0001070423-22-000026 | 10-Q | XBRL Viewer | Plains ALL American Pipeline LP

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Partners' Capital and Distributions - Preferred Unit Distributions (Details) - USD ($) $ / shares in Units, $ in Millions	Nov. 15, 2022	Nov. 14, 2022	Aug. 12, 2022	May 16, 2022	May 13, 2022	Feb. 14, 2022	Sep. 30, 2022
Series A Preferred Units \| Cash Distribution
Partners Capital and Distribution
Preferred unit distribution amount			$ 37.0		$ 37.0	$ 37.0
Preferred distributions per unit (usd per unit)			$ 0.525		$ 0.525	$ 0.525
Series A Preferred Units \| Cash Distribution \| Forecast
Partners Capital and Distribution
Preferred unit distribution amount		$ 37.0
Preferred distributions per unit (usd per unit)		$ 0.525
Series B Preferred Units \| Other current liabilities
Partners Capital and Distribution
Amount accrued to distributions payable							$ 18.0
Series B Preferred Units \| Cash Distribution
Partners Capital and Distribution
Preferred unit distribution amount				$ 24.5
Preferred distributions per unit (usd per unit)				$ 30.625
Series B Preferred Units \| Cash Distribution \| Forecast
Partners Capital and Distribution
Preferred unit distribution amount	$ 24.5
Preferred distributions per unit (usd per unit)	$ 30.625

Partners' Capital and Distributions - Noncontrolling Interest in Subsidiaries (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Noncontrolling Interest [Line Items]
Distributions paid	$ 274	$ 182	$ 775	$ 548
Contributions received	$ 26		$ 26	1
Permian JV
Noncontrolling Interest [Line Items]
Noncontrolling interests in subsidiaries (percent)	35.00%		35.00%
Red River LLC
Noncontrolling Interest [Line Items]
Noncontrolling interests in subsidiaries (percent)	33.00%		33.00%
Noncontrolling Interests
Noncontrolling Interest [Line Items]
Distributions paid	$ 73	$ 4	$ 194	10
Contributions received	26		26	$ 1
Permian JV \| Noncontrolling Interests
Noncontrolling Interest [Line Items]
Contributions received	$ 26
Permian JV \| Noncontrolling Interests \| Cash Distribution
Noncontrolling Interest [Line Items]
Distributions paid			180
Red River LLC \| Noncontrolling Interests \| Cash Distribution
Noncontrolling Interest [Line Items]
Distributions paid			$ 15

Derivatives and Risk Management Activities - Offsetting Asset and Liabilities (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Derivative Assets
Effect of Collateral Netting (Asset)	$ (82)
Derivative Liabilities
Effect of Collateral Netting (Liability)		$ 259
Commodity Derivatives
Derivative Assets
Effect of Collateral Netting (Asset)	(82)
Derivative Liabilities
Gross Position - Asset	357	100
Gross Position - Liability	(125)	(243)
Effect of Collateral Netting (Liability)		259
Net Carrying Value Presented on the Balance Sheet, Total	150	116
Other current assets \| Commodity Derivatives
Derivative Assets
Gross Position - Asset	311	90
Gross Position - Liability	(101)	(210)
Effect of Collateral Netting (Asset)	(82)
Net Carrying Value Presented on the Balance Sheet	128	139
Derivative Liabilities
Effect of Collateral Netting (Liability)		259
Other long-term assets, net \| Commodity Derivatives
Derivative Assets
Gross Position - Asset	38	3
Gross Position - Liability	(3)
Net Carrying Value Presented on the Balance Sheet	35	3
Other current liabilities \| Commodity Derivatives
Derivative Liabilities
Gross Position - Asset	6	4
Gross Position - Liability	(17)	(24)
Net Carrying Value Presented on the Balance Sheet	(11)	(20)
Other long-term liabilities and deferred credits \| Commodity Derivatives
Derivative Liabilities
Gross Position - Asset	2	3
Gross Position - Liability	(4)	(9)
Net Carrying Value Presented on the Balance Sheet	$ (2)	$ (6)

Partners' Capital and Distributions - Common Equity Repurchase Program (Details) - USD ($) $ in Millions	3 Months Ended					9 Months Ended
	Jun. 30, 2022	Mar. 31, 2022	Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2021	Sep. 30, 2022	Sep. 30, 2021
Common Units
Partners Capital and Distribution
Repurchase and cancellation of common units under the Common Equity Repurchase Program (units)	4,876,062	2,375,299	6,626,711	4,940,592	350,000
Common Equity Repurchase Program
Partners Capital and Distribution
Common equity repurchase program, remaining amount						$ 198
Common Equity Repurchase Program \| Common Units
Partners Capital and Distribution
Repurchase and cancellation of common units under the Common Equity Repurchase Program (units)						7,300,000	11,900,000
Common equity repurchase program, repurchased amount						$ 74	$ 117

Derivatives and Risk Management Activities - Financial Impact (Details) - Derivatives Not Designated as a Hedge - Commodity Derivatives - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Impact of derivative activities recognized in earnings
Net gain/(loss) from commodity derivative activity	$ 343	$ (189)	$ 227	$ (731)
Product sales revenues
Impact of derivative activities recognized in earnings
Net gain/(loss) from commodity derivative activity	320	(206)	183	(804)
Field operating costs
Impact of derivative activities recognized in earnings
Net gain/(loss) from commodity derivative activity	$ 23	$ 17	$ 44	$ 73

Segment Information (Tables)

9 Months Ended

Sep. 30, 2022

Segment Reporting [Abstract]

Segment financial data

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


	Crude Oil		NGL		Intersegment Revenues Elimination		Total
Three Months Ended September 30, 2022
Revenues (1):
Product sales	$	13,367	$	735	$	(101)	$	14,001
Services	308		35		(8)		335
Total revenues	$	13,675	$	770	$	(109)	$	14,336
Equity earnings in unconsolidated entities	$	105	$	—			$	105
Segment Adjusted EBITDA	$	536	$	86			$	622

Maintenance capital expenditures	$	35	$	41			$	76





Three Months Ended September 30, 2021
Revenues (1):
Product sales	$	10,468	$	133	$	(86)	$	10,515
Services	233		33		(5)		261
Total revenues	$	10,701	$	166	$	(91)	$	10,776
Equity earnings in unconsolidated entities	$	69	$	—			$	69
Segment Adjusted EBITDA	$	459	$	54			$	513

Maintenance capital expenditures	$	24	$	19			$	43





Nine Months Ended September 30, 2022
Revenues (1):
Product sales	$	41,802	$	1,943	$	(355)	$	43,390
Services	892		132		(24)		1,000
Total revenues	$	42,694	$	2,075	$	(379)	$	44,390
Equity earnings in unconsolidated entities	$	306	$	—			$	306
Segment Adjusted EBITDA	$	1,482	$	367			$	1,849

Maintenance capital expenditures	$	80	$	66			$	146





Nine Months Ended September 30, 2021
Revenues (1):
Product sales	$	27,553	$	932	$	(264)	$	28,221
Services	780		102		(14)		868
Total revenues	$	28,333	$	1,034	$	(278)	$	29,089
Equity earnings in unconsolidated entities	$	190	$	—			$	190
Segment Adjusted EBITDA	$	1,486	$	144			$	1,630

Maintenance capital expenditures	$	75	$	41			$	116

(1)Segment revenues include intersegment amounts that are eliminated in Purchases and related costs. 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.

Reconciliation of Segment Adjusted EBITDA to Net income attributable to PAA

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


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Segment Adjusted EBITDA	$	622	$	513	$	1,849	$	1,630
Adjustments: (1)
Depreciation and amortization of unconsolidated entities (2)	(21)		(21)		(58)		(109)
Gains/(losses) from derivative activities and inventory valuation adjustments (3)	376		(13)		363		23
Long-term inventory costing adjustments (4)	(83)		13		22		81
Deficiencies under minimum volume commitments, net (5)	(16)		(56)		(31)		(31)
Equity-indexed compensation expense (6)	(9)		(6)		(24)		(14)
Net gain/(loss) on foreign currency revaluation (7)	2		(3)		1		(2)
Line 901 incident (8)	—		—		(85)		—
Significant transaction-related expenses (9)	—		(2)		—		(5)
Adjusted EBITDA attributable to noncontrolling interests (10)	98		5		264		12
Depreciation and amortization	(238)		(178)		(711)		(551)
Gains/(losses) on asset sales and asset impairments, net	—		(221)		46		(592)
Gain on investment in unconsolidated entities	1		—		1		—
Interest expense, net	(99)		(106)		(305)		(319)
Other income/(expense), net	(82)		(10)		(237)		13
Income/(loss) before tax	551		(85)		1,095		136
Income tax (expense)/benefit	(109)		30		(177)		16
Net income/(loss)	442		(55)		918		152
Net income attributable to noncontrolling interests	(58)		(4)		(144)		(9)
Net income/(loss) attributable to PAA	$	384	$	(59)	$	774	$	143

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

(2)Includes our proportionate share of the depreciation and amortization expense (including write-downs related to cancelled projects) 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 differences in the timing of earnings from the derivative instruments and the underlying transactions and exclude the related gains and losses in determining Segment Adjusted EBITDA such that the earnings from the derivative instruments and the underlying transactions impact Segment Adjusted EBITDA in the same period. In addition, we exclude gains and losses on derivatives that are related to (i) investing activities, such as the purchase of linefill, and (ii) purchases of long-term inventory. 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)Our total equity-indexed compensation expense includes expense associated with awards that will be settled in units and awards that will be settled in cash. The awards that will be settled in units are included in our diluted net income per unit calculation when the applicable performance criteria have been met. We exclude compensation expense associated with these awards in determining Segment Adjusted EBITDA as the dilutive impact of the outstanding awards is included in our diluted net income per unit calculation, as applicable. The portion of compensation expense associated with awards that will settle in cash is not excluded in determining Segment Adjusted EBITDA. See Note 18 to our Consolidated Financial Statements included in Part IV of our 2021 Annual Report on Form 10-K for a discussion regarding our equity-indexed compensation plans.

(7)During the periods presented, there were fluctuations in the value of CAD to USD, resulting in the realization of foreign exchange gains and losses on the settlement of foreign currency transactions as well as the revaluation of monetary assets and liabilities denominated in a foreign currency. These gains and losses are not integral to our core operating performance and were therefore excluded in determining Segment Adjusted EBITDA.

(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 10 for additional information regarding the Line 901 incident.

(9)Includes expenses associated with the Permian JV transaction announced in July 2021. See Note 7 to our Consolidated Financial Statements included in Part IV of our 2021 Annual Report on Form 10-K for further discussion of the joint venture transaction.

(10)Reflects amounts attributable to noncontrolling interests in the Permian JV and Red River LLC.

Debt - Credit Facilities, Borrowings and Repayments and Letters of Credit (Details) - USD ($) $ in Millions		1 Months Ended	9 Months Ended
	Mar. 01, 2022	Aug. 31, 2022	Sep. 30, 2022	Sep. 30, 2021	Dec. 31, 2021
Debt
Repayments of senior notes			$ 750
Outstanding letters of credit			58		$ 98
3.65% senior notes due June 2022 \| Senior notes
Debt
Stated percentage	3.65%				3.65%
Repayments of senior notes	$ 750
Senior secured hedged inventory facility
Debt
Number of years maturity date was extended		1 year
Senior unsecured revolving credit facility
Debt
Number of years maturity date was extended		1 year
Credit facilities and commercial paper program
Debt
Total borrowings			19,300	$ 31,200
Total repayments			$ 19,300	$ 31,900

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - shares	Sep. 30, 2022	Jun. 30, 2022	Mar. 31, 2022	Dec. 31, 2021	Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2021	Dec. 31, 2020
Series A Preferred Units
Units outstanding (units)	71,090,468	71,090,468	71,090,468	71,090,468	71,090,468	71,090,468	71,090,468	71,090,468
Series B Preferred Units
Units outstanding (units)	800,000	800,000	800,000	800,000	800,000	800,000	800,000	800,000
Common Units
Units outstanding (units)	698,332,685	697,939,946	702,668,178	704,991,540	711,121,882	717,371,576	722,055,847	722,380,416

Summary of Significant Accounting Policies (Policies)	9 Months Ended
Summary of Significant Accounting Policies (Policies)	Sep. 30, 2022
Accounting Policies [Abstract]
Recent Accounting Pronouncements	Recent Accounting Pronouncements Except as discussed below and in our 2021 Annual Report on Form 10-K, there have been no new accounting pronouncements that have become effective or have been issued during the nine months ended September 30, 2022 that are of significance or potential significance to us. 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 adopted this guidance effective January 1, 2022, and our adoption did not have a material impact on our financial position, results of operations or cash flows.

