of AAP units and AAP Management Units. PAGP LTIP awards that are deemed to be dilutive are reduced by a hypothetical share repurchase based on the remaining unamortized fair value, as prescribed by the treasury stock method in guidance issued by the FASB. See Note 18 for information regarding PAGP LTIP awards.

On a weighted-average basis, for the year ended December 31, 2019, the possible exchange of 99 million AAP units would not have had a dilutive effect on basic net income/(loss) per Class A share. For the year ended December 31, 2020, the possible exchange of 1 million AAP Management Units would not have had a dilutive effect on basic net income/(loss) per Class A share on a weighted-average basis. For the year ended December 31, 2020, our PAGP LTIP awards were antidilutive. For the years ended December 31, 2019 and 2018 our PAGP LTIP awards were dilutive; however, there were less than 0.1 million dilutive LTIP awards for each period, which did not change the presentation of weighted average Class A shares outstanding or net income/(loss) per Class A share.

The following table sets forth the computation of basic and diluted net income/(loss) per Class A share (in millions, except per share data):


	Year Ended December 31,
	2020		2019		2018
Basic Net Income/(Loss) per Class A Share
Net income/(loss) attributable to PAGP	$	(568)	$	331	$	334
Basic weighted average Class A shares outstanding	186		168		158

Basic net income/(loss) per Class A share	$	(3.06)	$	1.97	$	2.12

Diluted Net Income/(Loss) per Class A Share
Net income/(loss) attributable to PAGP	$	(568)	$	331	$	334
Incremental net income/(loss) attributable to PAGP resulting from assumed exchange of AAP units and AAP Management Units	(189)		2		262
Net income/(loss) attributable to PAGP including incremental net income/(loss) from assumed exchange of AAP units and AAP Management Units	$	(757)	$	333	$	596

Basic weighted average Class A shares outstanding	186		168		158
Dilutive shares resulting from assumed exchange of AAP units and AAP Management Units	60		2		124
Diluted weighted average Class A shares outstanding	246		170		282

Diluted net income/(loss) per Class A share	$	(3.07)	$	1.96	$	2.11

Inventory, Linefill and Base Gas and Long-term Inventory

12 Months Ended

Dec. 31, 2020

Inventory, Linefill and Base Gas and Long-term Inventory

Inventory, Linefill and Base Gas and Long-term Inventory

Inventory, including long-term inventory, primarily consists of crude oil and NGL in pipelines, storage facilities and railcars that are valued at the lower of cost or net realizable value, with cost determined using an average cost method within specific inventory pools. At the end of each reporting period, we assess the carrying value of our inventory and make any adjustments necessary to reduce the carrying value to the applicable net realizable value. Any resulting adjustments are a component of “Purchases and related costs” on our accompanying Consolidated Statements of Operations. During the years ended December 31, 2020, 2019 and 2018, we recorded charges of $233 million (of which $40 million was associated with our long-term inventory), $11 million and $8 million, respectively, related to the write down of our crude oil and NGL inventory due to declines in prices. A portion of these inventory valuation adjustments was offset by the recognition of gains on derivative instruments being utilized to hedge future sales of our crude oil and NGL inventory. Such gains were recorded to “Supply and Logistics segment revenues” in our accompanying Consolidated Statements of Operations. See Note 13 for discussion of our derivative and risk management activities.

Linefill and base gas in assets we own are recorded at historical cost and consist of crude oil, NGL and natural gas. We classify as linefill or base gas (i) our proportionate share of barrels used to fill a pipeline that we own such that when an incremental barrel is pumped into or enters a pipeline it forces product out at another location, (ii) barrels that represent the minimum working requirements in tanks and caverns that we own and (iii) natural gas required to maintain the minimum operating pressure of natural gas storage facilities we own.

Linefill and base gas carrying amounts are reviewed for impairment in accordance with FASB guidance with respect to accounting for the impairment or disposal of long-lived assets. Carrying amounts that are not expected to be recoverable through future cash flows are written down to estimated fair value. See Note 6 for further discussion regarding impairment of long-lived assets. During 2020, 2019 and 2018, we did not recognize any material impairments of linefill and base gas.

Minimum working inventory requirements in third-party assets and other working inventory in our assets that are needed for our commercial operations are included within specific inventory pools in inventory (a current asset) in determining the average cost of operating inventory. At the end of each period, we reclassify the inventory not expected to be liquidated within the succeeding twelve months out of “Inventory,” at the average cost of the applicable inventory pools, and into “Long-term inventory,” which is reflected as a separate line item under “Other assets” on our Consolidated Balance Sheets.

Inventory, linefill and base gas and long-term inventory consisted of the following (barrels and natural gas volumes in thousands and carrying value in millions):


	December 31, 2020						December 31, 2019
	Volumes	Unit of Measure	Carrying Value		Price/ Unit (1)		Volumes	Unit of Measure	Carrying Value		Price/ Unit (1)
Inventory
Crude oil	13,450	barrels	$	441	$	32.79	8,613	barrels	$	450	$	52.25
NGL	12,302	barrels	199		$	16.18	7,574	barrels	142		$	18.75

Other	N/A		7		N/A		N/A		12		N/A
Inventory subtotal			647						604

Linefill and base gas
Crude oil	14,669	barrels	828		$	56.45	14,316	barrels	826		$	57.70
NGL	1,640	barrels	44		$	26.83	1,701	barrels	47		$	27.63
Natural gas	25,576	Mcf	110		$	4.30	24,976	Mcf	108		$	4.32
Linefill and base gas subtotal			982						981

Long-term inventory
Crude oil	2,499	barrels	111		$	44.42	2,598	barrels	152		$	58.51
NGL	1,185	barrels	19		$	16.03	1,707	barrels	30		$	17.57
Long-term inventory subtotal			130						182

Total			$	1,759					$	1,767

(1)Price per unit of measure is comprised of a weighted average associated with various grades, qualities and locations. Accordingly, these prices may not coincide with any published benchmarks for such products.

Property and Equipment

12 Months Ended

Dec. 31, 2020

Property, Plant and Equipment [Abstract]

Property and Equipment

Property and EquipmentIn accordance with our capitalization policy, expenditures made to expand the existing operating and/or earnings capacity of our assets are capitalized. We also capitalize certain costs directly related to the construction of such assets, including related internal labor costs, engineering costs and interest costs. For the years ended December 31, 2020, 2019 and 2018, capitalized interest recorded to property and equipment was $8 million, $14 million and $21 million, respectively. In addition, we capitalize interest related to investments in certain unconsolidated entities. See Note 9 for additional information. We also capitalize expenditures for the replacement and/or refurbishment of partially or fully depreciated assets in order to maintain the operating and/or earnings capacity of our existing assets. Repair and maintenance expenditures incurred in order to maintain the day to day operation of our existing assets are expensed as incurred.

Property and equipment, net is stated at cost and consisted of the following (in millions):


	Estimated Useful Lives (Years)	December 31,
		2020		2019
Pipelines and related facilities (1)	10 - 70	$	11,147	$	11,149
Storage, terminal and rail facilities	10 - 70	6,042		6,134
Trucking equipment and other	2 - 15	524		486
Construction in progress	N/A	272		518
Office property and equipment	2 - 50	293		269
Land and other	N/A	342		427
Property and equipment, gross		18,620		18,983
Accumulated depreciation		(4,000)		(3,616)
Property and equipment, net		$	14,620	$	15,367

(1)We include rights-of-way, which are intangible assets, in our Pipelines and related facilities amounts within property and equipment.

We calculate our depreciation using the straight-line method, based on estimated useful lives and salvage values of our assets. Depreciation expense for the years ended December 31, 2020, 2019 and 2018 was $566 million, $528 million and $455 million, respectively. See “Impairment of Long-Lived Assets (Held and Used)” below for a discussion of our policy for the recognition of asset impairments.

As of December 31, 2020, 2019 and 2018, we incurred liabilities for construction in progress that had not been paid of $51 million, $120 million and $206 million, respectively.

Impairment of Long-Lived Assets (Held and Used)

Long-lived assets with recorded values that are not expected to be recovered through future cash flows are written down to estimated fair value in accordance with FASB guidance with respect to the accounting for the impairment or disposal of long-lived assets. Under this guidance, a long-lived asset is tested for impairment when events or circumstances indicate that its carrying value may not be recoverable. The carrying value of a long-lived asset is not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. If the carrying value exceeds the sum of the undiscounted cash flows, an impairment loss equal to the amount by which the carrying value exceeds the fair value of the asset is recognized.

We periodically evaluate property and equipment and other long-lived assets for impairment when events or circumstances indicate that the carrying value of these assets may not be recoverable. The evaluation is highly dependent on the underlying assumptions of related cash flows. The subjective assumptions used to determine the existence of an impairment in carrying value include:

•whether there is an indication of impairment;

•the grouping of assets;

•the intention of “holding,” “abandoning” or “selling” an asset;

•the forecast of undiscounted expected future cash flow over the asset’s estimated useful life; and

•if an impairment exists, the fair value of the asset or asset group.

In addition, when we evaluate property and equipment and other long-lived assets for recoverability, it may also be necessary to review related depreciation estimates and methods.

During the year ended December 31, 2020, we recognized approximately $541 million of non-cash impairment losses, reflected in “(Gains)/losses on asset sales and asset impairments, net” on our Consolidated Statement of Operations.

Of our impairment losses, approximately $415 million was associated with certain pipeline assets in our Transportation segment located in the Central region. The macroeconomic and geopolitical conditions that occurred in 2020, including the collapse of oil prices driven by both the decrease in demand caused by the COVID-19 pandemic and excess supply, as well as changing market conditions and expected lower crude oil production in certain regions, resulted in expected decreases in future cash flows for certain of our assets, which was a triggering event that required us to assess the recoverability of our carrying value of such long-lived assets. As a result of our impairment review, we wrote off the portion of the carrying amount of these long-lived assets that exceeded their fair value. Our estimated fair values (which we consider a Level 3 measurement in the fair value hierarchy) were based upon a discounted cash flow approach utilizing various assumptions and the application of a discount rate of approximately 14%, which represents our estimate of the cost of capital of a theoretical market participant. Such assumptions included (but were not limited to) (i) future commodity volumes (consistent with historical information and estimates of future drilling and completion activity), (ii) tariff rates, (iii) future commodity prices (based on relevant indices and applicable quality and location differentials), and (iv) estimated fixed and variable costs.

The remaining impairment losses were associated with idled or underutilized assets, including certain pipelines in our Transportation segment located in the Western region and other long-lived assets in our Facilities segment, for which it has been determined that it is unlikely that opportunities will exist in the future to recover our investment in these assets. We wrote off substantially all of the carrying value of these assets.

We did not recognize any material impairments during the years ended December 31, 2019 or 2018.

Acquisitions and Divestitures	12 Months Ended
Acquisitions and Divestitures	Dec. 31, 2020
Business Combinations [Abstract]
Acquisitions and Divestitures	Acquisitions and Divestitures Acquisitions In February 2020, we acquired Felix Midstream LLC, now known as FM Gathering LLC (“FM Gathering”) from Felix Energy Holdings II, LLC for approximately $300 million, net of working capital and other adjustments. FM Gathering owns and operates a newly constructed crude oil gathering system in the Delaware Basin, with associated crude oil storage and truck offloading capacity, and is supported by a long-term acreage dedication. The assets acquired are included in our Transportation and Supply and Logistics segments. This acquisition was accounted for using the acquisition method of accounting and the determination of the fair value of the assets acquired and liabilities assumed was determined in accordance with the applicable accounting guidance. The assets acquired primarily consisted of property and equipment of $115 million and intangible assets of $187 million. The fair value of the tangible assets is a Level 3 measurement in the fair value hierarchy and was determined using a cost approach. The cost approach was based on costs incurred on similar recent construction projects. The fair value of the intangible assets is also a Level 3 measurement in the fair value hierarchy and was determined by applying a discounted cash flow approach. Such approach utilized discount rates varying from 18% to 19%, based on our estimate of the risk that a theoretical market participant would assign to the respective intangible assets. During the second quarter of 2019, we acquired a crude oil terminal, including tank bottoms and linefill, in Cushing, Oklahoma for cash consideration of $44 million, which was accounted for as an asset acquisition. Divestitures During the year ended December 31, 2020, we received cash proceeds of $451 million, primarily from the sale of: •certain Los Angeles Basin crude oil terminals previously disclosed in our Facilities segment for proceeds of approximately $200 million, subject to certain adjustments; •certain NGL terminals previously disclosed in our Facilities segment for proceeds of approximately $163 million (including $22 million related to a multi-year supply agreement related to the sale), subject to certain adjustments; and •a 10% ownership interest in Saddlehorn Pipeline Company, LLC (“Saddlehorn”) for proceeds of approximately $78 million, including working capital adjustments (see Note 9 for additional information). We recognized a loss related to these assets sales of $178 million, including non-cash impairments recognized upon classification to assets held for sale, for the year ended December 31, 2020. Such amount is included in “(Gains)/losses on asset sales and asset impairments, net” on our Consolidated Statement of Operations. During the year ended December 31, 2019, we sold certain non-core assets for total proceeds of $77 million that primarily consisted of a storage terminal in North Dakota, which was previously reported in our Facilities segment. For the year ended December 31, 2019, we recognized a net loss related to these asset sales of $16 million, which is comprised of gains of $31 million and losses of $47 million. Such amounts are included in “(Gains)/losses on asset sales and asset impairments, net” on our Consolidated Statement of Operations. During the year ended December 31, 2018, we received proceeds from asset sales of $1.334 billion, which primarily consisted of the sale of a 30% interest in BridgeTex Pipeline Company, LLC for proceeds of $868 million, resulting in a gain of $200 million. See Note 9 for additional discussion. The other assets sold during the year ended December 31, 2018 primarily included non-core property and equipment or are associated with the formation of strategic joint ventures and were previously reported in our Facilities and Transportation segments. For the year ended December 31, 2018, we recognized a net gain on sales of assets of $120 million, which is comprised of gains of $146 million and losses of $26 million. Such amounts are included in “(Gains)/losses on asset sales and asset impairments, net” on our Consolidated Statement of Operations.

Goodwill

12 Months Ended

Dec. 31, 2020

Goodwill and Intangible Assets Disclosure [Abstract]

Goodwill

Goodwill represents the future economic benefits arising from assets acquired in a business combination that are not individually identified and separately recognized.

In accordance with FASB guidance, we test goodwill to determine whether an impairment has occurred at least annually (as of June 30) and on an interim basis if it is more likely than not that a reporting unit’s fair value is less than its carrying value. Goodwill is tested for impairment at a level of reporting referred to as a reporting unit. A reporting unit is an operating segment or one level below an operating segment for which discrete financial information is available and regularly reviewed by segment management. Our reporting units are our operating segments. FASB guidance provides for a quantitative approach to testing goodwill for impairment; however, we may first assess certain qualitative factors to determine whether it is necessary to perform the quantitative goodwill impairment test. In the quantitative test, we compare the fair value of the reporting unit with the respective book values, including goodwill, by using an income approach based on a discounted cash flow model. This approach requires us to make long-term forecasts of future revenues, expenses and other expenditures. Those forecasts require the use of various assumptions and estimates, the most significant of which are net revenues (total revenues less purchases and related costs), operating expenses, general and administrative expenses and the weighted average cost of capital. Fair value of the reporting units is determined using significant unobservable inputs, or Level 3 inputs in the fair value hierarchy. When the fair value is greater than book value, then the reporting unit’s goodwill is not considered impaired. If the book value is greater than fair value, then goodwill is impaired by the amount by which a reporting unit’s carrying value exceeds its fair value, not to exceed the carrying value of goodwill.

During the first quarter of 2020, we recorded impairment losses of $2.515 billion related to goodwill. Our market capitalization declined significantly during the first quarter driven by macroeconomic and geopolitical conditions that occurred in 2020, including the collapse of oil prices driven by both the decrease in demand caused by the COVID-19 pandemic and excess supply, as well as changing market conditions and expected lower crude oil production in certain regions, that resulted in expected decreases in future cash flows for certain of our assets, which we concluded was a triggering event that required us to perform a quantitative impairment test as of March 31, 2020, utilizing a discounted cash flow approach. We applied a discount rate of approximately 14% in the determination of the fair value of each of our reporting units, which represents our estimate of the cost of capital of a theoretical market participant as of March 31, 2020. The fair values of the reporting units are Level 3 measurements in the fair value hierarchy and were based on various inputs, as discussed below. The discounted cash flows for each reporting unit were based on six years of projected cash flows and terminal values that we believe would be applied by a theoretical market participant in similar market transactions. The discounted cash flows for the respective reporting units utilized various other assumptions, including, but not limited to (i) volumes (based on historical information and estimates of future drilling and completion activity, as well as expectations of future demand recovery), (ii) tariff and storage rates, (iii) future commodity prices (based on relevant indices and applicable quality and location differentials), and (iv) estimated fixed and variable costs. We used a range of cash flows for the discounted cash flow calculations based on differing potential market scenarios, but for each of the reporting units, the ultimate outcome of the impairment test was unchanged by the various points within the range of cash flows. As a result of the impairment test, we concluded that the carrying value of each of our reporting units exceeded their respective fair values, resulting in a goodwill impairment charge for the entire goodwill balance for each reporting unit. Prior to the year ended December 31, 2020, we did not recognize any impairments of goodwill.

Goodwill by segment and changes in goodwill is reflected in the following table (in millions):


	Transportation		Facilities		Supply and Logistics		Total
Balance at December 31, 2018	$	1,040	$	978	$	503	$	2,521
Foreign currency translation adjustments	12		4		3		19

Balance at December 31, 2019	$	1,052	$	982	$	506	$	2,540
Acquisitions	2		—		—		2

Goodwill, gross	1,054		982		506		2,542
Impairments	(1,038)		(975)		(502)		(2,515)
Foreign currency translation adjustments	(16)		(7)		(4)		(27)
Accumulated impairment losses	(1,054)		(982)		(506)		(2,542)
Balance at December 31, 2020	$	—	$	—	$	—	$	—

Investments in Unconsolidated Entities

12 Months Ended

Dec. 31, 2020

Equity Method Investments and Joint Ventures [Abstract]

Investments in Unconsolidated Entities

Investments in entities over which we have significant influence but not control are accounted for under the equity method. We do not consolidate any part of the assets or liabilities of our equity investees. Our share of net income or loss is reflected as one line item on our Consolidated Statements of Operations entitled “Equity earnings in unconsolidated entities” and will increase or decrease, as applicable, the carrying value of our investments in unconsolidated entities on our Consolidated Balance Sheets. We evaluate our equity investments for impairment in accordance with FASB guidance with respect to the equity method of accounting for investments in common stock. An impairment of an equity investment results when factors indicate that the investment’s fair value is less than its carrying value and the reduction in value is other than temporary in nature.

Our investments in unconsolidated entities consisted of the following (in millions, except percentage data):


		Ownership Interest at December 31, 2020	Investment Balance December 31,
Entity (1)	Type of Operation		2020		2019
BridgeTex Pipeline Company, LLC (“BridgeTex”)	Crude Oil Pipeline	20%	$	421	$	431
Cactus II Pipeline LLC (“Cactus II”)	Crude Oil Pipeline	65%	752		738
Capline Pipeline Company LLC	Crude Oil Pipeline (2)	54%	514		484
Diamond Pipeline LLC (“Diamond”)	Crude Oil Pipeline	50%	480		476
Eagle Ford Pipeline LLC (“Eagle Ford Pipeline”)	Crude Oil Pipeline	50%	372		382
Eagle Ford Terminals Corpus Christi LLC (“Eagle Ford Terminals”)	Crude Oil Terminal and Dock	50%	122		126
Red Oak Pipeline LLC (“Red Oak”)	Crude Oil Pipeline	50%	35		20
Saddlehorn	Crude Oil Pipeline	30%	208		234
STACK Pipeline LLC (“STACK”)	Crude Oil Pipeline	50%	22		117
White Cliffs Pipeline, LLC	Crude Oil Pipeline	36%	192		196
Wink to Webster Pipeline LLC (“W2W Pipeline”)	Crude Oil Pipeline	16%	330		136
Other investments			316		343
Total Investments in Unconsolidated Entities			$	3,764	$	3,683

(1)Except for Eagle Ford Terminals, which is reported in our Facilities segment, the financial results from the entities are reported in our Transportation segment.

(2)The Capline pipeline was taken out of service pending the reversal of the pipeline system.

Impairments

During the year ended December 31, 2020, we recognized losses as a result of the write-down of certain of our investments in unconsolidated entities, as discussed further below. Such amounts are reflected in “Gain on/(impairment of) investments in unconsolidated entities, net” on our Consolidated Statement of Operations.

STACK. During the third quarter of 2020, we determined that there was an other-than-temporary impairment of our investment in STACK Pipeline LLC as a result of a continued decline of drilling activity and related volumes of crude oil in its area of operation. We recognized a loss of $91 million related to the write-down of the portion of the carrying amount of our investment that exceeded its fair value. The estimated fair value (which we consider a Level 3 measurement in the fair value hierarchy) was based on a discounted cash flow approach utilizing various assumptions and the application of a discount rate of approximately 14%, which represents our estimate of the cost of capital of a theoretical market participant. Such assumptions included (but were not limited to) (i) volumes (consistent with historical information and estimates of future drilling and completion activity), (ii) tariff rates, (iii) future commodity prices (based on relevant indices and applicable quality and location differentials), and (iv) estimated fixed and variable costs.

Red Oak. In June 2019, we announced the formation of Red Oak, a joint venture with a subsidiary of Phillips 66. We own a 50% interest in Red Oak, which is accounted for under the equity method of accounting. Red Oak was developing a new pipeline that would provide crude oil transportation service from Cushing, Oklahoma, and the Permian Basin in West Texas to multiple destinations along the Texas Gulf Coast, including Corpus Christi, Ingleside, Houston and Beaumont, Texas. In March 2020, the partners of Red Oak announced they were deferring the Red Oak pipeline project and suspending actions that would require additional capital spending on the project, and that they would re-evaluate demand for the project in light of recent market developments. Subsequently, the partners determined that the project would not proceed as previously contemplated. We determined that there was an other-than-temporary impairment of our investment in Red Oak, and we recognized a loss of $69 million related to the write-down of our investment in Red Oak to the estimated residual value of our share of the net assets during the second quarter of 2020.

Other investments. During the first quarter of 2020, we also recognized a loss of $43 million related to the write-down of certain of our investments included in “Other investments” in the table above due to an other-than-temporary impairment related to a decline in market conditions.

Formations

Capline LLC. During the first quarter of 2019, the owners of the Capline pipeline system contributed their undivided joint interests in the system to a newly formed entity, Capline Pipeline Company LLC (“Capline LLC”), in exchange for equity interests in such entity. After the contribution, Capline LLC owns 100% of the pipeline system. Each owner’s undivided joint interest in the Capline pipeline system prior to the transaction is equal to each owner’s equity interest in Capline LLC. Although we own a majority of Capline LLC’s equity, we do not have a controlling financial interest in Capline LLC because the other members have substantive participating rights. Therefore, we account for our ownership interest in Capline LLC as an equity method investment.

Under applicable accounting rules, the transaction resulted in a “loss of control” of our undivided joint interest, which was derecognized and contributed to Capline LLC. The “loss of control” required us to measure our equity interest in Capline LLC at fair value. At the time of the transaction, our 54% undivided joint interest in the Capline pipeline system had a carrying value of $175 million, which primarily related to property and equipment included in our Transportation segment. We determined the fair value of our investment in Capline LLC to be approximately $444 million, resulting in the recognition of a gain of $269 million during the year ended December 31, 2019. Such gain is included in “Gain on/(impairment of) investment in unconsolidated entities, net” on our Consolidated Statement of Operations.

The fair value of our investment in Capline LLC was based on an income approach utilizing a discounted cash flow analysis. The cash flow forecasts require the use of various assumptions and estimates which include those related to the timing and amount of capital expenditures, the expected tariff rates and volumes of crude oil, and the terminal value. We probability-weighted various forecasted cash flow scenarios utilized in the analysis when we considered the possible outcomes. We used a discount rate representing our estimate of the risk adjusted discount rate that would be used by market participants. If shipper interest varies from the levels assumed in our model, the related cash flows, and thus the fair value of our investment, could be materially impacted. The fair value of our investment was determined using significant unobservable inputs, or Level 3 inputs in the fair value hierarchy.

W2W Pipeline. In 2019, we participated in the formation of W2W Pipeline, a joint venture with subsidiaries of ExxonMobil, Lotus Midstream, LLC and three additional entities, in which we own a 16% interest. We account for our interest in W2W Pipeline under the equity method of accounting. W2W Pipeline has entered into an undivided joint-ownership arrangement with a subsidiary of Enterprise Products Partners, L.P. that has acquired 29% of the capacity of the pipeline segment from Midland, Texas to Webster, Texas, and W2W Pipeline now owns 71% of this segment of the pipeline. The pipeline originates in the Permian Basin in West Texas and transports crude oil to multiple destinations in the Houston and Galveston market areas. The pipeline system, which is currently in partial service, will provide approximately 1.5 million barrels per day of crude oil capacity (1.1 million barrels per day, net to the undivided joint ownership interest).

Cushing Connect. During the fourth quarter of 2019, we announced the formation of Cushing Connect Pipeline & Terminal LLC, a joint venture with Holly Energy Partners LP for (i) the development and construction of a new 160,000 barrel per day pipeline that will connect the Cushing, Oklahoma crude oil hub to the Tulsa, Oklahoma refining complex owned by a subsidiary of HollyFrontier Corporation and (ii) the ownership and operation of 1.5 million barrels of crude oil storage in Cushing, Oklahoma (the “JV Terminal”). We contributed the crude oil storage to Cushing Connect and own a 50% interest, which is accounted for under the equity method of accounting. The pipeline is expected to be in service during the first quarter of 2021.

Cactus II. In the second quarter of 2018, a subsidiary of Oxy and another third party each exercised their purchase options for a 20% interest and a 15% interest, respectively, in Cactus II, which owns the Cactus II pipeline system. Although we own a majority of Cactus II’s equity, we do not have a controlling financial interest in Cactus II because the other members have substantive participating rights. Therefore, we account for our ownership interest in Cactus II as an equity method investment. Following the exercise of the purchase options, we deconsolidated Cactus II resulting in a reduction of property and equipment of $74 million (which was representative of the costs incurred to date to construct the pipeline and equivalent to fair value), and we received $26 million of cash from Cactus II, which represented the other members’ portion of the property and equipment.

In addition, during the second quarter of 2018, we received a $100 million advance cash payment from Cactus II associated with pipeline capacity agreements, which is recorded as long-term deferred revenue within “Other long-term liabilities and deferred credits” on our Consolidated Balance Sheet. Such amount is being recognized in revenue ratably over the life of the contracts.

Divestitures

Saddlehorn. In February 2020, we sold a 10% ownership interest in Saddlehorn for proceeds of approximately $78 million and have retained a 30% ownership interest. We recorded a gain of approximately $21 million related to this sale, which is included in “Gain on/(impairment of) investments in unconsolidated entities, net” on our Condensed Consolidated Statement of Operations. We continue to account for our remaining interest under the equity method of accounting.

BridgeTex. During the third quarter of 2018, we sold a 30% interest in BridgeTex for proceeds of $868 million, including working capital adjustments, and have retained a 20% interest. We recorded a gain of $200 million related to this sale, which is included in “Gain on investment in unconsolidated entities” on our Consolidated Statement of Operations. We continue to account for our remaining interest under the equity method of accounting.

Distributions

Distributions received from unconsolidated entities are classified based on the nature of the distribution approach, which looks to the activity that generated the distribution. We consider distributions received from unconsolidated entities as a return on investment in those entities to the extent that the distribution was generated through operating results, and therefore classify these distributions as cash flows from operating activities in our Consolidated Statement of Cash Flows. Other distributions received from unconsolidated entities are considered a return of investment and classified as cash flows from investing activities on the Consolidated Statement of Cash Flows.

Contributions

We generally fund our portion of development, construction or capital investment projects of our equity method investees through capital contributions. Our contributions to these entities increase the carrying value of our investments and are reflected in our Consolidated Statements of Cash Flows as cash used in investing activities. During the years ended December 31, 2020, 2019 and 2018, we made cash contributions of $445 million, $504 million and $459 million, respectively, to certain of our equity method investees. In addition, we capitalized interest of $16 million, $20 million and $9 million during the years ended December 31, 2020, 2019 and 2018, respectively, related to contributions to unconsolidated entities for projects under development and construction. We anticipate that we will make additional contributions in 2021 related to ongoing projects.

Basis Differences

Our investments in unconsolidated entities exceeded our share of the underlying equity in the net assets of such entities by $170 million and $349 million at December 31, 2020 and 2019, respectively. Such basis differences are included in the carrying values of our investments on our Consolidated Balance Sheets. The portion of the basis differences attributable to depreciable or amortizable assets is amortized on a straight-line basis over the estimated useful life of the related assets, which reduces “Equity earnings in unconsolidated entities” on our Consolidated Statements of Operations. The portion of the basis differences attributable to goodwill is not amortized. The majority of the basis difference at both December 31, 2020 and 2019 was attributable to goodwill related to our ownership interest in BridgeTex and Capline with the remaining basis difference primarily related to capitalized interest incurred during construction of the assets of our unconsolidated entities. The basis difference at December 31, 2020 was further impacted by impairments as discussed above.

Summarized Financial Information of Unconsolidated Entities

Combined summarized financial information for all of our unconsolidated entities is shown in the tables below (in millions). None of our unconsolidated entities have noncontrolling interests.


	December 31,
	2020		2019
Current assets	$	580	$	652
Noncurrent assets	$	8,769	$	7,264
Current liabilities	$	343	$	298
Noncurrent liabilities	$	10	$	26


	Year Ended December 31,
	2020		2019		2018
Revenues	$	1,360	$	1,469	$	1,235
Operating income	$	828	$	994	$	824
Net income	$	826	$	995	$	824

Other Long-Term Assets, Net

12 Months Ended

Dec. 31, 2020

Other Assets [Abstract]

Other Long-Term Assets, Net

Other long-term assets, net of accumulated amortization, consisted of the following (in millions):


		December 31, 2020						December 31, 2019
	Estimated Useful Lives (Years)	Cost		Accumulated Amortization		Net		Cost		Accumulated Amortization		Net
Customer contracts and relationships (1)	3 – 29	$	1,291	$	(519)	$	772	$	1,134	$	(463)	$	671
Property tax abatement	13	23		(20)		3		23		(18)		5
Other agreements	1 – 70	40		(10)		30		42		(11)		31
Intangible assets (2)		1,354		(549)		805		1,199		(492)		707
Other		163		(3)		160		150		(1)		149
Other long-term assets, net		$	1,517	$	(552)	$	965	$	1,349	$	(493)	$	856

(1)Amounts for the year ended December 31, 2020 include intangible assets associated with the acquisition of FM Gathering. See Note 7 for additional information.

(2)We include rights-of-way, which are intangible assets, in our pipeline and related facilities amounts within property and equipment. See Note 6 for a discussion of property and equipment.

Intangible assets that have finite lives are tested for impairment when events or circumstances indicate that the carrying value may not be recoverable. We did not recognize any impairments of finite-lived intangible assets during the three years ended December 31, 2020.

Amortization expense for finite-lived intangible assets for the years ended December 31, 2020, 2019 and 2018 was $90 million, $76 million and $66 million, respectively. We estimate that our amortization expense related to finite-lived intangible assets for the next five years will be as follows (in millions):


2021	$	87
2022	$	86
2023	$	82
2024	$	80
2025	$	77

Debt

12 Months Ended

Dec. 31, 2020

Debt Disclosure [Abstract]

Debt

Debt consisted of the following (in millions):


	December 31, 2020		December 31, 2019
SHORT-TERM DEBT
PAA commercial paper notes, bearing a weighted-average interest rate of 0.7% and 2.2%, respectively (1)	$	547	$	93
PAA senior secured hedged inventory facility, bearing a weighted-average interest rate of 1.2% and 2.7%, respectively (1)	167		325
Other	117		86
Total short-term debt	831		504

LONG-TERM DEBT
PAA senior notes:
5.00% senior notes due February 2021	—		600
3.65% senior notes due June 2022	750		750
2.85% senior notes due January 2023	400		400
3.85% senior notes due October 2023	700		700
3.60% senior notes due November 2024	750		750
4.65% senior notes due October 2025	1,000		1,000
4.50% senior notes due December 2026	750		750
3.55% senior notes due December 2029	1,000		1,000
3.80% senior notes due September 2030	750		—
6.70% senior notes due May 2036	250		250
6.65% senior notes due January 2037	600		600
5.15% senior notes due June 2042 (2)	499		500
4.30% senior notes due January 2043 (2)	348		350
4.70% senior notes due June 2044 (2)	687		700
4.90% senior notes due February 2045 (2)	649		650
Unamortized discounts and debt issuance costs	(62)		(61)
PAA senior notes, net of unamortized discounts and debt issuance costs	9,071		8,939
Other long-term debt:
PAA GO Zone term loans, net of debt issuance costs of $1 and $1, respectively, bearing a weighted-average interest rate of 1.3% and 2.6%, respectively	199		199
Other	112		49
Total long-term debt	9,382		9,187
Total debt (3)	$	10,213	$	9,691

(1)We classified these PAA commercial paper notes and credit facility borrowings as short-term as of December 31, 2020 and 2019, as these notes and borrowings were primarily designated as working capital borrowings, were required to be repaid within one year and were primarily for hedged NGL and crude oil inventory and NYMEX and ICE margin deposits.

