PAA Plains All American Pipeline LP

Plains All American Pipeline, L.P. (Nasdaq: PAA) and Plains GP Holdings (Nasdaq: PAGP) today reported second-quarter 2021 results and provided various other updates.

• Completed the sale of Plains’ natural gas storage assets (transaction announced June 8th and closed August 2nd) resulting in net sales proceeds of approximately $850 million, a corresponding non-cash impairment charge of approximately $475 million, and a net loss for the second-quarter of $220 million
• Reported second-quarter Adjusted EBITDA of $579 million, increased full-year 2021 Adjusted EBITDA guidance by $25 million to +/- $2.175 billion, and reduced 2021 investment capital guidance by $50 million to +/- $325 million
• Increased forecasted 2021 Free Cash Flow after Distributions to +/- $1.35 billion, or +/- $450 million excluding proceeds from asset sales
• Announced definitive agreement to form strategic Permian Basin joint venture with Oryx Midstream – highly complementary assets, significant value for customers (cashless transaction, debt-free entity, near-term free-cash-flow accretive)
• Published 2020 Sustainability Report with enhanced data disclosure, including Scope 1 & 2 GHG emissions data, and additional context on environmental, social, and governance factors relevant to Plains’ business and stakeholders

“We delivered second-quarter results that exceeded the high-end of our expectations, reflecting timing-related benefits in our Supply & Logistics segment and over performance in our Transportation segment,” stated Willie Chiang, Chairman and CEO of Plains. “Importantly, since our first-quarter earnings call in May, we have advanced several key initiatives that maximize free cash flow to strengthen our balance sheet and improve returns to equity holders.”

Plains All American Pipeline

Summary Financial Information (unaudited)(in millions, except per unit data)

		Three Months EndedJune 30,								%					Six Months EndedJune 30,								%
GAAP Results		2021				2020				Change					2021				2020				Change
Net income/(loss) attributable to PAA (1)		$	(220	)		$	142			**					$	202			$	(2,705	)		**
Diluted net income/(loss) per common unit		$	(0.37	)		$	0.13			**					$	0.14			$	(3.85	)		**
Diluted weighted average common units outstanding		720				728				(1	)	%			721				728				(1	)	%
Net cash provided by operating activities		$	235			$	84			180		%			$	1,026			$	974			5		%
Distribution per common unit declared for the period		$	0.18			$	0.18			—		%			$	0.36			$	0.36			—		%

**      Indicates that variance as a percentage is not meaningful.        

(1)   Reported results for the three and six months ended June 30, 2021 include a non-cash impairment of approximately $475 million related to the sale of our gas storage assets. Reported results for the six months ended June 30, 2020 include aggregate non-cash goodwill and asset impairments totaling $3.2 billion, representing a net loss of $4.42 after tax per common unit.

		Three Months EndedJune 30,								%					Six Months EndedJune 30,								%
Non-GAAP Results (1)		2021				2020				Change					2021				2020				Change
Adjusted net income attributable to PAA		$	213			$	233			(9	)	%			$	445			$	688			(35	)	%
Diluted adjusted net income per common unit		$	0.23			$	0.25			(8	)	%			$	0.48			$	0.81			(41	)	%
Adjusted EBITDA		$	579			$	524			10		%			$	1,125			$	1,319			(15	)	%
Implied DCF per common unit and common unit equivalent		$	0.52			$	0.42			24		%			$	1.03			$	1.21			(15	)	%
Free Cash Flow		$	60			$	(166	)		**					$	738			$	122			**
Free Cash Flow after Distributions		$	(132	)		$	(359	)		**					$	379			$	(370	)		**

**      Indicates that variance as a percentage is not meaningful.        

(1)   See the section of this release entitled “Non-GAAP Financial Measures and Selected Items Impacting Comparability” and the tables attached hereto for information regarding our Non-GAAP financial measures, including their reconciliation to the most directly comparable measures as reported in accordance with GAAP, and certain selected items that PAA believes impact comparability of financial results between reporting periods.

Summary of Selected Financial Data by Segment (unaudited)(in millions)

	Segment Adjusted EBITDA
	Transportation				Facilities					Supply andLogistics
Three Months Ended June 30, 2021	$	433			$	140				$	5
Three Months Ended June 30, 2020	$	346			$	174				$	3
Percentage change in Segment Adjusted EBITDA versus 2020 period	25		%		(20		)	%		**
Percentage change in Segment Adjusted EBITDA versus 2020 period  further adjusted for impact of divested assets (1)	25		%		(12		)	%		N/A
	Segment Adjusted EBITDA
	Transportation				Facilities					Supply andLogistics
Six Months Ended June 30, 2021	$	821			$	311				$	(8	)
Six Months Ended June 30, 2020	$	788			$	384				$	144
Percentage change in Segment Adjusted EBITDA versus 2020 period	4		%		(19		)	%		**
Percentage change in Segment Adjusted EBITDA versus 2020 period  further adjusted for impact of divested assets (1)	4		%		(11		)	%		N/A

**      Indicates that variance as a percentage is not meaningful.

(1)   Estimated impact of divestitures completed during 2020 and 2021, assuming an effective date of January 1, 2020. Divested assets primarily included certain NGL storage terminals and Los Angeles Basin crude oil storage terminals that were previously included in our Facilities segment and the sale of a portion of our interest in a joint venture pipeline that was previously reported in our Transportation segment.Second-quarter 2021 Transportation Segment Adjusted EBITDA increased 25% versus comparable 2020 results due to increased tariff volumes in multiple regions primarily driven by improved crude oil demand and production versus the COVID-related reset to North American production experienced in the second quarter of 2020 as well as the benefit from the collection of deficiency payments associated with minimum volume commitments.