Inventory, Linefill and Long-term Inventory (Details) bbl in Thousands, $ in Millions	Sep. 30, 2022 USD ($) $ / bbl bbl	Dec. 31, 2021 USD ($) $ / bbl bbl
Inventory by category
Inventory	$ 603	$ 783
Linefill	954	907
Long-term inventory	301	253
Total	$ 1,858	$ 1,943
Crude oil
Inventory by category
Inventory, Volumes (in barrels) \| bbl	2,830	8,041
Linefill, Volumes (in barrels) \| bbl	15,499	15,199
Long-term inventory, Volumes (in barrels) \| bbl	3,079	2,973
Inventory	$ 207	$ 544
Linefill	900	862
Long-term inventory	$ 259	$ 209
Inventory (Price/Unit of measure) (in dollars per units) \| $ / bbl	73.14	67.65
Linefill (Price/Unit of measure) (in dollars per units) \| $ / bbl	58.07	56.71
Long-term inventory (Price/Unit of measure) (in dollars per units) \| $ / bbl	84.12	70.30
NGL
Inventory by category
Inventory, Volumes (in barrels) \| bbl	9,698	6,982
Linefill, Volumes (in barrels) \| bbl	1,894	1,633
Long-term inventory, Volumes (in barrels) \| bbl	1,069	1,135
Inventory	$ 389	$ 234
Linefill	54	45
Long-term inventory	$ 42	$ 44
Inventory (Price/Unit of measure) (in dollars per units) \| $ / bbl	40.11	33.51
Linefill (Price/Unit of measure) (in dollars per units) \| $ / bbl	28.51	27.56
Long-term inventory (Price/Unit of measure) (in dollars per units) \| $ / bbl	39.29	38.77
Other
Inventory by category
Inventory	$ 7	$ 5

Revenues and Accounts Receivable - Counterparty Deficiencies (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Minimum Volume Commitments
Contract liability, billed and collected	$ 143	$ 141
Minimum Volume Commitments
Minimum Volume Commitments
Contract liability, billed and collected	65	63
Counterparty deficiencies unbilled	11	16
Counterparty deficiencies	$ 76	$ 79

Segment Information - Segment Financial Data (Details) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2022 USD ($)	Sep. 30, 2021 USD ($)	Sep. 30, 2022 USD ($) segment	Sep. 30, 2021 USD ($) segment	Sep. 30, 2022 segment
Segment Reporting Information
Operating segments number \| segment			2	3	2
Revenues:
Revenues	$ 14,336	$ 10,776	$ 44,390	$ 29,089
Segment Reporting, Disclosure of Other Information about Entity's Reportable Segments
Equity earnings in unconsolidated entities	105	69	306	190
Segment Adjusted EBITDA	622	513	1,849	1,630
Maintenance capital expenditures	76	43	146	116
Operating Segments
Revenues:
Revenues	14,445	10,867	44,769	29,367
Intersegment Revenues Elimination
Revenues:
Revenues	(109)	(91)	(379)	(278)
Product sales revenues
Revenues:
Revenues	14,001	10,515	43,390	28,221
Product sales revenues \| Intersegment Revenues Elimination
Revenues:
Revenues	(101)	(86)	(355)	(264)
Services revenues
Revenues:
Revenues	335	261	1,000	868
Services revenues \| Intersegment Revenues Elimination
Revenues:
Revenues	(8)	(5)	(24)	(14)
Crude Oil
Segment Reporting, Disclosure of Other Information about Entity's Reportable Segments
Equity earnings in unconsolidated entities	105	69	306	190
Segment Adjusted EBITDA	536	459	1,482	1,486
Maintenance capital expenditures	35	24	80	75
Crude Oil \| Operating Segments
Revenues:
Revenues	13,675	10,701	42,694	28,333
Crude Oil \| Product sales revenues \| Operating Segments
Revenues:
Revenues	13,367	10,468	41,802	27,553
Crude Oil \| Services revenues \| Operating Segments
Revenues:
Revenues	308	233	892	780
NGL
Segment Reporting, Disclosure of Other Information about Entity's Reportable Segments
Segment Adjusted EBITDA	86	54	367	144
Maintenance capital expenditures	41	19	66	41
NGL \| Operating Segments
Revenues:
Revenues	770	166	2,075	1,034
NGL \| Product sales revenues \| Operating Segments
Revenues:
Revenues	735	133	1,943	932
NGL \| Services revenues \| Operating Segments
Revenues:
Revenues	$ 35	$ 33	$ 132	$ 102

Partners' Capital and Distributions

9 Months Ended

Sep. 30, 2022

Partners' Capital Notes [Abstract]

Partners' Capital and Distributions

Partners’ Capital and Distributions

Units Outstanding

The following tables present the activity for our preferred and common units:


	Limited Partners
	Series A Preferred Units	Series B Preferred Units	Common Units
Outstanding at December 31, 2021	71,090,468	800,000	704,991,540
Repurchase and cancellation of common units under the Common Equity Repurchase Program	—	—	(2,375,299)
Issuances of common units under equity-indexed compensation plans	—	—	51,937
Outstanding at March 31, 2022	71,090,468	800,000	702,668,178
Repurchase and cancellation of common units under the Common Equity Repurchase Program	—	—	(4,876,062)
Issuances of common units under equity-indexed compensation plans	—	—	147,830
Outstanding at June 30, 2022	71,090,468	800,000	697,939,946

Issuances of common units under equity-indexed compensation plans	—	—	392,739

Outstanding at September 30, 2022	71,090,468	800,000	698,332,685


	Limited Partners
	Series A Preferred Units	Series B Preferred Units	Common Units
Outstanding at December 31, 2020	71,090,468	800,000	722,380,416

Repurchase and cancellation of common units under the Common Equity Repurchase Program	—	—	(350,000)
Issuances of common units under equity-indexed compensation plans	—	—	25,431
Outstanding at March 31, 2021	71,090,468	800,000	722,055,847
Repurchase and cancellation of common units under the Common Equity Repurchase Program	—	—	(4,940,592)
Issuances of common units under equity-indexed compensation plans	—	—	256,321
Outstanding at June 30, 2021	71,090,468	800,000	717,371,576
Repurchase and cancellation of common units under the Common Equity Repurchase Program	—	—	(6,626,711)
Issuances of common units under equity-indexed compensation plans	—	—	377,017
Outstanding at September 30, 2021	71,090,468	800,000	711,121,882

Common Equity Repurchase Program

We repurchased 7.3 million and 11.9 million common units under our Common Equity Repurchase Program (the “Program”) through open market purchases that settled during the nine months ended September 30, 2022 and 2021, respectively, for a total purchase price of $74 million and $117 million, respectively, including commissions and fees. The repurchased common units were canceled immediately upon acquisition, as were the PAGP Class C shares held by us associated with the repurchased common units. At September 30, 2022, the remaining available capacity under the Program was $198 million. See Note 12 to our Consolidated Financial Statements included in Part IV of our 2021 Annual Report on Form 10-K for additional information regarding the Program.

Distributions

Series A Preferred Unit Distributions. The following table details distributions to our Series A preferred unitholders paid during or pertaining to the first nine months of 2022 (in millions, except per unit data):


	Series A Preferred Unitholders
Distribution Payment Date	Cash Distribution		Distribution per Unit
November 14, 2022 (1)	$	37	$	0.525
August 12, 2022	$	37	$	0.525
May 13, 2022	$	37	$	0.525
February 14, 2022	$	37	$	0.525

(1)Payable to unitholders of record at the close of business on October 31, 2022 for the period from July 1, 2022 through September 30, 2022. At September 30, 2022, such amount was accrued as distributions payable in “Other current liabilities” on our Condensed Consolidated Balance Sheet.

Series B Preferred Unit Distributions. Distributions on our Series B preferred units are payable semi-annually in arrears on the 15th day of May and November. The following table details distributions paid to our Series B preferred unitholders (in millions, except per unit data):


	Series B Preferred Unitholders
Distribution Payment Date	Cash Distribution		Distribution per Unit
November 15, 2022 (1)	$	24.5	$	30.625
May 16, 2022	$	24.5	$	30.625

(1)Payable to unitholders of record at the close of business on October 31, 2022 for the period from May 17, 2022 through November 14, 2022.

At September 30, 2022, approximately $18 million of accrued distributions payable to our Series B preferred unitholders was included in “Other current liabilities” on our Condensed Consolidated Balance Sheet.

Common Unit Distributions. The following table details distributions to our common unitholders paid during or pertaining to the first nine months of 2022 (in millions, except per unit data):


	Distributions						Cash Distribution per Common Unit
	Common Unitholders				Total Cash Distribution
Distribution Payment Date	Public		AAP
November 14, 2022 (1)	$	100	$	52	$	152	$	0.2175
August 12, 2022	$	99	$	53	$	152	$	0.2175
May 13, 2022	$	100	$	53	$	153	$	0.2175
February 14, 2022	$	84	$	43	$	127	$	0.1800

(1)Payable to unitholders of record at the close of business on October 31, 2022 for the period from July 1, 2022 through September 30, 2022.

Noncontrolling Interests in Subsidiaries

As of September 30, 2022, noncontrolling interests in our subsidiaries consisted of (i) a 35% interest in Plains Oyrx Permian Basin LLC (the “Permian JV”) and (ii) a 33% interest in Red River Pipeline Company LLC (“Red River LLC”).

During the nine months ended September 30, 2022, we paid distributions of $180 million and $15 million to noncontrolling interests in the Permian JV and Red River LLC, respectively.

During the three months ended September 30, 2022, we received a contribution of $26 million from noncontrolling interests in the Permian JV associated with the acquisition of the remaining 50% interest in an unconsolidated subsidiary of the Permian JV.

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Changes in Accumulated Other Comprehensive Income/(Loss)
Beginning balance	$ 12,719	$ 9,640	$ 12,810	$ 9,738
Total period activity	(173)	(44)	(150)	64
Ending balance	12,743	9,297	12,743	9,297
Derivative Instruments
Changes in Accumulated Other Comprehensive Income/(Loss)
Beginning balance			(208)	(258)
Reclassification adjustments			5	28
Unrealized gain on hedges			88	36
Total period activity			93	64
Ending balance	(115)	(194)	(115)	(194)
Translation Adjustments
Changes in Accumulated Other Comprehensive Income/(Loss)
Beginning balance			(642)	(657)
Currency translation adjustments			(241)	1
Total period activity			(241)	1
Ending balance	(883)	(656)	(883)	(656)
Other
Changes in Accumulated Other Comprehensive Income/(Loss)
Beginning balance			(3)	(3)
Other			(2)	(1)
Total period activity			(2)	(1)
Ending balance	(5)	(4)	(5)	(4)
Total
Changes in Accumulated Other Comprehensive Income/(Loss)
Beginning balance			(853)	(918)
Reclassification adjustments			5	28
Unrealized gain on hedges			88	36
Currency translation adjustments			(241)	1
Other			(2)	(1)
Total period activity			(150)	64
Ending balance	$ (1,003)	$ (854)	$ (1,003)	$ (854)

Debt

9 Months Ended

Sep. 30, 2022

Debt Disclosure [Abstract]

Debt

Debt consisted of the following (in millions):


	September 30, 2022		December 31, 2021
SHORT-TERM DEBT



Senior notes:
3.65% senior notes due June 2022 (1)	$	—	$	750
2.85% senior notes due January 2023	400		—
Other	59		72
Total short-term debt	459		822

LONG-TERM DEBT
Senior notes, net of unamortized discounts and debt issuance costs of $48 and $54, respectively	7,934		8,329


Other	52		69
Total long-term debt	7,986		8,398
Total debt (2)	$	8,445	$	9,220

(1)These senior notes were redeemed on March 1, 2022.

(2)Our fixed-rate senior notes had a face value of approximately $8.4 billion and $9.1 billion as of September 30, 2022 and December 31, 2021, respectively. We estimated the aggregate fair value of these notes as of September 30, 2022 and December 31, 2021 to be approximately $7.3 billion and $9.9 billion, respectively. Our 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. The fair value estimate for our senior notes is based upon observable market data and is classified in Level 2 of the fair value hierarchy.

Credit Facilities

In August 2022, we amended our credit facility agreements to, among other things, extend the maturity dates of our senior secured hedged inventory facility and senior unsecured revolving credit facility by one year to August 2025 and August 2027, respectively.

Borrowings and Repayments

Total borrowings under our credit facilities and commercial paper program for the nine months ended September 30, 2022 and 2021 were approximately $19.3 billion and $31.2 billion, respectively. Total repayments under our credit facilities and commercial paper program were approximately $19.3 billion and $31.9 billion for the nine months ended September 30, 2022 and 2021, 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.

On March 1, 2022, we redeemed our 3.65%, $750 million senior notes due June 2022.

Letters of Credit

In connection with our merchant activities, we provide certain suppliers with irrevocable standby letters of credit to secure our obligation for the purchase and transportation of crude oil and NGL. Additionally, we issue letters of credit to support insurance programs, derivative transactions, including hedging-related margin obligations, and construction activities. At September 30, 2022 and December 31, 2021, we had outstanding letters of credit of $58 million and $98 million, respectively.

- Definition

The entire disclosure for information about short-term and long-term debt arrangements, which includes amounts of borrowings under each line of credit, note payable, commercial paper issue, bonds indenture, debenture issue, own-share lending arrangements and any other contractual agreement to repay funds, and about the underlying arrangements, rationale for a classification as long-term, including repayment terms, interest rates, collateral provided, restrictions on use of assets and activities, whether or not in compliance with debt covenants, and other matters important to users of the financial statements, such as the effects of refinancing and noncompliance with debt covenants.

+ References

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+ Details

Derivatives and Risk Management Activities (Tables)

9 Months Ended

Sep. 30, 2022

Derivatives and Risk Management Activities

Impact of derivatives recognized in earnings

The following table summarizes the impact of our commodity derivatives recognized in earnings (in millions):


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Product sales revenues	$	320	$	(206)	$	183	$	(804)
Field operating costs	23		17		44		73

Net gain/(loss) from commodity derivative activity	$	343	$	(189)	$	227	$	(731)

Schedule of net broker receivable/(payable)

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


	September 30, 2022		December 31, 2021
Initial margin	$	97	$	133
Variation margin posted/(returned)	(154)		173
Letters of credit	(25)		(47)
Net broker receivable/(payable)	$	(82)	$	259

Summary of derivative assets and liabilities on condensed consolidated balance sheets on a gross basis

The following table reflects the Condensed 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 Condensed Consolidated Balance Sheet when the legal right of offset exists. Amounts in the table below are presented in millions.