(2)During the year ended December 31, 2020, we repurchased $17 million of our outstanding senior notes on the open market and recognized a gain of $3 million on these transactions, which is included in “Other income/(expense), net” on our Consolidated Statement of Operations.

(3)PAA’s fixed-rate senior notes had a face value of approximately $9.1 billion and $9.0 billion as of December 31, 2020 and 2019, respectively. We estimated the aggregate fair value of these notes as of December 31, 2020 and 2019 to be approximately $9.9 billion and $9.3 billion, respectively. PAA’s fixed-rate senior notes are traded among institutions, and these trades are routinely published by a reporting service. Our determination of fair value is based on reported trading activity near the end of the reporting period. We estimate that the carrying value of outstanding borrowings under PAA’s credit facilities, commercial paper program and GO Zone term loans approximates fair value as interest rates reflect current market rates. The fair value estimates for the PAA senior notes, credit facilities, commercial paper program and GO Zone term loans are based upon observable market data and are classified in Level 2 of the fair value hierarchy.

PAA Commercial Paper Program

PAA has a commercial paper program under which it may issue (and have outstanding at any time) up to $3.0 billion in the aggregate of privately placed, unsecured commercial paper notes. Such notes are backstopped by the PAA senior unsecured revolving credit facility and the PAA senior secured hedged inventory facility; as such, any borrowings under the PAA commercial paper program reduce the available capacity under these facilities.

Credit Agreements

PAA senior secured hedged inventory facility. PAA has a credit agreement that provides for a senior secured hedged inventory facility with a committed borrowing capacity of $1.4 billion, of which $400 million is available for the issuance of letters of credit. Subject to obtaining additional or increased lender commitments, the committed capacity of the facility may be increased to $1.9 billion. Proceeds from the facility are primarily used to finance purchased or stored hedged inventory, including NYMEX and ICE margin deposits. Such obligations under the committed facility are secured by the financed inventory and the associated accounts receivable and are repaid from the proceeds of the sale of the financed inventory. Borrowings accrue interest based, at PAA’s election, on certain floating rate indices as defined in the credit agreement, in each case plus a margin based on PAA’s credit rating at the applicable time. The agreement also provides for one or more one-year extensions, subject to applicable approval. In August 2019, PAA amended this agreement to, among other things, extend the maturity date of the facility to August 2022 for each extending lender. The maturity date with respect to each non-extending lender (which represent aggregate commitments of approximately $45 million out of total commitments of $1.4 billion from all lenders) remains August 2021.

PAA senior unsecured revolving credit facility. PAA has a credit agreement that provides for a senior unsecured revolving credit facility with a committed borrowing capacity of $1.6 billion. Subject to obtaining additional or increased lender commitments, the committed capacity may be increased to $2.1 billion. The credit agreement also provides for the issuance of letters of credit. Borrowings accrue interest based, at PAA’s election, on certain floating rate indices as defined in the credit agreement, in each case plus a margin based on PAA’s credit rating at the applicable time. The agreement also provides for one or more one-year extensions, subject to applicable approval. In August 2019, PAA amended this agreement to, among other things, extend the maturity date of the facility to August 2024 for each extending lender.

PAA GO Zone term loans. In August 2018, PAA entered into an agreement for two $100 million term loans (the “GO Zone term loans”) from the remarketing of its $100 million Mississippi Business Finance Corporation Gulf Opportunity Zone Industrial Development Revenue Bonds (PAA Natural Gas Storage, L.P. Project), Series 2009 and its $100 million Mississippi Business Finance Corporation Gulf Opportunity Zone Industrial Development Revenue Bonds (PAA Natural Gas Storage, L.P. Project), Series 2010 (collectively, the “GO Bonds”). The GO Zone term loans accrue interest, based on certain floating rate indices, in accordance with the interest payable on the related GO Bonds as provided in the GO Bonds Indenture pursuant to which such GO Bonds are issued and governed. The purchasers of the two GO Zone term loans have the right to put, at par, the GO Zone term loans in July 2023. The GO Bonds mature by their terms in May 2032 and August 2035, respectively.

PAA Senior Notes

PAA’s senior notes are co-issued, jointly and severally, by Plains All American Pipeline, L.P. and a 100%-owned consolidated finance subsidiary (neither of which have independent assets or operations) and are unsecured senior obligations of such entities and rank equally in right of payment with existing and future senior indebtedness of the issuers. PAA may, at its option, redeem any series of senior notes at any time in whole or from time to time in part, prior to maturity, at the redemption prices described in the indentures governing the senior notes. PAA’s senior notes are not guaranteed by any of its subsidiaries.

PAA Senior Notes Issuances. The table below summarizes PAA’s issuances of senior unsecured notes during the three years ended December 31, 2020 (in millions):

Year

Description

Maturity

Face Value

Interest Payment Dates

2020

3.80% Senior Notes issued at 99.794% of face value

September 2030

750

March 15 and September 15

2019

3.55% Senior Notes issued at 99.801% of face value

December 2029

1,000

June 15 and December 15

PAA Senior Notes Repayments. During the three years ended December 31, 2020, PAA repaid the following senior unsecured notes in full (in millions):


Year	Description	Repayment Date
2020	$600 million 5.00% Senior Notes due February 2021	November 2020	(1)

2019	$500 million 2.60% Senior Notes due December 2019	November 2019	(2)
2019	$500 million 5.75% Senior Notes due January 2020	December 2019	(2)

(1)These senior notes were repaid with proceeds from PAA’s 3.80% senior notes issued in June 2020 and cash on hand.

(2)These senior notes were repaid with proceeds from PAA’s 3.55% senior notes issued in September 2019 and cash on hand.

Maturities

The weighted average maturity of our senior notes and GO Zone term loans outstanding at December 31, 2020 was approximately 10 years. The following table presents the aggregate contractually scheduled maturities of such senior notes and GO Zone term loans for the next five years and thereafter. The amounts presented exclude unamortized discounts and debt issuance costs.


Calendar Year	Payment (in millions)
2021	$	—
2022	$	750
2023	$	1,300
2024	$	750
2025	$	1,000
Thereafter	$	5,533

Covenants and Compliance

The credit agreements for PAA’s revolving credit facilities (which impact the ability to access the PAA commercial paper program because they provide the financial backstop that supports PAA’s short-term credit ratings) and PAA’s term loans and the indentures governing PAA’s senior notes contain cross-default provisions. PAA’s credit agreements prohibit declaration or payments of distributions on, or purchases or redemptions of, units if any default or event of default is continuing. In addition, PAA’s agreements contain various covenants limiting PAA’s ability to, among other things:

•grant liens on certain property;

•incur indebtedness, including finance leases;

•sell substantially all of its assets or enter into a merger or consolidation;

•engage in certain transactions with affiliates; and

•enter into certain burdensome agreements.

The credit agreements for the PAA senior unsecured revolving credit facility, the PAA senior secured hedged inventory facility and the PAA GO Zone term loans treat a change of control as an event of default and also require PAA to maintain a debt-to-EBITDA coverage ratio that, on a trailing four-quarter basis, will not be greater than 5.00 to 1.00 (or 5.50 to 1.00 on all outstanding debt during an acquisition period (generally, the period consisting of three fiscal quarters following an acquisition greater than $150 million)). For covenant compliance purposes, Consolidated EBITDA may include certain adjustments, including those for material projects and certain non-recurring expenses. Additionally, letters of credit and borrowings to fund hedged inventory and margin requirements are excluded when calculating the debt coverage ratio.

A default under PAA’s credit agreements or indentures would permit the lenders to accelerate the maturity of the outstanding debt. As long as PAA is in compliance with the provisions contained in its credit agreements, PAA’s ability to make distributions of available cash is not restricted. As of December 31, 2020, PAA was in compliance with the covenants contained in its credit agreements and indentures.

Borrowings and Repayments

Total borrowings under PAA’s credit facilities and commercial paper program for the years ended December 31, 2020, 2019 and 2018 were approximately $29.3 billion, $13.3 billion and $45.4 billion, respectively. Total repayments under PAA’s credit facilities and commercial paper program were approximately $29.0 billion, $12.9 billion and $46.3 billion for the years ended December 31, 2020, 2019 and 2018, respectively. The variance in total gross borrowings and repayments is impacted by various business and financial factors including, but not limited to, the timing, average term and method of general partnership borrowing activities.

Letters of Credit

In connection with our supply and logistics activities, we provide certain suppliers with irrevocable standby letters of credit to secure our obligation for the purchase and transportation of crude oil, NGL and natural gas. These letters of credit are issued under PAA’s senior unsecured revolving credit facility and senior secured hedged inventory facility, and our liabilities with respect to these purchase obligations are recorded in accounts payable on our balance sheet in the month the crude oil, NGL or natural gas is purchased. Generally, these letters of credit are issued for periods of up to seventy days and are terminated upon completion of each transaction. Additionally, we issue letters of credit to support insurance programs, derivative transactions, including hedging-related margin obligations, and construction activities. At December 31, 2020 and 2019, we had outstanding letters of credit of $129 million and $157 million, respectively.

Debt Issuance Costs

Costs incurred in connection with the issuance of senior notes are recorded as a direct deduction from the related debt liability and are amortized using the straight-line method over the term of the related debt. Use of the straight-line method does not differ materially from the “effective interest” method of amortization.

Partners' Capital and Distributions

12 Months Ended

Dec. 31, 2020

Partners' Capital Notes [Abstract]

Partners' Capital and Distributions

Partners’ Capital and Distributions

Our Shares

Our Class A shares, Class B shares and Class C shares represent limited partner interests in us. The holders of our Class A and Class B shares are entitled to exercise the rights or privileges available to limited partners under our partnership agreement, but only holders of Class A shares are entitled to participate in our distributions.

Our Class C shares are non-economic and provide PAA, as the sole holder of such Class C shares, the right to vote, pro rata with the holders of our Class A and Class B shares, in the election of eligible PAGP GP directors. Pursuant to the Omnibus Agreement entered into on November 15, 2016, the number of Class C shares that PAA owns will at all times equal the number of outstanding PAA common units, excluding common units held by AAP, and Series A preferred units. Thus, the Class C shares function as a “pass-through” voting mechanism through which PAA votes at the direction of and as proxy for the PAA common unitholders, other than AAP, and Series A preferred unitholders in such director elections.

Exchange and Redemption Rights

Holders of AAP units and their permitted transferees each have the right to exchange all or a portion of their AAP units for Class A shares at an exchange ratio of one Class A share for each AAP unit exchanged (referred to herein as their “Exchange Right”). This Exchange Right may be exercised only if, simultaneously therewith, an equal number of our Class B shares and general partner units are transferred by the exercising party to us. Additionally, a holder of vested AAP Management Units is entitled to convert his or her AAP Management Units into AAP units and a like number of our Class B shares based on a conversion ratio of approximately 0.941 AAP units for each AAP Management Unit. Following any such conversion, the holder will have the Exchange Right for our Class A shares. Holders of AAP Management Units who convert such units into AAP units and Class B shares will not receive general partner units and thus will not need to include any general partner units in a transfer or the exercise of their Exchange Right. See Note 15 for information regarding the recognition of deferred tax assets associated the transfer of ownership resulting from Exchange Right exercises.

Additionally, subject to certain limitations, a holder of AAP units (other than us and GP LLC) has the right (a “Redemption Right”) to cause AAP to redeem any or all of such holder’s AAP units in exchange for the distribution of an equivalent number of PAA common units held by AAP (“AAP Unit Redemption”). In connection with any AAP Unit Redemption, the redeeming holder will transfer the AAP units to AAP and a corresponding number of our Class B shares and general partner units (if any), in each case, to us. The AAP units transferred to AAP will be canceled, the Class B shares transferred to us will be canceled and the general partner units transferred to us will remain outstanding and increase our ownership percentage in our general partner. Additionally, we will issue a corresponding number of Class C shares to PAA.

Shares Outstanding

The following table presents the activity for our Class A shares, Class B shares and Class C shares:


	Class A Shares	Class B Shares	Class C Shares
Outstanding at December 31, 2017	156,111,139	126,984,572	510,925,432

Exchange Right exercises	3,363,199	(3,363,199)	—
Redemption Right exercises	—	(4,017,035)	4,017,035
Issuance of Series A preferred units by a subsidiary	—	—	1,393,926
Other	11,250	—	601,887
Outstanding at December 31, 2018	159,485,588	119,604,338	516,938,280

Exchange Right exercises (1)	22,637,818	(22,637,818)	—
Redemption Right exercises (1)	—	(31,180,818)	31,180,818
Other	15,186	—	1,419,041
Outstanding at December 31, 2019	182,138,592	65,785,702	549,538,139

Conversion of AAP Management Units	—	595,117	—
Exchange Right exercises	11,858,457	(11,858,457)
Redemption Right exercises		(3,882,170)	3,882,170
Repurchase of common units by a subsidiary	—	—	(6,222,748)
Other	54,387		520,201
Outstanding at December 31, 2020	194,051,436	50,640,192	547,717,762

(1)Includes exercises by Oxy and an affiliate of The Energy & Minerals Group (“EMG”). See Note 17 for additional information.

Distributions

We distribute 100% of our available cash within 55 days following the end of each quarter to Class A shareholders of record. Available cash is generally defined as all cash on hand at the date of determination of available cash for the distribution in respect to such quarter (including expected distributions from AAP in respect of such quarter), less reserves established by our general partner for future requirements.

The following table details the distributions paid to our Class A shareholders during the periods indicated (in millions, except per share data):


Year	Distributions to Class A Shareholders		Distributions per Class A Share
2020	$	166	$	0.90
2019	$	231	$	1.38
2018	$	189	$	1.20

On January 7, 2021, we declared a cash distribution of $0.18 per outstanding Class A share. This distribution of $35 million was paid on February 12, 2021 to shareholders of record at the close of business on January 29, 2021, for the period October 1, 2020 through December 31, 2020.

Other Comprehensive Income/(Loss)

Other comprehensive income/(loss) attributable to our Class A shareholders is comprised solely of their proportionate share of PAA’s other comprehensive income/(loss) based on our indirect ownership interest in PAA during the period.

Consolidated Subsidiaries

Noncontrolling Interests in Subsidiaries

As of December 31, 2020, noncontrolling interests in our subsidiaries consisted of (i) limited partner interests in PAA including a 69% interest in PAA’s common units and PAA’s Series A preferred units combined and 100% of PAA’s Series B preferred units, (ii) an approximate 21% limited partner interest in AAP and (iii) a 33% interest in Red River Pipeline Company LLC (“Red River LLC”), as discussed further below.

In May 2019, we formed a joint venture, Red River LLC, with Delek Logistics Partners, LP (“Delek”) on our Red River pipeline system. We received approximately $128 million for Delek’s 33% interest in Red River LLC. We consolidate Red River LLC, with Delek’s 33% interest accounted for as a noncontrolling interest.

Additionally, during the year ended December 31, 2020, we received $12 million of contributions from noncontrolling interests in Red River LLC related to the Red River pipeline capacity expansion.

Repurchases of Units by Subsidiary

Common Equity Repurchase Program. In November 2020, the board of directors of our general partner approved a $500 million common equity repurchase program (the “Program”) to be utilized as an additional method of returning capital to investors. The Program authorizes the repurchase from time to time of up to $500 million of PAA common units and/or our Class A shares via open market purchases or negotiated transactions conducted in accordance with applicable regulatory requirements. No time limit has been set for completion of the Program, and the Program may be suspended or discontinued at any time. The Program does not obligate PAA or us to acquire a particular number of PAA common units or Class A shares. Any PAA common units or Class A shares that are repurchased will be canceled. Class C shares held by PAA associated with any publicly held common units that are repurchased will also be canceled.

PAA repurchased 6,222,748 common units under the Program through open market purchases during the year ended December 31, 2020. The total purchase price of these repurchases was $50 million, including commissions and fees. The repurchased common units were canceled immediately upon acquisition, as were the Class C shares held by PAA associated with the repurchased common units. We did not repurchase any Class A shares under the Program during the year ended December 31, 2020. At December 31, 2020, the remaining available capacity under the program was $450 million.

PAA’s capital attributable to AAP was adjusted, in accordance with ASC 810, to reflect the accretion of its interest in PAA as a result of the repurchase of common units from public unitholders. Such adjustment is recognized by PAGP in proportion to its ownership interest in AAP, which results in a net increase in partners’ capital attributable to PAGP. See Note 15 for additional information regarding the associated impact to the deferred tax asset.

Subsidiary Distributions

PAA Preferred Unit Distributions. The following table details distributions paid to PAA’s preferred unitholders during the year presented (in millions, except unit data):


	Series A Preferred Unitholders			Series B Preferred Unitholders
	Distribution (1)			Cash Distribution
Year	Cash		Units
2020	$	149	—	$	49
2019	$	149	—	$	49
2018	$	112	1,393,926	$	49

(1)PAA elected to pay distributions on its Series A preferred units in additional Series A preferred units for each quarterly distribution from their issuance through the February 2018 distribution. Distributions on PAA’s Series A preferred units have been paid in cash since the May 2018 distribution. During 2018, PAA issued additional Series A preferred units in lieu of cash distributions of $37 million.

On February 12, 2021, PAA paid a cash distribution of $37 million to its Series A preferred unitholders. At December 31, 2020, such amount was accrued as distributions payable in “Other current liabilities” on our Consolidated Balance Sheet. At December 31, 2020, approximately $6 million of accrued distributions payable to PAA’s Series B preferred unitholders was included in “Other current liabilities” on our Consolidated Balance Sheet.

PAA Common Unit Distributions. PAA distributes 100% of its available cash within 45 days following the end of each quarter to common unitholders of record, including AAP. Available cash is generally defined as all of PAA’s cash and cash equivalents on hand at the end of each quarter, less reserves established in the reasonable discretion of its general partner for future requirements.

The following table details distributions paid by PAA during the year presented (in millions, except per unit data):


	Distributions Paid						Distributions per common unit
Year	Public		AAP		Total
2020	$	432	$	223	$	655	$	0.90
2019	$	632	$	372	$	1,004	$	1.38
2018	$	532	$	339	$	871	$	1.20

On January 7, 2021, PAA declared a cash distribution of $0.18 per unit on its outstanding common units. The total distribution of $130 million was paid on February 12, 2021 to unitholders of record at the close of business on January 29, 2021, for the period from October 1, 2020 through December 31, 2020. Of this amount, approximately $44 million was paid to AAP.

AAP Distributions. AAP distributes all of the cash received from PAA distributions on a quarterly basis, less reserves established in the discretion of its general partner for future requirements. Generally, distributions are paid to its partners in proportion to their percentage interest in AAP. The following table details the distributions to AAP’s partners paid during the periods indicated from distributions received from PAA (in millions):


	Distributions to AAP’s Partners
Year	Noncontrolling Interests		PAGP		Total Cash Distributions

2020	$	57	$	166	$	223
2019	$	141	$	231	$	372
2018	$	150	$	189	$	339

On February 12, 2021, AAP distributed $44 million to its partners from distributions received from PAA. Of this amount, $9 million was distributed to noncontrolling interests and $35 million was distributed to us.

Other Distributions. During the years ended December 31, 2020 and 2019, distributions of $10 million and $6 million, respectively, were paid to noncontrolling interests in Red River LLC.

Derivatives and Risk Management Activities

12 Months Ended

Dec. 31, 2020

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivatives and Risk Management Activities

We identify the risks that underlie our core business activities and use risk management strategies to mitigate those risks when we determine that there is value in doing so. We use various derivative instruments to optimize our profits while managing our exposure to (i) hydrocarbon commodity (referred to herein as “commodity”) price risk, (ii) interest rate risk and (iii) currency exchange rate risk. Our commodity price risk management policies and procedures are designed to help ensure that our hedging activities address our risks by monitoring our derivative positions, as well as physical volumes, grades, locations, delivery schedules and storage capacity. Our interest rate and currency exchange rate risk management policies and procedures are designed to monitor our derivative positions and ensure that those positions are consistent with our objectives and approved strategies. Our policy is to use derivative instruments for risk management purposes and not for the purpose of speculating on changes in commodity prices, interest rates or currency exchange rates. When we apply hedge accounting, our policy is to formally document all relationships between hedging instruments and hedged items, as well as our risk management objectives for undertaking the hedge. This process includes specific identification of the hedging instrument and the hedged transaction, the nature of the risk being hedged and how the hedging instrument’s effectiveness will be assessed. At the inception of the hedging relationship, we assess whether the derivatives employed are highly effective in offsetting changes in cash flows of anticipated hedged transactions. Throughout the hedging relationship, retrospective and prospective hedge effectiveness is assessed on a qualitative basis.

We record all open derivatives on the balance sheet as either assets or liabilities measured at fair value. Changes in the fair value of derivatives are recognized currently in earnings unless specific hedge accounting criteria are met. For derivatives designated as cash flow hedges, changes in fair value are deferred in AOCI and recognized in earnings in the periods during which the underlying hedged transactions are recognized in earnings. Derivatives that are not designated as a hedging instrument and derivatives that do not qualify for hedge accounting are recognized in earnings each period. Cash settlements associated with our derivative activities are classified within the same category as the related hedged item in our Condensed Consolidated Statements of Cash Flows.

Our financial derivatives, used for hedging risk, are governed through ISDA master agreements and clearing brokerage agreements. These agreements include stipulations regarding the right of set off in the event that we or our counterparty default on performance obligations. If a default were to occur, both parties have the right to net amounts payable and receivable into a single net settlement between parties.

At December 31, 2020 and 2019, none of our outstanding derivatives contained credit-risk related contingent features that would result in a material adverse impact to us upon any change in our credit ratings. Although we may be required to post margin on our exchange-traded derivatives transacted through a clearing brokerage account, as described below, we do not require our non-cleared derivative counterparties to post collateral with us.

Commodity Price Risk Hedging

Our core business activities involve certain commodity price-related risks that we manage in various ways, including through the use of derivative instruments. Our policy is to (i) only purchase inventory for which we have a sales market, (ii) structure our sales contracts so that price fluctuations do not materially affect our operating income and (iii) not acquire and hold physical inventory or derivatives for the purpose of speculating on commodity price changes. The material commodity-related risks inherent in our business activities can be divided into the following general categories:

Commodity Purchases and Sales — In the normal course of our operations, we purchase and sell commodities. We use derivatives to manage the associated risks and to optimize profits. As of December 31, 2020, net derivative positions related to these activities included:

•A net long position of 5.8 million barrels associated with our crude oil purchases, which was unwound ratably during January 2021 to match monthly average pricing.

•A net short time spread position of 6.6 million barrels, which hedges a portion of our anticipated crude oil lease gathering purchases through March 2022.

•A net crude oil basis spread position of 0.6 million barrels at multiple locations through December 2021. These derivatives allow us to lock in grade basis differentials.

•A net short position of 37.4 million barrels through December 2022 related to anticipated net sales of crude oil and NGL inventory.

Natural Gas Processing/NGL Fractionation — We purchase natural gas for processing and operational needs. Additionally, we purchase NGL mix for fractionation and sell the resulting individual specification products (including ethane, propane, butane and condensate). In conjunction with these activities, we hedge the price risk associated with the purchase of the natural gas and the subsequent sale of the individual specification products. The following table summarizes our open derivative positions utilized to hedge the price risk associated with anticipated purchases and sales related to our natural gas processing and NGL fractionation activities as of December 31, 2020.


	Notional Volume (Short)/Long	Remaining Tenor
Natural gas purchases	37.3 Bcf	December 2021
Propane sales	(6.3) MMbls	December 2021
Butane sales	(2.3) MMbls	December 2021
Condensate sales (WTI position)	(0.6) MMbls	December 2021

Fuel gas requirements (1)	14.3 Bcf	December 2022
Power supply requirements (1)	0.7 TWh	December 2022

(1)Positions to hedge a portion of our power supply and fuel gas requirements at our Canadian natural gas processing and fractionation plants.

Physical commodity contracts that meet the definition of a derivative but are ineligible, or not designated, for the normal purchases and normal sales scope exception are recorded on the balance sheet at fair value, with changes in fair value recognized in earnings. We have determined that substantially all of our physical commodity contracts qualify for the normal purchases and normal sales scope exception.

Our commodity derivatives are not designated as a hedging relationship, as such, changes in the fair value are reported in earnings. A summary of the impact of our commodity derivatives recognized in earnings as follows (in millions):


	Year Ended December 31,
	2020		2019		2018
Supply and Logistics segment revenues	$	(302)	$	310	$	150
Field operating costs	5		14		(2)
Net gain/(loss) from commodity derivative activity	$	(297)	$	324	$	148

Our accounting policy is to offset derivative assets and liabilities executed with the same counterparty when a master netting arrangement exists. Accordingly, we also offset derivative assets and liabilities with amounts associated with cash margin. Our exchange-traded derivatives are transacted through clearing brokerage accounts and are subject to margin requirements as established by the respective exchange. On a daily basis, our account equity (consisting of the sum of our cash balance and the fair value of our open derivatives) is compared to our initial margin requirement resulting in the payment or return of variation margin. The following table provides the components of our net broker receivable/(payable) (in millions):


	December 31,
	2020		2019
Initial margin	$	91	$	73
Variation margin posted/(returned)	290		(45)
Letters of credit	(63)		(73)
Net broker receivable/(payable)	$	318	$	(45)

The following table reflects the Consolidated Balance Sheet line items that include the fair values of our commodity derivative assets and liabilities and the effect of the collateral netting. Such amounts are presented on a gross basis, before the effects of counterparty netting. However, we have elected to present our commodity derivative assets and liabilities with the same counterparty on a net basis on our Consolidated Balance Sheet when the legal right of offset exists. Amounts in the table below are presented in millions.


	December 31, 2020								December 31, 2019
					Effect of Collateral Netting		Net Carrying Value Presented on the Balance Sheet						Effect of Collateral Netting		Net Carrying Value Presented on the Balance Sheet
	Commodity Derivatives								Commodity Derivatives
	Assets		Liabilities						Assets		Liabilities
Derivative Assets
Other current assets	$	71	$	(314)	$	318	$	75	$	179	$	(37)	$	(45)	$	97
Other long-term assets, net	5		—		—		5		24		—		—		24
Derivative Liabilities
Other current liabilities	9		(40)		—		(31)		32		(56)		—		(24)
Other long-term liabilities and deferred credits	—		(32)		—		(32)		—		(12)		—		(12)
Total	$	85	$	(386)	$	318	$	17	$	235	$	(105)	$	(45)	$	85

Interest Rate Risk Hedging

We use interest rate derivatives to hedge the benchmark interest rate associated with interest payments occurring as a result of debt issuances. The derivative instruments we use to manage this risk consist of forward starting interest rate swaps and treasury locks. These derivatives are designated as cash flow hedges. As such, changes in fair value are deferred in AOCI and are reclassified to interest expense as we incur the interest expense associated with the underlying debt.

The following table summarizes the terms of our outstanding interest rate derivatives as of December 31, 2020 (notional amounts in millions):

Hedged Transaction

Number and Types of

Derivatives Employed

Notional

Amount

Expected

Termination Date

Average Rate Locked

Accounting

Treatment

Anticipated interest payments

8 forward starting swaps

(30-year)

200

6/15/2023

1.38

Cash flow hedge

Anticipated interest payments

8 forward starting swaps

(30-year)

200

6/14/2024

0.73

Cash flow hedge

As of December 31, 2020, there was a net loss of $258 million deferred in AOCI. The deferred net loss recorded in AOCI is expected to be reclassified to future earnings contemporaneously with (i) the earnings recognition of the underlying hedged commodity transactions or (ii) interest expense accruals associated with underlying debt instruments. We reclassified losses of $11 million, $9 million and $5 million during years ended December 31, 2020, 2019 and 2018, respectively. Of the total net loss deferred in AOCI at December 31, 2020, we expect to reclassify a loss of $13 million to earnings in the next twelve months. We estimate that substantially all of the remaining deferred loss will be reclassified to earnings through 2054 as the underlying hedged transactions impact earnings. A portion of these amounts is based on market prices as of December 31, 2020; thus, actual amounts to be reclassified will differ and could vary materially as a result of changes in market conditions.

The following table summarizes the net unrealized gain/(loss) recognized in AOCI for derivatives (in millions):


	Year Ended December 31,
	2020		2019		2018
Interest rate derivatives, net	$	(10)	$	(91)	$	38

At December 31, 2020, the net fair value of our interest rate hedges, which were included in “Other long-term assets” on our Consolidated Balance Sheet, totaled $46 million. At December 31, 2019, the fair value of these hedges was $44 million and included in “Other current liabilities.”

Currency Exchange Rate Risk Hedging

Because a significant portion of our Canadian business is conducted in CAD we use foreign currency derivatives to minimize the risk of unfavorable changes in exchange rates. These instruments include foreign currency exchange contracts, forwards and options.

Our use of foreign currency derivatives include (i) derivatives we use to hedge currency exchange risk created by the use of USD-denominated commodity derivatives to hedge commodity price risk associated with CAD-denominated commodity purchases and sales and (ii) foreign currency exchange contracts we use to manage our Canadian business cash requirements.

The following table summarizes our open forward exchange contracts as of December 31, 2020 (in millions):


		USD		CAD		Average Exchange Rate USD to CAD
Forward exchange contracts that exchange CAD for USD:
	2021	$	46	$	59	$1.00 - $1.28

Forward exchange contracts that exchange USD for CAD:
	2021	$	80	$	104	$1.00 - $1.30

These derivatives are not designated as a hedging relationship. As such, changes in fair value are recognized in earnings as a component of Supply and Logistics segment revenues. For the years ended December 31, 2020, 2019 and 2018, the amounts recognized in earnings for our currency exchange rate hedges were a gain of less than $1 million, a gain of $8 million and a loss of $23 million, respectively.

At December 31, 2020, the net fair value of these currency exchange rate hedges, which is included in “Other current assets” on our Consolidated Balance Sheet, totaled $2 million. At December 31, 2019, the net fair value of these currency exchange rate hedges, which was included in “Other current assets” and “Other current liabilities” on our Condensed Consolidated Balance Sheet, totaled $2 million and $1 million, respectively.

Preferred Distribution Rate Reset Option

A derivative feature embedded in a contract that does not meet the definition of a derivative in its entirety must be bifurcated and accounted for separately if the economic characteristics and risks of the embedded derivative are not clearly and closely related to those of the host contract. The Preferred Distribution Rate Reset Option of the PAA Series A preferred units is an embedded derivative that must be bifurcated from the related host contract, the PAA partnership agreement, and recorded at fair value on our Consolidated Balance Sheets. This embedded derivative is not designated as a hedging relationship and corresponding changes in fair value are recognized in “Other income/(expense), net” in our Consolidated Statement of Operations. For the years ended December 31, 2020, 2019 and 2018 we recognized net gains of $20 million, $2 million and a net loss of $14 million, respectively. The fair value of the Preferred Distribution Rate Reset Option, which was included in “Other long-term liabilities and deferred credits” on our Consolidated Balance Sheets, totaled $14 million and $34 million at December 31, 2020 and 2019, respectively. See Note 12 for additional information regarding our Series A preferred units and the Preferred Distribution Rate Reset Option.

Recurring Fair Value Measurements

Derivative Financial Assets and Liabilities

The following table sets forth by level within the fair value hierarchy our financial assets and liabilities that were accounted for at fair value on a recurring basis (in millions):


	Fair Value as of December 31, 2020								Fair Value as of December 31, 2019
Recurring Fair Value Measures (1)	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Commodity derivatives	$	(143)	$	(143)	$	(15)	$	(301)	$	42	$	105	$	(17)	$	130
Interest rate derivatives	—		46		—		46		—		(44)		—		(44)
Foreign currency derivatives	—		2		—		2		—		1		—		1
Preferred Distribution Rate Reset Option	—		—		(14)		(14)		—		—		(34)		(34)
Total net derivative asset/(liability)	$	(143)	$	(95)	$	(29)	$	(267)	$	42	$	62	$	(51)	$	53

(1)Derivative assets and liabilities are presented above on a net basis but do not include related cash margin deposits.

Level 1

Level 1 of the fair value hierarchy includes exchange-traded commodity derivatives and over-the-counter commodity contracts such as futures and swaps. The fair value of exchange-traded commodity derivatives and over-the-counter commodity contracts is based on unadjusted quoted prices in active markets.

Level 2

Level 2 of the fair value hierarchy includes exchange-cleared commodity derivatives and over-the-counter commodity, interest rate and foreign currency derivatives that are traded in observable markets with less volume and transaction frequency than active markets. In addition, it includes certain physical commodity contracts. The fair values of these derivatives are corroborated with market observable inputs.

Level 3

Level 3 of the fair value hierarchy includes certain physical commodity and other contracts, over-the-counter options and the Preferred Distribution Rate Reset Option contained in our partnership agreement which is classified as an embedded derivative.