Second-quarter 2021 Facilities Segment Adjusted EBITDA decreased 20% versus comparable 2020 results primarily due to the impact of asset sales and reduced NGL intersegment fee structure based on market conditions.        Second-quarter 2021 Supply and Logistics Segment Adjusted EBITDA was in line with comparable 2020 results.

Financial and Operating Guidance (unaudited)

(in millions, except volumes, per unit and per barrel data)

	Twelve Months Ended December 31,
	2019				2020				2021 (G)
									+ / -
Segment Adjusted EBITDA
Transportation	$	1,722			$	1,616			$	1,635
Facilities	705				731				540
Fee-Based	$	2,427			$	2,347			$	2,175
Supply and Logistics	803				210				—
Adjusted other income/(expense), net (1)	7				3				—
Adjusted EBITDA (2)	$	3,237			$	2,560			$	2,175
Interest expense, net of certain non-cash items (3)	(407		)		(415		)		(405		)
Maintenance capital	(287		)		(216		)		(180		)
Current income tax expense	(112		)		(51		)		(15		)
Other	(55		)		3				(25		)
Implied DCF (2)	$	2,376			$	1,881			$	1,550
Preferred unit distributions paid (4)	(198		)		(198		)		(200		)
Implied DCF Available to Common Unitholders	$	2,178			$	1,683			$	1,350
Implied DCF per Common Unit and Common Unit Equivalent (2)	$	2.91			$	2.29			$	1.90
Distributions per Common Unit (5)	$	1.38			$	0.90			$	0.72
Common Unit Distribution Coverage Ratio	2.17		x		2.57		x		2.61		x
Diluted Adjusted Net Income per Common Unit (2)	$	2.51			$	1.55			$	0.96
Operating Data
Transportation
Average daily volumes (MBbls/d)	6,893				6,340				6,050
Segment Adjusted EBITDA per barrel	$	0.68			$	0.70			$	0.74
Facilities
Average capacity (MMBbls/Mo)	125				124				110
Segment Adjusted EBITDA per barrel	$	0.47			$	0.49			$	0.41
Supply and Logistics
Average daily volumes (MBbls/d)	1,369				1,318				1,400
Segment Adjusted EBITDA per barrel	$	1.61			$	0.43			$	—
Investment Capital	$	1,340			$	921			$	325
Third-Quarter Adjusted EBITDA as a Percentage of Full Year (6)	23		%		27		%		22		%

(G) 2021 Guidance forecasts are intended to be + / - amounts.        

(1)   Represents “Other income, net” as reported on our Condensed Consolidated Statements of Operations, adjusted for selected items impacting comparability of $(17) million and $(36) million for the twelve months ended December 31, 2019 and 2020, respectively. See the “Selected Items Impacting Comparability” table for additional information.

(2)   See the section of this release entitled “Non-GAAP Financial Measures and Selected Items Impacting Comparability” for information regarding non-GAAP financial measures and, for the historical 2019 and 2020 periods, see the Non-GAAP Reconciliation tables attached hereto for a reconciliation of such non-GAAP financial measures to the most directly comparable measures as reported in accordance with GAAP. We do not provide a reconciliation of non-GAAP financial measures to the equivalent GAAP financial measures on a forward-looking basis as it is impractical to forecast certain items that we have defined as “Selected Items Impacting Comparability” without unreasonable effort, due to the uncertainty and inherent difficulty of predicting the occurrence and financial impact of such items and the periods in which such items may be recognized. Thus, a reconciliation of non-GAAP financial measures to the equivalent GAAP financial measures could result in disclosure that could be imprecise or potentially misleading.

(3)   Excludes certain non-cash items impacting interest expense such as amortization of debt issuance costs and terminated interest rate swaps.

(4)   Cash distributions paid to our preferred unitholders during 2019 and 2020. 2021(G) reflects the current annualized distribution requirement of $2.10 per Series A preferred unit and the current annualized distribution requirement of $61.25 per Series B preferred unit.

(5)   Cash distributions per common unit paid during 2019 and 2020. 2021(G) reflects the current annualized distribution rate of $0.72 per common unit.

(6)   2021 (G) includes our +/- forecast for the full year based on a certain set of assumptions as of the date of this earnings release and acknowledges that uncertainties under the current market environment could result in timing shifts across individual quarters.

Plains GP Holdings

PAGP owns an indirect non-economic controlling interest in PAA’s general partner and an indirect limited partner interest in PAA. As the control entity of PAA, PAGP consolidates PAA’s results into its financial statements, which is reflected in the condensed consolidating balance sheet and income statement tables attached hereto.

Conference Call

PAA and PAGP will hold a joint conference call at 4:30 p.m. CT on Tuesday, August 3, 2021 to discuss the following items:

1. PAA’s second-quarter 2021 performance;
2. Capitalization and liquidity; and
3. Financial and operating guidance.

Conference Call Webcast Instructions

To access the internet webcast, please go to https://edge.media-server.com/mmc/p/3wef49ho.

Alternatively, the webcast can be accessed on our website (www.plainsallamerican.com) under Investor Relations (Navigate to: Investor Relations / either “PAA” or “PAGP” / News & Events / Quarterly Earnings). Following the live webcast, an audio replay in MP3 format will be available on our website within two hours after the end of the call and will be accessible for a period of 365 days. A transcript will also be available after the call at the above referenced website.