	September 30, 2022								December 31, 2021
					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	$	311	$	(101)	$	(82)	$	128	$	90	$	(210)	$	259	$	139
Other long-term assets, net	38		(3)		—		35		3		—		—		3
Derivative Liabilities
Other current liabilities	6		(17)		—		(11)		4		(24)		—		(20)
Other long-term liabilities and deferred credits	2		(4)		—		(2)		3		(9)		—		(6)
Total	$	357	$	(125)	$	(82)	$	150	$	100	$	(243)	$	259	$	116

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

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


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Interest rate derivatives, net	$	16	$	6	$	88	$	36

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 September 30, 2022								Fair Value as of December 31, 2021
Recurring Fair Value Measures (1)	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Commodity derivatives	$	(29)	$	261	$	—	$	232	$	(17)	$	(124)	$	(2)	$	(143)
Interest rate derivatives	—		113		—		113		—		65		—		65

Preferred Distribution Rate Reset Option	—		—		(196)		(196)		—		—		—		—
Total net derivative asset/(liability)	$	(29)	$	374	$	(196)	$	149	$	(17)	$	(59)	$	(2)	$	(78)

(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):


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Beginning Balance	$	(147)	$	(13)	$	(2)	$	(29)
Net gains/(losses) for the period included in earnings	(49)		5		(196)		14
Settlements	—		1		2		8

Ending Balance	$	(196)	$	(7)	$	(196)	$	(7)

Change in unrealized gains/(losses) included in earnings relating to Level 3 derivatives still held at the end of the period	$	(49)	$	5	$	(196)	$	14

Commodity Derivatives

Derivatives and Risk Management Activities

Summary of open derivative positions

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 September 30, 2022:

Notional Volume

(Short)/Long

Remaining Tenor

Natural gas purchases

61.6 Bcf

December 2024

Propane sales

(12.2) MMbls

December 2024

Butane sales

(2.5) MMbls

December 2024

Condensate sales

(0.9) MMbls

December 2024

Fuel gas requirements (1)

9.1 Bcf

December 2023

Power supply requirements (1)

0.5 TWh

December 2023

(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 derivatives

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 September 30, 2022 (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

4 forward starting swaps

(30-year)

100

6/14/2024

0.74

Cash flow hedge

Revenues and Accounts Receivable - Disaggregation of Revenue (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Crude Oil \| Sales
Disaggregation of Revenue
Revenue from contracts with customers	$ 13,362	$ 10,427	$ 41,796	$ 27,776
Crude Oil \| Transportation
Disaggregation of Revenue
Revenue from contracts with customers	185	122	515	325
Crude Oil \| Terminalling, Storage and Other
Disaggregation of Revenue
Revenue from contracts with customers	90	99	270	345
NGL \| Sales
Disaggregation of Revenue
Revenue from contracts with customers	417	386	1,761	1,514
NGL \| Transportation
Disaggregation of Revenue
Revenue from contracts with customers	7	6	23	17
NGL \| Terminalling, Storage and Other
Disaggregation of Revenue
Revenue from contracts with customers	21	22	66	64
Operating Segments
Disaggregation of Revenue
Revenue from contracts with customers	14,082	11,062	44,431	30,041
Operating Segments \| Crude Oil
Disaggregation of Revenue
Revenue from contracts with customers	13,637	10,648	42,581	28,446
Operating Segments \| NGL
Disaggregation of Revenue
Revenue from contracts with customers	$ 445	$ 414	$ 1,850	$ 1,595

- 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.

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+ Details

Derivatives and Risk Management Activities - Broker Receivable/Payable (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Offsetting Assets, Liabilities
Initial margin	$ 97	$ 133
Variation margin posted/(returned)	(154)	173
Letters of credit	(58)	(98)
Net broker payable	(82)
Net broker receivable		259
Exchange traded
Offsetting Assets, Liabilities
Letters of credit	$ (25)	$ (47)

Derivatives and Risk Management Activities - Net Unrealized Gain/(Loss) Recognized in AOCI (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021	Dec. 31, 2021
Derivative assets and liabilities
Proceeds received from early termination of interest rate hedging instruments			$ 42
Other current assets
Derivative assets and liabilities
Net fair value of interest rate hedges	$ 70		70
Other long-term assets, net
Derivative assets and liabilities
Net fair value of interest rate hedges	43		43		$ 65
AOCI cash flow hedge
Derivative assets and liabilities
Net loss deferred in AOCI	115		115
Interest rate derivatives
Derivative assets and liabilities
Net unrealized gain/(loss) recognized in AOCI	16	$ 6	88	$ 36
Interest Rate Swaps Terminated \| Cash flow hedge
Derivative assets and liabilities
Notional amount of derivatives	100		$ 100
Proceeds received from early termination of interest rate hedging instruments	$ 42

Derivatives and Risk Management Activities - Preferred Distribution Rate (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021	Dec. 31, 2021
Derivatives and Risk Management Activities
Gain (loss) recognized			$ (196)	$ 13
Preferred Distribution Rate Reset Option \| Derivatives Not Designated as a Hedge
Derivatives and Risk Management Activities
Derivative liability	$ 196		$ 196
Derivative liability [Extensible Enumeration]	Other long-term liabilities and deferred credits		Other long-term liabilities and deferred credits
Preferred Distribution Rate Reset Option \| Derivatives Not Designated as a Hedge \| Maximum
Derivatives and Risk Management Activities
Derivative liability					$ 1
Derivative liability [Extensible Enumeration]					Other long-term liabilities and deferred credits
Preferred Distribution Rate Reset Option \| Derivatives Not Designated as a Hedge \| Other expense, net
Derivatives and Risk Management Activities
Gain (loss) recognized	$ (49)	$ 4	$ (196)	$ 13

Revenues and Accounts Receivable - Narrative (Details)	9 Months Ended	12 Months Ended
Revenues and Accounts Receivable - Narrative (Details)	Sep. 30, 2022	Dec. 31, 2021
Revenue from Contract with Customer [Abstract]
Substantially all trade accounts receivable, net, maximum age of balances past their invoice date	30 days	30 days

Partners' Capital and Distributions - Distributions (Details) - USD ($) $ / shares in Units, $ in Millions					3 Months Ended		9 Months Ended
	Nov. 14, 2022	Aug. 12, 2022	May 13, 2022	Feb. 14, 2022	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Partners Capital and Distribution
Distributions paid					$ 274	$ 182	$ 775	$ 548
Common Units \| Cash Distribution
Partners Capital and Distribution
Distributions paid		$ 152	$ 153	$ 127
Distributions per common unit, paid (usd per unit)		$ 0.2175	$ 0.2175	$ 0.1800
Common Units \| Forecast \| Cash Distribution
Partners Capital and Distribution
Distributions paid	$ 152
Distributions per common unit, paid (usd per unit)	$ 0.2175
Public \| Common Units \| Cash Distribution
Partners Capital and Distribution
Distributions paid		$ 99	$ 100	$ 84
Public \| Common Units \| Forecast \| Cash Distribution
Partners Capital and Distribution
Distributions paid	$ 100
AAP \| Common Units \| Cash Distribution
Partners Capital and Distribution
Distributions paid		$ 53	$ 53	$ 43
AAP \| Common Units \| Forecast \| Cash Distribution
Partners Capital and Distribution
Distributions paid	$ 52

Partners' Capital and Distributions - Units Outstanding (Details) - shares	3 Months Ended						9 Months Ended
	Sep. 30, 2022	Jun. 30, 2022	Mar. 31, 2022	Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2021	Sep. 30, 2022	Sep. 30, 2021
Series A Preferred Units
Activity for preferred units and common units
Outstanding, beginning of period (units)	71,090,468	71,090,468	71,090,468	71,090,468	71,090,468	71,090,468	71,090,468	71,090,468
Outstanding, end of period (units)	71,090,468	71,090,468	71,090,468	71,090,468	71,090,468	71,090,468	71,090,468	71,090,468
Series B Preferred Units
Activity for preferred units and common units
Outstanding, beginning of period (units)	800,000	800,000	800,000	800,000	800,000	800,000	800,000	800,000
Outstanding, end of period (units)	800,000	800,000	800,000	800,000	800,000	800,000	800,000	800,000
Common Units
Activity for preferred units and common units
Outstanding, beginning of period (units)	697,939,946	702,668,178	704,991,540	717,371,576	722,055,847	722,380,416	704,991,540	722,380,416
Repurchase and cancellation of common units under the Common Equity Repurchase Program (units)		(4,876,062)	(2,375,299)	(6,626,711)	(4,940,592)	(350,000)
Issuances of common units under equity-indexed compensation plans (units)	392,739	147,830	51,937	377,017	256,321	25,431
Outstanding, end of period (units)	698,332,685	697,939,946	702,668,178	711,121,882	717,371,576	722,055,847	698,332,685	711,121,882

Debt (Tables)

9 Months Ended

Sep. 30, 2022

Debt Disclosure [Abstract]

Schedule of debt

Debt consisted of the following (in millions):


	September 30, 2022		December 31, 2021
SHORT-TERM DEBT



Senior notes:
3.65% senior notes due June 2022 (1)	$	—	$	750
2.85% senior notes due January 2023	400		—
Other	59		72
Total short-term debt	459		822

LONG-TERM DEBT
Senior notes, net of unamortized discounts and debt issuance costs of $48 and $54, respectively	7,934		8,329


Other	52		69
Total long-term debt	7,986		8,398
Total debt (2)	$	8,445	$	9,220

(1)These senior notes were redeemed on March 1, 2022.

Organization and Basis of Consolidation and Presentation - Segments and Ownership (Details) shares in Millions	9 Months Ended		12 Months Ended
	Sep. 30, 2022 segment shares	Sep. 30, 2021 segment	Sep. 30, 2022 segment
Organization
Operating segments number \| segment	2	3	2
AAP \| PAGP
Organization
Ownership interest	81.00%
PAA \| AAP
Organization
Ownership interest (units) \| shares	241.5
Ownership interest	31.00%

Segment Information

9 Months Ended

Sep. 30, 2022

Segment Reporting [Abstract]

Segment Information

During the fourth quarter of 2021, we effected changes in the primary financial information provided to our CODM for assessing performance and allocating resources to present two operating segments, Crude Oil and NGL. Prior to the fourth quarter of 2021, this information was organized into three operating segments: Transportation, Facilities and Supply and Logistics. All segment data and related disclosures for earlier periods presented herein have been recast to reflect the new segment reporting structure. Our CODM evaluates segment performance based on measures including Segment Adjusted EBITDA (as defined below) and maintenance capital. During the fourth quarter of 2021, we modified our definition of Segment Adjusted EBITDA to exclude amounts attributable to noncontrolling interests. In connection with the Permian JV formation in October 2021, our CODM determined this modification resulted in amounts that were more meaningful to evaluate segment performance. Amounts attributable to noncontrolling interests for earlier periods presented herein have been recast to reflect this modification. See Note 20 to our Consolidated Financial Statements included in Part IV of our 2021 Annual Report on Form 10-K for additional information regarding the modifications to our segment reporting and for a full discussion of our basis for segmentation and performance measures.

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 (d) our proportionate share of the depreciation and amortization expense of unconsolidated entities, further adjusted (e) 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 either related to investing activities (such as the purchase of linefill) or purchases of long-term inventory, 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 and (f) to exclude the portion of all preceding items that is attributable to noncontrolling interests (“Adjusted EBITDA attributable to noncontrolling interests”).

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


	Crude Oil		NGL		Intersegment Revenues Elimination		Total
Three Months Ended September 30, 2022
Revenues (1):
Product sales	$	13,367	$	735	$	(101)	$	14,001
Services	308		35		(8)		335
Total revenues	$	13,675	$	770	$	(109)	$	14,336
Equity earnings in unconsolidated entities	$	105	$	—			$	105
Segment Adjusted EBITDA	$	536	$	86			$	622

Maintenance capital expenditures	$	35	$	41			$	76





Three Months Ended September 30, 2021
Revenues (1):
Product sales	$	10,468	$	133	$	(86)	$	10,515
Services	233		33		(5)		261
Total revenues	$	10,701	$	166	$	(91)	$	10,776
Equity earnings in unconsolidated entities	$	69	$	—			$	69
Segment Adjusted EBITDA	$	459	$	54			$	513

Maintenance capital expenditures	$	24	$	19			$	43





Nine Months Ended September 30, 2022
Revenues (1):
Product sales	$	41,802	$	1,943	$	(355)	$	43,390
Services	892		132		(24)		1,000
Total revenues	$	42,694	$	2,075	$	(379)	$	44,390
Equity earnings in unconsolidated entities	$	306	$	—			$	306
Segment Adjusted EBITDA	$	1,482	$	367			$	1,849

Maintenance capital expenditures	$	80	$	66			$	146





Nine Months Ended September 30, 2021
Revenues (1):
Product sales	$	27,553	$	932	$	(264)	$	28,221
Services	780		102		(14)		868
Total revenues	$	28,333	$	1,034	$	(278)	$	29,089
Equity earnings in unconsolidated entities	$	190	$	—			$	190
Segment Adjusted EBITDA	$	1,486	$	144			$	1,630

Maintenance capital expenditures	$	75	$	41			$	116

Segment Adjusted EBITDA Reconciliation

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


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Segment Adjusted EBITDA	$	622	$	513	$	1,849	$	1,630
Adjustments: (1)
Depreciation and amortization of unconsolidated entities (2)	(21)		(21)		(58)		(109)
Gains/(losses) from derivative activities and inventory valuation adjustments (3)	376		(13)		363		23
Long-term inventory costing adjustments (4)	(83)		13		22		81
Deficiencies under minimum volume commitments, net (5)	(16)		(56)		(31)		(31)
Equity-indexed compensation expense (6)	(9)		(6)		(24)		(14)
Net gain/(loss) on foreign currency revaluation (7)	2		(3)		1		(2)
Line 901 incident (8)	—		—		(85)		—
Significant transaction-related expenses (9)	—		(2)		—		(5)
Adjusted EBITDA attributable to noncontrolling interests (10)	98		5		264		12
Depreciation and amortization	(238)		(178)		(711)		(551)
Gains/(losses) on asset sales and asset impairments, net	—		(221)		46		(592)
Gain on investment in unconsolidated entities	1		—		1		—
Interest expense, net	(99)		(106)		(305)		(319)
Other income/(expense), net	(82)		(10)		(237)		13
Income/(loss) before tax	551		(85)		1,095		136
Income tax (expense)/benefit	(109)		30		(177)		16
Net income/(loss)	442		(55)		918		152
Net income attributable to noncontrolling interests	(58)		(4)		(144)		(9)
Net income/(loss) attributable to PAA	$	384	$	(59)	$	774	$	143

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

(2)Includes our proportionate share of the depreciation and amortization expense (including write-downs related to cancelled projects) of unconsolidated entities.