The fair values of our Level 3 physical commodity and other contracts and over-the-counter options are based on valuation models utilizing significant timing estimates, which involve management judgment, and pricing inputs from observable and unobservable markets with less volume and transaction frequency than active markets. Significant deviations from these estimates and inputs could result in a material change in fair value. We report unrealized gains and losses associated with these contracts in our Consolidated Statements of Operations as Supply and Logistics segment revenues.

Rollforward of Level 3 Net Asset/(Liability)

The following table provides a reconciliation of changes in fair value of the beginning and ending balances for our derivatives classified as Level 3 (in millions):


	Year Ended December 31,
	2020		2019
Beginning Balance	$	(51)	$	(24)
Net gains/(losses) for the period included in earnings	12		10
Settlements	10		(11)
Derivatives entered into during the period	—		(26)
Ending Balance	$	(29)	$	(51)

Change in unrealized gains/(losses) included in earnings relating to Level 3 derivatives still held at the end of the period	$	12	$	(16)

Leases

12 Months Ended

Dec. 31, 2020

Leases [Abstract]

Leases

Lessee

On January 1, 2019, we adopted ASC Topic 842, Leases (“Topic 842”), using the optional transitional method, thereby applying the new guidance at the effective date, without adjusting the comparative periods. Therefore, results for reporting periods beginning after January 1, 2019 are presented under Topic 842, while prior period amounts are not adjusted and continue to be reported in accordance with our historic accounting under ASC Topic 840, Leases (“Topic 840”). We evaluate all agreements entered into or modified after the date of adoption of Topic 842 that convey to us the use of property or equipment for a term to determine whether the agreement is or contains a lease. We lease certain property and equipment under noncancelable and cancelable operating and finance leases. Our operating leases primarily relate to railcars, office space, land, vehicles, and storage tanks, and our finance leases primarily relate to tractor trailers, land, storage tanks and vehicles. One of our finance leases is for storage tanks owned by an equity method investee, in which we own a 50% interest. For leases with an initial term of greater than 12 months, we recognize a right-of-use asset and lease liability on the balance sheet. Leases with an initial term of 12 months or less are not recorded on the balance sheet. Our lease agreements have remaining lease terms ranging from one year to approximately 60 years. When applicable, this range includes additional terms associated with leases for which we are reasonably certain to exercise the option to renew and such renewal options are recognized as part of our right-of-use assets and lease liabilities. We have renewal options for leases with terms ranging from one year to 25 years that are not recognized as part of our right-of-use assets or lease liabilities as we have determined we are not reasonably certain to exercise the option to renew.

Certain of our leases have variable lease payments, many of which are based on changes in market indices such as the Consumer Price Index. Our lease agreements for our tractor trailers contain residual value guarantees equal to the fair market value of the tractor trailers at the end of the lease term in the event that we elect not to purchase the asset for an amount equal to the fair value. Our lease agreements do not contain any material restrictive covenants.

For determining the present value of lease payments, we use the discount rate implicit in the lease when readily determinable; however, such rate is not readily determinable for most of our leases. For those leases for which the discount rate is not readily determinable, we utilize incremental borrowing rates that reflect collateralized borrowing with payments and terms that mirror our lease portfolio to discount the lease payments based on information available at the lease commencement date.

The following table presents components of lease cost, including both amounts recognized in income and amounts capitalized (in millions):


	Year Ended December 31,
Lease Cost	2020		2019
Operating lease cost	$	111	$	125
Short-term lease cost	31		35
Other (1) (2)	8		—
Total lease cost	$	150	$	160

(1)Includes finance lease costs, variable lease costs and sublease income.

(2)Includes approximately $6 million for the year ended December 31, 2020 associated with leased storage tanks owned by an equity method investee, in which we own a 50% interest.

Lease cost for the year ended December 31, 2018, accounted for in accordance with Topic 840, was $199 million.

The following table presents information related to cash flows arising from lease transactions (in millions):


	Year Ended December 31,
	2020		2019
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows for operating leases	$	108	$	116
Operating cash flows for finance leases	$	5	$	1
Financing cash flows for finance leases	$	19	$	18

Non-cash change in lease liabilities arising from obtaining new right-of-use assets or modifications:
Operating leases	$	5	$	77
Finance leases (1)	$	32	$	27

(1)Includes approximately $25 million and $12 million for the years ended December 31, 2020 and 2019, respectively, associated with leased storage tanks owned by an equity method investee, in which we own a 50% interest.

Information related to the weighted-average remaining lease term and discount rate is presented in the table below:


	December 31,
	2020		2019
Weighted-average remaining lease term (in years):
Operating leases	12		11
Finance leases	9		6

Weighted-average discount rate:
Operating leases	4.5	%	4.4	%
Finance leases	11.1	%	7.1	%

The following table presents the amount and location of our operating and finance lease right-of-use assets and liabilities on our Consolidated Balance Sheets (in millions):


		December 31,
Leases	Balance Sheet Location	2020		2019
Assets
Operating lease right-of-use assets	Long-term operating lease right-of-use assets, net	$	378	$	466

Finance lease right-of-use assets (1)	Property and equipment	$	141	$	124
	Accumulated depreciation	(27)		(16)
	Property and equipment, net	$	114	$	108

Total lease right-of-use assets		$	492	$	574

Liabilities
Operating lease liabilities
Current	Other current liabilities	$	78	$	94
Noncurrent	Long-term operating lease liabilities	317		387
Total operating lease liabilities		$	395	$	481

Finance lease liabilities (1)
Current	Short-term debt	$	11	$	18
Noncurrent	Other long-term debt, net	70		49
Total finance lease liabilities		$	81	$	67

Total lease liabilities		$	476	$	548

(1)Includes right-of-use assets of $35 million and $12 million and lease liabilities of $36 million and $12 million as of December 31, 2020 and 2019, respectively, associated with leased storage tanks owned by an equity method investee, in which we own a 50% interest.

The following table presents the maturity of undiscounted cash flows for future minimum lease payments under noncancelable leases as of December 31, 2020 reconciled to our lease liabilities on our Consolidated Balance Sheet (amounts in millions):


	Operating		Finance (2)
Future minimum lease payments (1):
2021	$	90	$	18
2022	82		18
2023	62		15
2024	49		14
2025	38		11
Thereafter	237		67
Total	558		143
Less: Present value discount	(163)		(62)
Lease liabilities	$	395	$	81

(1)Excludes future minimum payments for short-term and other immaterial leases not included on our Consolidated Balance Sheet.

(2)Includes payments of approximately $6 million for each of the years ending 2021 through 2025 and approximately $64 million thereafter associated with leased storage tanks owned by an equity method investee, in which we own a 50% interest.

Lessor

We evaluate all agreements entered into or modified after the date of adoption of Topic 842 that convey to others the use of property or equipment for a term to determine whether the agreement is or contains a lease. Significant judgment is required when determining whether a customer obtains the right to direct the use of identified property or equipment. The underlying assets associated with these agreements are evaluated for future use beyond the lease term.

Our Facilities and Transportation segments enter into agreements to conduct fee-based activities associated with (i) providing storage services primarily for crude oil, NGL and natural gas and (ii) transporting crude oil and NGL. Certain of these agreements convey counterparties the right to direct the operation of physically distinct assets. Such agreements include (i) fixed consideration, which is measured based on an available capacity during the period multiplied by the rate in the agreement, or (ii) a fixed monthly fee and variable consideration based on usage. These agreements often include options to extend or terminate the lease, with advance notice. These agreements are operating leases under Topic 842. For the years ended December 31, 2020 and 2019, our lease revenue was not material.

The table below presents the maturity of lease payments for operating lease agreements in effect as of December 31, 2020. This presentation includes minimum fixed lease payments and does not include an estimate of variable lease consideration. These agreements have remaining lease terms ranging from one year to 21 years. The following table presents the undiscounted cash flows expected to be received related to these agreements (in millions):


	2021		2022		2023		2024		2025		Thereafter
Lease revenue	$	40	$	27	$	22	$	18	$	16	$	205

Leases

Lessee

The following table presents components of lease cost, including both amounts recognized in income and amounts capitalized (in millions):


	Year Ended December 31,
Lease Cost	2020		2019
Operating lease cost	$	111	$	125
Short-term lease cost	31		35
Other (1) (2)	8		—
Total lease cost	$	150	$	160

(1)Includes finance lease costs, variable lease costs and sublease income.

(2)Includes approximately $6 million for the year ended December 31, 2020 associated with leased storage tanks owned by an equity method investee, in which we own a 50% interest.

Lease cost for the year ended December 31, 2018, accounted for in accordance with Topic 840, was $199 million.

The following table presents information related to cash flows arising from lease transactions (in millions):


	Year Ended December 31,
	2020		2019
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows for operating leases	$	108	$	116
Operating cash flows for finance leases	$	5	$	1
Financing cash flows for finance leases	$	19	$	18

Non-cash change in lease liabilities arising from obtaining new right-of-use assets or modifications:
Operating leases	$	5	$	77
Finance leases (1)	$	32	$	27

Information related to the weighted-average remaining lease term and discount rate is presented in the table below:


	December 31,
	2020		2019
Weighted-average remaining lease term (in years):
Operating leases	12		11
Finance leases	9		6

Weighted-average discount rate:
Operating leases	4.5	%	4.4	%
Finance leases	11.1	%	7.1	%

The following table presents the amount and location of our operating and finance lease right-of-use assets and liabilities on our Consolidated Balance Sheets (in millions):


		December 31,
Leases	Balance Sheet Location	2020		2019
Assets
Operating lease right-of-use assets	Long-term operating lease right-of-use assets, net	$	378	$	466

Finance lease right-of-use assets (1)	Property and equipment	$	141	$	124
	Accumulated depreciation	(27)		(16)
	Property and equipment, net	$	114	$	108

Total lease right-of-use assets		$	492	$	574

Liabilities
Operating lease liabilities
Current	Other current liabilities	$	78	$	94
Noncurrent	Long-term operating lease liabilities	317		387
Total operating lease liabilities		$	395	$	481

Finance lease liabilities (1)
Current	Short-term debt	$	11	$	18
Noncurrent	Other long-term debt, net	70		49
Total finance lease liabilities		$	81	$	67

Total lease liabilities		$	476	$	548


	Operating		Finance (2)
Future minimum lease payments (1):
2021	$	90	$	18
2022	82		18
2023	62		15
2024	49		14
2025	38		11
Thereafter	237		67
Total	558		143
Less: Present value discount	(163)		(62)
Lease liabilities	$	395	$	81

(1)Excludes future minimum payments for short-term and other immaterial leases not included on our Consolidated Balance Sheet.

Lessor


	2021		2022		2023		2024		2025		Thereafter
Lease revenue	$	40	$	27	$	22	$	18	$	16	$	205

Leases

Lessee

The following table presents components of lease cost, including both amounts recognized in income and amounts capitalized (in millions):


	Year Ended December 31,
Lease Cost	2020		2019
Operating lease cost	$	111	$	125
Short-term lease cost	31		35
Other (1) (2)	8		—
Total lease cost	$	150	$	160

(1)Includes finance lease costs, variable lease costs and sublease income.

(2)Includes approximately $6 million for the year ended December 31, 2020 associated with leased storage tanks owned by an equity method investee, in which we own a 50% interest.

Lease cost for the year ended December 31, 2018, accounted for in accordance with Topic 840, was $199 million.

The following table presents information related to cash flows arising from lease transactions (in millions):


	Year Ended December 31,
	2020		2019
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows for operating leases	$	108	$	116
Operating cash flows for finance leases	$	5	$	1
Financing cash flows for finance leases	$	19	$	18

Non-cash change in lease liabilities arising from obtaining new right-of-use assets or modifications:
Operating leases	$	5	$	77
Finance leases (1)	$	32	$	27

Information related to the weighted-average remaining lease term and discount rate is presented in the table below:


	December 31,
	2020		2019
Weighted-average remaining lease term (in years):
Operating leases	12		11
Finance leases	9		6

Weighted-average discount rate:
Operating leases	4.5	%	4.4	%
Finance leases	11.1	%	7.1	%

The following table presents the amount and location of our operating and finance lease right-of-use assets and liabilities on our Consolidated Balance Sheets (in millions):


		December 31,
Leases	Balance Sheet Location	2020		2019
Assets
Operating lease right-of-use assets	Long-term operating lease right-of-use assets, net	$	378	$	466

Finance lease right-of-use assets (1)	Property and equipment	$	141	$	124
	Accumulated depreciation	(27)		(16)
	Property and equipment, net	$	114	$	108

Total lease right-of-use assets		$	492	$	574

Liabilities
Operating lease liabilities
Current	Other current liabilities	$	78	$	94
Noncurrent	Long-term operating lease liabilities	317		387
Total operating lease liabilities		$	395	$	481

Finance lease liabilities (1)
Current	Short-term debt	$	11	$	18
Noncurrent	Other long-term debt, net	70		49
Total finance lease liabilities		$	81	$	67

Total lease liabilities		$	476	$	548


	Operating		Finance (2)
Future minimum lease payments (1):
2021	$	90	$	18
2022	82		18
2023	62		15
2024	49		14
2025	38		11
Thereafter	237		67
Total	558		143
Less: Present value discount	(163)		(62)
Lease liabilities	$	395	$	81

(1)Excludes future minimum payments for short-term and other immaterial leases not included on our Consolidated Balance Sheet.

Lessor


	2021		2022		2023		2024		2025		Thereafter
Lease revenue	$	40	$	27	$	22	$	18	$	16	$	205

Income Taxes

12 Months Ended

Dec. 31, 2020

Income Tax Disclosure [Abstract]

Income Taxes

Pursuant to FASB guidance related to accounting for uncertainty in income taxes, we may recognize the tax benefit from an uncertain tax position only if it is more likely than not that the tax position will be sustained upon examination by the taxing authorities, based on the technical merits of the tax position and also the past administrative practices and precedents of the taxing authority. As of December 31, 2020 and 2019, we had not recognized any material amounts in connection with uncertainty in income taxes.

U.S. Federal and State Taxes

Although we are organized as a limited partnership, we have elected to be treated as a corporation for U.S. federal income tax purposes and are therefore subject to both U.S. federal and state income taxes.

Canadian Federal and Provincial Taxes

All of our Canadian operations are conducted by entities that are treated as corporations for Canadian tax purposes (flow through for U.S. income tax purposes) and that are subject to Canadian federal and provincial taxes. Additionally, payments of interest and dividends from our Canadian entities to other Plains entities are subject to Canadian withholding tax that is treated as income tax expense.

Tax Components

Components of income tax expense are as follows (in millions):


	Year Ended December 31,
	2020		2019		2018
Current income tax expense:
State income tax	$	—	$	3	$	3
Canadian federal and provincial income tax	51		109		63
Total current income tax expense	$	51	$	112	$	66

Deferred income tax expense/(benefit):
Federal income tax	$	(149)	$	89	$	90
State income tax	1		21		14
Canadian federal and provincial income tax	(70)		(46)		132
Total deferred income tax expense/(benefit)	$	(218)	$	64	$	236
Total income tax expense/(benefit)	$	(167)	$	176	$	302

The difference between income tax expense based on the statutory federal income tax rate and our effective income tax expense is summarized as follows (in millions):


	Year Ended December 31,
	2020			2019			2018
Income/(loss) before tax	$	(2,607)		$	2,238		$	2,409
Net (income)/loss attributable to noncontrolling interests	1,872			(1,731)			(1,773)
Income taxes attributable to noncontrolling interests	19			(66)			(198)
	$	(716)		$	441		$	438
Federal statutory income tax rate	21		%	21		%	21		%
Income tax expense/(benefit) at statutory rate	$	(150)		$	93		$	92


Deferred tax rate adjustment	11			10			3
State income tax, net of federal benefit	(9)			7			9
Income taxes attributable to noncontrolling interests:
Canadian federal and provincial income tax	(19)			63			195

State income tax	—			3			3
Total income tax expense/(benefit)	$	(167)		$	176		$	302

The Canadian federal and provincial income tax for the year ended December 31, 2020 reflects the impact of permanent differences primarily related to an impairment of goodwill that was recognized during the year. A portion of the goodwill that was impaired had no basis for Canadian income tax purposes and thus was not a deductible expense in determining taxable income, resulting in a permanent difference for Canadian tax purposes. See Note 8 for additional information regarding this impairment.

During the second quarter of 2019, the Alberta government enacted legislation that reduces the Alberta provincial corporate income tax rate from 12% to 8% over the period from July 1, 2019 through January 1, 2022. As a result, during the second quarter of 2019, we recognized a reduction of our deferred income tax liability of approximately $60 million and a corresponding deferred tax benefit. In the fourth quarter of 2020, the Alberta government changed the timing of the rate reduction to decrease the corporate income tax rate to 8% starting July 1, 2020.

Deferred tax assets and liabilities are aggregated by the applicable tax paying entity and jurisdiction and result from the following (in millions):


	December 31,
	2020		2019
Deferred tax assets:
Investment in partnerships	$	917	$	874
Net operating losses	527		406
Derivative instruments	45		—
Lease liabilities	39		55
Other	16		16
Total deferred tax assets	1,544		1,351

Deferred tax liabilities:
Property and equipment in excess of tax values	(475)		(472)
Derivative instruments	—		(22)
Lease assets	(38)		(53)
Other	(3)		(5)
Total deferred tax liabilities	(516)		(552)
Net deferred tax assets	$	1,028	$	799

Balance sheet classification of deferred tax assets/(liabilities):
Deferred tax asset	$	1,444	$	1,280
Other long-term liabilities and deferred credits	(416)		(481)
	$	1,028	$	799

As a result of the exchange of the ownership interest in AAP in connection with our IPO and all subsequent exchanges, a deferred tax asset was created. These transfers of ownership were accounted for at the historical carrying basis for GAAP accounting purposes, but were recorded at the fair market value of the Class A shares at the time of exchange for U.S. federal income tax purposes. The resulting basis difference resulted in a deferred tax asset that was recorded as a component of partners’ capital as it results from transactions among shareholders. The deferred tax asset is amortized to deferred income tax expense as the associated basis step-up is realized on our tax returns. Also, in connection with the repurchase of common units by PAA and the associated adjustment to partners’ capital attributable to PAGP, a corresponding change to the deferred tax balance was recorded to partners’ capital. See Note 12 for additional information regarding exchanges and the repurchase of common units by PAA.

As of December 31, 2020, our federal, state, and foreign net operating loss carryforwards for income tax purposes were approximately $2,328 million, $690 million and $9 million, respectively. If not utilized, the state and foreign net operating losses will begin to expire in 2021 and 2034, respectively, and a portion of our federal net operating losses will begin to expire in 2033. Under the Tax Act, U.S. federal NOLs generated after 2017 will have an indefinite carryforward period but may only reduce up to 80% of taxable income in any given year. Our U.S. federal NOLs generated prior to 2018 will not be subject to the taxable income limitation and will remain subject to a 20 year carryforward period.

Generally, tax returns for our Canadian entities are open to audit from 2016 through 2020. Our U.S. and state tax years are generally open to examination from 2017 to 2020.

As of December 31, 2020, in reference to tax years 2008 to 2015, we had received notices of reassessment (“notices”) from the Canada Revenue Agency and the Alberta Tax and Revenue Administration (the “Canadian Tax Authorities”) related primarily to transfer pricing associated with cross-border intercompany financing transactions. These notices include assessments, including penalties and interest, associated with these transfer pricing matters totaling approximately $91 million (based on the exchange rate as of December 31, 2020). Payment of a portion of the assessment is required in order to file a notice of objection to dispute the reassessment. Accordingly, we have remitted approximately $64 million (based on the exchange rate as of December 31, 2020) related to the assessments, which is included in “Other long-term assets, net,” on our Consolidated Balance Sheets. We disagree with these notices and have contested the reassessments. We intend to vigorously defend our position, and we plan to pursue all remedies available to us to successfully resolve these matters, including administrative remedies with the Canadian Tax Authorities, and judicial remedies, if necessary. As of December 31, 2020, we believe that our tax position associated with these matters is “more likely than not” to be sustained and have not recognized any amounts for uncertainty in income taxes related to these notices.

- Definition

The entire disclosure for income taxes. Disclosures may include net deferred tax liability or asset recognized in an enterprise's statement of financial position, net change during the year in the total valuation allowance, approximate tax effect of each type of temporary difference and carryforward that gives rise to a significant portion of deferred tax liabilities and deferred tax assets, utilization of a tax carryback, and tax uncertainties information.

+ References + Details

Major Customers and Concentration of Credit Risk	12 Months Ended
Major Customers and Concentration of Credit Risk	Dec. 31, 2020
Risks and Uncertainties [Abstract]
Major Customers and Concentration of Credit Risk	Major Customers and Concentration of Credit Risk Marathon Petroleum Corporation and its subsidiaries accounted for 13%, 12% and 14% of our revenues for the years ended December 31, 2020, 2019 and 2018, respectively. ExxonMobil Corporation and its subsidiaries accounted for 12%, 12% and 14% of our revenues for the years ended December 31, 2020, 2019 and 2018, respectively. Phillips 66 Company and its subsidiaries accounted for 11% of our revenues for the year ended December 31, 2019. No other customers accounted for 10% or more of our revenues during any of the three years ended December 31, 2020. The majority of revenues from these customers pertain to our supply and logistics operations. The sales to these customers occur at multiple locations and we believe that the loss of these customers would have only a short-term impact on our operating results. There is risk, however, that we would not be able to identify and access a replacement market at comparable margins. Financial instruments that potentially subject us to concentrations of credit risk consist principally of trade receivables. Our accounts receivable are primarily from purchasers and shippers of crude oil and, to a lesser extent, purchasers of NGL. This industry concentration has the potential to impact our overall exposure to credit risk in that the customers may be similarly affected by changes in economic, industry or other conditions. We review credit exposure and financial information of our counterparties and generally require letters of credit for receivables from customers that are not considered creditworthy, unless the credit risk can otherwise be reduced. See Note 3 for additional discussion of our accounts receivable and our review of credit exposure.

Related Party Transactions

12 Months Ended

Dec. 31, 2020

Related Party Transactions

PAA’s Ownership of our Class C Shares

As of December 31, 2020 and 2019, PAA owned 547,717,762 and 549,538,139, respectively, Class C shares. See Note 12 for additional information regarding our Class C shares.

Omnibus Agreement

The Plains Entities entered into an Omnibus Agreement on November 15, 2016, which, among other things, provides for the following:

•our ability to issue additional Class A shares and use the net proceeds therefrom to purchase a like number of AAP units from AAP, and the corresponding ability of AAP to use the net proceeds therefrom to purchase a like number of PAA common units; and

•our ability to lend proceeds of any future indebtedness incurred by us to AAP, and AAP’s corresponding ability to lend such proceeds to PAA, in each case on substantially the same terms as incurred by us.

Transactions with Other Related Parties

Our other related parties include (i) principal owners and their affiliated entities and (ii) entities in which we hold investments and account for under the equity method of accounting (see Note 9 for information regarding such entities). We recognize as our principal owners entities that have a designated representative on the board of directors of PAGP GP and/or own greater than 10% of the limited partner interests in AAP. Such limited partner interests in AAP translates into a significantly smaller indirect ownership interest in PAA. We also consider subsidiaries or funds identified as affiliated with principal owners to be related parties.

As of December 31, 2020, Kayne Anderson Capital Advisors, L.P. was a principal owner. Through various transactions by an affiliate of EMG in May 2019, EMG’s limited partner interest in AAP was significantly reduced, which caused EMG to lose its right to designate a representative on the board of directors of PAGP GP. As a result, EMG’s board designee, John T. Raymond, was automatically removed from the PAGP GP board. Subsequent to such removal, Mr. Raymond was elected to continue to serve as a director of the PAGP GP board. Additionally, as a result of various transactions by Oxy in September 2019, Oxy no longer holds a limited partner interest in AAP and lost its right to designate a representative on the board of directors of PAGP GP. As a result, Oxy’s board designee, Oscar Brown, was automatically removed from the PAGP GP board. Following these transactions, we no longer recognize EMG or Oxy as a principal owner.

During the three years ended December 31, 2020, we recognized sales and transportation revenues, purchased petroleum products and utilized transportation and storage services from our principal owners and their affiliated entities and our equity method investees. These transactions were conducted at posted tariff rates or prices that we believe approximate market. Included in these transactions was a crude oil buy/sell agreement that includes a multi-year minimum volume commitment.

The impact to our Consolidated Statements of Operations from these transactions is included below (in millions):


	Year Ended December 31,
	2020		2019		2018



Revenues from related parties (1)	$	46	$	692	$	1,067




Purchases and related costs from related parties (1)	$	451	$	223	$	410

(1)Crude oil purchases that are part of inventory exchanges under buy/sell transactions are netted with the related sales, with any margin presented in “Purchases and related costs” in our Consolidated Statements of Operations.

Our receivable and payable amounts with these related parties as reflected on our Consolidated Balance Sheets were as follows (in millions):


	December 31,
	2020		2019



Trade accounts receivable and other receivables, net from related parties (1)	$	34	$	134




Trade accounts payable to related parties (1) (2)	$	88	$	102

(1)Includes amounts related to crude oil purchases and sales, transportation and storage services and amounts owed to us or advanced to us related to investment capital projects of equity method investees where we serve as construction manager.

(2)We have agreements to store at facilities and transport crude oil on pipelines that are owned by equity method investees, in which we own a 50% interest. A portion of our commitment to transport is supported by crude oil buy/sell or other agreements with third parties with commensurate quantities.

Equity-Indexed Compensation Plans

12 Months Ended

Dec. 31, 2020

Share-based Payment Arrangement [Abstract]

Equity-Indexed Compensation Plans

Our equity-indexed compensation plans primarily include PAGP and PAA LTIPs. Our LTIP awards include both liability-classified and equity-classified awards. In accordance with FASB guidance regarding share-based payments, the fair value of liability-classified LTIP awards is calculated based on the closing market price of the underlying PAGP share or PAA unit at each balance sheet date and adjusted for the present value of any distributions that are estimated to occur on the underlying shares or units over the vesting period that will not be received by the award recipients. The fair value for equity-classified awards is calculated in a similar manner on the respective grant dates. These fair values are recognized as compensation expense over the service period. We have elected to recognize forfeitures of awards when they occur.

Our LTIP awards contain (i) time-based vesting criteria, (ii) performance conditions, (iii) market conditions or (iv) a combination of time-based vesting criteria and performance conditions. For awards with performance conditions, expense is accrued over the service period only if the performance condition is considered probable of occurring. When awards with performance conditions that were previously considered improbable become probable, we incur additional expense in the period that the probability assessment changes. This is necessary to bring the accrued obligation associated with these awards up to the level it would be if we had been accruing for these awards since the grant date. For awards with market conditions, the probable outcomes are determined on the respective dates that the fair values are calculated, and the resulting expense is accrued over the service period.

The following is a summary of the awards authorized under our LTIPs as of December 31, 2020 (in millions):


LTIP						LTIP Awards Authorized
Plains GP Holdings, L.P. Long-Term Incentive Plan						3.8
Plains All American 2013 Long-Term Incentive Plan						13.1
Plains All American PNG Successor Long-Term Incentive Plan						1.3
Plains All American GP LLC 2006 Long-Term Incentive Tracking Unit Plan						10.8
Total (1)						29.0

(1)Of the 29.0 million total awards authorized, 5.6 million awards are currently available. The remaining balance has already vested or is currently outstanding.

Although other types of awards are contemplated under certain of the LTIPs, currently outstanding awards are limited to “phantom units,” which mature into the right to receive our Class A shares or common units of PAA (or cash equivalent) upon vesting, and “tracking units,” which, upon vesting, represent the right to receive a cash payment in an amount based upon the market value of a PAA common unit at the time of vesting. Some awards also include DERs, which, subject to applicable vesting criteria, entitle the grantee to a cash payment equal to the cash distribution paid on an outstanding Class A share or PAA common unit. The DERs terminate with the vesting or forfeiture of the underlying LTIP award.

As of December 31, 2020, 9.6 million PAA LTIP awards and 0.2 million PAGP LTIP awards were outstanding. Of this amount, 6.9 million PAA LTIP awards and 0.2 million PAGP LTIP awards include DERs. At December 31, 2020, certain of the outstanding LTIP awards were considered probable of vesting and such awards are expected to vest at various dates between January 2021 and August 2026.

Commitments and Contingencies

12 Months Ended

Dec. 31, 2020

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments

We have commitments, some of which are leases, related to real property, equipment and operating facilities. We also incur costs associated with leased land, rights-of-way, permits and regulatory fees. Future noncancelable commitments related to these items at December 31, 2020 are summarized below (in millions):


	2021		2022		2023		2024		2025		Thereafter		Total
Leases (1)	$	108	$	100	$	77	$	63	$	49	$	304	$	701
Other commitments (2)	312		303		285		278		252		763		2,193
Total	$	420	$	403	$	362	$	341	$	301	$	1,067	$	2,894

(1)Includes both operating and finance leases as defined by FASB guidance. Leases are primarily for (i) railcars, (ii) office space, (iii) land, (iv) vehicles, (v) storage tanks and (vi) tractor trailers. See Note 14 for additional information.

(2)Primarily includes storage, transportation and pipeline throughput agreements, as well as certain rights-of-way easements. Expense associated with our storage, transportation and pipeline throughput agreements was approximately $265 million, $236 million and $228 million for 2020, 2019 and 2018, respectively. A majority of the storage, transportation and pipeline throughput commitments are associated with agreements to store crude oil at facilities and transport crude oil on pipelines owned by equity method investees, in which we own a 50% interest, at posted tariff rates or prices that we believe approximate market. A portion of our commitment to transport is supported by crude oil buy/sell or other agreements with third parties with commensurate quantities.

Loss Contingencies — General

To the extent we are able to assess the likelihood of a negative outcome for a contingency, our assessments of such likelihood range from remote to probable. If we determine that a negative outcome is probable and the amount of loss is reasonably estimable, we accrue an undiscounted liability equal to the estimated amount. If a range of probable loss amounts can be reasonably estimated and no amount within the range is a better estimate than any other amount, then we accrue an undiscounted liability equal to the minimum amount in the range. In addition, we estimate legal fees that we expect to incur associated with loss contingencies and accrue those costs when they are material and probable of being incurred.

We do not record a contingent liability when the likelihood of loss is probable but the amount cannot be reasonably estimated or when the likelihood of loss is believed to be only reasonably possible or remote. For contingencies where an unfavorable outcome is reasonably possible and the impact would be material to our consolidated financial statements, we disclose the nature of the contingency and, where feasible, an estimate of the possible loss or range of loss.

Legal Proceedings — General

In the ordinary course of business, we are involved in various legal proceedings, including those arising from regulatory and environmental matters. In connection with determining the probability of loss associated with such legal proceedings and whether any potential losses associated therewith are estimable, we take into account what we believe to be all relevant known facts and circumstances, and what we believe to be reasonable assumptions regarding the application of those facts and circumstances to existing agreements, laws and regulations. Although we are insured against various risks to the extent we believe it is prudent, there is no assurance that the nature and amount of such insurance will be adequate, in every case, to fully protect us from losses arising from current or future legal proceedings.

Accordingly, we can provide no assurance that the outcome of the various legal proceedings that we are currently involved in, or will become involved with in the future, will not, individually or in the aggregate, have a material adverse effect on our consolidated financial condition, results of operations or cash flows.

Environmental — General

Although we have made significant investments in our maintenance and integrity programs, we have experienced (and likely will experience future) releases of hydrocarbon products into the environment from our pipeline, rail, storage and other facility operations. These releases can result from accidents or from unpredictable man-made or natural forces and may reach surface water bodies, groundwater aquifers or other sensitive environments. Damages and liabilities associated with any such releases from our existing or future assets could be significant and could have a material adverse effect on our consolidated financial condition, results of operations or cash flows.

We record environmental liabilities when environmental assessments and/or remedial efforts are probable and the amounts can be reasonably estimated. Generally, our recording of these accruals coincides with our completion of a feasibility study or our commitment to a formal plan of action. We do not discount our environmental remediation liabilities to present value. We also record environmental liabilities assumed in business combinations based on the estimated fair value of the environmental obligations caused by past operations of the acquired company. We record receivables for amounts we believe are recoverable from insurance or from third parties under indemnification agreements in the period that we determine the costs are probable of recovery.

Environmental expenditures that pertain to current operations or to future revenues are expensed or capitalized consistent with our capitalization policy for property and equipment. Expenditures that result from the remediation of an existing condition caused by past operations and that do not contribute to current or future profitability are expensed.

At December 31, 2020, our estimated undiscounted reserve for environmental liabilities (including liabilities related to the Line 901 incident, as discussed further below) totaled $141 million, of which $94 million was classified as short-term and $47 million was classified as long-term. At December 31, 2019, our estimated undiscounted reserve for environmental liabilities (including liabilities related to the Line 901 incident) totaled $140 million, of which $60 million was classified as short-term and $80 million was classified as long-term. Such short-term liabilities are reflected in “Trade accounts payable” and “Other current liabilities” and long-term liabilities are reflected in “Other long-term liabilities and deferred credits” on our Consolidated Balance Sheets. At December 31, 2020, we had recorded receivables totaling $97 million for amounts probable of recovery under insurance and from third parties under indemnification agreements, of which $96 million was classified as short-term and $1 million was classified as long-term. At December 31, 2019, we had recorded $72 million of such receivables, of which $35 million was classified as short-term and $37 million was classified as long-term. Such short- and long-term receivables are reflected in “Trade accounts receivable and other receivables, net” and “Other long-term assets, net,” respectively, on our Consolidated Balance Sheets.