Non-GAAP Financial Measures and Selected Items Impacting Comparability

To supplement our financial information presented in accordance with GAAP, management uses additional measures known as “non-GAAP financial measures” in its evaluation of past performance and prospects for the future and to assess the amount of cash that is available for distributions, debt repayments, common equity repurchases and other general partnership purposes.

The primary additional measures used by management are earnings before interest, taxes, depreciation and amortization (including our proportionate share of depreciation and amortization and write-downs related to cancelled projects of unconsolidated entities), gains and losses on asset sales and asset impairments, goodwill impairment losses and gains on and impairments of investments in unconsolidated entities, adjusted for certain selected items impacting comparability (“Adjusted EBITDA”), Implied Distributable Cash Flow (“DCF”), Free Cash Flow and Free Cash Flow after Distributions. Our definition and calculation of certain non-GAAP financial measures may not be comparable to similarly-titled measures of other companies. Adjusted EBITDA, Implied DCF and certain other non-GAAP financial performance measures are reconciled to Net Income/(Loss), and Free Cash Flow and Free Cash Flow after Distributions are reconciled to Net Cash Provided by Operating Activities (the most directly comparable measures as reported in accordance with GAAP) for the historical periods presented in the tables attached to this release, and should be viewed in addition to, and not in lieu of, our Condensed Consolidated Financial Statements and accompanying notes. In addition, we encourage you to visit our website at www.plainsallamerican.com (in particular the section under “Financial Information” entitled “Non-GAAP Reconciliations” within the Investor Relations tab), which presents a reconciliation of our commonly used non-GAAP and supplemental financial measures.

Performance Measures

Management believes that the presentation of Adjusted EBITDA and Implied DCF provides useful information to investors regarding our performance and results of operations because these measures, when used to supplement related GAAP financial measures, (i) provide additional information about our core operating performance and ability to fund distributions to our unitholders through cash generated by our operations and (ii) provide investors with the same financial analytical framework upon which management bases financial, operational, compensation and planning/budgeting decisions. We also present these and additional non-GAAP financial measures, including adjusted net income attributable to PAA and basic and diluted adjusted net income per common unit, as they are measures that investors, rating agencies and debt holders have indicated are useful in assessing us and our results of operations. These non-GAAP measures may exclude, for example, (i) charges for obligations that are expected to be settled with the issuance of equity instruments, (ii) gains and losses on derivative instruments that are related to underlying activities in another period (or the reversal of such adjustments from a prior period), gains and losses on derivatives that are related to investing activities (such as the purchase of linefill) and inventory valuation adjustments, as applicable, (iii) long-term inventory costing adjustments, (iv) items that are not indicative of our core operating results and/or (v) other items that we believe should be excluded in understanding our core operating performance. These measures may be further adjusted to include amounts related to deficiencies associated with minimum volume commitments whereby we have billed the counterparties for their deficiency obligation and such amounts are recognized as deferred revenue in “Other current liabilities” in our Condensed Consolidated Financial Statements. We also adjust for amounts billed by our equity method investees related to deficiencies under minimum volume commitments. All such amounts are presented net of applicable amounts subsequently recognized into revenue. Furthermore, the calculation of these measures contemplates tax effects as a separate reconciling item, where applicable. We have defined all such items as “selected items impacting comparability.” Due to the nature of the selected items, certain selected items impacting comparability may impact certain non-GAAP financial measures, referred to as adjusted results, but not impact other non-GAAP financial measures. We do not necessarily consider all of our selected items impacting comparability to be non-recurring, infrequent or unusual, but we believe that an understanding of these selected items impacting comparability is material to the evaluation of our operating results and prospects. Although we present selected items impacting comparability that management considers in evaluating our performance, you should also be aware that the items presented do not represent all items that affect comparability between the periods presented. Variations in our operating results are also caused by changes in volumes, prices, exchange rates, mechanical interruptions, acquisitions, divestitures, investment capital projects and numerous other factors. These types of variations may not be separately identified in this release, but will be discussed, as applicable, in management’s discussion and analysis of operating results in our Quarterly Report on Form 10-Q.

Liquidity Measures

Management also uses the non-GAAP financial measures Free Cash Flow and Free Cash Flow after Distributions to assess the amount of cash that is available for distributions, debt repayments, common equity repurchases and other general partnership purposes. Free Cash Flow is defined as Net Cash Provided by Operating Activities, less Net Cash Used in Investing Activities, which primarily includes acquisition, investment and maintenance capital expenditures, investments in unconsolidated entities and the impact from the purchase and sale of linefill and base gas, net of proceeds from the sales of assets and further impacted by cash received from or paid to noncontrolling interests. Free Cash Flow is further reduced by cash distributions paid to our preferred and common unitholders to arrive at Free Cash Flow after Distributions.