(10)Reflects amounts attributable to noncontrolling interests in the Permian JV and Red River LLC.

- 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
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-Name Accounting Standards Codification
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-URI https://asc.fasb.org/extlink&oid=126901519&loc=d3e8924-108599

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+ Details

Revenues and Accounts Receivable

9 Months Ended

Sep. 30, 2022

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. See Note 3 to our Consolidated Financial Statements included in Part IV of our 2021 Annual Report on Form 10-K for additional information regarding our types of revenues and policies for revenue recognition.

Revenues from Contracts with Customers. The following tables present our revenues from contracts with customers disaggregated by segment and type of activity (in millions):


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Crude Oil segment revenues from contracts with customers
Sales	$	13,362	$	10,427	$	41,796	$	27,776
Transportation	185		122		515		325
Terminalling, Storage and Other	90		99		270		345
Total Crude Oil segment revenues from contracts with customers	$	13,637	$	10,648	$	42,581	$	28,446


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
NGL segment revenues from contracts with customers
Sales	$	417	$	386	$	1,761	$	1,514
Transportation	7		6		23		17
Terminalling, Storage and Other	21		22		66		64
Total NGL segment revenues from contracts with customers	$	445	$	414	$	1,850	$	1,595

Reconciliation to Total Revenues of Reportable Segments. The following disclosures only include information regarding revenues associated with consolidated entities; revenues from entities accounted for by the equity method are not included. The following tables present the reconciliation of our revenues from contracts with customers to total revenues of reportable segments and total revenues as disclosed in our Condensed Consolidated Statements of Operations (in millions):


Three Months Ended September 30, 2022	Crude Oil		NGL		Total
Revenues from contracts with customers	$	13,637	$	445	$	14,082
Other items in revenues	38		325		363
Total revenues of reportable segments	$	13,675	$	770	$	14,445
Intersegment revenue elimination					(109)
Total revenues					$	14,336

Three Months Ended September 30, 2021	Crude Oil		NGL		Total
Revenues from contracts with customers	$	10,648	$	414	$	11,062
Other items in revenues	53		(248)		(195)
Total revenues of reportable segments	$	10,701	$	166	$	10,867
Intersegment revenue elimination					(91)
Total revenues					$	10,776

Nine Months Ended September 30, 2022	Crude Oil		NGL		Total
Revenues from contracts with customers	$	42,581	$	1,850	$	44,431
Other items in revenues	113		225		338
Total revenues of reportable segments	$	42,694	$	2,075	$	44,769
Intersegment revenues					(379)
Total revenues					$	44,390

Nine Months Ended September 30, 2021	Crude Oil		NGL		Total
Revenues from contracts with customers	$	28,446	$	1,595	$	30,041
Other items in revenues	(113)		(561)		(674)
Total revenues of reportable segments	$	28,333	$	1,034	$	29,367
Intersegment revenues					(278)
Total revenues					$	29,089

Minimum Volume Commitments. We have certain agreements that require counterparties to transport or throughput a minimum volume over an agreed upon period. 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):


Counterparty Deficiencies	Financial Statement Classification	September 30, 2022		December 31, 2021
Billed and collected	Liability	$	65	$	63
Unbilled (1)	N/A	11		16
Total		$	76	$	79

(1)Amounts were related to deficiencies for which the counterparties had not met their contractual minimum commitments and are not reflected in our Condensed 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 change in the liability balance associated with contracts with customers (in millions):


	Contract Liabilities
Balance at December 31, 2021	$	141
Amounts recognized as revenue	(23)

Additions	25

Balance at September 30, 2022	$	143

Remaining Performance Obligations. The information below includes the amount of consideration allocated to partially and wholly unsatisfied remaining 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 September 30, 2022 (in millions):


	Remainder of 2022		2023		2024		2025		2026		2027 and Thereafter
Pipeline revenues supported by minimum volume commitments and capacity agreements (1)	$	50	$	195	$	174	$	152	$	96	$	404
Terminalling, storage and other agreement revenues	67		234		178		106		80		604
Total	$	117	$	429	$	352	$	258	$	176	$	1,008

(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;

•Buy/sell arrangements with future committed volumes;

•Short-term contracts and those with variable consideration, due to the election of practical expedients;

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

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

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 merchant activities that can generally be described as high volume and low margin activities, in many cases involving exchanges of crude oil volumes.

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 September 30, 2022 and December 31, 2021, substantially all of our trade accounts receivable were less than 30 days past their invoice date. Our expected credit losses are immaterial. Although we consider our credit procedures to be adequate to mitigate any significant credit losses, 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 Condensed Consolidated Balance Sheets (in millions):


	September 30, 2022		December 31, 2021
Trade accounts receivable arising from revenues from contracts with customers	$	4,197	$	4,031
Other trade accounts receivables and other receivables (1)	6,916		5,126
Impact due to contractual rights of offset with counterparties	(7,012)		(4,452)
Trade accounts receivable and other receivables, net	$	4,101	$	4,705

(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 https://asc.fasb.org/topic&trid=49130388

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Reference 3: http://www.xbrl.org/2003/role/disclosureRef
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+ Details

Revenues and Accounts Receivable - Contract Balances (Details) $ in Millions	9 Months Ended
	Sep. 30, 2022 USD ($)
Change In Contract With Customer, Liability
Beginning balance	$ 141
Amounts recognized as revenue	(23)
Additions	25
Ending balance	$ 143

Inventory, Linefill and Long-term Inventory (Tables)

9 Months Ended

Sep. 30, 2022

Inventory Disclosure [Abstract]

Schedule of inventory

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


	September 30, 2022						December 31, 2021
	Volumes	Unit of Measure	Carrying Value		Price/ Unit (1)		Volumes	Unit of Measure	Carrying Value		Price/ Unit (1)
Inventory
Crude oil	2,830	barrels	$	207	$	73.14	8,041	barrels	$	544	$	67.65
NGL	9,698	barrels	389		$	40.11	6,982	barrels	234		$	33.51

Other	N/A		7		N/A		N/A		5		N/A
Inventory subtotal			603						783

Linefill
Crude oil	15,499	barrels	900		$	58.07	15,199	barrels	862		$	56.71
NGL	1,894	barrels	54		$	28.51	1,633	barrels	45		$	27.56

Linefill subtotal			954						907

Long-term inventory
Crude oil	3,079	barrels	259		$	84.12	2,973	barrels	209		$	70.30
NGL	1,069	barrels	42		$	39.29	1,135	barrels	44		$	38.77
Long-term inventory subtotal			301						253

Total			$	1,858					$	1,943

(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.

Schedule of linefill and long-term inventory

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


	September 30, 2022						December 31, 2021
	Volumes	Unit of Measure	Carrying Value		Price/ Unit (1)		Volumes	Unit of Measure	Carrying Value		Price/ Unit (1)
Inventory
Crude oil	2,830	barrels	$	207	$	73.14	8,041	barrels	$	544	$	67.65
NGL	9,698	barrels	389		$	40.11	6,982	barrels	234		$	33.51

Other	N/A		7		N/A		N/A		5		N/A
Inventory subtotal			603						783

Linefill
Crude oil	15,499	barrels	900		$	58.07	15,199	barrels	862		$	56.71
NGL	1,894	barrels	54		$	28.51	1,633	barrels	45		$	27.56

Linefill subtotal			954						907

Long-term inventory
Crude oil	3,079	barrels	259		$	84.12	2,973	barrels	209		$	70.30
NGL	1,069	barrels	42		$	39.29	1,135	barrels	44		$	38.77
Long-term inventory subtotal			301						253

Total			$	1,858					$	1,943

Partners' Capital and Distributions (Tables)

9 Months Ended

Sep. 30, 2022

Limited Partners' Capital Account

Schedule of activity for preferred units and common units

The following tables present the activity for our preferred and common units:


	Limited Partners
	Series A Preferred Units	Series B Preferred Units	Common Units
Outstanding at December 31, 2021	71,090,468	800,000	704,991,540
Repurchase and cancellation of common units under the Common Equity Repurchase Program	—	—	(2,375,299)
Issuances of common units under equity-indexed compensation plans	—	—	51,937
Outstanding at March 31, 2022	71,090,468	800,000	702,668,178
Repurchase and cancellation of common units under the Common Equity Repurchase Program	—	—	(4,876,062)
Issuances of common units under equity-indexed compensation plans	—	—	147,830
Outstanding at June 30, 2022	71,090,468	800,000	697,939,946

Issuances of common units under equity-indexed compensation plans	—	—	392,739

Outstanding at September 30, 2022	71,090,468	800,000	698,332,685


	Limited Partners
	Series A Preferred Units	Series B Preferred Units	Common Units
Outstanding at December 31, 2020	71,090,468	800,000	722,380,416

Repurchase and cancellation of common units under the Common Equity Repurchase Program	—	—	(350,000)
Issuances of common units under equity-indexed compensation plans	—	—	25,431
Outstanding at March 31, 2021	71,090,468	800,000	722,055,847
Repurchase and cancellation of common units under the Common Equity Repurchase Program	—	—	(4,940,592)
Issuances of common units under equity-indexed compensation plans	—	—	256,321
Outstanding at June 30, 2021	71,090,468	800,000	717,371,576
Repurchase and cancellation of common units under the Common Equity Repurchase Program	—	—	(6,626,711)
Issuances of common units under equity-indexed compensation plans	—	—	377,017
Outstanding at September 30, 2021	71,090,468	800,000	711,121,882

Series A Preferred Units

Limited Partners' Capital Account

Schedule of distributions

The following table details distributions to our Series A preferred unitholders paid during or pertaining to the first nine months of 2022 (in millions, except per unit data):


	Series A Preferred Unitholders
Distribution Payment Date	Cash Distribution		Distribution per Unit
November 14, 2022 (1)	$	37	$	0.525
August 12, 2022	$	37	$	0.525
May 13, 2022	$	37	$	0.525
February 14, 2022	$	37	$	0.525

Series B Preferred Units

Limited Partners' Capital Account

Schedule of distributions

The following table details distributions paid to our Series B preferred unitholders (in millions, except per unit data):


	Series B Preferred Unitholders
Distribution Payment Date	Cash Distribution		Distribution per Unit
November 15, 2022 (1)	$	24.5	$	30.625
May 16, 2022	$	24.5	$	30.625

(1)Payable to unitholders of record at the close of business on October 31, 2022 for the period from May 17, 2022 through November 14, 2022.

Common Units

Limited Partners' Capital Account

Schedule of distributions

The following table details distributions to our common unitholders paid during or pertaining to the first nine months of 2022 (in millions, except per unit data):


	Distributions						Cash Distribution per Common Unit
	Common Unitholders				Total Cash Distribution
Distribution Payment Date	Public		AAP
November 14, 2022 (1)	$	100	$	52	$	152	$	0.2175
August 12, 2022	$	99	$	53	$	152	$	0.2175
May 13, 2022	$	100	$	53	$	153	$	0.2175
February 14, 2022	$	84	$	43	$	127	$	0.1800

(1)Payable to unitholders of record at the close of business on October 31, 2022 for the period from July 1, 2022 through September 30, 2022.