In some cases, the actual cash expenditures associated with these liabilities may not occur for three years or longer. Our estimates used in determining these reserves are based on information currently available to us and our assessment of the ultimate outcome. Among the many uncertainties that impact our estimates are the necessary regulatory approvals for, and potential modification of, our remediation plans, the limited amount of data available upon initial assessment of the impact of soil or water contamination, changes in costs associated with environmental remediation services and equipment and the possibility of existing or future legal claims giving rise to additional liabilities. Therefore, although we believe that the reserve is adequate, actual costs incurred (which may ultimately include costs for contingencies that are currently not reasonably estimable or costs for contingencies where the likelihood of loss is currently believed to be only reasonably possible or remote) may be in excess of the reserve and may potentially have a material adverse effect on our consolidated financial condition, results of operations or cash flows.

Specific Legal, Environmental or Regulatory Matters

Line 901 Incident. In May 2015, we experienced a crude oil release from our Las Flores to Gaviota Pipeline (Line 901) in Santa Barbara County, California. A portion of the released crude oil reached the Pacific Ocean at Refugio State Beach through a drainage culvert. Following the release, we shut down the pipeline and initiated our emergency response plan. A Unified Command, which included the United States Coast Guard, the EPA, the State of California Department of Fish and Wildlife (“CDFW”), the California Office of Spill Prevention and Response and the Santa Barbara Office of Emergency Management, was established for the response effort. Clean-up and remediation operations with respect to impacted shoreline and other areas has been determined by the Unified Command to be complete, and the Unified Command has been dissolved. Our estimate of the amount of oil spilled, based on relevant facts, data and information, and as set forth in the Consent Decree described below, is approximately 2,934 barrels; of this amount, we estimate that 598 barrels reached the Pacific Ocean.

As a result of the Line 901 incident, several governmental agencies and regulators initiated investigations into the Line 901 incident, various claims have been made against us and a number of lawsuits have been filed against us, the majority of which have been resolved. Set forth below is a brief summary of actions and matters that are currently pending or recently resolved:

As the “responsible party” for the Line 901 incident we are liable for various costs and for certain natural resource damages under the Oil Pollution Act. In this regard, following the Line 901 incident, we entered into a cooperative Natural Resource Damage Assessment (“NRDA”) process with the federal and state agencies designated or authorized by law to act as trustees for the natural resources of the United States and the State of California (collectively, the “Trustees”). Additionally, various government agencies sought to collect civil fines and penalties under applicable state and federal regulations. On March 13, 2020, the United States and the People of the State of California filed a civil complaint against Plains All American Pipeline, L.P. and Plains Pipeline L.P. along with a pre-negotiated settlement agreement in the form of a Consent Decree (the “Consent Decree”) that was signed by the United States Department of Justice, Environmental and Natural Resources Division, the United States Department of Transportation, Pipeline and Hazardous Materials Safety Administration, the EPA, CDFW, the California Department of Parks and Recreation, the California State Lands Commission, the California Department of Forestry and Fire Protection’s Office of the State Fire Marshal, Central Coast Regional Water Quality Control Board, and Regents of the University of California. The Consent Decree was approved and entered by the Federal District Court for the Central District of California on October 14, 2020. Pursuant to the terms of the Consent Decree, Plains paid $24 million in civil penalties and $22.325 million as compensation for injuries to, destruction of, loss of, or loss of use of natural resources resulting from the Line 901 incident. The Consent Decree also contains requirements for implementing certain agreed-upon injunctive relief, as well as requirements for potentially restarting Line 901 and the Sisquoc to Pentland portion of Line 903. The Consent Decree resolved all claims asserted by the regulatory agencies.

Following an investigation and grand jury proceedings, in May of 2016, PAA was charged by a California state grand jury, pursuant to an indictment filed in California Superior Court, Santa Barbara County (the “May 2016 Indictment”), with alleged violations of California law in connection with the Line 901 incident. Fifteen charges from the May 2016 Indictment were the subject of a jury trial in California Superior Court in Santa Barbara County, and the jury returned a verdict on September 7, 2018, pursuant to which we were (i) found guilty on one felony discharge count and eight misdemeanor counts (which included one reporting count, one strict liability discharge count and six strict liability animal takings counts) and (ii) found not guilty on one strict liability animal takings count. The remaining counts were subsequently dismissed by the Court. On April 25, 2019, PAA was sentenced to pay fines and penalties in the aggregate amount of just under $3.35 million for the convictions covered by the September 2018 jury verdict (the “2019 Sentence”). The fines and penalties imposed in connection with the 2019 Sentence have been paid. The only pending matter relating to these proceedings is that the Superior Court indicated that it would conduct further hearings on the issue of whether there were any “direct victims” of the spill that are entitled to restitution under applicable law.

Shortly following the Line 901 incident, we established a claims line and encouraged any parties that were damaged by the release to contact us to discuss their damage claims. We received a number of claims through the claims line and we have processed those claims and made payments as appropriate. Nine class action lawsuits were filed against us; however, after various claims were either dismissed or consolidated, two proceedings remain pending in the United States District Court for the Central District of California. In the first proceeding, the plaintiffs claim two different classes of claimants were damaged by the release: (i) commercial fishermen who landed fish in certain specified fishing blocks in the waters off the coast of Southern California or persons or businesses who resold commercial seafood caught in those areas; and (ii) owners and lessees of residential beachfront properties, or properties with a private easement to a beach, where plaintiffs claim oil from the spill washed up. We are vigorously defending against those claims. A September 2020 trial date initially set by the Court has been postponed indefinitely due to COVID-19 related trial suspensions. In the second proceeding, the plaintiffs seek a declaratory judgment that Plains’ right-of-way agreements would not allow Plains to lay a new pipeline to replace Line 901 and/or the non-operating segment of Line 903 without paying additional compensation. No trial date has been set in that action.

In addition, four unitholder derivative lawsuits were filed by certain purported investors in PAA against PAGP and certain of PAA’s affiliates, officers and directors. After various claims were either dismissed or consolidated, one proceeding against PAGP remains pending in Delaware Chancery Court. Generally, the plaintiffs claim that PAGP failed to exercise proper oversight over PAA’s pipeline integrity efforts. We will vigorously defend the claim. No trial date has been set in this action.

We have also received several other individual lawsuits and claims from companies, governmental agencies and individuals alleging damages arising out of the Line 901 incident. These lawsuits and claims generally seek restitution, compensatory and punitive damages, and/or injunctive relief. The majority of these lawsuits have been settled or dismissed by the court. Remaining claims include claims for lost revenue or profit asserted by a former oil producer that declared bankruptcy and shut in its offshore production platform following the Line 901 incident, a state agency that received royalties on oil produced from that platform until it was abandoned by its owner, and various companies and individuals who provided labor, goods, or services associated with oil production activities they claim were disrupted following the Line 901 incident. The courts have not finally resolved whether those claims are legally viable; however, if necessary, we will mount vigorous defenses to them. We may be subject to additional claims and lawsuits, which could materially impact the liabilities and costs we currently expect to incur as a result of the Line 901 incident.

Taking the foregoing into account, as of December 31, 2020, we estimate that the aggregate total costs we have incurred or will incur with respect to the Line 901 incident will be approximately $460 million, which estimate includes actual and projected emergency response and clean-up costs, natural resource damage assessments, fines and penalties payable pursuant to the Consent Decree and certain third-party claims settlements, as well as estimates for certain legal fees. We accrue such estimates of aggregate total costs to “Field operating costs” in our Consolidated Statements of Operations. This estimate considers our prior experience in environmental investigation and remediation matters and available data from, and in consultation with, our environmental and other specialists, as well as currently available facts and presently enacted laws and regulations. We have made assumptions for (i) the resolution of certain third-party claims and lawsuits, but excluding claims and lawsuits with respect to which losses are not probable and reasonably estimable, and excluding future claims and lawsuits and (ii) the nature, extent and cost of legal services that will be required in connection with all lawsuits, claims and other matters requiring legal or expert advice associated with the Line 901 incident. Our estimate does not include any lost revenue associated with the shutdown of Line 901 or 903 and does not include any liabilities or costs that are not reasonably estimable at this time or that relate to contingencies where we currently regard the likelihood of loss as being only reasonably possible or remote. We believe we have accrued adequate amounts for all probable and reasonably estimable costs; however, this estimate is subject to uncertainties associated with the assumptions that we have made. For example, the amount of time it takes for us to resolve all of the current and future lawsuits and claims that relate to the Line 901 incident could turn out to be significantly longer than we have assumed, and as a result the costs we incur for legal services could be significantly higher than we have estimated. Accordingly, our assumptions and estimates may turn out to be inaccurate and our total costs could turn out to be materially higher; therefore, we can provide no assurance that we will not have to accrue significant additional costs in the future with respect to the Line 901 incident.

As of December 31, 2020, we had a remaining undiscounted gross liability of $86 million related to this event, which is reflected in “Trade accounts payable” and “Other current liabilities” on our Consolidated Balance Sheet. We maintain insurance coverage, which is subject to certain exclusions and deductibles, in the event of such environmental liabilities. Subject to such exclusions and deductibles, we believe that our coverage is adequate to cover the current estimated total emergency response and clean-up costs, claims settlement costs and remediation costs and we believe that this coverage is also adequate to cover any potential increase in the estimates for these costs that exceed the amounts currently identified. Through December 31, 2020, we had collected, subject to customary reservations, $245 million out of the approximate $335 million of release costs that we believe are probable of recovery from insurance carriers, net of deductibles. Therefore, as of December 31, 2020, we have recognized a receivable of approximately $90 million for the portion of the release costs that we believe is probable of recovery from insurance, net of deductibles and amounts already collected. Such amount is recognized as a current asset in “Trade accounts receivable and other receivables, net” on our Consolidated Balance Sheet. We have completed the required clean-up and remediation work as determined by the Unified Command and the Unified Command has been dissolved; however, we expect to make payments for additional costs associated with restoration of the impacted areas, as well as legal, professional and regulatory costs during future periods.

Environmental Remediation

We currently own or lease, and in the past have owned and leased, properties where hazardous liquids, including hydrocarbons, are or have been handled. These properties and the hazardous liquids or associated wastes disposed thereon may be subject to the U.S. federal Comprehensive Environmental Response, Compensation and Liability Act, as amended, and the U.S. federal Resource Conservation and Recovery Act, as amended, as well as state and Canadian federal and provincial laws and regulations. Under such laws and regulations, we could be required to remove or remediate hazardous liquids or associated wastes (including wastes disposed of or released by prior owners or operators) and to clean up contaminated property (including contaminated groundwater).

We maintain insurance of various types with varying levels of coverage that we consider adequate under the circumstances to cover our operations and properties. The insurance policies are subject to deductibles and retention levels that we consider reasonable and not excessive. Consistent with insurance coverage generally available in the industry, in certain circumstances our insurance policies provide limited coverage for losses or liabilities relating to gradual pollution, with broader coverage for sudden and accidental occurrences.

Assets we have acquired or will acquire in the future may have environmental remediation liabilities for which we are not indemnified. We have in the past experienced and in the future likely will experience releases of hydrocarbon products into the environment from our pipeline, rail, storage and other facility operations. We also may discover environmental impacts from past releases that were previously unidentified.

Insurance

Pipelines, terminals, trucks or other facilities or equipment may experience damage as a result of an accident, natural disaster, terrorist attack, cyber event or other event. These hazards can cause personal injury and loss of life, severe damage to and destruction of property and equipment, pollution or environmental damage and suspension of operations. We maintain various types and varying levels of insurance coverage to cover our operations and properties, and we self-insure certain risks, including gradual pollution, cybersecurity and named windstorms. However, such insurance does not cover every potential risk that might occur, associated with operating pipelines, terminals and other facilities and equipment, including the potential loss of significant revenues and cash flows.

The occurrence of a significant event not fully insured, indemnified or reserved against, or the failure of a party to meet its indemnification obligations, could materially and adversely affect our operations and financial condition. We believe that we maintain adequate insurance coverage, although insurance will not cover many types of interruptions that might occur, will not cover amounts up to applicable deductibles and will not cover all risks associated with certain of our assets and operations. With respect to our insurance coverage, our policies are subject to deductibles and retention levels that we consider reasonable and not excessive. Additionally, no assurance can be given that we will be able to maintain adequate insurance in the future at rates we consider reasonable. As a result, we may elect to self-insure or utilize higher deductibles in certain other insurance programs. In addition, although we believe that we have established adequate reserves and liquidity to the extent such risks are not insured, costs incurred in excess of these reserves may be higher or we may not receive insurance proceeds in a timely manner, which may potentially have a material adverse effect on our financial conditions, results of operations or cash flows.

Quarterly Financial Data (Unaudited)

12 Months Ended

Dec. 31, 2020

Quarterly Financial Information Disclosure [Abstract]

Quarterly Financial Data (Unaudited)


	First Quarter		Second Quarter		Third Quarter		Fourth Quarter		Total (1)

	(in millions, except per share data)
2020
Total revenues	$	8,269	$	3,225	$	5,833	$	5,963	$	23,290
Gross margin (2)	$	(190)	$	282	$	313	$	4	$	408
Operating income/(loss)	$	(2,775)	$	208	$	251	$	(67)	$	(2,383)
Net income/(loss)	$	(2,692)	$	137	$	139	$	(23)	$	(2,440)
Net income/(loss) attributable to PAGP	$	(581)	$	16	$	17	$	(20)	$	(568)
Basic net income/(loss) per Class A share	$	(3.18)	$	0.09	$	0.09	$	(0.11)	$	(3.06)
Diluted net income/(loss) per Class A share	$	(3.18)	$	0.09	$	0.09	$	(0.11)	$	(3.07)
Cash distributions per Class A share (3)	$	0.36	$	0.18	$	0.18	$	0.18	$	0.90
			0
2019
Total revenues	$	8,375	$	8,253	$	7,886	$	9,154	$	33,669
Gross margin (2)	$	790	$	525	$	565	$	402	$	2,282
Operating income	$	713	$	449	$	490	$	329	$	1,980
Net income	$	914	$	426	$	431	$	291	$	2,062
Net income attributable to PAGP	$	147	$	66	$	70	$	48	$	331
Basic net income per Class A share	$	0.92	$	0.41	$	0.41	$	0.26	$	1.97
Diluted net income per Class A share	$	0.92	$	0.40	$	0.41	$	0.26	$	1.96
Cash distributions per Class A share (3)	$	0.30	$	0.36	$	0.36	$	0.36	$	1.38

(1)The sum of the four quarters may not equal the total year due to rounding.

(2)Gross margin is calculated as Total revenues less (i) Purchases and related costs, (ii) Field operating costs, (iii) Depreciation and amortization and (iv) (Gains)/losses on asset sales and asset impairments, net.

(3)Represents cash distributions declared and paid in the period presented.

Operating Segments

12 Months Ended

Dec. 31, 2020

Segment Reporting [Abstract]

Operating Segments

We manage our operations through three operating segments: Transportation, Facilities and Supply and Logistics. See Note 3 for a summary of the types of products and services from which each segment derives its revenues. Our Chief Operating Decision Maker (“CODM”) (our Chief Executive Officer) evaluates segment performance based on measures including Segment Adjusted EBITDA (as defined below) and maintenance capital investment.

The measure of Segment Adjusted EBITDA forms the basis of our internal financial reporting and is the primary performance measure used by our CODM in assessing performance and allocating resources among our operating segments. We define Segment Adjusted EBITDA as revenues and equity earnings in unconsolidated entities less (a) purchases and related costs, (b) field operating costs and (c) segment general and administrative expenses, plus our proportionate share of the depreciation and amortization expense of unconsolidated entities, and further adjusted for certain selected items including (i) gains and losses on derivative instruments that are related to underlying activities in another period (or the reversal of such adjustments from a prior period), gains and losses on derivatives that are related to investing activities (such as the purchase of linefill) and inventory valuation adjustments, as applicable, (ii) long-term inventory costing adjustments, (iii) charges for obligations that are expected to be settled with the issuance of equity instruments, (iv) amounts related to deficiencies associated with minimum volume commitments, net of the applicable amounts subsequently recognized into revenue and (v) other items that our CODM believes are integral to understanding our core segment operating performance.

Segment Adjusted EBITDA excludes depreciation and amortization. We look at each period’s earnings before non-cash depreciation and amortization as an important measure of segment performance. The exclusion of depreciation and amortization expense could be viewed as limiting the usefulness of Segment Adjusted EBITDA as a performance measure because it does not account in current periods for the implied reduction in value of our capital assets, such as crude oil pipelines and facilities, caused by age-related decline and wear and tear. We compensate for this limitation by recognizing that depreciation and amortization are largely offset by repair and maintenance investments, which act to partially offset the aging and wear and tear in the value of our principal fixed assets. These maintenance investments are a component of field operating costs included in Segment Adjusted EBITDA or in maintenance capital, depending on the nature of the cost. Capital expenditures made to expand the existing operating and/or earnings capacity of our assets are classified as investment capital. Capital expenditures for the replacement and/or refurbishment of partially or fully depreciated assets in order to maintain the operating and/or earnings capacity of our existing assets are classified as maintenance capital, which is deducted in determining “available cash.” Repair and maintenance expenditures incurred in order to maintain the day to day operation of our existing assets are charged to expense as incurred.

The following tables reflect certain financial data for each segment (in millions):


	Transportation		Facilities		Supply and Logistics		Intersegment Adjustment		Total
Year Ended December 31, 2020
Revenues:
External customers (1)	$	1,016	$	622	$	22,058	$	(406)	$	23,290
Intersegment (2)	1,004		516		1		406		1,927
Total revenues of reportable segments	$	2,020	$	1,138	$	22,059	$	—	$	25,217
Equity earnings in unconsolidated entities	$	350	$	5	$	—			$	355
Segment Adjusted EBITDA	$	1,616	$	731	$	210			$	2,557
Investment and acquisition capital (3)	$	981	$	173	$	77			$	1,231
Maintenance capital	$	136	$	51	$	29			$	216

As of December 31, 2020
Total assets	$	14,416	$	6,165	$	5,370			$	25,951
Investments in unconsolidated entities	$	3,642	$	122	$	—			$	3,764


	Transportation		Facilities		Supply and Logistics		Intersegment Adjustment		Total
Year Ended December 31, 2019
Revenues:
External customers (1)	$	1,259	$	609	$	32,272	$	(471)	$	33,669
Intersegment (2)	1,061		562		4		471		2,098
Total revenues of reportable segments	$	2,320	$	1,171	$	32,276	$	—	$	35,767
Equity earnings in unconsolidated entities	$	388	$	—	$	—			$	388
Segment Adjusted EBITDA	$	1,722	$	705	$	803			$	3,230
Investment and acquisition capital (3)	$	1,127	$	227	$	33			$	1,387
Maintenance capital	$	161	$	97	$	29			$	287

As of December 31, 2019
Total assets	$	15,549	$	7,593	$	6,827			$	29,969
Investments in unconsolidated entities	$	3,557	$	126	$	—			$	3,683


	Transportation		Facilities		Supply and Logistics		Intersegment Adjustment		Total
Year Ended December 31, 2018
Revenues:
External customers (1)	$	1,116	$	588	$	32,819	$	(468)	$	34,055
Intersegment (2)	874		573		3		468		1,918
Total revenues of reportable segments	$	1,990	$	1,161	$	32,822	$	—	$	35,973
Equity earnings in unconsolidated entities	$	375	$	—	$	—			$	375
Segment Adjusted EBITDA	$	1,508	$	711	$	462			$	2,681
Investment and acquisition capital (3)	$	1,631	$	234	$	23			$	1,888
Maintenance capital	$	139	$	100	$	13			$	252

As of December 31, 2018
Total assets	$	13,947	$	7,464	$	5,419			$	26,830
Investments in unconsolidated entities	$	2,594	$	108	$	—			$	2,702

(1)Transportation revenues from External customers include certain inventory exchanges with our customers where our Supply and Logistics segment has transacted the inventory exchange and serves as the shipper on our pipeline systems. See Note 3 for a discussion of our related accounting policy. We have included an estimate of the revenues from these inventory exchanges in our Transportation segment revenues from External customers presented above and adjusted those revenues out such that Total revenues from External customers reconciles to our Consolidated Statements of Operations. This presentation is consistent with the information provided to our CODM.

(2)Segment revenues include intersegment amounts that are eliminated in Purchases and related costs and Field operating costs in our Consolidated Statements of Operations. Intersegment activities are conducted at posted tariff rates where applicable, or otherwise at rates similar to those charged to third parties or rates that we believe approximate market at the time the agreement is executed or renegotiated.

(3)Investment and acquisition capital expenditures, including investments in unconsolidated entities.

Segment Adjusted EBITDA Reconciliation

The following table reconciles Segment Adjusted EBITDA to Net income/(loss) attributable to PAGP (in millions):


	Year Ended December 31,
	2020		2019		2018
Segment Adjusted EBITDA	$	2,557	$	3,230	$	2,681
Adjustments (1):
Depreciation and amortization of unconsolidated entities (2)	(73)		(62)		(56)
Gains/(losses) from derivative activities, net of inventory valuation adjustments (3)	(480)		(160)		519
Long-term inventory costing adjustments (4)	(44)		20		(21)
Deficiencies under minimum volume commitments, net (5)	(74)		18		(7)
Equity-indexed compensation expense (6)	(19)		(17)		(55)
Net gain/(loss) on foreign currency revaluation (7)	3		(14)		(3)
Line 901 incident (8)	—		(10)		—
Significant acquisition-related expenses (9)	(3)		—		—
Unallocated general and administrative expenses	(5)		(5)		(4)
Depreciation and amortization	(656)		(604)		(521)
Gains/(losses) on asset sales and asset impairments, net	(719)		(28)		114
Goodwill impairment losses	(2,515)		—		—
Gain on/(impairment of) investments in unconsolidated entities, net	(182)		271		200
Interest expense, net	(436)		(425)		(431)
Other income/(expense), net	39		24		(7)
Income/(loss) before tax	(2,607)		2,238		2,409
Income tax (expense)/benefit	167		(176)		(302)
Net income/(loss)	(2,440)		2,062		2,107
Net (income)/loss attributable to noncontrolling interests	1,872		(1,731)		(1,773)
Net income/(loss) attributable to PAGP	$	(568)	$	331	$	334

(1)Represents adjustments utilized by our CODM in the evaluation of segment results.

(2)Includes our proportionate share of the depreciation and amortization of unconsolidated entities.

(3)We use derivative instruments for risk management purposes and our related processes include specific identification of hedging instruments to an underlying hedged transaction. Although we identify an underlying transaction for each derivative instrument we enter into, there may not be an accounting hedge relationship between the instrument and the underlying transaction. In the course of evaluating our results, we identify the earnings that were recognized during the period related to derivative instruments for which the identified underlying transaction does not occur in the current period and exclude the related gains and losses in determining Segment Adjusted EBITDA. In addition, we exclude gains and losses on derivatives that are related to investing activities, such as the purchase of linefill. We also exclude the impact of corresponding inventory valuation adjustments, as applicable.

(4)We carry crude oil and NGL inventory that is comprised of minimum working inventory requirements in third-party assets and other working inventory that is needed for our commercial operations. We consider this inventory necessary to conduct our operations and we intend to carry this inventory for the foreseeable future. Therefore, we classify this inventory as long-term on our balance sheet and do not hedge the inventory with derivative instruments (similar to linefill in our own assets). We exclude the impact of changes in the average cost of the long-term inventory (that result from fluctuations in market prices) and write-downs of such inventory that result from price declines from Segment Adjusted EBITDA.

(5)We, and certain of our equity method investments, have certain agreements that require counterparties to deliver, transport or throughput a minimum volume over an agreed upon period. Substantially all of such agreements were entered into with counterparties to economically support the return on our capital expenditure necessary to construct the related asset. Some of these agreements include make-up rights if the minimum volume is not met. We record a receivable from the counterparty in the period that services are provided or when the transaction occurs, including amounts for deficiency obligations from counterparties associated with minimum volume commitments. If a counterparty has a make-up right associated with a deficiency, we defer the revenue attributable to the counterparty’s make-up right and subsequently recognize the revenue at the earlier of when the deficiency volume is delivered or shipped, when the make-up right expires or when it is determined that the counterparty’s ability to utilize the make-up right is remote. We include the impact of amounts billed to counterparties for their deficiency obligation, net of applicable amounts subsequently recognized into revenue, as a selected item impacting comparability. Our CODM views the inclusion of the contractually committed revenues associated with that period as meaningful to Segment Adjusted EBITDA as the related asset has been constructed, is standing ready to provide the committed service and the fixed operating costs are included in the current period results.

(6)Includes equity-indexed compensation expense associated with awards that will or may be settled in units.

(7)Includes gains and losses realized on the settlement of foreign currency transactions as well as the revaluation of monetary assets and liabilities denominated in a foreign currency.

(8)Includes costs recognized during the period related to the Line 901 incident that occurred in May 2015, net of amounts we believe are probable of recovery from insurance. See Note 19 for additional information regarding the Line 901 incident.

(9)Includes acquisition-related expenses associated with the Felix Midstream LLC acquisition. See Note 7 for additional discussion. An adjustment for these non-recurring expenses is included in the calculation of Segment Adjusted EBITDA for the year ended December 31, 2020 as our CODM does not view such expenses as integral to understanding our core segment operating performance.

Geographic Data

We have operations in the United States and Canada. Set forth below are revenues and long-lived assets attributable to these geographic areas (in millions):


	Year Ended December 31,
Revenues (1)	2020		2019		2018
United States	$	17,942	$	27,162	$	28,362
Canada	5,348		6,507		5,693
	$	23,290	$	33,669	$	34,055

(1)Revenues are primarily attributed to each region based on where the services are provided or the product is shipped.


	December 31,
Long-Lived Assets (1)	2020		2019
United States	$	16,896	$	17,577
Canada	3,892		3,935
	$	20,788	$	21,512

(1)Excludes long-term derivative assets, long-term deferred tax assets and goodwill.

- Definition

The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 31
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8924-108599

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 34
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8981-108599

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 21
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8721-108599

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 40
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e9031-108599

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 32
-Subparagraph (f)
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8933-108599

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 32
-Subparagraph (e)
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8933-108599

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 26
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8844-108599

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 41
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e9038-108599

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 32
-Subparagraph (d)
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8933-108599

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 22
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8736-108599

Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 42
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e9054-108599

Reference 12: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 15
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8657-108599

Reference 13: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 21
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8721-108599

Reference 14: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-URI http://asc.fasb.org/topic&trid=2134510

+ Details

Summary of Significant Accounting Policies (Policies)

12 Months Ended

Dec. 31, 2020

Accounting Policies [Abstract]

Basis of Consolidation and Presentation

Variable Interest Entities

We have determined that our subsidiaries, PAA and AAP, are VIEs and should be consolidated by PAGP because:

Use of Estimates

Purchases and Related Costs

Field Operating Costs and General and Administrative Expenses

Foreign Currency Transactions/Translation

Cash and Cash Equivalents and Restricted Cash

Noncontrolling Interests

Asset Retirement Obligations

Fair Value Measurements

Fair Value MeasurementsFinancial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment, which affects the placement of assets and liabilities within the fair value hierarchy levels. The determination of the fair values includes not only the credit standing of the counterparties involved and the impact of credit enhancements (such as cash deposits and letters of credit) but also the impact of our nonperformance risk on our liabilities. The fair value of our commodity derivatives, interest rate derivatives and foreign currency derivatives includes adjustments for credit risk. Our credit adjustment methodology uses market observable inputs and requires judgment. There were no changes to any of our valuation techniques during the period.

Recent Accounting Pronouncements

Revenue Recognition

Revenue RecognitionWe disaggregate our revenues by segment and type of activity. These categories depict how the nature, amount, timing and uncertainty of revenues and cash flows are affected by economic factors.Revenues from sales of crude oil, NGL and natural gas are recognized at the time title to the product sold transfers to the purchaser, which occurs upon delivery of the product to the purchaser or its designee. Sales of crude oil and NGL consist of outright sales contracts. The consideration received under these contracts is variable based on commodity prices. Inventory exchanges under buy/sell transactions are excluded from Supply and Logistics segment revenues in our Consolidated Statements of Operations. Revenues recognized by our Supply and Logistics segment primarily represent margin based activities. In addition, we have certain crude oil sales agreements that are entered into in conjunction with storage arrangements and future inventory exchanges. The revenues under these agreements are deferred until all performance obligations associated with the related agreements are completed. The inventory that has been sold under these crude oil sales agreements is reflected in “Other current assets” on our Consolidated Balance Sheet until all of our performance obligations are complete. At that time, the inventory that has been sold is removed from our Consolidated Balance Sheet and recorded as “Purchases and related costs” in our Consolidated Statement of Operations.We may also utilize derivatives in connection with the transactions described above. Derivative revenue is not included as a component of revenue from contracts with customers, but is included in other items in revenue. The change in the fair value of derivatives that are not designated or do not qualify for hedge accounting is recognized in revenues each period.Our Transportation segment operations generally consist of fee-based activities associated with transporting crude oil and NGL on pipelines and trucks. Revenues from pipeline tariffs and fees are associated with the transportation of crude oil and NGL at a published tariff. We primarily recognize pipeline tariff and fee revenues over time as services are rendered, based on the volumes transported. As is common in the pipeline transportation industry, our tariffs incorporate a loss allowance factor. We recognize the allowance volumes collected as part of the transaction price and record this non-cash consideration at fair value, measured as of the contract inception date

Reconciliation to Total Revenues of Reportable Segments. The following disclosures only include information regarding revenues associated with consolidated entities, and revenues from entities accounted for by the equity method are not included in the disclosures.Minimum Volume Commitments. We have certain agreements that require counterparties to transport or throughput a minimum volume over an agreed upon period. Some of these agreements include make-up rights if the minimum volume is not met. We record a receivable from the counterparty in the period that services are provided or when the transaction occurs, including amounts for deficiency obligations from counterparties associated with minimum volume commitments. If a counterparty has a make-up right associated with a deficiency, we defer the revenue attributable to the counterparty’s make-up right as a contract liability and subsequently recognize the revenue at the earlier of when the deficiency volume is delivered or shipped, when the make-up right expires or when it is determined that the counterparty’s ability to utilize the make-up right is remote.Contract Balances. Our contract balances consist of amounts received associated with services or sales for which we have not yet completed the related performance obligation.


	2021		2022		2023		2024		2025		2026 and Thereafter
Pipeline revenues supported by minimum volume commitments and capacity agreements (1)	$	174	$	166	$	170	$	142	$	125	$	455
Storage, terminalling and throughput agreement revenues	340		273		206		173		114		328
Total	$	514	$	439	$	376	$	315	$	239	$	783

(1)Calculated as volumes committed under contracts multiplied by the current applicable tariff rate.

•Minimum volume commitments on certain of our joint venture pipeline systems;

•Acreage dedications;

•Supply and Logistics buy/sell arrangements with future committed volumes;

•All other Supply and Logistics contracts, due to the election of practical expedients related to variable consideration and short-term contracts, as discussed below;

•Transportation and Facilities contracts that are short-term, as discussed below;

•Contracts within the scope of ASC Topic 842, Leases; and

•Contracts within the scope of ASC Topic 815, Derivatives and Hedging.

Trade Accounts Receivable and Other Receivables, Net

Net Income Per Class A Share

Basic net income/(loss) per Class A share is determined by dividing net income/(loss) attributable to PAGP by the weighted average number of Class A shares outstanding during the period. Our Class B and Class C shares do not share in the earnings of the Partnership; accordingly, basic and diluted net income/(loss) per Class B and Class C share has not been presented.

Inventory, Linefill and Base Gas and Long-term Inventory

Property and Equipment

In accordance with our capitalization policy, expenditures made to expand the existing operating and/or earnings capacity of our assets are capitalized. We also capitalize certain costs directly related to the construction of such assets, including related internal labor costs, engineering costs and interest costs. For the years ended December 31, 2020, 2019 and 2018, capitalized interest recorded to property and equipment was $8 million, $14 million and $21 million, respectively. In addition, we capitalize interest related to investments in certain unconsolidated entities. See Note 9 for additional information. We also capitalize expenditures for the replacement and/or refurbishment of partially or fully depreciated assets in order to maintain the operating and/or earnings capacity of our existing assets. Repair and maintenance expenditures incurred in order to maintain the day to day operation of our existing assets are expensed as incurred.We calculate our depreciation using the straight-line method, based on estimated useful lives and salvage values of our assets. In addition, when we evaluate property and equipment and other long-lived assets for recoverability, it may also be necessary to review related depreciation estimates and methods.

Impairment of Long-Lived Assets (Held and Used)

•whether there is an indication of impairment;

•the grouping of assets;

•the intention of “holding,” “abandoning” or “selling” an asset;

•the forecast of undiscounted expected future cash flow over the asset’s estimated useful life; and

•if an impairment exists, the fair value of the asset or asset group.

In addition, when we evaluate property and equipment and other long-lived assets for recoverability, it may also be necessary to review related depreciation estimates and methods.