PLAINS ALL AMERICAN PIPELINE, L.P. AND SUBSIDIARIESFINANCIAL SUMMARY (unaudited)

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS(in millions, except per unit data)

	Three Months EndedJune 30,								Six Months EndedJune 30,
	2021				2020				2021				2020
REVENUES	$	9,930			$	3,225			$	18,313			$	11,494
COSTS AND EXPENSES
Purchases and related costs	9,277				2,525				16,669				9,893
Field operating costs	252				253				471				557
General and administrative expenses	72				72				139				141
Depreciation and amortization	196				166				374				333
(Gains)/losses on asset sales and asset impairments, net	369				(1		)		370				618
Goodwill impairment losses	—				—				—				2,515
Total costs and expenses	10,166				3,015				18,023				14,057
OPERATING INCOME/(LOSS)	(236		)		210				290				(2,563		)
OTHER INCOME/(EXPENSE)
Equity earnings in unconsolidated entities	33				81				121				191
Gain on/(impairment of) investments in unconsolidated entities, net	—				(69		)		—				(91		)
Interest expense, net	(107		)		(108		)		(213		)		(215		)
Other income/(expense), net	84				18				23				(13		)
INCOME/(LOSS) BEFORE TAX	(226		)		132				221				(2,691		)
Current income tax expense	(1		)		(15		)		(3		)		(22		)
Deferred income tax (expense)/benefit	11				27				(11		)		12
NET INCOME/(LOSS)	(216		)		144				207				(2,701		)
Net income attributable to noncontrolling interests	(4		)		(2		)		(5		)		(4		)
NET INCOME/(LOSS) ATTRIBUTABLE TO PAA	$	(220	)		$	142			$	202			$	(2,705	)
NET INCOME/(LOSS) PER COMMON UNIT:
Net income/(loss) allocated to common unitholders — Basic and Diluted	$	(269	)		$	92			$	103			$	(2,805	)
Basic and diluted weighted average common units outstanding	720				728				721				728
Basic and diluted net income/(loss) per common unit	$	(0.37	)		$	0.13			$	0.14			$	(3.85	)

PLAINS ALL AMERICAN PIPELINE, L.P. AND SUBSIDIARIESFINANCIAL SUMMARY (unaudited)

CONDENSED CONSOLIDATED BALANCE SHEET DATA(in millions)

	June 30,2021				December 31,2020
ASSETS
Current assets (including Cash and cash equivalents of $24 and $22, respectively)	$	5,676			$	3,665
Property and equipment, net	13,451				14,611
Investments in unconsolidated entities	3,745				3,764
Linefill and base gas	909				982
Long-term operating lease right-of-use assets, net	344				378
Long-term inventory	210				130
Other long-term assets, net	1,056				967
Total assets	$	25,391			$	24,497
LIABILITIES AND PARTNERS’ CAPITAL
Current liabilities	$	6,163			$	4,253
Senior notes, net	8,326				9,071
Other long-term debt, net	63				311
Long-term operating lease liabilities	289				317
Other long-term liabilities and deferred credits	910				807
Total liabilities	15,751				14,759
Partners’ capital excluding noncontrolling interests	9,495				9,593
Noncontrolling interests	145				145
Total partners’ capital	9,640				9,738
Total liabilities and partners’ capital	$	25,391			$	24,497

DEBT CAPITALIZATION RATIOS(in millions)

	June 30,2021					December 31,2020
Short-term debt	$	1,456				$	831
Long-term debt	8,389					9,382
Total debt	$	9,845				$	10,213
Long-term debt	$	8,389				$	9,382
Partners’ capital	9,640					9,738
Total book capitalization	$	18,029				$	19,120
Total book capitalization, including short-term debt	$	19,485				$	19,951
Long-term debt-to-total book capitalization	47			%		49			%
Total debt-to-total book capitalization, including short-term debt	51			%		51			%

PLAINS ALL AMERICAN PIPELINE, L.P. AND SUBSIDIARIESFINANCIAL SUMMARY (unaudited)

COMPUTATION OF BASIC AND DILUTED NET INCOME/(LOSS) PER COMMON UNIT (1)(in millions, except per unit data)

	Three Months EndedJune 30,								Six Months EndedJune 30,
	2021				2020				2021				2020
Basic and Diluted Net Income/(Loss) per Common Unit
Net income/(loss) attributable to PAA	$	(220	)		$	142			$	202			$	(2,705	)
Distributions to Series A preferred unitholders	(37		)		(37		)		(74		)		(74		)
Distributions to Series B preferred unitholders	(12		)		(12		)		(25		)		(25		)
Other	—				(1		)		—				(1		)
Net income/(loss) allocated to common unitholders	$	(269	)		$	92			$	103			$	(2,805	)
Basic and diluted weighted average common units outstanding (2) (3)	720				728				721				728
Basic and diluted net income/(loss) per common unit	$	(0.37	)		$	0.13			$	0.14			$	(3.85	)

(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, if any, are allocated to 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.

(2)   The possible conversion of our Series A preferred units was excluded from the calculation of diluted net income/(loss) per common unit for the three and six months ended June 30, 2021 and 2020 as the effect was antidilutive.

(3)   Our equity-indexed compensation plan awards that contemplate the issuance of common units are considered 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 are deemed to be dilutive are 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 six months ended June 30, 2021 and 2020, the effect of equity-indexed compensation plan awards was antidilutive, or did not change the presentation of diluted weighted average common units outstanding or diluted net income/(loss) per common unit.