Commitments and Contingencies - Legal, Environmental or Regulatory (Details)			1 Months Ended		9 Months Ended	12 Months Ended	89 Months Ended
	Nov. 01, 2022 USD ($)	Oct. 27, 2022 USD ($)	Sep. 30, 2021 USD ($)	May 31, 2015 bbl	Sep. 30, 2022 USD ($) lawsuit	Sep. 30, 2021 USD ($)	Sep. 30, 2022 USD ($) lawsuit	Dec. 31, 2021 USD ($)	Apr. 25, 2019 USD ($)	Sep. 07, 2018 count
Line 901 Incident
Legal, Environmental or Regulatory Matters
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					$ 730,000,000		$ 730,000,000
Coverage limit under insurance program					500,000,000		500,000,000
Recoveries from insurance carriers							265,000,000
Total release costs probable of recovery					$ 505,000,000		$ 505,000,000
Line 901 Incident \| Civil Penalties \| Judicial Ruling
Legal, Environmental or Regulatory Matters
Amount paid to plaintiff						$ 24,000,000
Line 901 Incident \| Consent Decree, Compensation for Injuries to, Destruction of, Loss of Use of, Natural Resources \| Judicial Ruling
Legal, Environmental or Regulatory Matters
Amount paid to plaintiff						$ 22,325,000
Line 901 Incident \| May 2016 Indictment
Legal, Environmental or Regulatory Matters
Number of felony discharges 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
Number of misdemeanor charges found not guilty, strict liability animal takings \| count										1
Line 901 Incident \| May 2016 Indictment \| Judicial Ruling
Legal, Environmental or Regulatory Matters
Fines or penalties assessed									$ 3,350,000
Line 901 Incident \| May 2016 Indictment \| Maximum \| Judicial Ruling
Legal, Environmental or Regulatory Matters
Amount awarded to claimants by court			$ 150,000
Line 901 Incident \| Class Action Lawsuits
Legal, Environmental or Regulatory Matters
Number of cases filed \| lawsuit							9
Line 901 Incident \| Class Action Lawsuits \| Pending Litigation
Legal, Environmental or Regulatory Matters
Number of proceedings pending \| lawsuit					2		2
Line 901 Incident \| Class Action Lawsuit Claim of Damages \| Pending Litigation
Legal, Environmental or Regulatory Matters
Litigation settlement agreement amount, subject to approval					$ 230,000,000
Line 901 Incident \| Class Action Lawsuit Claim of Damages \| Settled Litigation \| Subsequent Event
Legal, Environmental or Regulatory Matters
Payments for legal settlements		$ 230,000,000
Line 901 Incident \| Unitholder Derivative Lawsuits \| Pending Litigation
Legal, Environmental or Regulatory Matters
Number of proceedings pending \| lawsuit					1		1
Line 901 Incident \| Unitholder Derivative Lawsuits \| Settled Litigation \| Subsequent Event
Legal, Environmental or Regulatory Matters
Litigation settlement agreement, payment of plaintiff's attorneys' fees by our insurers	$ 1,000,000
Trade accounts payable and Other current liabilities \| Line 901 Incident
Legal, Environmental or Regulatory Matters
Remaining undiscounted liability					$ 330,000,000		$ 330,000,000
Trade accounts receivable and other receivables, net \| Line 901 Incident
Legal, Environmental or Regulatory Matters
Receivable for remaining portion of release costs probable of recovery from insurance					240,000,000		240,000,000
Excluding Line 901 Incident
Legal, Environmental or Regulatory Matters
Estimated undiscounted reserve for environmental liabilities					55,000,000		55,000,000	$ 57,000,000
Estimated undiscounted reserve for environmental liabilities, short-term					$ 10,000,000		$ 10,000,000	$ 11,000,000
Estimated undiscounted reserve for environmental liabilities, short-term [Extensible Enumeration]					Other current liabilities		Other current liabilities	Other current liabilities
Estimated undiscounted reserve for environmental liabilities, long-term					$ 45,000,000		$ 45,000,000	$ 46,000,000
Estimated undiscounted reserve for environmental liabilities, long-term [Extensible Enumeration]					Other long-term liabilities and deferred credits		Other long-term liabilities and deferred credits	Other long-term liabilities and deferred credits
Amounts probable of recovery under insurance and from third parties under indemnification agreements					$ 6,000,000		$ 6,000,000	$ 11,000,000
Excluding Line 901 Incident \| Other long-term assets, net
Legal, Environmental or Regulatory Matters
Amounts probable of recovery under insurance and from third parties under indemnification agreements					$ 1,000,000		$ 1,000,000	$ 1,000,000

Related Party Transactions (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021	Dec. 31, 2021
Related Party Transactions [Abstract]
Revenues from related parties	$ 11	$ 8	$ 33	$ 25
Purchases and related costs from related parties	90	$ 103	274	$ 288
Trade accounts receivable and other receivables, net from related parties	55		55		$ 41
Trade accounts payable to related parties	$ 56		$ 56		$ 72

- Definition

The aggregate amount of receivables to be collected from related parties where one party can exercise control or significant influence over another party; including affiliates, owners or officers and their immediate families, pension trusts, and so forth, at the financial statement date. which are usually due within one year (or one business cycle).

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- Definition

Carrying amount as of the balance sheet date of obligations due all related parties. For classified balance sheets, represents the current portion of such liabilities (due within one year or within the normal operating cycle if longer).

+ References

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Amount of revenue, fees and commissions earned from transactions between (a) a parent company and its subsidiaries; (b) subsidiaries of a common parent; (c) an entity and trusts for the benefit of employees, for example, but not limited to, pension and profit-sharing trusts that are managed by or under the trusteeship of the entity's management; (d) an entity and its principal, owners, management, or members of their immediate families; and (e) affiliates.

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+ Details

Net Income/(Loss) Per Common Unit (Tables)

9 Months Ended

Sep. 30, 2022

Earnings Per Share [Abstract]

Computation of basic and diluted net income/(loss) per common unit

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


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Basic and Diluted Net Income/(Loss) per Common Unit
Net income/(loss) attributable to PAA	$	384	$	(59)	$	774	$	143
Distributions to Series A preferred unitholders	(37)		(37)		(112)		(112)
Distributions to Series B preferred unitholders	(12)		(12)		(37)		(37)
Amounts allocated to participating securities	(2)		(1)		(4)		(1)

Net income/(loss) allocated to common unitholders (1)	$	333	$	(109)	$	621	$	(7)

Basic and diluted weighted average common units outstanding	698		715		702		719

Basic and diluted net income/(loss) per common unit	$	0.48	$	(0.15)	$	0.89	$	(0.01)

(1)We calculate net income/(loss) allocated to common unitholders based on the distributions pertaining to the current period’s net income. After adjusting for the appropriate period’s distributions, the remaining undistributed earnings or excess distributions over earnings (i.e., undistributed loss), if any, are allocated to the common unitholders and participating securities in accordance with the contractual terms of our partnership agreement in effect for the period and as further prescribed under the two-class method.

Commitments and Contingencies	9 Months Ended
Commitments and Contingencies	Sep. 30, 2022
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies 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 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). Assets we have acquired or will acquire in the future may have environmental remediation liabilities for which we are not indemnified or insured. 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. We also may discover environmental impacts from past releases that were previously unidentified. 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 September 30, 2022, our estimated undiscounted reserve for environmental liabilities (excluding liabilities related to the Line 901 incident, as discussed further below) totaled $55 million, of which $10 million was classified as short-term and $45 million was classified as long-term. At December 31, 2021, our estimated undiscounted reserve for environmental liabilities (excluding liabilities related to the Line 901 incident) totaled $57 million, of which $11 million was classified as short-term and $46 million was classified as long-term. Such short-term liabilities are reflected in “Other current liabilities” and long-term liabilities are reflected in “Other long-term liabilities and deferred credits” on our Condensed Consolidated Balance Sheets. At September 30, 2022 and December 31, 2021, we had recorded receivables (excluding receivables related to the Line 901 incident) totaling $6 million and $11 million, respectively, for amounts probable of recovery under insurance and from third parties under indemnification agreements, $1 million of which for each period is reflected in “Other long-term assets, net” and the remainder is reflected in “Trade accounts receivable and other receivables, net” on our Condensed 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, which resolved all regulatory claims related to the incident, 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. On October 13, 2022, Plains sold Line 901 and the Sisquoc to Pentland portion of Line 903 to Pacific Pipeline Company, an indirect wholly owned subsidiary of Exxon Mobil Corporation. As required by the terms of the Consent Decree, such purchaser assumed responsibility for compliance with the Consent Decree as it relates to the future ownership and operation of Line 901 and the Sisquoc to Pentland portion of Line 903. 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. In September 2021, the Superior Court concluded a series of hearings on the issue of whether there were any “direct victims” of the spill that are entitled to restitution under applicable criminal law. Through a series of final orders issued at the trial court level and without affecting any rights of the claimants under civil law, the Court dismissed the vast majority of the claims and ruled that the claimants were not entitled to restitution under applicable criminal laws. The Court did award an aggregate amount of less than $150,000 to a handful of claimants and we settled with approximately 40 claimants before the hearings for aggregate consideration that is not material. The prosecution and certain separately represented claimants have appealed the Court’s rulings. 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 remained pending in the United States District Court for the Central District of California. In the first proceeding, the plaintiffs claimed 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. In order to fully and finally resolve all claims and litigation for both classes, we have reached an agreement in principle to settle this case in exchange for a payment of $230 million (the “Class Action Settlement”). The Class Action Settlement was formally approved by the trial court on September 20, 2022, and we made the $230 million settlement payment on October 27, 2022. 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 and the purchaser of Line 901 and the Sisquoc to Pentland portion of Line 903 will be joining this proceeding as a co-defendant with respect to its interest in such acquired pipelines. In addition, after various other unitholder derivative lawsuits were either dismissed or consolidated, one proceeding remains pending in Delaware Chancery Court. Generally, the plaintiffs in the remaining derivative lawsuit claim that PAGP’s Board of Directors failed to exercise proper oversight over PAA’s pipeline integrity efforts. In April 2022, Plains entered into a settlement agreement to settle this lawsuit, subject to court approval and notice to all PAA unitholders (the “Derivative Settlement”). Following preliminary court approval, on May 23, 2022 we filed a Current Report on Form 8-K with the SEC. We also posted notice on our website and mailed copies of the notice to all record holders of PAA common units as of August 10, 2022. The key terms of the Derivative Settlement include a payment of Plaintiff’s attorneys’ fees by our insurers in the amount of approximately $1.0 million and the agreement of Plains to comply with various covenants regarding the implementation or continuation of certain Board oversight practices with respect to pipeline integrity. At a settlement hearing held on November 1, 2022, the Delaware Chancery Court approved the terms of the Derivative Settlement. We 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. The following lawsuits remain: (i) a lawsuit filed in the United States District Court for the Central District of California that was remanded to the California Superior Court in Santa Barbara County 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; (ii) a lawsuit filed by the California State Land Commission in California Superior Court in Santa Barbara County, seeking lost royalties following the shut-down of Line 901, as well as cost related to the decommissioning of such platform, and (iii) lawsuits filed in California Superior Court in Santa Barbara County, by various companies and individuals who provided labor, goods, or services associated with oil production activities they claim were disrupted following the Line 901 incident. We are vigorously defending these remaining lawsuits and believe we have strong defenses, including a lack of duty owed to the claimants to keep Line 901 in service. In connection with the foregoing, including the Class Action Settlement and the Derivative Settlement, we have made adjustments to our total estimated Line 901 costs and the portion of such costs that we believe are probable of recovery from insurance carriers, net of deductibles. Effective as of September 30, 2022, we estimate that the aggregate total costs we have incurred or will incur with respect to the Line 901 incident will be approximately $730 million, which includes actual and projected emergency response and clean-up costs, natural resource damage assessments, fines and penalties payable pursuant to the Consent Decree, certain third party claims settlements (including the Class Action Settlement and the Derivative Settlement), and estimated costs associated with our remaining Line 901 lawsuits and claims as described above, as well as estimates for certain legal fees and statutory interest where applicable. We accrue such estimates of aggregate total costs to “Field operating costs” in our Condensed 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, with respect to potential losses that we regard as only reasonably possible or remote, we have made assumptions regarding the strength of our legal position based on our assessment of the relevant facts and applicable law and precedent; if our assumptions regarding such matters turn out to be inaccurate (i.e., we are found to be liable under circumstances where we regard the likelihood of loss as being only reasonably possible or remote), we could be responsible for significant costs and expenses that are not currently included in our estimates and accruals. In addition, for any potential losses that we regard as probable and for which we have accrued an estimate of the potential losses, our estimates regarding damages, legal fees, court costs and interest could turn out to be inaccurate and the actual losses we incur could be significantly higher than the amounts included in our estimates and accruals. Also, 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 September 30, 2022, we had a remaining undiscounted gross liability of approximately $330 million related to this event, which aggregate amount is reflected in “Trade accounts payable” and “Other current liabilities” on our Condensed Consolidated Balance Sheet. We maintain insurance coverage, which is subject to certain exclusions and deductibles, in the event of such environmental liabilities; however, after giving effect to the settlements described above and assuming full collection of costs that we believe are probable of recovery from insurance providers, net of deductibles, we will reach the limit of our $500 million 2015 insurance program applicable to the Line 901 incident. Through September 30, 2022, we had collected, subject to customary reservations, approximately $265 million out of the $505 million of release costs that we believe are probable of recovery from insurance carriers (including the 2015 insurance program), net of deductibles. Therefore, as of September 30, 2022, we have recognized a receivable of approximately $240 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 Condensed 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. Taking into account the costs that we have included in our total estimate of costs for the Line 901 incident and considering what we regard as very strong defenses to the claims made in our remaining Line 901 lawsuits, we do not believe the ultimate resolution of such remaining lawsuits will have a material adverse effect on our consolidated financial condition, results of operations or cash flows. Other Litigation Matters. On July 19, 2022 Hartree Natural Gas Storage, LLC (“Hartree”) filed a lawsuit under seal in the Superior Court for the State of Delaware asserting claims against PAA Natural Gas Storage, L.P. and PAA arising out of a Membership Interest Purchase Agreement relating to the 2021 sale of the Pine Prairie Energy Center natural gas storage facility to Hartree. We believe the claims are without merit and that the outcome of the lawsuit will not have a material adverse effect on our financial condition, results of operations or cash flows. We intend to vigorously defend against the claims asserted in the lawsuit. 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. 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. 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. While we strive to maintain adequate insurance coverage, our actual costs may exceed our coverage levels and 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.