Goodwill

Goodwill represents the future economic benefits arising from assets acquired in a business combination that are not individually identified and separately recognized.

Investments in Unconsolidated Entities

Distributions

Contributions

Basis Differences

Intangible Assets

Intangible assets that have finite lives are tested for impairment when events or circumstances indicate that the carrying value may not be recoverable.

Debt

Letters of CreditIn connection with our supply and logistics activities, we provide certain suppliers with irrevocable standby letters of credit to secure our obligation for the purchase and transportation of crude oil, NGL and natural gas. These letters of credit are issued under PAA’s senior unsecured revolving credit facility and senior secured hedged inventory facility, and our liabilities with respect to these purchase obligations are recorded in accounts payable on our balance sheet in the month the crude oil, NGL or natural gas is purchased. Generally, these letters of credit are issued for periods of up to seventy days and are terminated upon completion of each transaction. Additionally, we issue letters of credit to support insurance programs, derivative transactions, including hedging-related margin obligations, and construction activities.

Debt Issuance Costs

Derivatives

We identify the risks that underlie our core business activities and use risk management strategies to mitigate those risks when we determine that there is value in doing so. We use various derivative instruments to optimize our profits while managing our exposure to (i) hydrocarbon commodity (referred to herein as “commodity”) price risk, (ii) interest rate risk and (iii) currency exchange rate risk. Our commodity price risk management policies and procedures are designed to help ensure that our hedging activities address our risks by monitoring our derivative positions, as well as physical volumes, grades, locations, delivery schedules and storage capacity. Our interest rate and currency exchange rate risk management policies and procedures are designed to monitor our derivative positions and ensure that those positions are consistent with our objectives and approved strategies. Our policy is to use derivative instruments for risk management purposes and not for the purpose of speculating on changes in commodity prices, interest rates or currency exchange rates. We record all open derivatives on the balance sheet as either assets or liabilities measured at fair value. Changes in the fair value of derivatives are recognized currently in earnings unless specific hedge accounting criteria are met.Cash settlements associated with our derivative activities are classified within the same category as the related hedged item in our Condensed Consolidated Statements of Cash Flows.

Derivative Hedge Accounting Documentation

When we apply hedge accounting, our policy is to formally document all relationships between hedging instruments and hedged items, as well as our risk management objectives for undertaking the hedge. This process includes specific identification of the hedging instrument and the hedged transaction, the nature of the risk being hedged and how the hedging instrument’s effectiveness will be assessed.

Derivative Hedge Effectiveness Determination

At the inception of the hedging relationship, we assess whether the derivatives employed are highly effective in offsetting changes in cash flows of anticipated hedged transactions. Throughout the hedging relationship, retrospective and prospective hedge effectiveness is assessed on a qualitative basis.

Derivatives That Qualify for Hedge Accounting

For derivatives designated as cash flow hedges, changes in fair value are deferred in AOCI and recognized in earnings in the periods during which the underlying hedged transactions are recognized in earnings.

Derivatives That Do Not Qualify for Hedge Accounting

Derivatives that are not designated as a hedging instrument and derivatives that do not qualify for hedge accounting are recognized in earnings each period.

Lessee

Lessor

Income Taxes

Income tax expense is estimated using the tax rate in effect or to be in effect during the relevant periods in the jurisdictions in which we operate. Deferred income tax assets and liabilities are recognized for temporary differences between the basis of assets and liabilities for financial reporting and tax purposes and are stated at enacted tax rates expected to be in effect when taxes are actually paid or recovered. To the extent we do not consider it more likely than not that a deferred tax asset will be recovered, a valuation allowance is established. Changes in tax legislation are included in the relevant computations in the period in which such changes are effective. We review contingent tax liabilities for estimated exposures on a more likely than not standard related to our current tax positions.Pursuant to FASB guidance related to accounting for uncertainty in income taxes, we may recognize the tax benefit from an uncertain tax position only if it is more likely than not that the tax position will be sustained upon examination by the taxing authorities, based on the technical merits of the tax position and also the past administrative practices and precedents of the taxing authority.As a result of the exchange of the ownership interest in AAP in connection with our IPO and all subsequent exchanges, a deferred tax asset was created. These transfers of ownership were accounted for at the historical carrying basis for GAAP accounting purposes, but were recorded at the fair market value of the Class A shares at the time of exchange for U.S. federal income tax purposes. The resulting basis difference resulted in a deferred tax asset that was recorded as a component of partners’ capital as it results from transactions among shareholders. The deferred tax asset is amortized to deferred income tax expense as the associated basis step-up is realized on our tax returns. Also, in connection with the repurchase of common units by PAA and the associated adjustment to partners’ capital attributable to PAGP, a corresponding change to the deferred tax balance was recorded to partners’ capital. See Note 12 for additional information regarding exchanges and the repurchase of common units by PAA.

Concentration of Credit Risk

Financial instruments that potentially subject us to concentrations of credit risk consist principally of trade receivables. Our accounts receivable are primarily from purchasers and shippers of crude oil and, to a lesser extent, purchasers of NGL. This industry concentration has the potential to impact our overall exposure to credit risk in that the customers may be similarly affected by changes in economic, industry or other conditions. We review credit exposure and financial information of our counterparties and generally require letters of credit for receivables from customers that are not considered creditworthy, unless the credit risk can otherwise be reduced.

Equity-indexed Compensation

Loss Contingencies

Environmental Matters

Operating Segments

Our Chief Operating Decision Maker (“CODM”) (our Chief Executive Officer) evaluates segment performance based on measures including Segment Adjusted EBITDA (as defined below) and maintenance capital investment.

Summary of Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2020

Accounting Policies [Abstract]

Restrictions on Cash and Cash Equivalents

The following table presents a reconciliation of cash and cash equivalents and restricted cash reported on our Consolidated Balance Sheets that sum to the total of the amount shown on our Consolidated Statements of Cash Flows (in millions):


	December 31,
	2020		2019
Cash and cash equivalents	$	25	$	47
Restricted cash	38		37
Total cash and cash equivalents and restricted cash	$	63	$	84

Schedule of Change in Asset Retirement Obligation

The following table presents the change in the liability for asset retirement obligations, substantially all of which is reflected in “Other long-term liabilities and deferred credits” on our Consolidated Balance Sheets as of December 31, 2020, 2019 and 2018 (in millions):


	December 31,
	2020		2019		2018
Beginning balance	$	137	$	109	$	103
Liabilities incurred	12		3		3
Liabilities settled	(1)		(3)		(3)
Accretion expense	5		5		4
Revisions in estimated cash flows	(18)		23		2
Ending balance	$	135	$	137	$	109

Revenues and Accounts Receivable (Tables)

12 Months Ended

Dec. 31, 2020

Disaggregation of Revenue [Line Items]

Disaggregation of Revenue

The following tables present the reconciliation of our revenues from contracts with customers (as described above for each segment) to segment revenues and total revenues as disclosed in our Consolidated Statements of Operations (in millions):


Year Ended December 31, 2020	Transportation		Facilities		Supply and Logistics		Total
Revenues from contracts with customers	$	2,005	$	1,099	$	22,351	$	25,455
Other items in revenues	15		39		(292)		(238)
Total revenues of reportable segments	$	2,020	$	1,138	$	22,059	$	25,217
Intersegment revenues							(1,927)
Total revenues							$	23,290


Year Ended December 31, 2019	Transportation		Facilities		Supply and Logistics		Total
Revenues from contracts with customers	$	2,283	$	1,122	$	31,966	$	35,371
Other items in revenues	37		49		310		396
Total revenues of reportable segments	$	2,320	$	1,171	$	32,276	$	35,767
Intersegment revenues							(2,098)
Total revenues							$	33,669


Year Ended December 31, 2018	Transportation		Facilities		Supply and Logistics		Total
Revenues from contracts with customers	$	1,976	$	1,136	$	32,700	$	35,812
Other items in revenues	14		25		122		161
Total revenues of reportable segments	$	1,990	$	1,161	$	32,822	$	35,973
Intersegment revenues							(1,918)
Total revenues							$	34,055

Contracts with Customers, Change in Contract Asset and Liability Balance

The following table presents amounts in Other current assets and deferred revenue associated with these agreements (in millions):


	December 31,
	2020		2019
Other current assets	$	229	$	142
Deferred revenue (1)	$	361	$	155

(1)Included in “Other current liabilities” on our Consolidated Balance Sheet.

The following table presents the changes in the liability balance associated with contracts with customers (in millions):


	Contract Liabilities
Balance at December 31, 2018	$	338
Amounts recognized as revenue	(227)

Additions (1)	244
Other	(1)
Balance at December 31, 2019	$	354
Amounts recognized as revenue (1)	(246)
Additions (2)	393

Balance at December 31, 2020	$	501


	December 31,
	2020		2019
Trade accounts receivable arising from revenues from contracts with customers	$	2,317	$	3,381
Other trade accounts receivables and other receivables (1)	2,818		3,576
Impact due to contractual rights of offset with counterparties	(2,582)		(3,343)
Trade accounts receivable and other receivables, net	$	2,553	$	3,614

(1) The balance is comprised primarily of accounts receivable associated with buy/sell arrangements that are not within the scope of ASC 606.

Contract with Customer, Counterparty Deficiencies


		December 31,
Counterparty deficiencies	Financial Statement Classification	2020		2019
Billed and collected	Liability	$	73	$	22
Unbilled (1)	N/A	4		20
Total		$	77	$	42

Remaining Performance Obligations

The following table presents the amount of consideration associated with remaining performance obligations for the population of contracts with external customers meeting the presentation requirements as of December 31, 2020 (in millions):


	2021		2022		2023		2024		2025		2026 and Thereafter
Pipeline revenues supported by minimum volume commitments and capacity agreements (1)	$	174	$	166	$	170	$	142	$	125	$	455
Storage, terminalling and throughput agreement revenues	340		273		206		173		114		328
Total	$	514	$	439	$	376	$	315	$	239	$	783

(1)Calculated as volumes committed under contracts multiplied by the current applicable tariff rate.

Supply and Logistics

Disaggregation of Revenue [Line Items]

Disaggregation of Revenue

The following table presents our Supply and Logistics segment revenues from contracts with customers disaggregated by type of activity (in millions):


	Year Ended December 31,
	2020		2019		2018
Supply and Logistics segment revenues from contracts with customers
Crude oil transactions	$	21,202	$	30,082	$	29,592
NGL and other transactions	1,149		1,884		3,108
Total Supply and Logistics segment revenues from contracts with customers	$	22,351	$	31,966	$	32,700

Transportation

Disaggregation of Revenue [Line Items]

Disaggregation of Revenue

The following table presents our Transportation segment revenues from contracts with customers disaggregated by type of activity (in millions):


	Year Ended December 31,
	2020		2019		2018
Transportation segment revenues from contracts with customers
Tariff activities:
Crude oil pipelines	$	1,805	$	2,039	$	1,724
NGL pipelines	101		99		103
Total tariff activities	1,906		2,138		1,827
Trucking	99		145		149
Total Transportation segment revenues from contracts with customers	$	2,005	$	2,283	$	1,976

Facilities

Disaggregation of Revenue [Line Items]

Disaggregation of Revenue

The following table presents our Facilities segment revenues from contracts with customers disaggregated by type of activity (in millions):


	Year Ended December 31,
	2020		2019		2018
Facilities segment revenues from contracts with customers
Crude oil, NGL and other terminalling and storage	$	704	$	697	$	688
NGL and natural gas processing and fractionation	350		349		364
Rail load / unload	45		76		84
Total Facilities segment revenues from contracts with customers	$	1,099	$	1,122	$	1,136

Net Income/(Loss) Per Class A Share (Tables)

12 Months Ended

Dec. 31, 2020

Earnings Per Share [Abstract]

Calculation of basic and diluted net income per Class A share

The following table sets forth the computation of basic and diluted net income/(loss) per Class A share (in millions, except per share data):


	Year Ended December 31,
	2020		2019		2018
Basic Net Income/(Loss) per Class A Share
Net income/(loss) attributable to PAGP	$	(568)	$	331	$	334
Basic weighted average Class A shares outstanding	186		168		158

Basic net income/(loss) per Class A share	$	(3.06)	$	1.97	$	2.12

Diluted Net Income/(Loss) per Class A Share
Net income/(loss) attributable to PAGP	$	(568)	$	331	$	334
Incremental net income/(loss) attributable to PAGP resulting from assumed exchange of AAP units and AAP Management Units	(189)		2		262
Net income/(loss) attributable to PAGP including incremental net income/(loss) from assumed exchange of AAP units and AAP Management Units	$	(757)	$	333	$	596

Basic weighted average Class A shares outstanding	186		168		158
Dilutive shares resulting from assumed exchange of AAP units and AAP Management Units	60		2		124
Diluted weighted average Class A shares outstanding	246		170		282

Diluted net income/(loss) per Class A share	$	(3.07)	$	1.96	$	2.11

Inventory, Linefill and Base Gas and Long-term Inventory (Tables)

12 Months Ended

Dec. 31, 2020

Inventory, Linefill and Base Gas and Long-term Inventory

Schedule of inventory, linefill and base gas and long-term inventory

Inventory, linefill and base gas and long-term inventory consisted of the following (barrels and natural gas volumes in thousands and carrying value in millions):


	December 31, 2020						December 31, 2019
	Volumes	Unit of Measure	Carrying Value		Price/ Unit (1)		Volumes	Unit of Measure	Carrying Value		Price/ Unit (1)
Inventory
Crude oil	13,450	barrels	$	441	$	32.79	8,613	barrels	$	450	$	52.25
NGL	12,302	barrels	199		$	16.18	7,574	barrels	142		$	18.75

Other	N/A		7		N/A		N/A		12		N/A
Inventory subtotal			647						604

Linefill and base gas
Crude oil	14,669	barrels	828		$	56.45	14,316	barrels	826		$	57.70
NGL	1,640	barrels	44		$	26.83	1,701	barrels	47		$	27.63
Natural gas	25,576	Mcf	110		$	4.30	24,976	Mcf	108		$	4.32
Linefill and base gas subtotal			982						981

Long-term inventory
Crude oil	2,499	barrels	111		$	44.42	2,598	barrels	152		$	58.51
NGL	1,185	barrels	19		$	16.03	1,707	barrels	30		$	17.57
Long-term inventory subtotal			130						182

Total			$	1,759					$	1,767

Property and Equipment (Tables)

12 Months Ended

Dec. 31, 2020

Property, Plant and Equipment [Abstract]

Components of property and equipment, net

Property and equipment, net is stated at cost and consisted of the following (in millions):


	Estimated Useful Lives (Years)	December 31,
		2020		2019
Pipelines and related facilities (1)	10 - 70	$	11,147	$	11,149
Storage, terminal and rail facilities	10 - 70	6,042		6,134
Trucking equipment and other	2 - 15	524		486
Construction in progress	N/A	272		518
Office property and equipment	2 - 50	293		269
Land and other	N/A	342		427
Property and equipment, gross		18,620		18,983
Accumulated depreciation		(4,000)		(3,616)
Property and equipment, net		$	14,620	$	15,367

(1)We include rights-of-way, which are intangible assets, in our Pipelines and related facilities amounts within property and equipment.

Goodwill (Tables)

12 Months Ended

Dec. 31, 2020

Goodwill and Intangible Assets Disclosure [Abstract]

Schedule of goodwill by segment and changes during the period

Goodwill by segment and changes in goodwill is reflected in the following table (in millions):


	Transportation		Facilities		Supply and Logistics		Total
Balance at December 31, 2018	$	1,040	$	978	$	503	$	2,521
Foreign currency translation adjustments	12		4		3		19

Balance at December 31, 2019	$	1,052	$	982	$	506	$	2,540
Acquisitions	2		—		—		2

Goodwill, gross	1,054		982		506		2,542
Impairments	(1,038)		(975)		(502)		(2,515)
Foreign currency translation adjustments	(16)		(7)		(4)		(27)
Accumulated impairment losses	(1,054)		(982)		(506)		(2,542)
Balance at December 31, 2020	$	—	$	—	$	—	$	—

Investments in Unconsolidated Entities (Tables)

12 Months Ended

Dec. 31, 2020

Equity Method Investments and Joint Ventures [Abstract]

Investments in and summarized financial information for entities accounted for under the equity method of accounting

Our investments in unconsolidated entities consisted of the following (in millions, except percentage data):


		Ownership Interest at December 31, 2020	Investment Balance December 31,
Entity (1)	Type of Operation		2020		2019
BridgeTex Pipeline Company, LLC (“BridgeTex”)	Crude Oil Pipeline	20%	$	421	$	431
Cactus II Pipeline LLC (“Cactus II”)	Crude Oil Pipeline	65%	752		738
Capline Pipeline Company LLC	Crude Oil Pipeline (2)	54%	514		484
Diamond Pipeline LLC (“Diamond”)	Crude Oil Pipeline	50%	480		476
Eagle Ford Pipeline LLC (“Eagle Ford Pipeline”)	Crude Oil Pipeline	50%	372		382
Eagle Ford Terminals Corpus Christi LLC (“Eagle Ford Terminals”)	Crude Oil Terminal and Dock	50%	122		126
Red Oak Pipeline LLC (“Red Oak”)	Crude Oil Pipeline	50%	35		20
Saddlehorn	Crude Oil Pipeline	30%	208		234
STACK Pipeline LLC (“STACK”)	Crude Oil Pipeline	50%	22		117
White Cliffs Pipeline, LLC	Crude Oil Pipeline	36%	192		196
Wink to Webster Pipeline LLC (“W2W Pipeline”)	Crude Oil Pipeline	16%	330		136
Other investments			316		343
Total Investments in Unconsolidated Entities			$	3,764	$	3,683

(1)Except for Eagle Ford Terminals, which is reported in our Facilities segment, the financial results from the entities are reported in our Transportation segment.

(2)The Capline pipeline was taken out of service pending the reversal of the pipeline system.

Combined summarized financial information for all of our unconsolidated entities is shown in the tables below (in millions). None of our unconsolidated entities have noncontrolling interests.


	December 31,
	2020		2019
Current assets	$	580	$	652
Noncurrent assets	$	8,769	$	7,264
Current liabilities	$	343	$	298
Noncurrent liabilities	$	10	$	26


	Year Ended December 31,
	2020		2019		2018
Revenues	$	1,360	$	1,469	$	1,235
Operating income	$	828	$	994	$	824
Net income	$	826	$	995	$	824

Other Long-Term Assets, Net (Tables)

12 Months Ended

Dec. 31, 2020

Other Assets [Abstract]

Components of other long-term assets, net of accumulated amortization

Other long-term assets, net of accumulated amortization, consisted of the following (in millions):


		December 31, 2020						December 31, 2019
	Estimated Useful Lives (Years)	Cost		Accumulated Amortization		Net		Cost		Accumulated Amortization		Net
Customer contracts and relationships (1)	3 – 29	$	1,291	$	(519)	$	772	$	1,134	$	(463)	$	671
Property tax abatement	13	23		(20)		3		23		(18)		5
Other agreements	1 – 70	40		(10)		30		42		(11)		31
Intangible assets (2)		1,354		(549)		805		1,199		(492)		707
Other		163		(3)		160		150		(1)		149
Other long-term assets, net		$	1,517	$	(552)	$	965	$	1,349	$	(493)	$	856

(1)Amounts for the year ended December 31, 2020 include intangible assets associated with the acquisition of FM Gathering. See Note 7 for additional information.

(2)We include rights-of-way, which are intangible assets, in our pipeline and related facilities amounts within property and equipment. See Note 6 for a discussion of property and equipment.

Estimated amortization expense related to finite-lived intangible assets for the next five years

We estimate that our amortization expense related to finite-lived intangible assets for the next five years will be as follows (in millions):


2021	$	87
2022	$	86
2023	$	82
2024	$	80
2025	$	77

Debt (Tables)

12 Months Ended

Dec. 31, 2020

Debt Disclosure [Abstract]

Schedule of debt

Debt consisted of the following (in millions):


	December 31, 2020		December 31, 2019
SHORT-TERM DEBT
PAA commercial paper notes, bearing a weighted-average interest rate of 0.7% and 2.2%, respectively (1)	$	547	$	93
PAA senior secured hedged inventory facility, bearing a weighted-average interest rate of 1.2% and 2.7%, respectively (1)	167		325
Other	117		86
Total short-term debt	831		504

LONG-TERM DEBT
PAA senior notes:
5.00% senior notes due February 2021	—		600
3.65% senior notes due June 2022	750		750
2.85% senior notes due January 2023	400		400
3.85% senior notes due October 2023	700		700
3.60% senior notes due November 2024	750		750
4.65% senior notes due October 2025	1,000		1,000
4.50% senior notes due December 2026	750		750
3.55% senior notes due December 2029	1,000		1,000
3.80% senior notes due September 2030	750		—
6.70% senior notes due May 2036	250		250
6.65% senior notes due January 2037	600		600
5.15% senior notes due June 2042 (2)	499		500
4.30% senior notes due January 2043 (2)	348		350
4.70% senior notes due June 2044 (2)	687		700
4.90% senior notes due February 2045 (2)	649		650
Unamortized discounts and debt issuance costs	(62)		(61)
PAA senior notes, net of unamortized discounts and debt issuance costs	9,071		8,939
Other long-term debt:
PAA GO Zone term loans, net of debt issuance costs of $1 and $1, respectively, bearing a weighted-average interest rate of 1.3% and 2.6%, respectively	199		199
Other	112		49
Total long-term debt	9,382		9,187
Total debt (3)	$	10,213	$	9,691

Summary of PAA's issuances of senior unsecured notes

The table below summarizes PAA’s issuances of senior unsecured notes during the three years ended December 31, 2020 (in millions):

Year

Description

Maturity

Face Value

Interest Payment Dates

2020

3.80% Senior Notes issued at 99.794% of face value

September 2030

750

March 15 and September 15

2019

3.55% Senior Notes issued at 99.801% of face value

December 2029

1,000

June 15 and December 15

During the three years ended December 31, 2020, PAA repaid the following senior unsecured notes in full (in millions):


Year	Description	Repayment Date
2020	$600 million 5.00% Senior Notes due February 2021	November 2020	(1)

2019	$500 million 2.60% Senior Notes due December 2019	November 2019	(2)
2019	$500 million 5.75% Senior Notes due January 2020	December 2019	(2)

(1)These senior notes were repaid with proceeds from PAA’s 3.80% senior notes issued in June 2020 and cash on hand.

(2)These senior notes were repaid with proceeds from PAA’s 3.55% senior notes issued in September 2019 and cash on hand.

Aggregate maturities of long-term debt

The following table presents the aggregate contractually scheduled maturities of such senior notes and GO Zone term loans for the next five years and thereafter. The amounts presented exclude unamortized discounts and debt issuance costs.


Calendar Year	Payment (in millions)
2021	$	—
2022	$	750
2023	$	1,300
2024	$	750
2025	$	1,000
Thereafter	$	5,533

- Definition

Tabular disclosure of long-debt instruments or arrangements, including identification, terms, features, collateral requirements and other information necessary to a fair presentation. These are debt arrangements that originally required repayment more than twelve months after issuance or greater than the normal operating cycle of the entity, if longer.

+ References

Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.5-02.22)
-URI http://asc.fasb.org/extlink&oid=120391452&loc=d3e13212-122682

Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 45
-Paragraph 1A
-URI http://asc.fasb.org/extlink&oid=119993939&loc=d3e28541-108399

Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 6
-URI http://asc.fasb.org/extlink&oid=109259400&loc=d3e21506-112644

Reference 4: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(e),(f))
-URI http://asc.fasb.org/extlink&oid=120395691&loc=d3e23780-122690

Reference 5: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 45
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=119993939&loc=d3e28551-108399

Reference 6: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 7
-URI http://asc.fasb.org/extlink&oid=109259400&loc=d3e21521-112644

Reference 7: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=109259400&loc=d3e21538-112644

Reference 8: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 942
-SubTopic 470
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=75038535&loc=d3e64711-112823

Reference 9: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 55
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=114775985&loc=d3e28878-108400

Reference 10: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=109259400&loc=d3e21475-112644

+ Details

Partners' Capital and Distributions (Tables)

12 Months Ended

Dec. 31, 2020

Partners Capital and Distribution [Line Items]

Schedule of changes in shares outstanding

The following table presents the activity for our Class A shares, Class B shares and Class C shares:


	Class A Shares	Class B Shares	Class C Shares
Outstanding at December 31, 2017	156,111,139	126,984,572	510,925,432

Exchange Right exercises	3,363,199	(3,363,199)	—
Redemption Right exercises	—	(4,017,035)	4,017,035
Issuance of Series A preferred units by a subsidiary	—	—	1,393,926
Other	11,250	—	601,887
Outstanding at December 31, 2018	159,485,588	119,604,338	516,938,280

Exchange Right exercises (1)	22,637,818	(22,637,818)	—
Redemption Right exercises (1)	—	(31,180,818)	31,180,818
Other	15,186	—	1,419,041
Outstanding at December 31, 2019	182,138,592	65,785,702	549,538,139

Conversion of AAP Management Units	—	595,117	—
Exchange Right exercises	11,858,457	(11,858,457)
Redemption Right exercises		(3,882,170)	3,882,170
Repurchase of common units by a subsidiary	—	—	(6,222,748)
Other	54,387		520,201
Outstanding at December 31, 2020	194,051,436	50,640,192	547,717,762

(1)Includes exercises by Oxy and an affiliate of The Energy & Minerals Group (“EMG”). See Note 17 for additional information.

Class A Shares

Partners Capital and Distribution [Line Items]

Schedule of distributions

The following table details the distributions paid to our Class A shareholders during the periods indicated (in millions, except per share data):


Year	Distributions to Class A Shareholders		Distributions per Class A Share
2020	$	166	$	0.90
2019	$	231	$	1.38
2018	$	189	$	1.20

PAA | Series A Preferred Units

Partners Capital and Distribution [Line Items]

Schedule of distributions

PAA Preferred Unit Distributions. The following table details distributions paid to PAA’s preferred unitholders during the year presented (in millions, except unit data):


	Series A Preferred Unitholders			Series B Preferred Unitholders
	Distribution (1)			Cash Distribution
Year	Cash		Units
2020	$	149	—	$	49
2019	$	149	—	$	49
2018	$	112	1,393,926	$	49

PAA | Series B Preferred Units

Partners Capital and Distribution [Line Items]

Schedule of distributions

PAA Preferred Unit Distributions. The following table details distributions paid to PAA’s preferred unitholders during the year presented (in millions, except unit data):


	Series A Preferred Unitholders			Series B Preferred Unitholders
	Distribution (1)			Cash Distribution
Year	Cash		Units
2020	$	149	—	$	49
2019	$	149	—	$	49
2018	$	112	1,393,926	$	49

PAA | Common Units

Partners Capital and Distribution [Line Items]

Schedule of distributions

The following table details distributions paid by PAA during the year presented (in millions, except per unit data):


	Distributions Paid						Distributions per common unit
Year	Public		AAP		Total
2020	$	432	$	223	$	655	$	0.90
2019	$	632	$	372	$	1,004	$	1.38
2018	$	532	$	339	$	871	$	1.20

AAP

Partners Capital and Distribution [Line Items]

Schedule of distributions

The following table details the distributions to AAP’s partners paid during the periods indicated from distributions received from PAA (in millions):


	Distributions to AAP’s Partners
Year	Noncontrolling Interests		PAGP		Total Cash Distributions

2020	$	57	$	166	$	223
2019	$	141	$	231	$	372
2018	$	150	$	189	$	339

Derivatives and Risk Management Activities (Tables)

12 Months Ended

Dec. 31, 2020

Derivatives and Risk Management Activities

Impact of derivative activities recognized in earnings

A summary of the impact of our commodity derivatives recognized in earnings as follows (in millions):


	Year Ended December 31,
	2020		2019		2018
Supply and Logistics segment revenues	$	(302)	$	310	$	150
Field operating costs	5		14		(2)
Net gain/(loss) from commodity derivative activity	$	(297)	$	324	$	148

Schedule of net broker receivable (payable)

The following table provides the components of our net broker receivable/(payable) (in millions):


	December 31,
	2020		2019
Initial margin	$	91	$	73
Variation margin posted/(returned)	290		(45)
Letters of credit	(63)		(73)
Net broker receivable/(payable)	$	318	$	(45)

Summary of derivative assets and liabilities on Consolidated Balance Sheets on a gross basis


	December 31, 2020								December 31, 2019
					Effect of Collateral Netting		Net Carrying Value Presented on the Balance Sheet						Effect of Collateral Netting		Net Carrying Value Presented on the Balance Sheet
	Commodity Derivatives								Commodity Derivatives
	Assets		Liabilities						Assets		Liabilities
Derivative Assets
Other current assets	$	71	$	(314)	$	318	$	75	$	179	$	(37)	$	(45)	$	97
Other long-term assets, net	5		—		—		5		24		—		—		24
Derivative Liabilities
Other current liabilities	9		(40)		—		(31)		32		(56)		—		(24)
Other long-term liabilities and deferred credits	—		(32)		—		(32)		—		(12)		—		(12)
Total	$	85	$	(386)	$	318	$	17	$	235	$	(105)	$	(45)	$	85

Net deferred gain/(loss) recognized in AOCI for derivatives

The following table summarizes the net unrealized gain/(loss) recognized in AOCI for derivatives (in millions):


	Year Ended December 31,
	2020		2019		2018
Interest rate derivatives, net	$	(10)	$	(91)	$	38

Schedule of derivative financial assets and liabilities accounted for at fair value on a recurring basis, by level within the fair value hierarchy

The following table sets forth by level within the fair value hierarchy our financial assets and liabilities that were accounted for at fair value on a recurring basis (in millions):


	Fair Value as of December 31, 2020								Fair Value as of December 31, 2019
Recurring Fair Value Measures (1)	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Commodity derivatives	$	(143)	$	(143)	$	(15)	$	(301)	$	42	$	105	$	(17)	$	130
Interest rate derivatives	—		46		—		46		—		(44)		—		(44)
Foreign currency derivatives	—		2		—		2		—		1		—		1
Preferred Distribution Rate Reset Option	—		—		(14)		(14)		—		—		(34)		(34)
Total net derivative asset/(liability)	$	(143)	$	(95)	$	(29)	$	(267)	$	42	$	62	$	(51)	$	53

(1)Derivative assets and liabilities are presented above on a net basis but do not include related cash margin deposits.

Reconciliation of changes in fair value of derivatives classified as Level 3

The following table provides a reconciliation of changes in fair value of the beginning and ending balances for our derivatives classified as Level 3 (in millions):


	Year Ended December 31,
	2020		2019
Beginning Balance	$	(51)	$	(24)
Net gains/(losses) for the period included in earnings	12		10
Settlements	10		(11)
Derivatives entered into during the period	—		(26)
Ending Balance	$	(29)	$	(51)

Change in unrealized gains/(losses) included in earnings relating to Level 3 derivatives still held at the end of the period	$	12	$	(16)

Commodity derivatives

Derivatives and Risk Management Activities

Summary of open derivative contracts

The following table summarizes our open derivative positions utilized to hedge the price risk associated with anticipated purchases and sales related to our natural gas processing and NGL fractionation activities as of December 31, 2020.


	Notional Volume (Short)/Long	Remaining Tenor
Natural gas purchases	37.3 Bcf	December 2021
Propane sales	(6.3) MMbls	December 2021
Butane sales	(2.3) MMbls	December 2021
Condensate sales (WTI position)	(0.6) MMbls	December 2021

Fuel gas requirements (1)	14.3 Bcf	December 2022
Power supply requirements (1)	0.7 TWh	December 2022

(1)Positions to hedge a portion of our power supply and fuel gas requirements at our Canadian natural gas processing and fractionation plants.

Interest Rate Swaps

Derivatives and Risk Management Activities

Schedule of terms of outstanding interest rate derivatives

The following table summarizes the terms of our outstanding interest rate derivatives as of December 31, 2020 (notional amounts in millions):

Hedged Transaction

Number and Types of

Derivatives Employed

Notional

Amount

Expected

Termination Date

Average Rate Locked

Accounting

Treatment

Anticipated interest payments

8 forward starting swaps

(30-year)

200

6/15/2023

1.38

Cash flow hedge

Anticipated interest payments

8 forward starting swaps

(30-year)

200

6/14/2024

0.73

Cash flow hedge

Foreign currency derivatives

Derivatives and Risk Management Activities

Summary of open derivative contracts

The following table summarizes our open forward exchange contracts as of December 31, 2020 (in millions):


		USD		CAD		Average Exchange Rate USD to CAD
Forward exchange contracts that exchange CAD for USD:
	2021	$	46	$	59	$1.00 - $1.28

Forward exchange contracts that exchange USD for CAD:
	2021	$	80	$	104	$1.00 - $1.30

Leases (Tables)

12 Months Ended

Dec. 31, 2020

Leases [Abstract]

Schedule of Lease Costs and Other Lessee Information

The following table presents components of lease cost, including both amounts recognized in income and amounts capitalized (in millions):


	Year Ended December 31,
Lease Cost	2020		2019
Operating lease cost	$	111	$	125
Short-term lease cost	31		35
Other (1) (2)	8		—
Total lease cost	$	150	$	160

(1)Includes finance lease costs, variable lease costs and sublease income.

(2)Includes approximately $6 million for the year ended December 31, 2020 associated with leased storage tanks owned by an equity method investee, in which we own a 50% interest.