PLAINS ALL AMERICAN PIPELINE, L.P. AND SUBSIDIARIESFINANCIAL SUMMARY (unaudited)

NON-GAAP RECONCILIATIONS

COMPUTATION OF BASIC AND DILUTED ADJUSTED NET INCOME PER COMMON UNIT (1)(in millions, except per unit data)

	Three Months EndedJune 30,								Six Months EndedJune 30,
	2021				2020				2021				2020
Basic Adjusted Net Income per Common Unit
Net income/(loss) attributable to PAA	$	(220	)		$	142			$	202			$	(2,705	)
Selected items impacting comparability - Adjusted net income  attributable to PAA (2)	433				91				243				3,393
Adjusted net income attributable to PAA	$	213			$	233			$	445			$	688
Distributions to Series A preferred unitholders	(37		)		(37		)		(74		)		(74		)
Distributions to Series B preferred unitholders	(12		)		(12		)		(25		)		(25		)
Other	(1		)		(1		)		(1		)		(1		)
Adjusted net income allocated to common unitholders	$	163			$	183			$	345			$	588
Basic weighted average common units outstanding	720				728				721				728
Basic adjusted net income per common unit	$	0.23			$	0.25			$	0.48			$	0.81
Diluted Adjusted Net Income per Common Unit
Net income/(loss) attributable to PAA	$	(220	)		$	142			$	202			$	(2,705	)
Selected items impacting comparability - Adjusted net income  attributable to PAA (2)	433				91				243				3,393
Adjusted net income attributable to PAA	$	213			$	233			$	445			$	688
Distributions to Series A preferred unitholders	(37		)		(37		)		(74		)		(74		)
Distributions to Series B preferred unitholders	(12		)		(12		)		(25		)		(25		)
Other	(1		)		(1		)		(1		)		(1		)
Adjusted net income allocated to common unitholders	$	163			$	183			$	345			$	588
Basic weighted average common units outstanding	720				728				721				728
Effect of dilutive securities:
Series A preferred units (3)	—				—				—				—
Equity-indexed compensation plan awards (4)	—				—				—				1
Diluted weighted average common units outstanding	720				728				721				729
Diluted adjusted net income per common unit	$	0.23			$	0.25			$	0.48			$	0.81

(1)   We calculate adjusted net income 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, 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.

(2)   Certain of our non-GAAP financial measures may not be impacted by each of the selected items impacting comparability. See the “Selected Items Impacting Comparability” table for additional information.

(3)   The possible conversion of our Series A preferred units was excluded from the calculation of diluted net income per common unit for the three and six months ended June 30, 2021 and 2020 as the effect was antidilutive.

(4)   Our equity-indexed compensation plan awards that contemplate the issuance of common units are considered 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 are deemed to be dilutive are 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 months ended June 30, 2021 and 2020 and for the six months ended June 30, 2021, the effect of equity-indexed compensation plan awards was antidilutive.

PLAINS ALL AMERICAN PIPELINE, L.P. AND SUBSIDIARIESFINANCIAL SUMMARY (unaudited)

NON-GAAP RECONCILIATIONS (continued)

Net Income/(Loss) Per Common Unit to Adjusted Net Income Per Common Unit Reconciliations:

	Three Months EndedJune 30,								Six Months EndedJune 30,
	2021				2020				2021				2020
Basic net income/(loss) per common unit	$	(0.37	)		$	0.13			$	0.14			$	(3.85	)
Selected items impacting comparability per common unit (1)	0.60				0.12				0.34				4.66
Basic adjusted net income per common unit	$	0.23			$	0.25			$	0.48			$	0.81
Diluted net income/(loss) per common unit	$	(0.37	)		$	0.13			$	0.14			$	(3.85	)
Selected items impacting comparability per common unit (1)	0.60				0.12				0.34				4.66
Diluted adjusted net income per common unit	$	0.23			$	0.25			$	0.48			$	0.81

(1)   See the “Selected Items Impacting Comparability” and the “Computation of Basic and Diluted Adjusted Net Income Per Common Unit” tables for additional information.

	Twelve Months EndedDecember 31,
	2020				2019
Basic net income/(loss) per common unit	$	(3.83	)		$	2.70
Selected items impacting comparability per common unit (1)	5.38				(0.14		)
Basic adjusted net income per common unit	$	1.55			$	2.56
Diluted net income/(loss) per common unit	$	(3.83	)		$	2.65
Selected items impacting comparability per common unit (1)	5.38				(0.14		)
Diluted adjusted net income per common unit	$	1.55			$	2.51

(1)   See the “Selected Items Impacting Comparability” table for additional information.

PLAINS ALL AMERICAN PIPELINE, L.P. AND SUBSIDIARIESFINANCIAL SUMMARY (unaudited)

NON-GAAP RECONCILIATIONS (continued)(in millions, except per unit and ratio data)

	Three Months EndedJune 30,								Six Months EndedJune 30,
	2021				2020				2021				2020
Net Income/(Loss) to Adjusted EBITDA and Implied DCF Reconciliation
Net Income/(Loss)	$	(216	)		$	144			$	207			$	(2,701	)
Interest expense, net	107				108				213				215
Income tax expense/(benefit)	(10		)		(12		)		14				10
Depreciation and amortization	196				166				374				333
(Gains)/losses on asset sales and asset impairments, net	369				(1		)		370				618
Goodwill impairment losses	—				—				—				2,515
(Gain on)/impairment of investments in unconsolidated entities, net	—				69				—				91
Depreciation and amortization of unconsolidated entities (1)	68				16				88				33
Selected items impacting comparability - Adjusted EBITDA (2)	65				34				(141		)		205
Adjusted EBITDA	$	579			$	524			$	1,125			$	1,319
Interest expense, net of certain non-cash items (3)	(101		)		(103		)		(202		)		(206		)
Maintenance capital	(37		)		(54		)		(73		)		(104		)
Current income tax expense	(1		)		(15		)		(3		)		(22		)
Distributions from unconsolidated entities in excess of/(less than)  adjusted equity earnings (4)	(5		)		11				1				9
Distributions to noncontrolling interests (5)	—				(4		)		(6		)		(4		)
Implied DCF	$	435			$	359			$	842			$	992
Preferred unit distributions paid (6)	(62		)		(62		)		(99		)		(99		)
Implied DCF Available to Common Unitholders	$	373			$	297			$	743			$	893
Weighted Average Common Units Outstanding	720				728				721				728
Weighted Average Common Units and Common Unit Equivalents	791				799				792				799
Implied DCF per Common Unit (7)	$	0.52			$	0.41			$	1.03			$	1.23
Implied DCF per Common Unit and Common Unit Equivalent (8)	$	0.52			$	0.42			$	1.03			$	1.21
Cash Distribution Paid per Common Unit	$	0.18			$	0.18			$	0.36			$	0.54
Common Unit Cash Distributions (5)	$	130			$	131			$	260			$	393
Common Unit Distribution Coverage Ratio	2.87x				2.27x				2.86x				2.27x
Implied DCF Excess	$	243			$	166			$	483			$	500