Derivatives and Risk Management Activities - Interest Rate Risk Hedging (Details) - Cash flow hedge $ in Millions	9 Months Ended
	Sep. 30, 2022 USD ($) contract
8 forward starting interest rate swaps (30-year), 1.38%
Interest Rate Risk Hedging
Number of interest rate derivatives \| contract	8
Term of derivative contract	30 years
Notional amount of derivatives \| $	$ 200
Average rate locked (percent)	1.38%
4 forward starting interest rate swaps (30-year), 0.74%
Interest Rate Risk Hedging
Number of interest rate derivatives \| contract	4
Term of derivative contract	30 years
Notional amount of derivatives \| $	$ 100
Average rate locked (percent)	0.74%

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
CURRENT ASSETS
Cash and cash equivalents	$ 623	$ 449
Trade accounts receivable and other receivables, net	4,101	4,705
Inventory	603	783
Other current assets	247	200
Total current assets	5,574	6,137
PROPERTY AND EQUIPMENT	19,310	19,257
Accumulated depreciation	(4,745)	(4,354)
Property and equipment, net	14,565	14,903
OTHER ASSETS
Investments in unconsolidated entities	3,684	3,805
Intangible assets, net	1,785	1,960
Linefill	954	907
Long-term operating lease right-of-use assets, net	338	393
Long-term inventory	301	253
Other long-term assets, net	256	251
Total assets	27,457	28,609
CURRENT LIABILITIES
Trade accounts payable	3,995	4,810
Short-term debt	459	822
Other current liabilities	879	600
Total current liabilities	5,333	6,232
LONG-TERM LIABILITIES
Senior notes, net	7,934	8,329
Other long-term debt, net	52	69
Long-term operating lease liabilities	300	339
Other long-term liabilities and deferred credits	1,095	830
Total long-term liabilities	9,381	9,567
COMMITMENTS AND CONTINGENCIES (NOTE 10)
PARTNERS’ CAPITAL
Total partners’ capital excluding noncontrolling interests	9,944	9,972
Noncontrolling interests	2,799	2,838
Total partners’ capital	12,743	12,810
Total liabilities and partners’ capital	27,457	28,609
Series A Preferred Units
PARTNERS’ CAPITAL
Partners' capital	1,505	1,505
Series B Preferred Units
PARTNERS’ CAPITAL
Partners' capital	787	787
Common Units
PARTNERS’ CAPITAL
Partners' capital	$ 7,652	$ 7,680

Inventory, Linefill and Long-term Inventory

9 Months Ended

Sep. 30, 2022

Inventory Disclosure [Abstract]

Inventory, Linefill and Long-term Inventory

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


	September 30, 2022						December 31, 2021
	Volumes	Unit of Measure	Carrying Value		Price/ Unit (1)		Volumes	Unit of Measure	Carrying Value		Price/ Unit (1)
Inventory
Crude oil	2,830	barrels	$	207	$	73.14	8,041	barrels	$	544	$	67.65
NGL	9,698	barrels	389		$	40.11	6,982	barrels	234		$	33.51

Other	N/A		7		N/A		N/A		5		N/A
Inventory subtotal			603						783

Linefill
Crude oil	15,499	barrels	900		$	58.07	15,199	barrels	862		$	56.71
NGL	1,894	barrels	54		$	28.51	1,633	barrels	45		$	27.56

Linefill subtotal			954						907

Long-term inventory
Crude oil	3,079	barrels	259		$	84.12	2,973	barrels	209		$	70.30
NGL	1,069	barrels	42		$	39.29	1,135	barrels	44		$	38.77
Long-term inventory subtotal			301						253

Total			$	1,858					$	1,943

Revenues and Accounts Receivable (Tables)

9 Months Ended

Sep. 30, 2022

Revenue from Contract with Customer [Abstract]

Disaggregation of revenue

The following tables present our revenues from contracts with customers disaggregated by segment and type of activity (in millions):


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Crude Oil segment revenues from contracts with customers
Sales	$	13,362	$	10,427	$	41,796	$	27,776
Transportation	185		122		515		325
Terminalling, Storage and Other	90		99		270		345
Total Crude Oil segment revenues from contracts with customers	$	13,637	$	10,648	$	42,581	$	28,446


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
NGL segment revenues from contracts with customers
Sales	$	417	$	386	$	1,761	$	1,514
Transportation	7		6		23		17
Terminalling, Storage and Other	21		22		66		64
Total NGL segment revenues from contracts with customers	$	445	$	414	$	1,850	$	1,595

The following tables present the reconciliation of our revenues from contracts with customers to total revenues of reportable segments and total revenues as disclosed in our Condensed Consolidated Statements of Operations (in millions):


Three Months Ended September 30, 2022	Crude Oil		NGL		Total
Revenues from contracts with customers	$	13,637	$	445	$	14,082
Other items in revenues	38		325		363
Total revenues of reportable segments	$	13,675	$	770	$	14,445
Intersegment revenue elimination					(109)
Total revenues					$	14,336

Three Months Ended September 30, 2021	Crude Oil		NGL		Total
Revenues from contracts with customers	$	10,648	$	414	$	11,062
Other items in revenues	53		(248)		(195)
Total revenues of reportable segments	$	10,701	$	166	$	10,867
Intersegment revenue elimination					(91)
Total revenues					$	10,776

Nine Months Ended September 30, 2022	Crude Oil		NGL		Total
Revenues from contracts with customers	$	42,581	$	1,850	$	44,431
Other items in revenues	113		225		338
Total revenues of reportable segments	$	42,694	$	2,075	$	44,769
Intersegment revenues					(379)
Total revenues					$	44,390

Nine Months Ended September 30, 2021	Crude Oil		NGL		Total
Revenues from contracts with customers	$	28,446	$	1,595	$	30,041
Other items in revenues	(113)		(561)		(674)
Total revenues of reportable segments	$	28,333	$	1,034	$	29,367
Intersegment revenues					(278)
Total revenues					$	29,089

Contract with customer, counterparty deficiencies

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):


Counterparty Deficiencies	Financial Statement Classification	September 30, 2022		December 31, 2021
Billed and collected	Liability	$	65	$	63
Unbilled (1)	N/A	11		16
Total		$	76	$	79

Contracts with customers, change in asset and liability balance

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


	Contract Liabilities
Balance at December 31, 2021	$	141
Amounts recognized as revenue	(23)

Additions	25

Balance at September 30, 2022	$	143


	September 30, 2022		December 31, 2021
Trade accounts receivable arising from revenues from contracts with customers	$	4,197	$	4,031
Other trade accounts receivables and other receivables (1)	6,916		5,126
Impact due to contractual rights of offset with counterparties	(7,012)		(4,452)
Trade accounts receivable and other receivables, net	$	4,101	$	4,705

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

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 September 30, 2022 (in millions):


	Remainder of 2022		2023		2024		2025		2026		2027 and Thereafter
Pipeline revenues supported by minimum volume commitments and capacity agreements (1)	$	50	$	195	$	174	$	152	$	96	$	404
Terminalling, storage and other agreement revenues	67		234		178		106		80		604
Total	$	117	$	429	$	352	$	258	$	176	$	1,008

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

Segment Information - Segment Adjusted EBITDA Reconciliation (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Segment Reporting Information
Segment Adjusted EBITDA	$ 622	$ 513	$ 1,849	$ 1,630
Adjustments:
Depreciation and amortization of unconsolidated entities	(21)	(21)	(58)	(109)
Gains/(losses) from derivative activities and inventory valuation adjustments	376	(13)	363	23
Long-term inventory costing adjustments	(83)	13	22	81
Deficiencies under minimum volume commitments, net	(16)	(56)	(31)	(31)
Equity-indexed compensation expense	(9)	(6)	(24)	(14)
Net gain (loss) on foreign currency revaluation	2	(3)	1	(2)
Significant transaction-related expenses		(2)		(5)
Adjusted EBITDA attributable to noncontrolling interests	98	5	264	12
Depreciation and amortization	(238)	(178)	(711)	(551)
Gains/(losses) on asset sales and asset impairments, net	0	(221)	46	(592)
Gain on investment in unconsolidated entities	1		1
Interest expense, net	(99)	(106)	(305)	(319)
Other income/(expense), net	(82)	(10)	(237)	13
INCOME/(LOSS) BEFORE TAX	551	(85)	1,095	136
Income tax (expense)/benefit	(109)	30	(177)	16
NET INCOME/(LOSS)	442	(55)	918	152
Net income attributable to noncontrolling interests	(58)	(4)	(144)	(9)
NET INCOME/(LOSS) ATTRIBUTABLE TO PAA	$ 384	$ (59)	774	$ 143
Line 901 Incident
Adjustments:
Line 901 incident			$ (85)

Derivatives and Risk Management Activities - Fair Value (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021	Dec. 31, 2021
Level 3
Rollforward of Level 3 Net Asset/(Liability)
Beginning Balance	$ (147)	$ (13)	$ (2)	$ (29)
Net gains/(losses) for the period included in earnings	(49)	5	(196)	14
Settlements		1	2	8
Ending Balance	(196)	(7)	(196)	(7)
Change in unrealized gains/(losses) included in earnings relating to Level 3 derivatives still held at the end of the period	(49)	$ 5	(196)	$ 14
Recurring Fair Value Measures
Recurring Fair Value Measurements
Total net derivative asset/(liability)	149		149		$ (78)
Recurring Fair Value Measures \| Commodity derivatives
Recurring Fair Value Measurements
Total net derivative asset/(liability)	232		232		(143)
Recurring Fair Value Measures \| Interest rate derivatives
Recurring Fair Value Measurements
Total net derivative asset/(liability)	113		113		65
Recurring Fair Value Measures \| Preferred Distribution Rate Reset Option
Recurring Fair Value Measurements
Total net derivative asset/(liability)	(196)		(196)
Recurring Fair Value Measures \| Level 1
Recurring Fair Value Measurements
Total net derivative asset/(liability)	(29)		(29)		(17)
Recurring Fair Value Measures \| Level 1 \| Commodity derivatives
Recurring Fair Value Measurements
Total net derivative asset/(liability)	(29)		(29)		(17)
Recurring Fair Value Measures \| Level 2
Recurring Fair Value Measurements
Total net derivative asset/(liability)	374		374		(59)
Recurring Fair Value Measures \| Level 2 \| Commodity derivatives
Recurring Fair Value Measurements
Total net derivative asset/(liability)	261		261		(124)
Recurring Fair Value Measures \| Level 2 \| Interest rate derivatives
Recurring Fair Value Measurements
Total net derivative asset/(liability)	113		113		65
Recurring Fair Value Measures \| Level 3
Recurring Fair Value Measurements
Total net derivative asset/(liability)	(196)		(196)		(2)
Recurring Fair Value Measures \| Level 3 \| Commodity derivatives
Recurring Fair Value Measurements
Total net derivative asset/(liability)					$ (2)
Recurring Fair Value Measures \| Level 3 \| Preferred Distribution Rate Reset Option
Recurring Fair Value Measurements
Total net derivative asset/(liability)	$ (196)		$ (196)

Related Party Transactions (Tables)

9 Months Ended

Sep. 30, 2022

Schedule of related party transactions

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


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Revenues from related parties	$	11	$	8	$	33	$	25

Purchases and related costs from related parties	$	90	$	103	$	274	$	288

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


	September 30, 2022		December 31, 2021
Trade accounts receivable and other receivables, net from related parties (1)	$	55	$	41

Trade accounts payable to related parties (1) (2)	$	56	$	72

(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 crude oil at facilities and transport crude oil or utilize capacity on pipelines that are owned by equity method investees. A portion of our commitment to transport is supported by crude oil buy/sell or other agreements with third parties with commensurate quantities.

Revenues and Accounts Receivable - Trade Accounts Receivable and Other Receivables (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Revenue from Contract with Customer [Abstract]
Trade accounts receivable arising from revenues from contracts with customers	$ 4,197	$ 4,031
Other trade accounts receivables and other receivables	6,916	5,126
Impact due to contractual rights of offset with counterparties	(7,012)	(4,452)
Trade accounts receivable and other receivables, net	$ 4,101	$ 4,705

Cover Page - shares	9 Months Ended
Cover Page - shares	Sep. 30, 2022	Oct. 31, 2022
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2022
Document Transition Report	false
Entity File Number	1-14569
Entity Registrant Name	PLAINS ALL AMERICAN PIPELINE LP
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	76-0582150
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	Common Units
Trading Symbol	PAA
Security Exchange Name	NASDAQ
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Small Business Entity	false
Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding (units)		698,332,685
Entity Central Index Key	0001070423
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q3

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
REVENUES
Total revenues	$ 14,336	$ 10,776	$ 44,390	$ 29,089
COSTS AND EXPENSES
Purchases and related costs	13,071	10,074	41,181	26,743
Field operating costs	318	274	971	746
General and administrative expenses	83	67	243	205
Depreciation and amortization	238	178	711	551
(Gains)/losses on asset sales and asset impairments, net	0	221	(46)	592
Total costs and expenses	13,710	10,814	43,060	28,837
OPERATING INCOME/(LOSS)	626	(38)	1,330	252
OTHER INCOME/(EXPENSE)
Equity earnings in unconsolidated entities	105	69	306	190
Gain on investment in unconsolidated entities	1		1
Interest expense (net of capitalized interest of $1, $4, $3 and $14, respectively)	(99)	(106)	(305)	(319)
Other income/(expense), net	(82)	(10)	(237)	13
INCOME/(LOSS) BEFORE TAX	551	(85)	1,095	136
Current income tax expense	(12)	(8)	(60)	(11)
Deferred income tax (expense)/benefit	(97)	38	(117)	27
NET INCOME/(LOSS)	442	(55)	918	152
Net income attributable to noncontrolling interests	(58)	(4)	(144)	(9)
NET INCOME/(LOSS) ATTRIBUTABLE TO PAA	384	(59)	774	143
NET INCOME/(LOSS) PER COMMON UNIT (NOTE 4):
Net income/(loss) allocated to common unitholders - Basic	333	(109)	621	(7)
Net income/(loss) allocated to common unitholders - Diluted	$ 333	$ (109)	$ 621	$ (7)
Common Units
NET INCOME/(LOSS) PER COMMON UNIT (NOTE 4):
Basic weighted average common units outstanding (units)	698	715	702	719
Diluted weighted average common units outstanding (units)	698	715	702	719
Basic net income/(loss) per common unit (usd per unit)	$ 0.48	$ (0.15)	$ 0.89	$ (0.01)
Diluted net income/(loss) per common unit (usd per unit)	$ 0.48	$ (0.15)	$ 0.89	$ (0.01)
Product sales revenues
REVENUES
Total revenues	$ 14,001	$ 10,515	$ 43,390	$ 28,221
Services revenues
REVENUES
Total revenues	$ 335	$ 261	$ 1,000	$ 868