The following table presents information related to cash flows arising from lease transactions (in millions):


	Year Ended December 31,
	2020		2019
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows for operating leases	$	108	$	116
Operating cash flows for finance leases	$	5	$	1
Financing cash flows for finance leases	$	19	$	18

Non-cash change in lease liabilities arising from obtaining new right-of-use assets or modifications:
Operating leases	$	5	$	77
Finance leases (1)	$	32	$	27

Information related to the weighted-average remaining lease term and discount rate is presented in the table below:


	December 31,
	2020		2019
Weighted-average remaining lease term (in years):
Operating leases	12		11
Finance leases	9		6

Weighted-average discount rate:
Operating leases	4.5	%	4.4	%
Finance leases	11.1	%	7.1	%

Schedule of Assets and Liabilities, Lessee

The following table presents the amount and location of our operating and finance lease right-of-use assets and liabilities on our Consolidated Balance Sheets (in millions):


		December 31,
Leases	Balance Sheet Location	2020		2019
Assets
Operating lease right-of-use assets	Long-term operating lease right-of-use assets, net	$	378	$	466

Finance lease right-of-use assets (1)	Property and equipment	$	141	$	124
	Accumulated depreciation	(27)		(16)
	Property and equipment, net	$	114	$	108

Total lease right-of-use assets		$	492	$	574

Liabilities
Operating lease liabilities
Current	Other current liabilities	$	78	$	94
Noncurrent	Long-term operating lease liabilities	317		387
Total operating lease liabilities		$	395	$	481

Finance lease liabilities (1)
Current	Short-term debt	$	11	$	18
Noncurrent	Other long-term debt, net	70		49
Total finance lease liabilities		$	81	$	67

Total lease liabilities		$	476	$	548

Schedule of Finance Lease Maturity


	Operating		Finance (2)
Future minimum lease payments (1):
2021	$	90	$	18
2022	82		18
2023	62		15
2024	49		14
2025	38		11
Thereafter	237		67
Total	558		143
Less: Present value discount	(163)		(62)
Lease liabilities	$	395	$	81

(1)Excludes future minimum payments for short-term and other immaterial leases not included on our Consolidated Balance Sheet.

Schedule of Operating Lease Maturity


	Operating		Finance (2)
Future minimum lease payments (1):
2021	$	90	$	18
2022	82		18
2023	62		15
2024	49		14
2025	38		11
Thereafter	237		67
Total	558		143
Less: Present value discount	(163)		(62)
Lease liabilities	$	395	$	81

(1)Excludes future minimum payments for short-term and other immaterial leases not included on our Consolidated Balance Sheet.

Schedule of Lessor Future Revenues Maturity

The following table presents the undiscounted cash flows expected to be received related to these agreements (in millions):


	2021		2022		2023		2024		2025		Thereafter
Lease revenue	$	40	$	27	$	22	$	18	$	16	$	205

Income Taxes (Tables)

12 Months Ended

Dec. 31, 2020

Income Tax Disclosure [Abstract]

Components of income tax expense

Components of income tax expense are as follows (in millions):


	Year Ended December 31,
	2020		2019		2018
Current income tax expense:
State income tax	$	—	$	3	$	3
Canadian federal and provincial income tax	51		109		63
Total current income tax expense	$	51	$	112	$	66

Deferred income tax expense/(benefit):
Federal income tax	$	(149)	$	89	$	90
State income tax	1		21		14
Canadian federal and provincial income tax	(70)		(46)		132
Total deferred income tax expense/(benefit)	$	(218)	$	64	$	236
Total income tax expense/(benefit)	$	(167)	$	176	$	302

Summary of differences between income tax expense based on the statutory federal income tax rate and the effective income tax expense

The difference between income tax expense based on the statutory federal income tax rate and our effective income tax expense is summarized as follows (in millions):


	Year Ended December 31,
	2020			2019			2018
Income/(loss) before tax	$	(2,607)		$	2,238		$	2,409
Net (income)/loss attributable to noncontrolling interests	1,872			(1,731)			(1,773)
Income taxes attributable to noncontrolling interests	19			(66)			(198)
	$	(716)		$	441		$	438
Federal statutory income tax rate	21		%	21		%	21		%
Income tax expense/(benefit) at statutory rate	$	(150)		$	93		$	92


Deferred tax rate adjustment	11			10			3
State income tax, net of federal benefit	(9)			7			9
Income taxes attributable to noncontrolling interests:
Canadian federal and provincial income tax	(19)			63			195

State income tax	—			3			3
Total income tax expense/(benefit)	$	(167)		$	176		$	302

Deferred tax assets and liabilities

Deferred tax assets and liabilities are aggregated by the applicable tax paying entity and jurisdiction and result from the following (in millions):


	December 31,
	2020		2019
Deferred tax assets:
Investment in partnerships	$	917	$	874
Net operating losses	527		406
Derivative instruments	45		—
Lease liabilities	39		55
Other	16		16
Total deferred tax assets	1,544		1,351

Deferred tax liabilities:
Property and equipment in excess of tax values	(475)		(472)
Derivative instruments	—		(22)
Lease assets	(38)		(53)
Other	(3)		(5)
Total deferred tax liabilities	(516)		(552)
Net deferred tax assets	$	1,028	$	799

Balance sheet classification of deferred tax assets/(liabilities):
Deferred tax asset	$	1,444	$	1,280
Other long-term liabilities and deferred credits	(416)		(481)
	$	1,028	$	799

Related Party Transactions (Tables)

12 Months Ended

Dec. 31, 2020

Schedule of related party transactions

The impact to our Consolidated Statements of Operations from these transactions is included below (in millions):


	Year Ended December 31,
	2020		2019		2018



Revenues from related parties (1)	$	46	$	692	$	1,067




Purchases and related costs from related parties (1)	$	451	$	223	$	410

Our receivable and payable amounts with these related parties as reflected on our Consolidated Balance Sheets were as follows (in millions):


	December 31,
	2020		2019



Trade accounts receivable and other receivables, net from related parties (1)	$	34	$	134




Trade accounts payable to related parties (1) (2)	$	88	$	102

Equity-Indexed Compensation Plans (Tables)

12 Months Ended

Dec. 31, 2020

Share-based Payment Arrangement [Abstract]

Summary of LTIP awards authorized

The following is a summary of the awards authorized under our LTIPs as of December 31, 2020 (in millions):


LTIP						LTIP Awards Authorized
Plains GP Holdings, L.P. Long-Term Incentive Plan						3.8
Plains All American 2013 Long-Term Incentive Plan						13.1
Plains All American PNG Successor Long-Term Incentive Plan						1.3
Plains All American GP LLC 2006 Long-Term Incentive Tracking Unit Plan						10.8
Total (1)						29.0

(1)Of the 29.0 million total awards authorized, 5.6 million awards are currently available. The remaining balance has already vested or is currently outstanding.

Commitments and Contingencies (Tables)

12 Months Ended

Dec. 31, 2020

Commitments and Contingencies Disclosure [Abstract]

Schedule of future non-cancelable commitments


	2021		2022		2023		2024		2025		Thereafter		Total
Leases (1)	$	108	$	100	$	77	$	63	$	49	$	304	$	701
Other commitments (2)	312		303		285		278		252		763		2,193
Total	$	420	$	403	$	362	$	341	$	301	$	1,067	$	2,894

Quarterly Financial Data (Unaudited) (Tables)

12 Months Ended

Dec. 31, 2020

Quarterly Financial Information Disclosure [Abstract]

Quarterly financial data (unaudited)


	First Quarter		Second Quarter		Third Quarter		Fourth Quarter		Total (1)

	(in millions, except per share data)
2020
Total revenues	$	8,269	$	3,225	$	5,833	$	5,963	$	23,290
Gross margin (2)	$	(190)	$	282	$	313	$	4	$	408
Operating income/(loss)	$	(2,775)	$	208	$	251	$	(67)	$	(2,383)
Net income/(loss)	$	(2,692)	$	137	$	139	$	(23)	$	(2,440)
Net income/(loss) attributable to PAGP	$	(581)	$	16	$	17	$	(20)	$	(568)
Basic net income/(loss) per Class A share	$	(3.18)	$	0.09	$	0.09	$	(0.11)	$	(3.06)
Diluted net income/(loss) per Class A share	$	(3.18)	$	0.09	$	0.09	$	(0.11)	$	(3.07)
Cash distributions per Class A share (3)	$	0.36	$	0.18	$	0.18	$	0.18	$	0.90
			0
2019
Total revenues	$	8,375	$	8,253	$	7,886	$	9,154	$	33,669
Gross margin (2)	$	790	$	525	$	565	$	402	$	2,282
Operating income	$	713	$	449	$	490	$	329	$	1,980
Net income	$	914	$	426	$	431	$	291	$	2,062
Net income attributable to PAGP	$	147	$	66	$	70	$	48	$	331
Basic net income per Class A share	$	0.92	$	0.41	$	0.41	$	0.26	$	1.97
Diluted net income per Class A share	$	0.92	$	0.40	$	0.41	$	0.26	$	1.96
Cash distributions per Class A share (3)	$	0.30	$	0.36	$	0.36	$	0.36	$	1.38

(1)The sum of the four quarters may not equal the total year due to rounding.

(3)Represents cash distributions declared and paid in the period presented.

Operating Segments (Tables)

12 Months Ended

Dec. 31, 2020

Segment Reporting [Abstract]

Segment financial data

The following tables reflect certain financial data for each segment (in millions):


	Transportation		Facilities		Supply and Logistics		Intersegment Adjustment		Total
Year Ended December 31, 2020
Revenues:
External customers (1)	$	1,016	$	622	$	22,058	$	(406)	$	23,290
Intersegment (2)	1,004		516		1		406		1,927
Total revenues of reportable segments	$	2,020	$	1,138	$	22,059	$	—	$	25,217
Equity earnings in unconsolidated entities	$	350	$	5	$	—			$	355
Segment Adjusted EBITDA	$	1,616	$	731	$	210			$	2,557
Investment and acquisition capital (3)	$	981	$	173	$	77			$	1,231
Maintenance capital	$	136	$	51	$	29			$	216

As of December 31, 2020
Total assets	$	14,416	$	6,165	$	5,370			$	25,951
Investments in unconsolidated entities	$	3,642	$	122	$	—			$	3,764


	Transportation		Facilities		Supply and Logistics		Intersegment Adjustment		Total
Year Ended December 31, 2019
Revenues:
External customers (1)	$	1,259	$	609	$	32,272	$	(471)	$	33,669
Intersegment (2)	1,061		562		4		471		2,098
Total revenues of reportable segments	$	2,320	$	1,171	$	32,276	$	—	$	35,767
Equity earnings in unconsolidated entities	$	388	$	—	$	—			$	388
Segment Adjusted EBITDA	$	1,722	$	705	$	803			$	3,230
Investment and acquisition capital (3)	$	1,127	$	227	$	33			$	1,387
Maintenance capital	$	161	$	97	$	29			$	287

As of December 31, 2019
Total assets	$	15,549	$	7,593	$	6,827			$	29,969
Investments in unconsolidated entities	$	3,557	$	126	$	—			$	3,683


	Transportation		Facilities		Supply and Logistics		Intersegment Adjustment		Total
Year Ended December 31, 2018
Revenues:
External customers (1)	$	1,116	$	588	$	32,819	$	(468)	$	34,055
Intersegment (2)	874		573		3		468		1,918
Total revenues of reportable segments	$	1,990	$	1,161	$	32,822	$	—	$	35,973
Equity earnings in unconsolidated entities	$	375	$	—	$	—			$	375
Segment Adjusted EBITDA	$	1,508	$	711	$	462			$	2,681
Investment and acquisition capital (3)	$	1,631	$	234	$	23			$	1,888
Maintenance capital	$	139	$	100	$	13			$	252

As of December 31, 2018
Total assets	$	13,947	$	7,464	$	5,419			$	26,830
Investments in unconsolidated entities	$	2,594	$	108	$	—			$	2,702

(3)Investment and acquisition capital expenditures, including investments in unconsolidated entities.

Reconciliation of Segment Adjusted EBITDA to net income attributable to PAGP

The following table reconciles Segment Adjusted EBITDA to Net income/(loss) attributable to PAGP (in millions):


	Year Ended December 31,
	2020		2019		2018
Segment Adjusted EBITDA	$	2,557	$	3,230	$	2,681
Adjustments (1):
Depreciation and amortization of unconsolidated entities (2)	(73)		(62)		(56)
Gains/(losses) from derivative activities, net of inventory valuation adjustments (3)	(480)		(160)		519
Long-term inventory costing adjustments (4)	(44)		20		(21)
Deficiencies under minimum volume commitments, net (5)	(74)		18		(7)
Equity-indexed compensation expense (6)	(19)		(17)		(55)
Net gain/(loss) on foreign currency revaluation (7)	3		(14)		(3)
Line 901 incident (8)	—		(10)		—
Significant acquisition-related expenses (9)	(3)		—		—
Unallocated general and administrative expenses	(5)		(5)		(4)
Depreciation and amortization	(656)		(604)		(521)
Gains/(losses) on asset sales and asset impairments, net	(719)		(28)		114
Goodwill impairment losses	(2,515)		—		—
Gain on/(impairment of) investments in unconsolidated entities, net	(182)		271		200
Interest expense, net	(436)		(425)		(431)
Other income/(expense), net	39		24		(7)
Income/(loss) before tax	(2,607)		2,238		2,409
Income tax (expense)/benefit	167		(176)		(302)
Net income/(loss)	(2,440)		2,062		2,107
Net (income)/loss attributable to noncontrolling interests	1,872		(1,731)		(1,773)
Net income/(loss) attributable to PAGP	$	(568)	$	331	$	334

(1)Represents adjustments utilized by our CODM in the evaluation of segment results.

(2)Includes our proportionate share of the depreciation and amortization of unconsolidated entities.

(6)Includes equity-indexed compensation expense associated with awards that will or may be settled in units.

(7)Includes gains and losses realized on the settlement of foreign currency transactions as well as the revaluation of monetary assets and liabilities denominated in a foreign currency.

Revenues attributable to geographic areas

We have operations in the United States and Canada. Set forth below are revenues and long-lived assets attributable to these geographic areas (in millions):


	Year Ended December 31,
Revenues (1)	2020		2019		2018
United States	$	17,942	$	27,162	$	28,362
Canada	5,348		6,507		5,693
	$	23,290	$	33,669	$	34,055

(1)Revenues are primarily attributed to each region based on where the services are provided or the product is shipped

Long-lived assets attributable to geographic areas


	December 31,
Long-Lived Assets (1)	2020		2019
United States	$	16,896	$	17,577
Canada	3,892		3,935
	$	20,788	$	21,512

(1)Excludes long-term derivative assets, long-term deferred tax assets and goodwill.

Organization and Basis of Consolidation and Presentation (Details) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2020 USD ($) segment shares	Dec. 31, 2019 USD ($)
Organization and basis of presentation
Operating segments number \| segment	3
Deferred tax asset \| $	$ 1,444	$ 1,280
Consolidated Entity Excluding VIE
Organization and basis of presentation
Deferred tax asset \| $	$ 1,444	$ 1,280
AAP
Organization and basis of presentation
Consolidated subsidiary, ownership interest (as a percent)	79.00%
Consolidated subsidiary, ownership interest (in units)	193.1
AAP \| GP LLC
Organization and basis of presentation
Consolidated subsidiary, ownership interest (in units)	1.0
PAA \| AAP
Organization and basis of presentation
Consolidated subsidiary, ownership interest (as a percent)	31.00%
Consolidated subsidiary, ownership interest (in units)	245.8
GP LLC
Organization and basis of presentation
Consolidated subsidiary, ownership interest (as a percent)	100.00%

Summary of Significant Accounting Policies - Various Policies (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Foreign Currency Transactions/Translation
Gain on revaluation of foreign currency transactions and monetary assets and liabilities	$ 16	$ 1	$ 1
Cash and Cash Equivalents and Restricted Cash
Outstanding checks included in accounts payable that were reclassified from cash and cash equivalents	$ 27	$ 39

Summary of Significant Accounting Policies - Cash and Restricted Cash (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Accounting Policies [Abstract]
Cash and cash equivalents	$ 25	$ 47
Restricted cash	38	37
Total cash and cash equivalents and restricted cash	$ 63	$ 84	$ 69	$ 40

Summary of Significant Accounting Policies - Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance	$ 137	$ 109	$ 103
Liabilities incurred	12	3	3
Liabilities settled	(1)	(3)	(3)
Accretion expense	5	5	4
Revisions in estimated cash flows	(18)	23	2
Ending balance	$ 135	$ 137	$ 109

Revenues and Accounts Receivable - Disaggregation of Revenue (Details) - Operating Segments - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	$ 25,455	$ 35,371	$ 35,812
Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	22,351	31,966	32,700
Supply and Logistics \| Crude oil transactions
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	21,202	30,082	29,592
Supply and Logistics \| NGL and other transactions
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,149	1,884	3,108
Transportation
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	2,005	2,283	1,976
Transportation \| Total tariff activities
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,906	2,138	1,827
Transportation \| Crude oil pipelines
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,805	2,039	1,724
Transportation \| NGL pipelines
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	101	99	103
Transportation \| Trucking
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	99	145	149
Facilities
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,099	1,122	1,136
Facilities \| Crude oil, NGL and other terminalling and storage
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	704	697	688
Facilities \| NGL and natural gas processing and fractionation
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	350	349	364
Facilities \| Rail load / unload
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	$ 45	$ 76	$ 84

Revenues and Accounts Receivable - Agreement Balances (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Contract With Customer, Asset And Liability [Line Items]
Other current assets	$ 405	$ 312
Contract liability, deferred revenue	501	354	$ 338
Crude Oil Sales Agreements Entered Into In Conjunction WIth Storage Arrangements And Future Inventory Exchanges
Contract With Customer, Asset And Liability [Line Items]
Other current assets	229	142
Contract liability, deferred revenue	$ 361	$ 155

Revenues and Accounts Receivable - Segment Revenue (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2020	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Disaggregation of Revenue [Line Items]
Total revenues	$ 5,963	$ 5,833	$ 3,225	$ 8,269	$ 9,154	$ 7,886	$ 8,253	$ 8,375	$ 23,290	$ 33,669	$ 34,055
Transportation
Disaggregation of Revenue [Line Items]
Total revenues									610	788	648
Facilities
Disaggregation of Revenue [Line Items]
Total revenues									622	609	588
Supply and Logistics
Disaggregation of Revenue [Line Items]
Total revenues									22,058	32,272	32,819
Operating Segments
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									25,455	35,371	35,812
Total revenues									25,217	35,767	35,973
Operating Segments \| Transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									2,005	2,283	1,976
Total revenues									2,020	2,320	1,990
Operating Segments \| Facilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									1,099	1,122	1,136
Total revenues									1,138	1,171	1,161
Operating Segments \| Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									22,351	31,966	32,700
Total revenues									22,059	32,276	32,822
Intersegment
Disaggregation of Revenue [Line Items]
Total revenues									(1,927)	(2,098)	(1,918)
Intersegment \| Transportation
Disaggregation of Revenue [Line Items]
Total revenues									(1,004)	(1,061)	(874)
Intersegment \| Facilities
Disaggregation of Revenue [Line Items]
Total revenues									(516)	(562)	(573)
Intersegment \| Supply and Logistics
Disaggregation of Revenue [Line Items]
Total revenues									(1)	(4)	(3)
Other \| Operating Segments
Disaggregation of Revenue [Line Items]
Total revenues									(238)	396	161
Other \| Operating Segments \| Transportation
Disaggregation of Revenue [Line Items]
Total revenues									15	37	14
Other \| Operating Segments \| Facilities
Disaggregation of Revenue [Line Items]
Total revenues									39	49	25
Other \| Operating Segments \| Supply and Logistics
Disaggregation of Revenue [Line Items]
Total revenues									$ (292)	$ 310	$ 122

- Definition

Amount, excluding tax collected from customer, of revenue from satisfaction of performance obligation by transferring promised good or service to customer. Tax collected from customer is tax assessed by governmental authority that is both imposed on and concurrent with specific revenue-producing transaction, including, but not limited to, sales, use, value added and excise.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 30
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8906-108599

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 40
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e9031-108599

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 41
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e9038-108599

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 32
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8933-108599

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 32
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8933-108599

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 4
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=121604090&loc=SL49130543-203045

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 22
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8736-108599

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 22
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8736-108599

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 42
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e9054-108599

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 5
-URI http://asc.fasb.org/extlink&oid=121604090&loc=SL49130545-203045

Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 924
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SAB Topic 11.L)
-URI http://asc.fasb.org/extlink&oid=6472922&loc=d3e499488-122856

+ Details

- Definition

Amount of revenue recognized from goods sold, services rendered, insurance premiums, or other activities that constitute an earning process. Includes, but is not limited to, investment and interest income before deduction of interest expense when recognized as a component of revenue, and sales and trading gain (loss).

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 22
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8736-108599

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 323
-SubTopic 10
-Section 50
-Paragraph 3
-Subparagraph (c)
-URI http://asc.fasb.org/extlink&oid=114001798&loc=d3e33918-111571

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 50
-Paragraph 28
-Subparagraph (f)
-URI http://asc.fasb.org/extlink&oid=75031198&loc=d3e14064-108612

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 32
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8933-108599

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 32
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8933-108599

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 22
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8736-108599

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 40
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e9031-108599

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 30
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8906-108599

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 41
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e9038-108599

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 42
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e9054-108599

Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08(g)(1)(ii))
-URI http://asc.fasb.org/extlink&oid=120395691&loc=d3e23780-122690

Reference 12: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 942
-SubTopic 235
-Section S99
-Paragraph 1
-Subparagraph (SX 210.9-05(b)(2))
-URI http://asc.fasb.org/extlink&oid=120399901&loc=d3e537907-122884

Reference 13: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section S99
-Paragraph 2
-Subparagraph (SX 210.5-03(1))
-URI http://asc.fasb.org/extlink&oid=120395209&loc=SL114868664-224227

+ Details

Revenues and Accounts Receivable - Counterparty Deficiencies (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Contract With Customer, Asset And Liability [Line Items]
Contract liability, deferred revenue	$ 501	$ 354	$ 338
Minimum Volume Commitments
Contract With Customer, Asset And Liability [Line Items]
Contract liability, deferred revenue	73	22
Counterparty deficiencies unbilled and uncollected	4	20
Counterparty deficiencies	$ 77	$ 42

Revenues and Accounts Receivable - Contract Balances (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Change in Contract Liabilities [Roll Forward]
Beginning balance	$ 354	$ 338
Amounts recognized as revenue	(246)	(227)
Additions	393	244
Other		(1)
Ending balance	501	354
Crude Oil Sales Agreements Entered Into In Conjunction WIth Storage Arrangements And Future Inventory Exchanges
Change in Contract Liabilities [Roll Forward]
Beginning balance	155
Additions	361	155
Ending balance	$ 361	$ 155

Revenues and Accounts Receivable - Narrative (Details)	12 Months Ended
Revenues and Accounts Receivable - Narrative (Details)	Dec. 31, 2020	Dec. 31, 2019
Revenue from Contract with Customer [Abstract]
General payment terms	30 days
Substantially all trade accounts receivable, net, maximum age of balances past their scheduled invoice date	30 days	30 days

Revenues and Accounts Receivable - Contract Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Revenue from Contract with Customer [Abstract]
Trade accounts receivable arising from revenues from contracts with customers	$ 2,317	$ 3,381
Other trade accounts receivables and other receivables	2,818	3,576
Impact due to contractual rights of offset with counterparties	(2,582)	(3,343)
Trade accounts receivable and other receivables, net	$ 2,553	$ 3,614

Net Income/(Loss) Per Class A Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2020	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Basic Net Income/(Loss) per Class A Share
Net income/(loss) attributable to PAGP	$ (20)	$ 17	$ 16	$ (581)	$ 48	$ 70	$ 66	$ 147	$ (568)	$ 331	$ 334
Diluted Net Income/(Loss) per Class A Share
Net income attributable to PAGP	$ (20)	$ 17	$ 16	$ (581)	$ 48	$ 70	$ 66	$ 147	(568)	331	334
Incremental net income/(loss) attributable to PAGP resulting from assumed exchange of AAP units and AAP Management Units									(189)	2	262
Net income/(loss) attributable to PAGP including incremental net income/(loss) from assumed exchange of AAP units and AAP Management Units									$ (757)	$ 333	$ 596
AAP Units
Basic and diluted earnings per share
Antidilutive securities excluded from computation of earnings per share (per share)										99.0
AAP Management Units
Basic and diluted earnings per share
Antidilutive securities excluded from computation of earnings per share (per share)									1.0
Class A Shares
Basic Net Income/(Loss) per Class A Share
Basic weighted average Class A shares outstanding (in shares)									186.0	168.0	158.0
Basic net income/(loss) per Class A share (in dollars per share)	$ (0.11)	$ 0.09	$ 0.09	$ (3.18)	$ 0.26	$ 0.41	$ 0.41	$ 0.92	$ (3.06)	$ 1.97	$ 2.12
Diluted Net Income/(Loss) per Class A Share
Basic weighted average Class A shares outstanding (in shares)									186.0	168.0	158.0
Dilutive shares resulting from assumed exchange of AAP units and AAP Management Units (in shares)									60.0	2.0	124.0
Diluted weighted average Class A shares outstanding (in shares)									246.0	170.0	282.0
Diluted net income/(loss) per Class A share (in dollars per share)	$ (0.11)	$ 0.09	$ 0.09	$ (3.18)	$ 0.26	$ 0.41	$ 0.40	$ 0.92	$ (3.07)	$ 1.96	$ 2.11
Maximum
Basic and diluted earnings per share
Dilutive awards (less than) (in shares)										0.1	0.1

Inventory, Linefill and Base Gas and Long-term Inventory (Details) bbl in Thousands, Mcf in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2020 USD ($) $ / bbl $ / Mcf bbl Mcf	Dec. 31, 2019 USD ($) $ / bbl $ / Mcf bbl Mcf	Dec. 31, 2018 USD ($)
Inventory-related disclosures
Charge related to the write-down of inventory	$ 233	$ 11	$ 8
Charge related to the write-down of inventory, long-term inventory	40
Inventory by category
Inventory	647	604
Linefill and base gas	982	981
Long-term inventory	130	182
Total	$ 1,759	$ 1,767
Crude oil
Inventory by category
Inventory, Volumes (in barrels or in Mcf) \| bbl	13,450	8,613
Linefill and base gas, Volumes (in barrels or in Mcf) \| bbl	14,669	14,316
Long-term inventory, Volumes (in barrels or in Mcf) \| bbl	2,499	2,598
Inventory	$ 441	$ 450
Linefill and base gas	828	826
Long-term inventory	$ 111	$ 152
Inventory, Price/Unit of measure (in dollars per unit) \| $ / bbl	32.79	52.25
Linefill and base gas, Price/Unit of measure (in dollars per unit) \| $ / bbl	56.45	57.70
Long-term inventory, Price/Unit of measure (in dollars per unit) \| $ / bbl	44.42	58.51
NGL
Inventory by category
Inventory, Volumes (in barrels or in Mcf) \| bbl	12,302	7,574
Linefill and base gas, Volumes (in barrels or in Mcf) \| bbl	1,640	1,701
Long-term inventory, Volumes (in barrels or in Mcf) \| bbl	1,185	1,707
Inventory	$ 199	$ 142
Linefill and base gas	44	47
Long-term inventory	$ 19	$ 30
Inventory, Price/Unit of measure (in dollars per unit) \| $ / bbl	16.18	18.75
Linefill and base gas, Price/Unit of measure (in dollars per unit) \| $ / bbl	26.83	27.63
Long-term inventory, Price/Unit of measure (in dollars per unit) \| $ / bbl	16.03	17.57
Natural gas
Inventory by category
Linefill and base gas, Volumes (in barrels or in Mcf) \| Mcf	25,576	24,976
Linefill and base gas	$ 110	$ 108
Linefill and base gas, Price/Unit of measure (in dollars per unit) \| $ / Mcf	4.30	4.32
Other
Inventory by category
Inventory	$ 7	$ 12

Property and Equipment (Details) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
Property and Equipment (Details) - USD ($) $ in Millions	Dec. 31, 2020	Mar. 31, 2020	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Property and Equipment
Capitalized interest			$ 24	$ 34	$ 30
Property and equipment, gross	$ 18,620		18,620	18,983
Accumulated depreciation	(4,000)		(4,000)	(3,616)
Property and equipment, net	14,620		14,620	15,367
Depreciation expense			566	528	455
Construction in progress expenditures incurred but not yet paid			$ 51	120	206
Level 3 \| Measurement Input, Discount Rate \| Valuation Technique, Discounted Cash Flow
Property and Equipment
Discount rate, asset impairment analysis, cost of capital, theoretical market participant			14.00%
Pipelines and related facilities
Property and Equipment
Property and equipment, gross	11,147		$ 11,147	11,149
Pipelines and related facilities \| Minimum
Property and Equipment
Estimated useful lives			10 years
Pipelines and related facilities \| Maximum
Property and Equipment
Estimated useful lives			70 years
Storage, terminal and rail facilities
Property and Equipment
Property and equipment, gross	6,042		$ 6,042	6,134
Storage, terminal and rail facilities \| Minimum
Property and Equipment
Estimated useful lives			10 years
Storage, terminal and rail facilities \| Maximum
Property and Equipment
Estimated useful lives			70 years
Trucking equipment and other
Property and Equipment
Property and equipment, gross	524		$ 524	486
Trucking equipment and other \| Minimum
Property and Equipment
Estimated useful lives			2 years
Trucking equipment and other \| Maximum
Property and Equipment
Estimated useful lives			15 years
Construction in progress
Property and Equipment
Property and equipment, gross	272		$ 272	518
Office property and equipment
Property and Equipment
Property and equipment, gross	293		$ 293	269
Office property and equipment \| Minimum
Property and Equipment
Estimated useful lives			2 years
Office property and equipment \| Maximum
Property and Equipment
Estimated useful lives			50 years
Land and other
Property and Equipment
Property and equipment, gross	342		$ 342	427
Transportation \| Pipelines and related facilities
Property and Equipment
Non-cash impairment losses, long-lived assets			415
Property and equipment
Property and Equipment
Capitalized interest			8	$ 14	$ 21
(Gains)/losses on asset sales and asset impairments, net
Property and Equipment
Non-cash impairment losses, long-lived assets	$ 95	$ 446	$ 541

Acquisitions and Divestitures - Acquisitions (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended	12 Months Ended
	Feb. 29, 2020	Jun. 30, 2019	Dec. 31, 2020	Dec. 31, 2019
Business Acquisition [Line Items]
Payments to acquire businesses			$ 310	$ 50
Crude Oil Terminal
Business Acquisition [Line Items]
Cash consideration		$ 44
Felix Midstream LLC
Business Acquisition [Line Items]
Payments to acquire businesses	$ 300
FM Gathering LLC
Business Acquisition [Line Items]
Property and equipment acquired			115
Intangible assets acquired			$ 187
FM Gathering LLC \| Minimum \| Level 3 \| Measurement Input, Discount Rate \| Valuation Technique, Discounted Cash Flow
Business Acquisition [Line Items]
Intangible assets, estimate of risk, theoretical market participant			18.00%
FM Gathering LLC \| Maximum \| Level 3 \| Measurement Input, Discount Rate \| Valuation Technique, Discounted Cash Flow
Business Acquisition [Line Items]
Intangible assets, estimate of risk, theoretical market participant			19.00%

Acquisitions and Divestitures - Divestitures (Details) - USD ($) $ in Millions	1 Months Ended	9 Months Ended	12 Months Ended
	Feb. 29, 2020	Sep. 30, 2018	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Divestitures
Proceeds from sales of assets			$ 429	$ 77	$ 1,334
Gains/(losses) on asset sales and asset impairments, net			(719)	(28)	114
(Gains)/losses on asset sales and asset impairments, net
Divestitures
Gains/(losses) on asset sales and asset impairments, net			178
Disposed of by sale
Divestitures
Proceeds from sales of assets				77
Proceeds from sale, including proceeds attributable to agreements entered into in conjunction with sale of productive assets			451
Disposed of by sale \| (Gains)/losses on asset sales and asset impairments, net
Divestitures
Recognized gains/(losses) related to sale of assets, net				16	120
Recognized gains related to sale of assets				31	146
Recognized losses related to sales of assets				$ 47	$ 26
Los Angeles Basin Crude Oil Terminals \| Disposed of by sale \| Facilities
Divestitures
Proceeds from sales of assets			200
NGL Terminals \| Disposed of by sale
Divestitures
Proceeds attributable to multi-year supply agreement entered into in conjunction with sale of assets			22
NGL Terminals \| Disposed of by sale \| Facilities
Divestitures
Proceeds from sale, including proceeds attributable to agreements entered into in conjunction with sale of productive assets			$ 163
Saddlehorn
Divestitures
Ownership percentage sold	10.00%		10.00%
Proceeds from sale of equity method investments	$ 78		$ 78
BridgeTex Pipeline Company, LLC (“BridgeTex”)
Divestitures
Ownership percentage sold		30.00%			30.00%
Proceeds from sale of equity method investments		$ 868			$ 868
Gain on sale of investment in unconsolidated entities		$ 200			$ 200