(1)   Adjustment to exclude our proportionate share of depreciation and amortization expense (including write-downs related to cancelled projects) of unconsolidated entities.

(2)   Certain of our non-GAAP financial measures may not be impacted by each of the selected items impacting comparability.

(3)   Excludes certain non-cash items impacting interest expense such as amortization of debt issuance costs and terminated interest rate swaps.  

(4)   Comprised of cash distributions received from unconsolidated entities less equity earnings in unconsolidated entities (adjusted for our proportionate share of depreciation and amortization, including write-downs related to cancelled projects, and selected items impacting comparability of unconsolidated entities).  

(5)   Cash distributions paid during the period presented.  

(6)   Cash distributions paid to our preferred unitholders during the period presented.

(7)   Implied DCF Available to Common Unitholders for the period divided by the weighted average common units outstanding for the period.

(8)   Implied DCF Available to Common Unitholders for the period, adjusted for Series A preferred unit cash distributions paid, divided by the weighted average common units and common unit equivalents outstanding for the period. Our Series A preferred units are convertible into common units, generally on a one-for-one basis and subject to customary anti-dilution adjustments, in whole or in part, subject to certain minimum conversion amounts.

PLAINS ALL AMERICAN PIPELINE, L.P. AND SUBSIDIARIESFINANCIAL SUMMARY (unaudited)

NON-GAAP RECONCILIATIONS (continued)(in millions, except per unit and ratio data)

	Twelve Months EndedDecember 31,
	2020				2019
Net Income/(Loss) to Adjusted EBITDA and Implied DCF Reconciliation
Net Income/(Loss)	$	(2,580	)		$	2,180
Interest expense, net	436				425
Income tax expense/(benefit)	(19		)		66
Depreciation and amortization	653				601
(Gains)/losses on asset sales and asset impairments, net	719				28
Goodwill impairment losses	2,515				—
(Gain on)/impairment of investments in unconsolidated entities, net	182				(271		)
Depreciation and amortization of unconsolidated entities (1)	73				62
Selected items impacting comparability - Adjusted EBITDA (2)	581				146
Adjusted EBITDA	$	2,560			$	3,237
Interest expense, net of certain non-cash items (3)	(415		)		(407		)
Maintenance capital	(216		)		(287		)
Current income tax expense	(51		)		(112		)
Distributions from unconsolidated entities in excess of/(less than) adjusted equity earnings (4)	13				(49		)
Distributions to noncontrolling interests (5)	(10		)		(6		)
Implied DCF	$	1,881			$	2,376
Preferred unit distributions paid (6)	(198		)		(198		)
Implied DCF Available to Common Unitholders	$	1,683			$	2,178
Weighted Average Common Units Outstanding	728				727
Weighted Average Common Units and Common Unit Equivalents	799				798
Implied DCF per Common Unit (7)	$	2.31			$	2.99
Implied DCF per Common Unit and Common Unit Equivalent (8)	$	2.29			$	2.91
Cash Distribution Paid per Common Unit	$	0.90			$	1.38
Common Unit Cash Distributions (5)	$	655			$	1,004
Common Unit Distribution Coverage Ratio	2.57x				2.17x
Implied DCF Excess	$	1,028			$	1,174

(1)   Adjustment to exclude our proportionate share of depreciation and amortization expense of unconsolidated entities.

(2)   Certain of our non-GAAP financial measures may not be impacted by each of the selected items impacting comparability.

(3)   Excludes certain non-cash items impacting interest expense such as amortization of debt issuance costs and terminated interest rate swaps.  

(4)   Comprised of cash distributions received from unconsolidated entities less equity earnings in unconsolidated entities (adjusted for our proportionate share of depreciation and amortization and selected items impacting comparability of unconsolidated entities).  

(5)   Cash distributions paid during the period presented.  

(6)   Cash distributions paid to our preferred unitholders during the period presented.

(7)   Implied DCF Available to Common Unitholders for the period divided by the weighted average common units outstanding for the period.

(8)   Implied DCF Available to Common Unitholders for the period, adjusted for Series A preferred unit cash distributions paid, divided by the weighted average common units and common unit equivalents outstanding for the period. Our Series A preferred units are convertible into common units, generally on a one-for-one basis and subject to customary anti-dilution adjustments, in whole or in part, subject to certain minimum conversion amounts.