Net Income/(Loss) Per Common Unit (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Basic and Diluted Net Income/(Loss) per Common Unit
Net income/(loss) attributable to PAA	$ 384	$ (59)	$ 774	$ 143
Amounts allocated to participating securities	(2)	(1)	(4)	(1)
Net income/(loss) allocated to common unitholders - Basic	333	(109)	621	(7)
Net income/(loss) allocated to common unitholders - Diluted	$ 333	$ (109)	$ 621	$ (7)
Equity-indexed Compensation Plan Award \| Weighted average
Net Income/(Loss) Per Common Unit
Antidilutive securities excluded from computation of net income per common unit (units)		0.6		0.5
Dilutive equity-indexed compensation plan awards (units)	2.4		1.3
Series A Preferred Units
Basic and Diluted Net Income/(Loss) per Common Unit
Distributions to preferred unitholders	$ (37)	$ (37)	$ (112)	$ (112)
Series A Preferred Units \| Weighted average
Net Income/(Loss) Per Common Unit
Antidilutive securities excluded from computation of net income per common unit (units)	71.0	71.0	71.0	71.0
Series B Preferred Units
Basic and Diluted Net Income/(Loss) per Common Unit
Distributions to preferred unitholders	$ (12)	$ (12)	$ (37)	$ (37)
Common Units
Basic and Diluted Net Income/(Loss) per Common Unit
Basic weighted average common units outstanding (units)	698.0	715.0	702.0	719.0
Diluted weighted average common units outstanding (units)	698.0	715.0	702.0	719.0
Basic net income/(loss) per common unit (usd per unit)	$ 0.48	$ (0.15)	$ 0.89	$ (0.01)
Diluted net income/(loss) per common unit (usd per unit)	$ 0.48	$ (0.15)	$ 0.89	$ (0.01)

Organization and Basis of Consolidation and Presentation

9 Months Ended

Sep. 30, 2022

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Organization and Basis of Consolidation and Presentation

Organization

Plains All American Pipeline, L.P. (“PAA”) is a Delaware limited partnership formed in 1998. Our operations are conducted directly and indirectly through our primary operating subsidiaries. As used in this Form 10-Q and unless the context indicates otherwise, the terms “Partnership,” “we,” “us,” “our,” “ours” and similar terms refer to PAA and its subsidiaries.

Our 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, we own 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. Our assets and the services we provide are primarily focused on and conducted through two operating segments: Crude Oil and NGL. See Note 11 for further discussion of our operating segments.

Our non-economic general partner interest is held by PAA GP LLC (“PAA GP”), a Delaware limited liability company, whose sole member is Plains AAP, L.P. (“AAP”), a Delaware limited partnership. In addition to its ownership of PAA GP, as of September 30, 2022, AAP also owned a limited partner interest in us through its ownership of approximately 241.5 million of our common units (approximately 31% of our total outstanding common units and Series A preferred units combined). Plains All American GP LLC (“GP LLC”), a Delaware limited liability company, is AAP’s general partner. Plains GP Holdings, L.P. (“PAGP”) is the sole and managing member of GP LLC, and, at September 30, 2022, owned an approximate 81% limited partner interest in AAP. PAA GP Holdings LLC (“PAGP GP”) is the general partner of PAGP.

As the sole member of GP LLC, PAGP has responsibility for conducting our business and managing our operations; however, the board of directors of PAGP GP has ultimate responsibility for managing the business and affairs of PAGP, AAP and us. GP LLC employs our domestic officers and personnel; our Canadian officers and personnel are employed by our subsidiary, Plains Midstream Canada ULC.

References to our “general partner,” as the context requires, include any or all of PAGP GP, PAGP, GP LLC, AAP and PAA GP.

Definitions

Additional defined terms are used in this Form 10-Q 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
Btu	=	British thermal unit
CAD	=	Canadian dollar
CODM	=	Chief Operating Decision Maker
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
SEC	=	United States Securities and Exchange Commission
TWh	=	Terawatt hour
USD	=	United States dollar
WTI	=	West Texas Intermediate

Basis of Consolidation and Presentation

The accompanying unaudited condensed consolidated interim financial statements and related notes thereto should be read in conjunction with our 2021 Annual Report on Form 10-K. The accompanying condensed consolidated financial statements include the accounts of PAA 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. The financial statements have been prepared in accordance with the instructions for interim reporting as set forth by the SEC. The condensed consolidated balance sheet data as of December 31, 2021 was derived from audited financial statements, but does not include all disclosures required by GAAP. The results of operations for the three and nine months ended September 30, 2022 should not be taken as indicative of results to be expected for the entire year. All adjustments (consisting only of normal recurring adjustments) that in the opinion of management were necessary for a fair statement of the results for the interim periods have been reflected. 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, including the reclassifications discussed below.

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

Reclassification of Prior Period Information

During the fourth quarter of 2021, we effected changes in the primary financial information provided to our CODM (our Chief Executive Officer) for assessing performance and allocating resources to present two operating segments, Crude Oil and NGL. Prior to the fourth quarter of 2021, this information was organized into three operating segments: Transportation, Facilities and Supply and Logistics. See Note 11 for further discussion of our operating segments. In connection with this change, we changed the presentation of Revenues on our Condensed Consolidated Statements of Operations. “Product sales revenues” include amounts that were previously presented as “Supply and Logistics segment revenues,” while “Services revenues” includes amounts previously presented as “Transportation segment revenues” and “Facilities segment revenues.”

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN PARTNERS' CAPITAL - USD ($) $ in Millions	Total	Partners’ Capital Excluding Noncontrolling Interests	Noncontrolling Interests	Limited Partners Series A Preferred Units Partners’ Capital Excluding Noncontrolling Interests	Limited Partners Series B Preferred Units Partners’ Capital Excluding Noncontrolling Interests	Limited Partners Common Units Partners’ Capital Excluding Noncontrolling Interests
Beginning balance at Dec. 31, 2020	$ 9,738	$ 9,593	$ 145	$ 1,505	$ 787	$ 7,301
Increase (Decrease) in Partners' Capital
Net income/(loss)	152	143	9	112	37	(6)
Distributions (Note 7)	(548)	(538)	(10)	(112)	(37)	(389)
Other comprehensive income/(loss)	64	64				64
Repurchase of common units (Note 7)	(117)	(117)				(117)
Contributions from noncontrolling interests (Note 7)	1		1
Other	7	7				7
Ending balance at Sep. 30, 2021	9,297	9,152	145	1,505	787	6,860
Beginning balance at Jun. 30, 2021	9,640	9,495	145	1,505	787	7,203
Increase (Decrease) in Partners' Capital
Net income/(loss)	(55)	(59)	4	37	12	(108)
Distributions (Note 7)	(182)	(178)	(4)	(37)	(12)	(129)
Other comprehensive income/(loss)	(44)	(44)				(44)
Repurchase of common units (Note 7)	(64)	(64)				(64)
Other	2	2				2
Ending balance at Sep. 30, 2021	9,297	9,152	145	1,505	787	6,860
Beginning balance at Dec. 31, 2021	12,810	9,972	2,838	1,505	787	7,680
Increase (Decrease) in Partners' Capital
Net income/(loss)	918	774	144	112	37	625
Distributions (Note 7)	(775)	(581)	(194)	(112)	(37)	(432)
Other comprehensive income/(loss)	(150)	(150)				(150)
Repurchase of common units (Note 7)	(74)	(74)				(74)
Contributions from noncontrolling interests (Note 7)	26		26
Other	(12)	3	(15)			3
Ending balance at Sep. 30, 2022	12,743	9,944	2,799	1,505	787	7,652
Beginning balance at Jun. 30, 2022	12,719	9,931	2,788	1,505	787	7,639
Increase (Decrease) in Partners' Capital
Net income/(loss)	442	384	58	37	12	335
Distributions (Note 7)	(274)	(201)	(73)	(37)	(12)	(152)
Other comprehensive income/(loss)	(173)	(173)				(173)
Contributions from noncontrolling interests (Note 7)	26		26
Other	3	3				3
Ending balance at Sep. 30, 2022	$ 12,743	$ 9,944	$ 2,799	$ 1,505	$ 787	$ 7,652

- Definition

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

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

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Reference 32: http://www.xbrl.org/2003/role/exampleRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 55
-Paragraph 4K
-URI https://asc.fasb.org/extlink&oid=120409616&loc=SL4591552-111686

Reference 33: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 250
-SubTopic 10
-Section 50
-Paragraph 8
-URI https://asc.fasb.org/extlink&oid=124431687&loc=d3e22658-107794

+ Details

Derivatives and Risk Management Activities - Commodity Price Risk Hedging (Details) bbl in Millions	9 Months Ended
	Sep. 30, 2022 TWh bbl Bcf
Crude oil purchases \| Long
Commodity Price Risk Hedging:
Derivative position notional amount (in barrels or Bcf)	5.8
Time spread on hedging anticipated crude oil lease gathering purchases \| Short
Commodity Price Risk Hedging:
Derivative position notional amount (in barrels or Bcf)	7.8
Crude oil basis spread position
Commodity Price Risk Hedging:
Derivative position notional amount (in barrels or Bcf)	2.7
Anticipated net sales of crude oil and NGL inventory \| Short
Commodity Price Risk Hedging:
Derivative position notional amount (in barrels or Bcf)	14.3
Natural gas purchases for processing and operational needs \| Long
Commodity Price Risk Hedging:
Derivative position notional amount (in barrels or Bcf) \| Bcf	61.6
Propane contracts related to subsequent sale of products \| Short
Commodity Price Risk Hedging:
Derivative position notional amount (in barrels or Bcf)	12.2
Butane contracts related to subsequent sale of products \| Short
Commodity Price Risk Hedging:
Derivative position notional amount (in barrels or Bcf)	2.5
Condensate sales contracts related to subsequent sale of products \| Short
Commodity Price Risk Hedging:
Derivative position notional amount (in barrels or Bcf)	0.9
Fuel gas requirements \| Long
Commodity Price Risk Hedging:
Derivative position notional amount (in barrels or Bcf) \| Bcf	9.1
Power supply requirements \| Long
Commodity Price Risk Hedging:
Derivative position notional amount (in Terawatt hours) \| TWh	0.5

Related Party Transactions

9 Months Ended

Sep. 30, 2022

Related Party Transactions

See Note 17 to our Consolidated Financial Statements included in Part IV of our 2021 Annual Report on Form 10-K for a complete discussion of related parties, including the determination of our related parties and nature of involvement with such related parties.

During the three and nine months ended September 30, 2022 and 2021, we recognized sales and transportation revenues, purchased petroleum products and utilized transportation and storage services from our related parties. These transactions were conducted at posted tariff rates or prices that we believe approximate market.

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


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Revenues from related parties	$	11	$	8	$	33	$	25

Purchases and related costs from related parties	$	90	$	103	$	274	$	288

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


	September 30, 2022		December 31, 2021
Trade accounts receivable and other receivables, net from related parties (1)	$	55	$	41

Trade accounts payable to related parties (1) (2)	$	56	$	72

Debt - Components (Details) - USD ($) $ in Millions	Sep. 30, 2022	Mar. 01, 2022	Dec. 31, 2021
SHORT-TERM DEBT
Total short-term debt	$ 459		$ 822
LONG-TERM DEBT
Senior notes, net	7,934		8,329
Other long-term debt, net	52		69
Total long-term debt	7,986		8,398
Total debt	8,445		9,220
Senior notes
LONG-TERM DEBT
Senior notes, net	7,934		8,329
Unamortized discounts and debt issuance costs	48		54
Debt instrument face value	8,400		9,100
Senior notes \| Level 2
LONG-TERM DEBT
Debt instrument fair value	7,300		9,900
Other
LONG-TERM DEBT
Other long-term debt, net	52		69
Other
SHORT-TERM DEBT
Total short-term debt	59		72
3.65% senior notes due June 2022 \| Senior notes
SHORT-TERM DEBT
Total short-term debt			$ 750
Stated percentage		3.65%	3.65%
2.85% senior notes due January 2023 \| Senior notes
SHORT-TERM DEBT
Total short-term debt	$ 400
Stated percentage	2.85%

Net Income/(Loss) Per Common Unit

9 Months Ended

Sep. 30, 2022

Earnings Per Share [Abstract]

Net Income/(Loss) Per Common Unit

We calculate basic and diluted net income/(loss) per common unit by dividing net income/(loss) attributable to PAA (after deducting amounts allocated to the preferred unitholders and participating securities) by the basic and diluted weighted average number of common units outstanding during the period. Participating securities include equity-indexed compensation plan awards that have vested distribution equivalent rights, which entitle the grantee to a cash payment equal to the cash distribution paid on our outstanding common units.

The diluted weighted average number of common units is computed based on the weighted average number of common units plus the effect of potentially dilutive securities outstanding during the period, which include (i) our Series A preferred units and (ii) our equity-indexed compensation plan awards. See Note 12 and Note 18 to our Consolidated Financial Statements included in Part IV of our 2021 Annual Report on Form 10-K for a discussion of our Series A preferred units and equity-indexed compensation plan awards. When applying the if-converted method prescribed by FASB guidance, the possible conversion of approximately 71 million Series A preferred units, on a weighted-average basis, were excluded from the calculation of diluted net income per common unit for each of the three and nine months ended September 30, 2022 and 2021 as the effect was antidilutive. Our equity-indexed compensation plan awards that contemplate the issuance of common units are considered potentially dilutive unless (i) they become vested only upon the satisfaction of a performance condition and (ii) that performance condition has yet to be satisfied. Equity-indexed compensation plan awards that were deemed to be dilutive during the period were reduced by a hypothetical common unit repurchase based on the remaining unamortized fair value, as prescribed by the treasury stock method in guidance issued by the FASB. For the three and nine months ended September 30, 2022, approximately 2.4 million and 1.3 million, respectively, equity-indexed compensation plan awards, on a weighted-average basis, were dilutive, but did not change basic net income per common unit for the periods presented. For the three and nine months ended September 30, 2021, approximately 0.6 million and 0.5 million equity-indexed compensation awards, on a weighted-average basis, were excluded from the computation of diluted net loss per common unit as the effect was antidilutive.