Goodwill (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
Goodwill (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Changes in goodwill
Balance at beginning of period	$ 2,540	$ 2,540	$ 2,521
Foreign currency translation adjustments			19
Acquisitions		2
Goodwill, gross		2,542
Impairment	$ (2,515)	(2,515)	0	$ 0
Foreign currency translation adjustments		(27)
Accumulated impairment losses		(2,542)
Balance at end of period		0	2,540	2,521
Level 3 \| Valuation Technique, Discounted Cash Flow
Goodwill disclosures
Goodwill impairment analysis, projected cash flows, period	6 years
Level 3 \| Measurement Input, Discount Rate \| Valuation Technique, Discounted Cash Flow
Goodwill disclosures
Goodwill impairment analysis, discount rate, cost of capital, theoretical market participant	14.00%
Operating Segments \| Transportation
Changes in goodwill
Balance at beginning of period	$ 1,052	1,052	1,040
Foreign currency translation adjustments			12
Acquisitions		2
Goodwill, gross		1,054
Impairment		(1,038)
Foreign currency translation adjustments		(16)
Accumulated impairment losses		(1,054)
Balance at end of period		0	1,052	1,040
Operating Segments \| Facilities
Changes in goodwill
Balance at beginning of period	982	982	978
Foreign currency translation adjustments			4
Acquisitions		0
Goodwill, gross		982
Impairment		(975)
Foreign currency translation adjustments		(7)
Accumulated impairment losses		(982)
Balance at end of period		0	982	978
Operating Segments \| Supply and Logistics
Changes in goodwill
Balance at beginning of period	$ 506	506	503
Foreign currency translation adjustments			3
Acquisitions		0
Goodwill, gross		506
Impairment		(502)
Foreign currency translation adjustments		(4)
Accumulated impairment losses		(506)
Balance at end of period		$ 0	$ 506	$ 503

Investments in Unconsolidated Entities - Equity Method Investments (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended					9 Months Ended	12 Months Ended
	Feb. 29, 2020	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Mar. 31, 2019	Jun. 30, 2018	Sep. 30, 2018	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Investments in Unconsolidated Entities
Investments in unconsolidated entities								$ 3,764	$ 3,683	$ 2,702
Carrying value of undivided joint interest								14,620	15,367
Advance cash payment, pipeline capacity agreements								501	354	338
Capital contributions to equity method investees excluding capitalized interest								445	504	459
Capitalized interest related to contributions to unconsolidated entities								24	34	30
Amount by which investments in unconsolidated entities exceeded our share of the underlying equity in the net assets								$ 170	349
Level 3 \| Measurement Input, Discount Rate \| Valuation Technique, Discounted Cash Flow
Investments in Unconsolidated Entities
Discount rate, asset impairment analysis, cost of capital, theoretical market participant								14.00%
Gain on/(impairment of) investments in unconsolidated entities, net
Investments in Unconsolidated Entities
Write down of investments		$ 91	$ 69	$ 43
BridgeTex Pipeline Company, LLC (“BridgeTex”)
Investments in Unconsolidated Entities
Ownership interest in unconsolidated entity							20.00%	20.00%
Investments in unconsolidated entities								$ 421	431
Proceeds from sale of equity method investment							$ 868			$ 868
Ownership percentage sold							30.00%			30.00%
Gain on sale of investment in unconsolidated entities							$ 200			$ 200
Cactus II Pipeline LLC (“Cactus II”)
Investments in Unconsolidated Entities
Ownership interest in unconsolidated entity								65.00%
Investments in unconsolidated entities								$ 752	738
Reduction of property and equipment from deconsolidation						$ 74
Proceeds from sale of equity method investment						$ 26
Capline Pipeline Company LLC
Investments in Unconsolidated Entities
Ownership interest in unconsolidated entity								54.00%
Investments in unconsolidated entities								$ 514	484
Fair value of investment in unconsolidated entity					$ 444
Capline Pipeline Company LLC \| Gain on/(impairment of) investments in unconsolidated entities, net
Investments in Unconsolidated Entities
Gain from remeasurement to fair value of retained investment		2		267					269
Diamond Pipeline LLC (“Diamond”)
Investments in Unconsolidated Entities
Ownership interest in unconsolidated entity								50.00%
Investments in unconsolidated entities								$ 480	476
Eagle Ford Pipeline LLC (“Eagle Ford Pipeline”)
Investments in Unconsolidated Entities
Ownership interest in unconsolidated entity								50.00%
Investments in unconsolidated entities								$ 372	382
Eagle Ford Terminals Corpus Christi LLC (“Eagle Ford Terminals”)
Investments in Unconsolidated Entities
Ownership interest in unconsolidated entity								50.00%
Investments in unconsolidated entities								$ 122	126
Red Oak Pipeline LLC (“Red Oak”)
Investments in Unconsolidated Entities
Ownership interest in unconsolidated entity			50.00%					50.00%
Investments in unconsolidated entities								$ 35	20
Write down of investments			$ 69
Saddlehorn
Investments in Unconsolidated Entities
Ownership interest in unconsolidated entity	30.00%							30.00%
Investments in unconsolidated entities								$ 208	234
Proceeds from sale of equity method investment	$ 78							$ 78
Ownership percentage sold	10.00%							10.00%
Saddlehorn \| Gain on/(impairment of) investments in unconsolidated entities, net
Investments in Unconsolidated Entities
Gain on sale of investment in unconsolidated entities	$ 21
STACK Pipeline LLC (“STACK”)
Investments in Unconsolidated Entities
Ownership interest in unconsolidated entity								50.00%
Investments in unconsolidated entities								$ 22	117
Write down of investments		$ 91
STACK Pipeline LLC (“STACK”) \| Level 3 \| Measurement Input, Discount Rate \| Valuation Technique, Discounted Cash Flow
Investments in Unconsolidated Entities
Discount rate, asset impairment analysis, cost of capital, theoretical market participant								14.00%
White Cliffs Pipeline, LLC
Investments in Unconsolidated Entities
Ownership interest in unconsolidated entity								36.00%
Investments in unconsolidated entities								$ 192	$ 196
Wink to Webster Pipeline LLC (“W2W Pipeline”)
Investments in Unconsolidated Entities
Ownership interest in unconsolidated entity								16.00%	16.00%
Investments in unconsolidated entities								$ 330	$ 136
Other investments
Investments in Unconsolidated Entities
Investments in unconsolidated entities								316	$ 343
Write down of investments				$ 43
Cushing Connect Pipeline & Terminal LLC
Investments in Unconsolidated Entities
Ownership interest in unconsolidated entity									50.00%
Equity Method Investees
Investments in Unconsolidated Entities
Capitalized interest related to contributions to unconsolidated entities								$ 16	$ 20	$ 9
Capline Pipeline Company LLC \| Capline pipeline system
Investments in Unconsolidated Entities
Percentage of Capline pipeline system owned					100.00%
Oxy \| Cactus II Pipeline LLC (“Cactus II”)
Investments in Unconsolidated Entities
Interest acquired						20.00%
Third Party \| Cactus II Pipeline LLC (“Cactus II”)
Investments in Unconsolidated Entities
Interest acquired						15.00%
Other long-term liabilities and deferred credits \| Cactus II Pipeline LLC (“Cactus II”)
Investments in Unconsolidated Entities
Advance cash payment, pipeline capacity agreements						$ 100
Undivided joint interest in Capline pipeline system
Investments in Unconsolidated Entities
Undivided joint interest ownership percentage					54.00%
Carrying value of undivided joint interest					$ 175
Undivided joint interest in pipeline segment \| Wink to Webster Pipeline LLC (“W2W Pipeline”) \| Midland, Texas to Webster, Texas pipeline segment
Investments in Unconsolidated Entities
Undivided joint interest ownership percentage									71.00%
Undivided joint interest in pipeline segment \| Enterprise Products Partners, L.P. \| Midland, Texas to Webster, Texas pipeline segment
Investments in Unconsolidated Entities
Undivided joint interest ownership percentage									29.00%

Investments in Unconsolidated Entities - Summarized Financial Information (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2020	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Investments in Unconsolidated Entities
Current assets	$ 3,668				$ 4,614				$ 3,668	$ 4,614
Current liabilities	4,255				5,019				4,255	5,019
Noncurrent liabilities	10,506				10,465				10,506	10,465
Revenues	5,963	$ 5,833	$ 3,225	$ 8,269	9,154	$ 7,886	$ 8,253	$ 8,375	23,290	33,669	$ 34,055
Operating income	(67)	$ 251	$ 208	$ (2,775)	329	$ 490	$ 449	$ 713	(2,383)	1,980	2,272
Equity Method Investment, Nonconsolidated Investee
Investments in Unconsolidated Entities
Current assets	580				652				580	652
Noncurrent assets	8,769				7,264				8,769	7,264
Current liabilities	343				298				343	298
Noncurrent liabilities	$ 10				$ 26				10	26
Revenues									1,360	1,469	1,235
Operating income									828	994	824
Net income									$ 826	$ 995	$ 824

- Definition

Sum of the carrying amounts as of the balance sheet date of all assets that are expected to be realized in cash, sold, or consumed within one year (or the normal operating cycle, if longer). Assets are probable future economic benefits obtained or controlled by an entity as a result of past transactions or events.

+ References + Details

- Definition

Sum of the carrying amounts as of the balance sheet date of all assets that are expected to be realized in cash, sold or consumed after one year or beyond the normal operating cycle, if longer.

+ References

+ Details

- Definition

Aggregate revenue less cost of goods and services sold or operating expenses directly attributable to the revenue generation activity.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 323
-SubTopic 10
-Section 50
-Paragraph 3
-Subparagraph (c)
-URI http://asc.fasb.org/extlink&oid=114001798&loc=d3e33918-111571

Reference 2: http://www.xbrl.org/2003/role/exampleRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 31
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8924-108599

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 30
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8906-108599

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08(g)(1)(ii))
-URI http://asc.fasb.org/extlink&oid=120395691&loc=d3e23780-122690

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 22
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8736-108599

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 50
-Paragraph 28
-Subparagraph (f)
-URI http://asc.fasb.org/extlink&oid=75031198&loc=d3e14064-108612

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 32
-Subparagraph (f)
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8933-108599

Reference 8: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section S99
-Paragraph 2
-Subparagraph (SX 210.5-03.1,2)
-URI http://asc.fasb.org/extlink&oid=120395209&loc=SL114868664-224227

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 32
-Subparagraph (c)
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8933-108599

+ Details

- Definition

Total obligations incurred as part of normal operations that are expected to be paid during the following twelve months or within one business cycle, if longer.

+ References + Details

- Definition

Amount of obligation due after one year or beyond the normal operating cycle, if longer.

+ References

Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 201.5-02(25))
-URI http://asc.fasb.org/extlink&oid=120391452&loc=d3e13212-122682

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08(g)(1)(ii))
-URI http://asc.fasb.org/extlink&oid=120395691&loc=d3e23780-122690

Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.5-02(23))
-URI http://asc.fasb.org/extlink&oid=120391452&loc=d3e13212-122682

Reference 4: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.5-02(22))
-URI http://asc.fasb.org/extlink&oid=120391452&loc=d3e13212-122682

Reference 5: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 201.5-02(26))
-URI http://asc.fasb.org/extlink&oid=120391452&loc=d3e13212-122682

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 50
-Paragraph 28
-Subparagraph (f)
-URI http://asc.fasb.org/extlink&oid=75031198&loc=d3e14064-108612

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 50
-Paragraph 3
-Subparagraph (bb)
-URI http://asc.fasb.org/extlink&oid=121559654&loc=d3e5710-111685

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 323
-SubTopic 10
-Section 50
-Paragraph 3
-Subparagraph (c)
-URI http://asc.fasb.org/extlink&oid=114001798&loc=d3e33918-111571

Reference 9: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 201.5-02(24))
-URI http://asc.fasb.org/extlink&oid=120391452&loc=d3e13212-122682

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 50
-Paragraph 3
-Subparagraph (c)
-URI http://asc.fasb.org/extlink&oid=121559654&loc=d3e5710-111685

Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 45
-Paragraph 25
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=116870748&loc=SL6758485-165988

Other Long-Term Assets, Net - Schedule of Other Long-term Assets (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Finite-Lived Intangible Assets
Finite-lived intangible assets, cost	$ 1,354	$ 1,199
Finite-lived intangible assets, accumulated amortization	(549)	(492)
Finite-lived intangible assets, net	805	707
Other Assets, Noncurrent [Abstract]
Other, cost	163	150
Other, accumulated amortization	(3)	(1)
Other, net	160	149
Other long-term assets, cost	1,517	1,349
Other long-term assets, accumulated amortization	(552)	(493)
Other long-term assets, net	965	856
Customer contracts and relationships
Finite-Lived Intangible Assets
Finite-lived intangible assets, cost	1,291	1,134
Finite-lived intangible assets, accumulated amortization	(519)	(463)
Finite-lived intangible assets, net	$ 772	671
Customer contracts and relationships \| Minimum
Finite-Lived Intangible Assets
Estimated Useful Lives	3 years
Customer contracts and relationships \| Maximum
Finite-Lived Intangible Assets
Estimated Useful Lives	29 years
Property tax abatement
Finite-Lived Intangible Assets
Estimated Useful Lives	13 years
Finite-lived intangible assets, cost	$ 23	23
Finite-lived intangible assets, accumulated amortization	(20)	(18)
Finite-lived intangible assets, net	3	5
Other agreements
Finite-Lived Intangible Assets
Finite-lived intangible assets, cost	40	42
Finite-lived intangible assets, accumulated amortization	(10)	(11)
Finite-lived intangible assets, net	$ 30	$ 31
Other agreements \| Minimum
Finite-Lived Intangible Assets
Estimated Useful Lives	1 year
Other agreements \| Maximum
Finite-Lived Intangible Assets
Estimated Useful Lives	70 years

Other Long-Term Assets, Net - Amortization Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Other Assets [Abstract]
Amortization expense for finite-lived intangible assets	$ 90	$ 76	$ 66
Estimated amortization expense related to finite-lived intangible assets for the next five years
2021	87
2022	86
2023	82
2024	80
2025	$ 77

Debt - Components (Details) - USD ($) $ in Millions	12 Months Ended
Debt - Components (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Short-term debt:
Total short-term debt	$ 831	$ 504
Long-term debt:
PAA senior notes, net of unamortized discounts and debt issuance costs	9,071	8,939
Noncurrent portion of other long-term debt	311	248
Total long-term debt	9,382	9,187
Total debt	10,213	9,691
Line of Credit \| PAA commercial paper notes
Short-term debt:
Short-term notes and borrowings	$ 547	$ 93
Weighted average interest rate, short-term	0.70%	2.20%
Line of Credit \| PAA senior secured hedged inventory facility
Short-term debt:
Short-term notes and borrowings	$ 167	$ 325
Weighted average interest rate, short-term	1.20%	2.70%
Other
Short-term debt:
Total short-term debt	$ 117	$ 86
PAA senior notes
Long-term debt:
Unamortized discounts and debt issuance costs	(62)	(61)
PAA senior notes, net of unamortized discounts and debt issuance costs	9,071	8,939
Senior notes repurchase amount	17
Debt instrument face value	9,100	9,000
PAA senior notes \| Other income/(expense), net
Long-term debt:
Gain on repurchase of senior notes	3
PAA senior notes \| Level 2
Long-term debt:
Debt instrument fair value	9,900	9,300
PAA senior notes \| 5.00% senior notes due February 2021
Long-term debt:
Long-term debt, before deducting unamortized discounts and debt issuance costs	$ 0	600
Debt instrument, interest rate (as a percent)	5.00%
PAA senior notes \| 3.65% senior notes due June 2022
Long-term debt:
Long-term debt, before deducting unamortized discounts and debt issuance costs	$ 750	750
Debt instrument, interest rate (as a percent)	3.65%
PAA senior notes \| 2.85% senior notes due January 2023
Long-term debt:
Long-term debt, before deducting unamortized discounts and debt issuance costs	$ 400	400
Debt instrument, interest rate (as a percent)	2.85%
PAA senior notes \| 3.85% senior notes due October 2023
Long-term debt:
Long-term debt, before deducting unamortized discounts and debt issuance costs	$ 700	700
Debt instrument, interest rate (as a percent)	3.85%
PAA senior notes \| 3.60% senior notes due November 2024
Long-term debt:
Long-term debt, before deducting unamortized discounts and debt issuance costs	$ 750	750
Debt instrument, interest rate (as a percent)	3.60%
PAA senior notes \| 4.65% senior notes due October 2025
Long-term debt:
Long-term debt, before deducting unamortized discounts and debt issuance costs	$ 1,000	1,000
Debt instrument, interest rate (as a percent)	4.65%
PAA senior notes \| 4.50% senior notes due December 2026
Long-term debt:
Long-term debt, before deducting unamortized discounts and debt issuance costs	$ 750	750
Debt instrument, interest rate (as a percent)	4.50%
PAA senior notes \| 3.55% senior notes due December 2029
Long-term debt:
Long-term debt, before deducting unamortized discounts and debt issuance costs	$ 1,000	$ 1,000
Debt instrument, interest rate (as a percent)	3.55%	3.55%
Debt instrument face value		$ 1,000
PAA senior notes \| 3.80% senior notes due September 2030
Long-term debt:
Long-term debt, before deducting unamortized discounts and debt issuance costs	$ 750	0
Debt instrument, interest rate (as a percent)	3.80%
Debt instrument face value	$ 750
PAA senior notes \| 6.70% senior notes due May 2036
Long-term debt:
Long-term debt, before deducting unamortized discounts and debt issuance costs	$ 250	250
Debt instrument, interest rate (as a percent)	6.70%
PAA senior notes \| 6.65% senior notes due January 2037
Long-term debt:
Long-term debt, before deducting unamortized discounts and debt issuance costs	$ 600	600
Debt instrument, interest rate (as a percent)	6.65%
PAA senior notes \| 5.15% senior notes due June 2042
Long-term debt:
Long-term debt, before deducting unamortized discounts and debt issuance costs	$ 499	500
Debt instrument, interest rate (as a percent)	5.15%
PAA senior notes \| 4.30% senior notes due January 2043
Long-term debt:
Long-term debt, before deducting unamortized discounts and debt issuance costs	$ 348	350
Debt instrument, interest rate (as a percent)	4.30%
PAA senior notes \| 4.70% senior notes due June 2044
Long-term debt:
Long-term debt, before deducting unamortized discounts and debt issuance costs	$ 687	700
Debt instrument, interest rate (as a percent)	4.70%
PAA senior notes \| 4.90% senior notes due February 2045
Long-term debt:
Long-term debt, before deducting unamortized discounts and debt issuance costs	$ 649	650
Debt instrument, interest rate (as a percent)	4.90%
Term loan \| GO Zone Term Loans
Long-term debt:
Noncurrent portion of other long-term debt	$ 199	199
Debt issuance costs	$ 1	$ 1
Weighted average long term debt interest rate	1.30%	2.60%
Other long-term debt
Long-term debt:
Noncurrent portion of other long-term debt	$ 112	$ 49

Debt - Commercial Paper and Credit Facilities (Details)	12 Months Ended
Debt - Commercial Paper and Credit Facilities (Details)	Dec. 31, 2020 USD ($) extension	Aug. 31, 2018 USD ($) debt_instrument
PAA commercial paper notes
Debt Instrument [Line Items]
Maximum aggregate borrowing capacity	$ 3,000,000,000.0
PAA senior secured hedged inventory facility
Debt Instrument [Line Items]
Maximum aggregate borrowing capacity	1,900,000,000
Committed borrowing capacity	$ 1,400,000,000
Number of years by which maturity date of credit facility may be extended	1 year
PAA senior secured hedged inventory facility \| Minimum
Debt Instrument [Line Items]
Credit facility extensions available \| extension	1
PAA senior secured hedged inventory facility \| Letters of credit
Debt Instrument [Line Items]
Committed borrowing capacity	$ 400,000,000
PAA senior unsecured revolving credit facility
Debt Instrument [Line Items]
Maximum aggregate borrowing capacity	2,100,000,000
Committed borrowing capacity	$ 1,600,000,000
Number of years by which maturity date of credit facility may be extended	1 year
PAA senior unsecured revolving credit facility \| Minimum
Debt Instrument [Line Items]
Credit facility extensions available \| extension	1
GO Zone Term Loans \| Term loan
Debt Instrument [Line Items]
Number of debt instruments \| debt_instrument		2
GO Zone Term Loan Series 2009 \| Term loan
Debt Instrument [Line Items]
Debt instrument face value		$ 100,000,000
GO Zone Term Loan Series 2010 \| Term loan
Debt Instrument [Line Items]
Debt instrument face value		$ 100,000,000
Non-extending Lender \| PAA senior secured hedged inventory facility
Debt Instrument [Line Items]
Committed borrowing capacity	$ 45,000,000

Debt - Senior Notes (Details) - USD ($) $ in Millions	12 Months Ended
Debt - Senior Notes (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Repayments of PAA senior notes	$ 617	$ 1,000
PAA senior notes
Debt Instrument [Line Items]
Debt instrument face value	$ 9,100	$ 9,000
PAA senior notes \| 3.80% senior notes due September 2030
Debt Instrument [Line Items]
Debt instrument, interest rate (as a percent)	3.80%
Offering price percentage	99.794%
Debt instrument face value	$ 750
PAA senior notes \| 3.55% senior notes due December 2029
Debt Instrument [Line Items]
Debt instrument, interest rate (as a percent)	3.55%	3.55%
Offering price percentage		99.801%
Debt instrument face value		$ 1,000
PAA senior notes \| 5.00% senior notes due February 2021
Debt Instrument [Line Items]
Debt instrument, interest rate (as a percent)	5.00%
Repayments of PAA senior notes	$ 600
PAA senior notes \| 2.60% senior notes due December 2019
Debt Instrument [Line Items]
Debt instrument, interest rate (as a percent)		2.60%
Repayments of PAA senior notes		$ 500
PAA senior notes \| 5.75% senior notes due January 2020
Debt Instrument [Line Items]
Debt instrument, interest rate (as a percent)		5.75%
Repayments of PAA senior notes		$ 500
Consolidated Finance Subsidiary Issuer
Debt Instrument [Line Items]
Consolidated subsidiary, ownership interest held by the parent (as a percent)	100.00%

Debt - Maturities (Details) $ in Millions	12 Months Ended
Debt - Maturities (Details) $ in Millions	Dec. 31, 2020 USD ($)
Debt Disclosure [Abstract]
Weighted-average maturity of long-term debt	10 years
Maturities
2021	$ 0
2022	750
2023	1,300
2024	750
2025	1,000
Thereafter	$ 5,533

Debt - Covenants (Details) $ in Millions	12 Months Ended
Debt - Covenants (Details) $ in Millions	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)	Dec. 31, 2018 USD ($)
Debt Instrument [Line Items]
Coverage ratio of debt-to-EBITDA, maximum	5.00
Ratio of debt-to-EBITDA during acquisition period, maximum	5.50
Threshold for acquisition period qualification	$ 150
Outstanding letters of credit	129	$ 157
Credit agreements and PAA commercial paper program
Debt Instrument [Line Items]
Total borrowings	29,300	13,300	$ 45,400
Total repayments	$ 29,000	$ 12,900	$ 46,300
Letters of credit \| Maximum
Debt Instrument [Line Items]
Periods for which letters of credit are issued	70 days

Partners' Capital and Distributions - Shares and Exchange and Redemption Rights (Details)	12 Months Ended
	Dec. 31, 2020 shares	Dec. 31, 2019 shares	Dec. 31, 2018 shares
Class A Shares
Increase (Decrease) in Partners' Capital
Balance, beginning of period (in shares)	182,138,592	159,485,588	156,111,139
Exchange Right exercises (in shares)	11,858,457	22,637,818	3,363,199
Other (in shares)	54,387	15,186	11,250
Balance, end of period (in shares)	194,051,436	182,138,592	159,485,588
Class B Shares
Increase (Decrease) in Partners' Capital
Balance, beginning of period (in shares)	65,785,702	119,604,338	126,984,572
Conversion of AAP Management Units (in shares)	595,117
Exchange Right exercises (in shares)	(11,858,457)	(22,637,818)	(3,363,199)
Redemption Right exercises (in shares)	(3,882,170)	(31,180,818)	(4,017,035)
Balance, end of period (in shares)	50,640,192	65,785,702	119,604,338
Class C Shares
Increase (Decrease) in Partners' Capital
Balance, beginning of period (in shares)	549,538,139	516,938,280	510,925,432
Redemption Right exercises (in shares)	3,882,170	31,180,818	4,017,035
Issuances of Series A preferred units by a subsidiary (in shares)			1,393,926
Repurchase of common units by a subsidiary (in shares)	(6,222,748)
Other (in shares)	520,201	1,419,041	601,887
Balance, end of period (in shares)	547,717,762	549,538,139	516,938,280
AAP \| Exchange Of AAP Units And Class B Shares For Class A Shares
Partners Capital and Distribution [Line Items]
Ratio for conversion or exchange of units	1
AAP \| Conversion of AAP Management Units into AAP Units
Partners Capital and Distribution [Line Items]
Ratio for conversion or exchange of units	0.941

Partners' Capital and Distributions - Distributions, Class A (Details) - Class A Shares - USD ($) $ / shares in Units, $ in Millions			3 Months Ended								12 Months Ended
	Feb. 12, 2021	Jan. 07, 2021	Dec. 31, 2020	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Partners Capital and Distribution [Line Items]
Percentage of available cash distributed											100.00%
Number of days after end of quarter within which distributions must be paid to shareholders											55 days
Cash distributions per Class A share (in dollars per share)			$ 0.18	$ 0.18	$ 0.18	$ 0.36	$ 0.36	$ 0.36	$ 0.36	$ 0.30	$ 0.90	$ 1.38
Cash Distribution
Partners Capital and Distribution [Line Items]
Distributions paid to limited partners											$ 166	$ 231	$ 189
Cash distributions per Class A share (in dollars per share)											$ 0.90	$ 1.38	$ 1.20
Fourth quarter distribution \| Cash Distribution \| Subsequent Event
Partners Capital and Distribution [Line Items]
Distributions paid to limited partners	$ 35
Distributions per Class A share declared (in dollars per share)		$ 0.18

Partners' Capital and Distributions - Consolidated Subsidiaries (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	May 31, 2019	Dec. 31, 2020	Dec. 31, 2019	Nov. 30, 2020
Subsidiary, Sale of Stock [Line Items]
Proceeds from sale of noncontrolling interests			$ 128
Contributions from noncontrolling interests		$ 12
Common Equity Repurchase Program
Subsidiary, Sale of Stock [Line Items]
Common equity repurchase program, authorized amount				$ 500
Common equity repurchase program, remaining amount		450
Noncontrolling Interests
Subsidiary, Sale of Stock [Line Items]
Contributions from noncontrolling interests		$ 12
PAA \| Common Units and Series A Preferred Units
Subsidiary, Sale of Stock [Line Items]
Ownership percentage		69.00%
PAA \| Series B Preferred Units
Subsidiary, Sale of Stock [Line Items]
Ownership percentage		100.00%
AAP
Subsidiary, Sale of Stock [Line Items]
Ownership percentage		21.00%
Red River Pipeline Company LLC
Subsidiary, Sale of Stock [Line Items]
Ownership percentage		33.00%
Delek Logistics Partners, LP \| Red River Pipeline Company LLC
Subsidiary, Sale of Stock [Line Items]
Ownership percentage		33.00%
Red River Pipeline Company LLC \| Noncontrolling Interests
Subsidiary, Sale of Stock [Line Items]
Contributions from noncontrolling interests		$ 12
PAA \| Common Equity Repurchase Program
Subsidiary, Sale of Stock [Line Items]
PAA common units repurchased and cancelled		6,222,748
Total purchase price of PAA common units repurchased		$ 50
Delek Logistics Partners, LP \| Red River Pipeline Company LLC
Subsidiary, Sale of Stock [Line Items]
Ownership percentage	33.00%
Proceeds from sale of noncontrolling interests	$ 128

Partners' Capital and Distributions - PAA Distributions (Details) - PAA - USD ($) $ / shares in Units, $ in Millions			12 Months Ended
	Feb. 12, 2021	Jan. 07, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Partners Capital and Distribution [Line Items]
Percentage of available cash distributed			100.00%
Number of days after end of quarter within which distributions must be paid to unitholders			45 days
Cash Distribution \| Series A Preferred Units
Partners Capital and Distribution [Line Items]
Total distribution amount			$ 149	$ 149	$ 112
Cash Distribution \| Series B Preferred Units
Partners Capital and Distribution [Line Items]
Total distribution amount			49	49	49
Cash Distribution \| Common Units
Partners Capital and Distribution [Line Items]
Distributions paid to limited partners			$ 655	$ 1,004	$ 871
Distributions per common unit (in dollars per share)			$ 0.90	$ 1.38	$ 1.20
Cash Distribution \| Common Units \| Subsequent Event
Partners Capital and Distribution [Line Items]
Distributions paid to limited partners	$ 130
Distributions per common unit (in dollars per share)		$ 0.18
Unit Distribution \| Series A Preferred Units
Partners Capital and Distribution [Line Items]
Distribution made to limited partner, unit distributions paid (in units)			0	0	1,393,926
Distributions paid to limited partners					$ 37
Public \| Cash Distribution \| Common Units
Partners Capital and Distribution [Line Items]
Distributions paid to limited partners			$ 432	$ 632	532
AAP \| Cash Distribution \| Common Units
Partners Capital and Distribution [Line Items]
Distributions paid to limited partners			$ 223	372	$ 339
AAP \| Fourth quarter distribution \| Cash Distribution \| Common Units \| Subsequent Event
Partners Capital and Distribution [Line Items]
Distributions paid to limited partners	44
Other current liabilities \| Series B Preferred Units
Partners Capital and Distribution [Line Items]
Distributions payable				$ 6
Other current liabilities \| Cash Distribution \| Series A Preferred Units \| Subsequent Event
Partners Capital and Distribution [Line Items]
Distributions paid to limited partners	$ 37

Partners' Capital and Distributions - AAP Distributions (Details) - USD ($) $ in Millions		12 Months Ended
	Feb. 12, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
AAP \| Cash Distribution
Partners Capital and Distribution [Line Items]
Distributions to noncontrolling interests		$ 57	$ 141	$ 150
Distributions to PAGP		166	231	189
Distributions paid to limited partners		223	372	$ 339
Red River Pipeline Company LLC
Partners Capital and Distribution [Line Items]
Distributions to noncontrolling interests		$ 10	$ 6
Fourth quarter distribution \| AAP \| Cash Distribution \| Subsequent Event
Partners Capital and Distribution [Line Items]
Distributions to noncontrolling interests	$ 9
Distributions to PAGP	35
Distributions paid to limited partners	$ 44

Derivatives and Risk Management Activities - Commodity Price Risk Hedging (Details) bbl in Millions	12 Months Ended
	Dec. 31, 2020 TWh bbl Bcf MMBbls
Net long position associated with crude oil purchases
Commodity Price Risk Hedging:
Derivative position notional amount (in barrels or Bcf)	5.8
Net short time spread position hedging anticipated crude oil lease gathering purchases
Commodity Price Risk Hedging:
Derivative position notional amount (in barrels or Bcf)	6.6
Net crude oil grade basis spread positions
Commodity Price Risk Hedging:
Derivative position notional amount (in barrels or Bcf)	0.6
Net short position related to anticipated net sales of crude oil and NGL inventory
Commodity Price Risk Hedging:
Derivative position notional amount (in barrels or Bcf)	37.4
Long natural gas position for natural gas purchases
Commodity Price Risk Hedging:
Derivative position notional amount (in barrels or Bcf) \| Bcf	37.3
Short propane position related to subsequent sale of products
Commodity Price Risk Hedging:
Derivative position notional amount (in barrels or Bcf) \| MMBbls	6.3
Short butane position related to subsequent sale of products
Commodity Price Risk Hedging:
Derivative position notional amount (in barrels or Bcf) \| MMBbls	2.3
Short condensate WTI position related to subsequent sale of products
Commodity Price Risk Hedging:
Derivative position notional amount (in barrels or Bcf) \| MMBbls	0.6
Long fuel gas position for fuel gas requirements
Commodity Price Risk Hedging:
Derivative position notional amount (in barrels or Bcf) \| Bcf	14.3
Long power position for power supply requirements
Commodity Price Risk Hedging:
Derivative position notional amount (in Terawatt hours) \| TWh	0.7

Derivatives and Risk Management Activities - Financial Impact (Details) - Derivatives Not Designated as a Hedge - Commodity derivatives - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Impact of derivative activities recognized in earnings
Total gain (loss) on derivatives recognized in net income	$ (297)	$ 324	$ 148
Supply and Logistics segment revenues
Impact of derivative activities recognized in earnings
Total gain (loss) on derivatives recognized in net income	(302)	310	150
Field operating costs
Impact of derivative activities recognized in earnings
Total gain (loss) on derivatives recognized in net income	$ 5	$ 14	$ (2)

Derivatives and Risk Management Activities - Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Derivative assets and liabilities
Initial margin	$ 91	$ 73
Variation margin posted/(returned)	290	(45)
Letters of credit	(129)	(157)
Net broker receivable	318
Net broker payable		(45)
Exchange Traded
Derivative assets and liabilities
Letters of credit	$ (63)	$ (73)