PLAINS ALL AMERICAN PIPELINE, L.P. AND SUBSIDIARIESFINANCIAL SUMMARY (unaudited)

NON-GAAP RECONCILIATIONS (continued)

Net Income/(Loss) Per Common Unit to Implied DCF Per Common Unit and Common Unit Equivalent Reconciliations:

	Three Months EndedJune 30,								Six Months EndedJune 30,
	2021				2020				2021				2020
Basic net income/(loss) per common unit	$	(0.37	)		$	0.13			$	0.14			$	(3.85	)
Reconciling items per common unit (1) (2)	0.89				0.28				0.89				5.08
Implied DCF per common unit	$	0.52			$	0.41			$	1.03			$	1.23
Basic net income/(loss) per common unit	$	(0.37	)		$	0.13			$	0.14			$	(3.85	)
Reconciling items per common unit and common unit equivalent (1) (3)	0.89				0.29				0.89				5.06
Implied DCF per common unit and common unit equivalent	$	0.52			$	0.42			$	1.03			$	1.21

	Twelve Months EndedDecember 31,
	2020				2019
Basic net income/(loss) per common unit	$	(3.83	)		$	2.70
Reconciling items per common unit (1) (4)	6.14				0.29
Implied DCF per common unit	$	2.31			$	2.99
Basic net income/(loss) per common unit	$	(3.83	)		$	2.70
Reconciling items per common unit and common unit equivalent (1) (3)	6.12				0.21
Implied DCF per common unit and common unit equivalent	$	2.29			$	2.91

(1)   Represents adjustments to Net Income to calculate Implied DCF Available to Common Unitholders. See the “Net Income/(Loss) to Adjusted EBITDA and Implied DCF Reconciliation” table for additional information.

(2)   Based on weighted average common units outstanding for the period of 720 million, 728 million, 721 million and 728 million, respectively.

(3)   Based on weighted average common units outstanding for the period, as well as weighted average Series A preferred units outstanding of 71 million for each of the periods presented.

(4)   Based on weighted average common units outstanding for the period of 728 million and 727 million, respectively.

PLAINS ALL AMERICAN PIPELINE, L.P. AND SUBSIDIARIESFINANCIAL SUMMARY (unaudited)

NON-GAAP RECONCILIATIONS (continued)(in millions)

	Three Months EndedJune 30,								Six Months EndedJune 30,
	2021				2020				2021				2020
Free Cash Flow and Free Cash Flow after Distributions  Reconciliation (1):
Net cash provided by operating activities	$	235			$	84			$	1,026			$	974
Adjustments to reconcile net cash provided by operating activities to  free cash flow:
Net cash used in investing activities	(175		)		(248		)		(283		)		(858		)
Cash contributions from noncontrolling interests	—				2				1				10
Cash distributions paid to noncontrolling interests (2)	—				(4		)		(6		)		(4		)
Free Cash Flow	$	60			$	(166	)		$	738			$	122
Cash distributions (3)	(192		)		(193		)		(359		)		(492		)
Free Cash Flow after Distributions	$	(132	)		$	(359	)		$	379			$	(370	)

(1)   Management uses the Non-GAAP financial measures Free Cash Flow and Free Cash Flow after Distributions to assess the amount of cash that is available for distributions, debt repayments, common equity repurchases and other general partnership purposes.

(2)   Cash distributions paid during the period presented.

(3)   Cash distributions paid to preferred and common unitholders during the period.

PLAINS ALL AMERICAN PIPELINE, L.P. AND SUBSIDIARIESFINANCIAL SUMMARY (unaudited)

SELECTED ITEMS IMPACTING COMPARABILITY(in millions)

	Three Months EndedJune 30,								Six Months EndedJune 30,
	2021				2020				2021				2020
Selected Items Impacting Comparability: (1)
Gains/(losses) from derivative activities and inventory valuation adjustments (2)	$	(86	)		$	(99	)		$	44			$	(104	)
Long-term inventory costing adjustments (3)	27				51				68				(64		)
Deficiencies under minimum volume commitments, net (4)	(6		)		(7		)		26				(6		)
Equity-indexed compensation expense (5)	(4		)		(5		)		(9		)		(8		)
Net gain/(loss) on foreign currency revaluation (6)	7				23				15				(23		)
Significant transaction-related expenses (7)	(3		)		—				(3		)		(3		)
Net gain on early repayment of senior notes (8)	—				3				—				3
Selected items impacting comparability - Adjusted EBITDA	$	(65	)		$	(34	)		$	141			$	(205	)
Gain on/(impairment of) investments in unconsolidated entities, net	—				(69		)		—				(91		)
Gains/(losses) on asset sales and asset impairments, net	(369		)		1				(370		)		(618		)
Goodwill impairment losses	—				—				—				(2,515		)
Tax effect on selected items impacting comparability	1				11				(14		)		36
Selected items impacting comparability - Adjusted net income attributable to  PAA	$	(433	)		$	(91	)		$	(243	)		$	(3,393	)

(1)   Certain of our non-GAAP financial measures may not be impacted by each of the selected items impacting comparability.

(2)   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 of operations, 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 adjusted results such that the earnings from the derivative instruments and the underlying transactions impact adjusted results in the same period. In addition, we exclude gains and losses on derivatives that are related to investing activities, such as the purchase of linefill.

(3)   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 treat 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 as a selected item impacting comparability.

(4)   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 capital expenditure necessary to construct the related asset. Some of these agreements include make-up rights if the minimum volume is not met. We, or our equity method investees, 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, or our equity method investees, 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 or equity earnings, as a selected item impacting comparability. We believe the inclusion of the contractually committed revenues associated with that period is meaningful to investors 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.

(5)   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 consider the compensation expense associated with these awards as a selected item impacting comparability 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 be settled in cash is not considered a selected item impacting comparability.