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


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Basic and Diluted Net Income/(Loss) per Common Unit
Net income/(loss) attributable to PAA	$	384	$	(59)	$	774	$	143
Distributions to Series A preferred unitholders	(37)		(37)		(112)		(112)
Distributions to Series B preferred unitholders	(12)		(12)		(37)		(37)
Amounts allocated to participating securities	(2)		(1)		(4)		(1)

Net income/(loss) allocated to common unitholders (1)	$	333	$	(109)	$	621	$	(7)

Basic and diluted weighted average common units outstanding	698		715		702		719

Basic and diluted net income/(loss) per common unit	$	0.48	$	(0.15)	$	0.89	$	(0.01)

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 918	$ 152
Reconciliation of net income to net cash provided by operating activities:
Depreciation and amortization	711	551
(Gains)/losses on asset sales and asset impairments, net	(46)	592
Deferred income tax expense/(benefit)	117	(27)
Gains on sales of linefill	(35)
Loss on foreign currency revaluation	42	3
Settlement of terminated interest rate hedging instruments	42
Change in fair value of Preferred Distribution Rate Reset Option (Note 8)	196	(13)
Equity earnings in unconsolidated entities	(306)	(190)
Distributions on earnings from unconsolidated entities	344	322
Other	41	39
Changes in assets and liabilities, net of acquisitions	50	(68)
Net cash provided by operating activities	2,074	1,361
CASH FLOWS FROM INVESTING ACTIVITIES
Cash paid in connection with acquisitions, net of cash acquired	(68)	(32)
Investments in unconsolidated entities	(3)	(78)
Additions to property, equipment and other	(312)	(257)
Cash paid for purchases of linefill	(69)	(36)
Proceeds from sales of assets	58	878
Cash received from sales of linefill	72	3
Other investing activities	31
Net cash (used in)/provided by investing activities	(291)	478
CASH FLOWS FROM FINANCING ACTIVITIES
Net repayments under commercial paper program (Note 6)		(546)
Net repayments under senior secured hedged inventory facility (Note 6)		(167)
Repayment of GO Zone term loans		(200)
Repayments of senior notes (Note 6)	(750)
Repurchase of common units (Note 7)	(74)	(117)
Distributions paid to noncontrolling interests (Note 7)	(194)	(10)
Other financing activities	(47)	(142)
Net cash used in financing activities	(1,608)	(1,707)
Effect of translation adjustment	(5)	2
Net increase in cash and cash equivalents and restricted cash	170	134
Cash and cash equivalents and restricted cash, beginning of period	453	60
Cash and cash equivalents and restricted cash, end of period	623	194
Cash paid for:
Interest, net of amounts capitalized	268	265
Income taxes, net of amounts refunded	85	32
Noncontrolling Interests
CASH FLOWS FROM FINANCING ACTIVITIES
Contributions from noncontrolling interests (Note 7)	26	1
Series A Preferred Units
CASH FLOWS FROM FINANCING ACTIVITIES
Distributions paid to unitholders (Note 7)	(112)	(112)
Series B Preferred Units
CASH FLOWS FROM FINANCING ACTIVITIES
Distributions paid to unitholders (Note 7)	(25)	(25)
Common Units
CASH FLOWS FROM FINANCING ACTIVITIES
Distributions paid to unitholders (Note 7)	$ (432)	$ (389)

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME/(LOSS) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Statement of Comprehensive Income [Abstract]
Net income/(loss)	$ 442	$ (55)	$ 918	$ 152
Other comprehensive income/(loss)	(173)	(44)	(150)	64
Comprehensive income/(loss)	269	(99)	768	216
Comprehensive income attributable to noncontrolling interests	(58)	(4)	(144)	(9)
Comprehensive income/(loss) attributable to PAA	$ 211	$ (103)	$ 624	$ 207

- 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

+ Details

- Definition

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

+ References

+ Details

Summary of Significant Accounting Policies	9 Months Ended
Summary of Significant Accounting Policies	Sep. 30, 2022
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	Summary of Significant Accounting Policies Recent Accounting Pronouncements Except as discussed below and in our 2021 Annual Report on Form 10-K, there have been no new accounting pronouncements that have become effective or have been issued during the nine months ended September 30, 2022 that are of significance or potential significance to us. 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 adopted this guidance effective January 1, 2022, and our adoption did not have a material impact on our financial position, results of operations or cash flows.

Derivatives and Risk Management Activities

9 Months Ended

Sep. 30, 2022

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 commodity price risk and interest 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 or interest 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 in a hedging relationship for accounting purposes 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 September 30, 2022 and December 31, 2021, 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 material physical inventory or derivatives for the purpose of speculating on commodity price changes. The material commodity-related risks inherent in our business activities are described below.

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 September 30, 2022, 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 October 2022 to match monthly average pricing.

•A net short time spread position of 7.8 million barrels, which hedges a portion of our anticipated crude oil lease gathering purchases through December 2024.

•A net crude oil basis spread position of 2.7 million barrels at multiple locations through December 2024. These derivatives allow us to lock in grade and location basis differentials.

•A net short position of 14.3 million barrels through December 2023 related to anticipated net sales of crude oil and NGL inventory.

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 September 30, 2022:

Notional Volume

(Short)/Long

Remaining Tenor

Natural gas purchases

61.6 Bcf

December 2024

Propane sales

(12.2) MMbls

December 2024

Butane sales

(2.5) MMbls

December 2024

Condensate sales

(0.9) MMbls

December 2024

Fuel gas requirements (1)

9.1 Bcf

December 2023

Power supply requirements (1)

0.5 TWh

December 2023

(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 in a hedging relationship for accounting purposes; as such, changes in the fair value are reported in earnings. The following table summarizes the impact of our commodity derivatives recognized in earnings (in millions):


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Product sales revenues	$	320	$	(206)	$	183	$	(804)
Field operating costs	23		17		44		73

Net gain/(loss) from commodity derivative activity	$	343	$	(189)	$	227	$	(731)

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):


	September 30, 2022		December 31, 2021
Initial margin	$	97	$	133
Variation margin posted/(returned)	(154)		173
Letters of credit	(25)		(47)
Net broker receivable/(payable)	$	(82)	$	259


	September 30, 2022								December 31, 2021
					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	$	311	$	(101)	$	(82)	$	128	$	90	$	(210)	$	259	$	139
Other long-term assets, net	38		(3)		—		35		3		—		—		3
Derivative Liabilities
Other current liabilities	6		(17)		—		(11)		4		(24)		—		(20)
Other long-term liabilities and deferred credits	2		(4)		—		(2)		3		(9)		—		(6)
Total	$	357	$	(125)	$	(82)	$	150	$	100	$	(243)	$	259	$	116

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 September 30, 2022 (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

4 forward starting swaps

(30-year)

100

6/14/2024

0.74

Cash flow hedge

As of September 30, 2022, there was a net loss of $115 million deferred in AOCI. The deferred net loss recorded in AOCI is expected to be reclassified to future earnings contemporaneously with interest expense accruals associated with underlying debt instruments. During the three months ended September 30, 2022, we terminated $100 million of notional interest hedging instruments previously expected to terminate in June 2024 for proceeds of $42 million. The early termination did not result in an impact to the relationship between the hedging instrument and hedged item. 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 September 30, 2022; 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):


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Interest rate derivatives, net	$	16	$	6	$	88	$	36

At September 30, 2022, the net fair value of our interest rate hedges, which were included in “Other current assets” and “Other long-term assets, net” on our Condensed Consolidated Balance Sheet, totaled $70 million and $43 million, respectively. At December 31, 2021, the net fair value of these hedges totaled $65 million and was included in “Other long-term assets, net.”

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 our Series A preferred units is an embedded derivative that must be bifurcated from the related host contract, our partnership agreement, and recorded at fair value on our Condensed Consolidated Balance Sheets. This embedded derivative is not designated in a hedging relationship for accounting purposes and corresponding changes in fair value are recognized in “Other expense, net” in our Condensed Consolidated Statement of Operations. For the three months ended September 30, 2022 and 2021, we recognized a loss of $49 million and a gain of $4 million, respectively. For the nine months ended September 30, 2022 and 2021, we recognized a net loss of $196 million and a net gain of $13 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 Condensed Consolidated Balance Sheets, totaled $196 million and less than $1 million at September 30, 2022 and December 31, 2021, respectively. See Note 12 to our Consolidated Financial Statements included in Part IV of our 2021 Annual Report on Form 10-K 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 September 30, 2022								Fair Value as of December 31, 2021
Recurring Fair Value Measures (1)	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Commodity derivatives	$	(29)	$	261	$	—	$	232	$	(17)	$	(124)	$	(2)	$	(143)
Interest rate derivatives	—		113		—		113		—		65		—		65

Preferred Distribution Rate Reset Option	—		—		(196)		(196)		—		—		—		—
Total net derivative asset/(liability)	$	(29)	$	374	$	(196)	$	149	$	(17)	$	(59)	$	(2)	$	(78)

(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 Condensed Consolidated Statements of Operations as Product sales revenues.

The fair value of the Preferred Distribution Rate Reset Option of our Series A preferred units contained in our partnership agreement is based on a Monte Carlo simulation that estimates the fair value of the Series A preferred units with and without the Preferred Distribution Rate Reset Option. This model utilizes observable and unobservable inputs, including our common unit price, ten-year U.S. Treasury rates, default probabilities and timing estimates, some of which involve management judgment. In general, an increase in ten-year U.S. Treasury rates would increase the fair value of the feature and our liability and expense. The future impact on “Other income/(expense), net” depends on how inputs change in relation to one another.

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):


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Beginning Balance	$	(147)	$	(13)	$	(2)	$	(29)
Net gains/(losses) for the period included in earnings	(49)		5		(196)		14
Settlements	—		1		2		8

Ending Balance	$	(196)	$	(7)	$	(196)	$	(7)

Change in unrealized gains/(losses) included in earnings relating to Level 3 derivatives still held at the end of the period	$	(49)	$	5	$	(196)	$	14

Revenues and Accounts Receivable - Segment Revenue (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Disaggregation of Revenue
Total revenues	$ 14,336	$ 10,776	$ 44,390	$ 29,089
Operating Segments
Disaggregation of Revenue
Revenue from contracts with customers	14,082	11,062	44,431	30,041
Other items in revenues	363	(195)	338	(674)
Total revenues	14,445	10,867	44,769	29,367
Operating Segments \| Crude Oil
Disaggregation of Revenue
Revenue from contracts with customers	13,637	10,648	42,581	28,446
Other items in revenues	38	53	113	(113)
Total revenues	13,675	10,701	42,694	28,333
Operating Segments \| NGL
Disaggregation of Revenue
Revenue from contracts with customers	445	414	1,850	1,595
Other items in revenues	325	(248)	225	(561)
Total revenues	770	166	2,075	1,034
Intersegment revenue elimination
Disaggregation of Revenue
Total revenues	$ (109)	$ (91)	$ (379)	$ (278)

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 https://asc.fasb.org/extlink&oid=126901519&loc=d3e8736-108599

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
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+ Details

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Parenthetical) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Income Statement [Abstract]
Interest expense, capitalized interest	$ 1	$ 4	$ 3	$ 14

Revenues and Accounts Receivable - Performance Obligations (Details) $ in Millions	Sep. 30, 2022 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2022-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Remaining performance obligation	$ 117
Remaining performance obligations, expected timing of satisfaction, period	3 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Remaining performance obligation	$ 429
Remaining performance obligations, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Remaining performance obligation	$ 352
Remaining performance obligations, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Remaining performance obligation	$ 258
Remaining performance obligations, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Remaining performance obligation	$ 176
Remaining performance obligations, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Remaining performance obligation	$ 1,008
Remaining performance obligations, expected timing of satisfaction, period
Pipeline revenues supported by minimum volume commitments and capacity agreements \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2022-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Remaining performance obligation	$ 50
Remaining performance obligations, expected timing of satisfaction, period	3 months
Pipeline revenues supported by minimum volume commitments and 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	$ 195
Remaining performance obligations, expected timing of satisfaction, period	1 year
Pipeline revenues supported by minimum volume commitments and 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	$ 174
Remaining performance obligations, expected timing of satisfaction, period	1 year
Pipeline revenues supported by minimum volume commitments and 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	$ 152
Remaining performance obligations, expected timing of satisfaction, period	1 year
Pipeline revenues supported by minimum volume commitments and 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	$ 96
Remaining performance obligations, expected timing of satisfaction, period	1 year
Pipeline revenues supported by minimum volume commitments and capacity agreements \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Remaining performance obligation	$ 404
Remaining performance obligations, expected timing of satisfaction, period
Terminalling, storage and other agreement revenues \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2022-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Remaining performance obligation	$ 67
Remaining performance obligations, expected timing of satisfaction, period	3 months
Terminalling, storage and other agreement 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	$ 234
Remaining performance obligations, expected timing of satisfaction, period	1 year
Terminalling, storage and other agreement 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	$ 178
Remaining performance obligations, expected timing of satisfaction, period	1 year
Terminalling, storage and other agreement 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	$ 106
Remaining performance obligations, expected timing of satisfaction, period	1 year
Terminalling, storage and other agreement 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	$ 80
Remaining performance obligations, expected timing of satisfaction, period	1 year
Terminalling, storage and other agreement revenues \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Remaining performance obligation	$ 604
Remaining performance obligations, expected timing of satisfaction, period