Derivatives and Risk Management Activities - Offsetting (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Derivative Asset Positions
Effect of Collateral Netting (Asset)		$ (45)
Derivative Liability Positions
Effect of Collateral Netting (Liability)	$ 318
Commodity derivatives
Derivative Asset Positions
Effect of Collateral Netting (Asset)		(45)
Derivative Liability Positions
Gross Position - Asset	85	235
Gross Position - Liability	(386)	(105)
Effect of Collateral Netting (Liability)	318
Net Carrying Value Presented on the Balance Sheet, Total	17	85
Other current assets \| Commodity derivatives
Derivative Asset Positions
Gross Position - Asset	71	179
Gross Position - Liability	(314)	(37)
Effect of Collateral Netting (Asset)		(45)
Net Carrying Value Presented on the Balance Sheet	75	97
Derivative Liability Positions
Effect of Collateral Netting (Liability)	318
Other long-term assets, net \| Commodity derivatives
Derivative Asset Positions
Gross Position - Asset	5	24
Gross Position - Liability	0	0
Net Carrying Value Presented on the Balance Sheet	5	24
Other current liabilities \| Commodity derivatives
Derivative Liability Positions
Gross Position - Asset	9	32
Gross Position - Liability	(40)	(56)
Net Carrying Value Presented on the Balance Sheet	(31)	(24)
Other long-term liabilities and deferred credits \| Commodity derivatives
Derivative Liability Positions
Gross Position - Asset	0	0
Gross Position - Liability	(32)	(12)
Net Carrying Value Presented on the Balance Sheet	$ (32)	$ (12)

Derivatives and Risk Management Activities - Interest Rate Risk Hedging (Details) - Cash Flow Hedging $ in Millions	12 Months Ended
	Dec. 31, 2020 USD ($) contract
Eight Forward Starting Thirty Year Interest Rate Swaps 1.38 Percent
Interest Rate Derivatives [Abstract]
Number of interest rate derivatives \| contract	8
Term of derivative contract	30 years
Notional amount \| $	$ 200
Average rate locked (percent)	1.38%
8 forward starting interest rate swaps (30-year), 0.73%
Interest Rate Derivatives [Abstract]
Number of interest rate derivatives \| contract	8
Term of derivative contract	30 years
Notional amount \| $	$ 200
Average rate locked (percent)	0.73%

Derivatives and Risk Management Activities - Net Unrealized Gain/(Loss) Recognized in AOCI (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Derivatives, Fair Value [Line Items]
Net loss in reclassified to earnings	$ 11	$ 9	$ 5
Net loss in reclassification to earnings	13
Other long-term assets, net
Derivatives, Fair Value [Line Items]
Interest rate fair value hedge liability at fair value	46
Other current liabilities
Derivatives, Fair Value [Line Items]
Interest rate fair value hedge liability at fair value		44
AOCI cash flow hedge
Derivatives, Fair Value [Line Items]
Net loss deferred in AOCI	258
Interest rate derivatives
Derivatives, Fair Value [Line Items]
Net deferred gain/(loss) recognized in AOCI on derivatives	$ (10)	$ (91)	$ 38

Derivatives and Risk Management Activities - Currency Exchange Rate Risk Hedging (Details) $ in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2020 USD ($) $ / $	Dec. 31, 2019 USD ($)	Dec. 31, 2018 USD ($)	Dec. 31, 2020 CAD ($) $ / $
Foreign Currency Derivatives \| Supply and Logistics segment revenues \| Derivatives Not Designated as a Hedge
Currency Exchange Rate Risk Hedging:
Gain/(loss) recognized in earnings \| $	$ 1	$ 8	$ (23)
Forward exchange contracts that exchange CAD for USD maturing in 2021
Currency Exchange Rate Risk Hedging:
Notional amount	$ 46			$ 59
Forward exchange contracts that exchange CAD for USD maturing in 2021 \| Minimum
Currency Exchange Rate Risk Hedging:
Average exchange rate (cad per usd) \| $ / $	1.00			1.00
Forward exchange contracts that exchange CAD for USD maturing in 2021 \| Maximum
Currency Exchange Rate Risk Hedging:
Average exchange rate (cad per usd) \| $ / $	1.28			1.28
Forward exchange contracts that exchange USD for CAD maturing in 2021
Currency Exchange Rate Risk Hedging:
Notional amount	$ 80			$ 104
Forward exchange contracts that exchange USD for CAD maturing in 2021 \| Minimum
Currency Exchange Rate Risk Hedging:
Average exchange rate (cad per usd) \| $ / $	1.00			1.00
Forward exchange contracts that exchange USD for CAD maturing in 2021 \| Maximum
Currency Exchange Rate Risk Hedging:
Average exchange rate (cad per usd) \| $ / $	1.30			1.30
Interest Rate Derivatives \| Other current assets \| Derivatives in Hedging Relationships
Currency Exchange Rate Risk Hedging:
Derivative asset \| $		2
Interest Rate Derivatives \| Other current assets \| Maximum \| Derivatives in Hedging Relationships
Currency Exchange Rate Risk Hedging:
Derivative asset \| $	$ 2
Interest Rate Derivatives \| Other current liabilities \| Derivatives in Hedging Relationships
Currency Exchange Rate Risk Hedging:
Derivative liability \| $		$ 1

Derivatives and Risk Management Activities - Preferred Distribution Rate (Details) - Preferred Distribution Rate Reset Option - Derivatives Not Designated as a Hedge - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Other long-term liabilities and deferred credits
Derivatives and Risk Management Activities
Derivative liability	$ 14	$ 34
Other income/(expense), net
Derivatives and Risk Management Activities
Gain/(loss) recognized	$ 20	$ 2	$ (14)

Derivatives and Risk Management Activities - Fair Value (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Level 3
Rollforward of Level 3 Net Asset/(Liability)
Beginning Balance	$ (51)	$ (24)
Net gains/(losses) for the period included in earnings	12	10
Settlements	10	(11)
Derivatives entered into during the period	0	(26)
Ending Balance	(29)	(51)
Change in unrealized gains/(losses) included in earnings relating to Level 3 derivatives still held at the end of the period	12	(16)
Recurring Fair Value Measures
Recurring Fair Value Measurements
Total net derivative asset/(liability)	(267)	53
Recurring Fair Value Measures \| Commodity derivatives
Recurring Fair Value Measurements
Total net derivative asset/(liability)	(301)	130
Recurring Fair Value Measures \| Interest rate derivatives
Recurring Fair Value Measurements
Total net derivative asset/(liability)	46	(44)
Recurring Fair Value Measures \| Foreign currency derivatives
Recurring Fair Value Measurements
Total net derivative asset/(liability)	2	1
Recurring Fair Value Measures \| Preferred Distribution Rate Reset Option
Recurring Fair Value Measurements
Total net derivative asset/(liability)	(14)	(34)
Recurring Fair Value Measures \| Level 1
Recurring Fair Value Measurements
Total net derivative asset/(liability)	(143)	42
Recurring Fair Value Measures \| Level 1 \| Commodity derivatives
Recurring Fair Value Measurements
Total net derivative asset/(liability)	(143)	42
Recurring Fair Value Measures \| Level 1 \| Interest rate derivatives
Recurring Fair Value Measurements
Total net derivative asset/(liability)	0	0
Recurring Fair Value Measures \| Level 1 \| Foreign currency derivatives
Recurring Fair Value Measurements
Total net derivative asset/(liability)	0	0
Recurring Fair Value Measures \| Level 1 \| Preferred Distribution Rate Reset Option
Recurring Fair Value Measurements
Total net derivative asset/(liability)	0	0
Recurring Fair Value Measures \| Level 2
Recurring Fair Value Measurements
Total net derivative asset/(liability)	(95)	62
Recurring Fair Value Measures \| Level 2 \| Commodity derivatives
Recurring Fair Value Measurements
Total net derivative asset/(liability)	(143)	105
Recurring Fair Value Measures \| Level 2 \| Interest rate derivatives
Recurring Fair Value Measurements
Total net derivative asset/(liability)	46	(44)
Recurring Fair Value Measures \| Level 2 \| Foreign currency derivatives
Recurring Fair Value Measurements
Total net derivative asset/(liability)	2	1
Recurring Fair Value Measures \| Level 2 \| Preferred Distribution Rate Reset Option
Recurring Fair Value Measurements
Total net derivative asset/(liability)	0	0
Recurring Fair Value Measures \| Level 3
Recurring Fair Value Measurements
Total net derivative asset/(liability)	(29)	(51)
Recurring Fair Value Measures \| Level 3 \| Commodity derivatives
Recurring Fair Value Measurements
Total net derivative asset/(liability)	(15)	(17)
Recurring Fair Value Measures \| Level 3 \| Interest rate derivatives
Recurring Fair Value Measurements
Total net derivative asset/(liability)	0	0
Recurring Fair Value Measures \| Level 3 \| Foreign currency derivatives
Recurring Fair Value Measurements
Total net derivative asset/(liability)	0	0
Recurring Fair Value Measures \| Level 3 \| Preferred Distribution Rate Reset Option
Recurring Fair Value Measurements
Total net derivative asset/(liability)	$ (14)	$ (34)

Leases - Narrative Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Lessee, Lease, Description [Line Items]
Lease expense		$ 199
Equity Method Investees \| Agreement to store at facilities owned by equity method investee
Lessee, Lease, Description [Line Items]
Ownership interest in unconsolidated entity	50.00%
Minimum
Lessee, Lease, Description [Line Items]
Lessee, leases, term of contract	1 year
Lessee, leases, renewal term	1 year
Lessor, Lease, Description [Line Items]
Lessor, operating lease, term of contract	1 year
Maximum
Lessee, Lease, Description [Line Items]
Lessee, leases, term of contract	60 years
Lessee, leases, renewal term	25 years
Lessor, Lease, Description [Line Items]
Lessor, operating lease, term of contract	21 years

Leases - Lease Costs (Details) - USD ($) $ in Millions	12 Months Ended
Leases - Lease Costs (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Lessee, Lease, Description [Line Items]
Operating lease cost	$ 111	$ 125
Short-term lease cost	31	35
Other	8	0
Total lease cost	150	$ 160
Equity Method Investees \| Agreement to store at facilities owned by equity method investee
Lessee, Lease, Description [Line Items]
Other	$ 6
Ownership interest in unconsolidated entity	50.00%

Leases - Other Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Lessee, Lease, Description [Line Items]
Operating cash flows for operating leases	$ 108	$ 116
Operating cash flows for finance leases	5	1
Financing cash flows for finance leases	19	18
Non-cash change in lease liabilities arising from obtaining new right of use assets or modifications, operating leases	5	77
Non-cash change in lease liabilities arising from obtaining new right of use assets or modifications, finance leases	$ 32	$ 27
Weighted-average remaining lease term (in years):
Operating lease, weighted-average lease term	12 years	11 years
Finance lease, weighted-average lease term	9 years	6 years
Weighted-average discount rate:
Operating lease, weighted-average discount rate	4.50%	4.40%
Finance lease, weighted-average discount rate	11.10%	7.10%
Equity Method Investees \| Agreement to store at facilities owned by equity method investee
Lessee, Lease, Description [Line Items]
Non-cash change in lease liabilities arising from obtaining new right of use assets or modifications, finance leases	$ 25	$ 12
Ownership interest in unconsolidated entity	50.00%

Leases - Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Lessee, Lease, Assets and Liabilities [Line Items]
Long-term operating lease right-of-use assets, net	$ 378	$ 466
Finance lease right-of-use assets, gross	141	124
Finance lease right-of-use assets, accumulated depreciation	(27)	(16)
Finance lease right-of-use assets, net	$ 114	$ 108
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]	us-gaap:PropertyPlantAndEquipmentNet	us-gaap:PropertyPlantAndEquipmentNet
Total lease right-of-use assets	$ 492	$ 574
Operating lease liabilities
Operating lease liabilities, current	$ 78	$ 94
Operating Lease, Liability, Current, Statement of Financial Position [Extensible List]	us-gaap:OtherLiabilitiesCurrent	us-gaap:OtherLiabilitiesCurrent
Long-term operating lease liabilities	$ 317	$ 387
Total operating lease liabilities	395	481
Finance lease liabilities
Finance lease liabilities, current	$ 11	$ 18
Finance Lease, Liability, Current, Statement of Financial Position [Extensible List]	us-gaap:DebtCurrent	us-gaap:DebtCurrent
Finance lease liabilities, noncurrent	$ 70	$ 49
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	us-gaap:OtherLongTermDebtNoncurrent	us-gaap:OtherLongTermDebtNoncurrent
Total finance lease liabilities	$ 81	$ 67
Total lease liabilities	476	548
Equity Method Investees \| Agreement to store at facilities owned by equity method investee
Lessee, Lease, Assets and Liabilities [Line Items]
Finance lease right-of-use assets, net	35	12
Finance lease liabilities
Total finance lease liabilities	$ 36	$ 12
Ownership interest in unconsolidated entity	50.00%

Leases - Maturity of Lease Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Operating
2021	$ 90
2022	82
2023	62
2024	49
2025	38
Thereafter	237
Total	558
Less: Present value discount	(163)
Lease liability	395	$ 481
Finance
2021	18
2022	18
2023	15
2024	14
2025	11
Thereafter	67
Total	143
Less: Present value discount	(62)
Lease liabilities	81	67
Equity Method Investees \| Agreement to store at facilities owned by equity method investee
Finance
2021	6
2022	6
2023	6
2024	6
2025	6
Thereafter	64
Lease liabilities	$ 36	$ 12
Ownership interest in unconsolidated entity	50.00%

Leases - Lessor Revenue (Details) $ in Millions	Dec. 31, 2020 USD ($)
Leases [Abstract]
2021	$ 40
2022	27
2023	22
2024	18
2025	16
Thereafter	$ 205

Income Taxes - Components (Details) - USD ($) $ in Millions	12 Months Ended
Income Taxes - Components (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Current income tax expense:
State income tax	$ 0	$ 3	$ 3
Canadian federal and provincial income tax	51	109	63
Total current income tax expense	51	112	66
Deferred income tax expense/(benefit):
Federal income tax	(149)	89	90
State income tax	1	21	14
Canadian federal and provincial income tax	(70)	(46)	132
Total deferred income tax expense/(benefit)	(218)	64	236
Total income tax expense/(benefit)	$ (167)	$ 176	$ 302

Income Taxes - Reconciliation of Income Tax Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Income Tax Disclosure [Abstract]
Income/(loss) before tax	$ (2,607)	$ 2,238	$ 2,409
Net (income)/loss attributable to noncontrolling interests	1,872	(1,731)	(1,773)
Income taxes attributable to noncontrolling interests	19	(66)	(198)
Income/(loss) before tax after deducting net income and taxes attributable to noncontrolling interest	$ (716)	$ 441	$ 438
Federal statutory income tax rate	21.00%	21.00%	21.00%
Income tax expense/(benefit) at statutory rate	$ (150)	$ 93	$ 92
Deferred tax rate adjustment	11	10	3
State income tax, net of federal benefit	(9)	7	9
Income taxes attributable to noncontrolling interests:
Canadian federal and provincial income tax	(19)	63	195
State income tax	0	3	3
Total income tax expense/(benefit)	$ (167)	$ 176	$ 302

Income Taxes - Narrative (Details) - USD ($) $ in Millions		3 Months Ended	30 Months Ended
Income Taxes - Narrative (Details) - USD ($) $ in Millions	Jul. 01, 2020	Jun. 30, 2019	Jan. 01, 2022	Dec. 31, 2020
U.S. federal
Income Tax Examination [Line Items]
Net operating loss carryforwards				$ 2,328
State
Income Tax Examination [Line Items]
Net operating loss carryforwards				690
Foreign
Income Tax Examination [Line Items]
Net operating loss carryforwards				9
Canadian Tax Authorities \| Foreign
Income Tax Examination [Line Items]
Amount of assessments received, including penalty and interest				91
Canadian Tax Authorities \| Other long-term assets, net \| Foreign
Income Tax Examination [Line Items]
Amount of disputed assessments paid				$ 64
Alberta Government, Canada
Income Tax Examination [Line Items]
Foreign tax rate	8.00%	12.00%
Deferred tax benefit from change in tax rate		$ 60
Alberta Government, Canada \| Forecast
Income Tax Examination [Line Items]
Foreign tax rate			8.00%

Income Taxes - Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Deferred tax assets:
Investment in partnerships	$ 917	$ 874
Net operating losses	527	406
Derivative instruments	45	0
Lease liabilities	39	55
Other	16	16
Total deferred tax assets	1,544	1,351
Deferred tax liabilities:
Property and equipment in excess of tax values	(475)	(472)
Derivative instruments	0	(22)
Lease assets	(38)	(53)
Other	(3)	(5)
Total deferred tax liabilities	(516)	(552)
Net deferred tax assets	1,028	799
Deferred tax asset	1,444	1,280
Other long-term liabilities and deferred credits
Deferred tax liabilities:
Net deferred tax liabilities	(416)	(481)
Other long-term assets, net
Deferred tax liabilities:
Deferred tax asset	$ 1,444	$ 1,280

Major Customers and Concentration of Credit Risk (Details) - Revenues - Customer Concentration Risk	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Marathon Petroleum Corporation
Major Customers and Concentration of Credit Risk
Major customer percentage of total revenue	13.00%	12.00%	14.00%
ExxonMobil Corporation
Major Customers and Concentration of Credit Risk
Major customer percentage of total revenue	12.00%	12.00%	14.00%
Phillips 66 Company
Major Customers and Concentration of Credit Risk
Major customer percentage of total revenue		11.00%

Related Party Transactions - Additional Information (Details) - shares	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Agreements to store at facilities or transport on pipelines owned by equity method investees \| Equity Method Investees
Related Party Transaction [Line Items]
Ownership interest in unconsolidated entity	50.00%
PAGP \| Class C Shares \| PAA
Related Party Transaction [Line Items]
Class C shares held by PAA (in shares)	547,717,762	549,538,139
AAP \| Principal Owner \| Minimum
Related Party Transaction [Line Items]
Limited partner interest percentage	10.00%

Related Party Transactions - Schedule of Related Parties (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Related Party Transactions [Abstract]
Revenues from related parties	$ 46	$ 692	$ 1,067
Purchases and related costs from related parties	451	223	$ 410
Trade accounts receivable and other receivables, net from related parties	34	134
Trade accounts payable to related parties	$ 88	$ 102

Equity-Indexed Compensation Plans - Plan Information (Details) shares in Millions	Dec. 31, 2020 shares
Equity-Indexed Compensation Plans
LTIP awards authorized (in shares or units)	29.0
Currently available (in units)	5.6
Plains GP Holdings, L.P. Long-Term Incentive Plan
Equity-Indexed Compensation Plans
LTIP awards authorized (in shares or units)	3.8
Units outstanding (in units)	0.2
Units outstanding that include DERs (in units)	0.2
Plains All American 2013 Long-Term Incentive Plan
Equity-Indexed Compensation Plans
LTIP awards authorized (in shares or units)	13.1
Plains All American PNG Successor Long-Term Incentive Plan
Equity-Indexed Compensation Plans
LTIP awards authorized (in shares or units)	1.3
Plains All American GP LLC 2006 Long-Term Incentive Tracking Unit Plan
Equity-Indexed Compensation Plans
LTIP awards authorized (in shares or units)	10.8
PAA LTIP \| PAA
Equity-Indexed Compensation Plans
Units outstanding (in units)	9.6
Units outstanding that include DERs (in units)	6.9

Commitments and Contingencies - Commitments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Leases
2021	$ 108
2022	100
2023	77
2024	63
2025	49
Thereafter	304
Total	701
Other commitments
2021	312
2022	303
2023	285
2024	278
2025	252
Thereafter	763
Total	2,193
Total
2021	420
2022	403
2023	362
2024	341
2025	301
Thereafter	1,067
Total	2,894
Expense associated with agreements	$ 265	$ 236	$ 228
Agreements to store at facilities or transport on pipelines owned by equity method investees \| Equity Method Investees
Total
Ownership interest in unconsolidated entity	50.00%

Commitments and Contingencies - Legal, Environmental or Regulatory (Details) $ in Thousands	1 Months Ended	12 Months Ended	68 Months Ended
	May 31, 2015 bbl	Dec. 31, 2020 USD ($)	Dec. 31, 2020 USD ($) lawsuit	Dec. 31, 2019 USD ($)	Apr. 25, 2019 USD ($)	Sep. 07, 2018 count
Legal, Environmental or Regulatory Matters
Estimated undiscounted reserve for environmental liabilities		$ 141,000	$ 141,000	$ 140,000
Estimated undiscounted reserve for environmental liabilities, short-term		94,000	94,000	60,000
Amounts probable of recovery under insurance and from third parties under indemnification agreements		97,000	97,000	72,000
Other long-term liabilities and deferred credits
Legal, Environmental or Regulatory Matters
Estimated undiscounted reserve for environmental liabilities, long-term		47,000	47,000	80,000
Trade accounts receivable and other receivables, net
Legal, Environmental or Regulatory Matters
Amounts probable of recovery under insurance and from third parties under indemnification agreements		96,000	96,000	35,000
Other long-term assets, net
Legal, Environmental or Regulatory Matters
Amounts probable of recovery under insurance and from third parties under indemnification agreements		1,000	1,000	$ 37,000
Line 901 Incident
Legal, Environmental or Regulatory Matters
Estimated undiscounted reserve for environmental liabilities		86,000	86,000
Amounts probable of recovery under insurance and from third parties under indemnification agreements		90,000	90,000
Estimated size of release (in bbl) \| bbl	2,934
Estimated size of release to reach Pacific Ocean (in bbl) \| bbl	598
Aggregate total estimated costs		460,000	460,000
Recoveries from insurance carriers			245,000
Total release costs probable of recovery		335,000	$ 335,000
Line 901 Incident \| Civil Penalties
Legal, Environmental or Regulatory Matters
Penalties or compensation paid		24,000
Line 901 Incident \| Compensation for Injuries to, Destruction of, Loss of Use of, Natural Resources
Legal, Environmental or Regulatory Matters
Penalties or compensation paid		$ 22,325
Line 901 Incident \| May 2016 Indictment
Legal, Environmental or Regulatory Matters
Number of felony charges found guilty \| count						1
Number of misdemeanor charges found guilty \| count						8
Number of misdemeanor charges found guilty, reporting \| count						1
Number of misdemeanor charges found guilty, strict liability discharge \| count						1
Number of misdemeanor charges found guilty, strict liability animal takings \| count						6
Fines or penalties assessed					$ 3,350
Number of misdemeanor charges not guilty, strict liability animal takings \| count						1
Line 901 Incident \| Class Action Lawsuits
Legal, Environmental or Regulatory Matters
Number of cases filed during the period \| lawsuit			9
Line 901 Incident \| Unitholder Derivative Lawsuits
Legal, Environmental or Regulatory Matters
Number of cases filed during the period \| lawsuit			4

Quarterly Financial Data (Unaudited) (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2020	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Total revenues	$ 5,963	$ 5,833	$ 3,225	$ 8,269	$ 9,154	$ 7,886	$ 8,253	$ 8,375	$ 23,290	$ 33,669	$ 34,055
Gross margin	4	313	282	(190)	402	565	525	790	408	2,282
Operating income/(loss)	(67)	251	208	(2,775)	329	490	449	713	(2,383)	1,980	2,272
Net income/(loss)	(23)	139	137	(2,692)	291	431	426	914	(2,440)	2,062	2,107
Net income attributable to PAGP	(20)	17	16	(581)	$ 48	$ 70	$ 66	$ 147	(568)	331	334
Goodwill impairment losses				2,515					2,515	0	$ 0
Non-cash impairment losses upon classification to assets held for sale				167
Gain on/(impairment of) investments in unconsolidated entities, net
Write down of investments		91	$ 69	43
Gain on/(impairment of) investments in unconsolidated entities, net \| Capline Pipeline Company LLC
Gain from remeasurement to fair value of retained investment		$ 2		267						$ 269
(Gains)/losses on asset sales and asset impairments, net
Non-cash impairment losses, long-lived assets	$ 95			$ 446					$ 541
Class A Shares
Basic net income/(loss) per Class A share (in dollars per share)	$ (0.11)	$ 0.09	$ 0.09	$ (3.18)	$ 0.26	$ 0.41	$ 0.41	$ 0.92	$ (3.06)	$ 1.97	$ 2.12
Diluted net income/(loss) per Class A share (in dollars per share)	(0.11)	0.09	0.09	(3.18)	0.26	0.41	0.40	0.92	(3.07)	1.96	$ 2.11
Cash distributions per Class A share (in dollars per share)	$ 0.18	$ 0.18	$ 0.18	$ 0.36	$ 0.36	$ 0.36	$ 0.36	$ 0.30	$ 0.90	$ 1.38

Operating Segments - Segment Financial Data (Details) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2020 USD ($)	Sep. 30, 2020 USD ($)	Jun. 30, 2020 USD ($)	Mar. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)	Sep. 30, 2019 USD ($)	Jun. 30, 2019 USD ($)	Mar. 31, 2019 USD ($)	Dec. 31, 2020 USD ($) segment	Dec. 31, 2019 USD ($)	Dec. 31, 2018 USD ($)
Operating Segments
Operating segments number \| segment									3
Revenues:
Total revenues	$ 5,963	$ 5,833	$ 3,225	$ 8,269	$ 9,154	$ 7,886	$ 8,253	$ 8,375	$ 23,290	$ 33,669	$ 34,055
Segment Reporting, Disclosure of Other Information about Entity's Reportable Segments
Equity earnings in unconsolidated entities									355	388	375
Segment Adjusted EBITDA									2,557	3,230	2,681
Investment and acquisition capital									1,231	1,387	1,888
Maintenance capital									216	287	252
Total assets	25,951				29,969				25,951	29,969	26,830
Investments in unconsolidated entities	3,764				3,683				3,764	3,683	2,702
Transportation
Revenues:
Total revenues									610	788	648
Segment Reporting, Disclosure of Other Information about Entity's Reportable Segments
Equity earnings in unconsolidated entities									350	388	375
Segment Adjusted EBITDA									1,616	1,722	1,508
Investment and acquisition capital									981	1,127	1,631
Maintenance capital									136	161	139
Total assets	14,416				15,549				14,416	15,549	13,947
Investments in unconsolidated entities	3,642				3,557				3,642	3,557	2,594
Facilities
Revenues:
Total revenues									622	609	588
Segment Reporting, Disclosure of Other Information about Entity's Reportable Segments
Equity earnings in unconsolidated entities									5	0	0
Segment Adjusted EBITDA									731	705	711
Investment and acquisition capital									173	227	234
Maintenance capital									51	97	100
Total assets	6,165				7,593				6,165	7,593	7,464
Investments in unconsolidated entities	122				126				122	126	108
Supply and Logistics
Revenues:
Total revenues									22,058	32,272	32,819
Segment Reporting, Disclosure of Other Information about Entity's Reportable Segments
Segment Adjusted EBITDA									210	803	462
Investment and acquisition capital									77	33	23
Maintenance capital									29	29	13
Total assets	5,370				6,827				5,370	6,827	5,419
Investments in unconsolidated entities	$ 0				$ 0				0	0	0
Operating Segments Excluding Intersegment Elimination \| Transportation
Revenues:
Total revenues									1,016	1,259	1,116
Operating Segments Excluding Intersegment Elimination \| Facilities
Revenues:
Total revenues									622	609	588
Operating Segments Excluding Intersegment Elimination \| Supply and Logistics
Revenues:
Total revenues									22,058	32,272	32,819
Intersegment
Revenues:
Total revenues									(1,927)	(2,098)	(1,918)
Intersegment \| Transportation
Revenues:
Total revenues									(1,004)	(1,061)	(874)
Intersegment \| Facilities
Revenues:
Total revenues									(516)	(562)	(573)
Intersegment \| Supply and Logistics
Revenues:
Total revenues									(1)	(4)	(3)
Intersegment Adjustment
Revenues:
Total revenues									(406)	(471)	(468)
Operating Segments
Revenues:
Total revenues									25,217	35,767	35,973
Operating Segments \| Transportation
Revenues:
Total revenues									2,020	2,320	1,990
Operating Segments \| Facilities
Revenues:
Total revenues									1,138	1,171	1,161
Operating Segments \| Supply and Logistics
Revenues:
Total revenues									$ 22,059	$ 32,276	$ 32,822

Operating Segments - Reconciliation of Segment Adjusted EBITDA (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2020	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Segment Adjusted EBITDA									$ 2,557	$ 3,230	$ 2,681
Adjustments:
Depreciation and amortization of unconsolidated entities									(73)	(62)	(56)
Gains/(losses) from derivative activities, net of inventory valuation adjustments									(480)	(160)	519
Long-term inventory costing adjustments									(44)	20	(21)
Deficiencies under minimum volume commitments, net									(74)	18	(7)
Equity-indexed compensation expense									(19)	(17)	(55)
Net gain/(loss) on foreign currency revaluation									3	(14)	(3)
Significant acquisition-related expenses									(3)	0	0
Unallocated general and administrative expenses									(276)	(302)	(320)
Depreciation and amortization									(656)	(604)	(521)
Gains/(losses) on asset sales and asset impairments, net									(719)	(28)	114
Goodwill impairment losses				$ (2,515)					(2,515)	0	0
Gain on/(impairment of) investments in unconsolidated entities, net									(182)	271	200
Interest expense, net									(436)	(425)	(431)
Other income/(expense), net									39	24	(7)
INCOME/(LOSS) BEFORE TAX									(2,607)	2,238	2,409
Income tax (expense)/benefit									167	(176)	(302)
NET INCOME/(LOSS)	$ (23)	$ 139	$ 137	(2,692)	$ 291	$ 431	$ 426	$ 914	(2,440)	2,062	2,107
Net (income)/loss attributable to noncontrolling interests									1,872	(1,731)	(1,773)
Net income/(loss) attributable to PAGP	$ (20)	$ 17	$ 16	$ (581)	$ 48	$ 70	$ 66	$ 147	(568)	331	334
Unallocated
Adjustments:
Unallocated general and administrative expenses									(5)	(5)	(4)
Line 901 Incident
Adjustments:
Line 901 incident									$ 0	$ (10)	$ 0

Operating Segments - Geographical Data (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2020	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Geographic Data
Revenues	$ 5,963	$ 5,833	$ 3,225	$ 8,269	$ 9,154	$ 7,886	$ 8,253	$ 8,375	$ 23,290	$ 33,669	$ 34,055
Long-Lived Assets	20,788				21,512				20,788	21,512
United States
Geographic Data
Revenues									17,942	27,162	28,362
Long-Lived Assets	16,896				17,577				16,896	17,577
Canada
Geographic Data
Revenues									5,348	6,507	$ 5,693
Long-Lived Assets	$ 3,892				$ 3,935				$ 3,892	$ 3,935

- Definition

+ References

+ Details

Revenues and Accounts Receivable - Performance Obligations (Details) $ in Millions	Dec. 31, 2020 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Remaining performance obligation	$ 514
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Remaining performance obligation	439
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Remaining performance obligation	376
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Remaining performance obligation	315
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Remaining performance obligation	239
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Remaining performance obligation	783
Pipeline revenues supported by minimum volume commitments and long-term capacity agreements \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Remaining performance obligation	$ 174
Remaining performance obligation, expected timing of satisfaction, period	1 year
Pipeline revenues supported by minimum volume commitments and long-term capacity agreements \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Remaining performance obligation	$ 166
Remaining performance obligation, expected timing of satisfaction, period	1 year
Pipeline revenues supported by minimum volume commitments and long-term capacity agreements \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Remaining performance obligation	$ 170
Remaining performance obligation, expected timing of satisfaction, period	1 year
Pipeline revenues supported by minimum volume commitments and long-term capacity agreements \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Remaining performance obligation	$ 142
Remaining performance obligation, expected timing of satisfaction, period	1 year
Pipeline revenues supported by minimum volume commitments and long-term capacity agreements \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Remaining performance obligation	$ 125
Remaining performance obligation, expected timing of satisfaction, period	1 year
Pipeline revenues supported by minimum volume commitments and long-term capacity agreements \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Remaining performance obligation	$ 455
Remaining performance obligation, expected timing of satisfaction, period
Long-term storage, terminalling and throughput agreements revenues \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Remaining performance obligation	$ 340
Remaining performance obligation, expected timing of satisfaction, period	1 year
Long-term storage, terminalling and throughput agreements revenues \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Remaining performance obligation	$ 273
Remaining performance obligation, expected timing of satisfaction, period	1 year
Long-term storage, terminalling and throughput agreements revenues \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Remaining performance obligation	$ 206
Remaining performance obligation, expected timing of satisfaction, period	1 year
Long-term storage, terminalling and throughput agreements revenues \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Remaining performance obligation	$ 173
Remaining performance obligation, expected timing of satisfaction, period	1 year
Long-term storage, terminalling and throughput agreements revenues \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Remaining performance obligation	$ 114
Remaining performance obligation, expected timing of satisfaction, period	1 year
Long-term storage, terminalling and throughput agreements revenues \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Remaining performance obligation	$ 328
Remaining performance obligation, expected timing of satisfaction, period