(6)   During the periods presented, there were fluctuations in the value of the Canadian dollar to the U.S. dollar, 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 thus classified as a selected item impacting comparability.

(7)   Includes expenses associated with the Permian Basin joint venture transaction announced in July 2021 and the acquisition of Felix Midstream LLC in February 2020.

(8)   Includes net gains recognized in connection with the repurchase of our outstanding senior notes on the open market.

PLAINS ALL AMERICAN PIPELINE, L.P. AND SUBSIDIARIESFINANCIAL SUMMARY (unaudited)

SELECTED ITEMS IMPACTING COMPARABILITY (continued)(in millions)

	Twelve Months EndedDecember 31,
	2020				2019
Selected Items Impacting Comparability: (1)
Losses from derivative activities and inventory valuation adjustments (2)	$	(460	)		$	(158	)
Long-term inventory costing adjustments (3)	(44		)		20
Deficiencies under minimum volume commitments, net (4)	(74		)		18
Equity-indexed compensation expense (5)	(19		)		(17		)
Net gain on foreign currency revaluation (6)	16				1
Line 901 incident (7)	—				(10		)
Significant transaction-related expenses (8)	(3		)		—
Net gain on early repayment of senior notes (9)	3				—
Selected items impacting comparability - Adjusted EBITDA	$	(581	)		$	(146	)
Losses from derivative activities (2)	—				(1		)
Gain on/(impairment of) investments in unconsolidated entities, net	(182		)		271
Gains/(losses) on asset sales and asset impairments, net	(719		)		(28		)
Goodwill impairment losses	(2,515		)		—
Tax effect on selected items impacting comparability	76				12
Selected items impacting comparability - Adjusted net income attributable to PAA	$	(3,921	)		$	108

(1)   Certain of our non-GAAP financial measures may not be impacted by each of the selected items impacting comparability.

(2)   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 of operations, 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 adjusted results such that the earnings from the derivative instruments and the underlying transactions impact adjusted results in the same period. In addition, we exclude gains and losses on derivatives that are related to investing activities, such as the purchase of linefill.

(3)   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 treat 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 as a selected item impacting comparability.

(4)   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 capital expenditure necessary to construct the related asset. Some of these agreements include make-up rights if the minimum volume is not met. We, or our equity method investees, 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, or our equity method investees, 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 or equity earnings, as a selected item impacting comparability. We believe the inclusion of the contractually committed revenues associated with that period is meaningful to investors 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.

(5)   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 consider the compensation expense associated with these awards as a selected item impacting comparability 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 be settled in cash is not considered a selected item impacting comparability.

(6)   During the periods presented, there were fluctuations in the value of the Canadian dollar to the U.S. dollar, 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 thus classified as a selected item impacting comparability.

(7)   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.

(8)   Includes expenses associated with the acquisition of Felix Midstream LLC in February 2020.

(9)   Includes net gains recognized in connection with the repurchase of our outstanding senior notes on the open market.

PLAINS ALL AMERICAN PIPELINE, L.P. AND SUBSIDIARIESFINANCIAL SUMMARY (unaudited)

SELECTED FINANCIAL DATA BY SEGMENT(in millions)

	Three Months EndedJune 30, 2021													Three Months EndedJune 30, 2020
	Transportation				Facilities				Supply andLogistics					Transportation				Facilities				Supply andLogistics
Revenues (1)	$	553			$	244			$	9,623				$	457			$	276			$	2,925
Purchases and related costs (1)	(60		)		(3		)		(9,700		)			(44		)		(7		)		(2,903		)
Field operating costs (1) (2)	(140		)		(74		)		(42		)			(140		)		(72		)		(45		)
Segment general and administrative expenses (2) (3)	(28		)		(21		)		(23		)			(24		)		(27		)		(21		)
Equity earnings in unconsolidated entities	31				2				—					81				—				—
Adjustments: (4)
Depreciation and amortization of unconsolidated entities	67				1				—					15				1				—
(Gains)/losses from derivative activities and inventory valuation adjustments	(1		)		(9		)		173					(6		)		(1		)		97
Long-term inventory costing adjustments	—				—				(27		)			—				—				(51		)
Deficiencies under minimum volume commitments, net	7				(1		)		—					4				3				—
Equity-indexed compensation expense	2				1				1					3				1				1
Net gain on foreign currency revaluation	—				—				(1		)			—				—				—
Significant transaction-related expenses	2				—				1					—				—				—
Segment Adjusted EBITDA	$	433			$	140			$	5				$	346			$	174			$	3
Maintenance capital	$	20			$	14			$	3				$	31			$	15			$	8

(1)   Includes intersegment amounts.

(2)   Field operating costs and Segment general and administrative expenses include equity-indexed compensation expense.

(3)   Segment general and administrative expenses reflect direct costs attributable to each segment and an allocation of other expenses to the segments. The proportional allocations by segment require judgment by management and are based on the business activities that exist during each period.

(4)   Represents adjustments utilized by our CODM in the evaluation of segment results. Many of these adjustments are also considered selected items impacting comparability when calculating consolidated non-GAAP financial measures such as Adjusted EBITDA. See the “Selected Items Impacting Comparability” table for additional discussion.

PLAINS ALL AMERICAN PIPELINE, L.P. AND SUBSIDIARIESFINANCIAL SUMMARY (unaudited)

SELECTED FINANCIAL DATA BY SEGMENT(in millions)

	Six Months EndedJune 30, 2021													Six Months EndedJune 30, 2020
	Transportation				Facilities				Supply andLogistics					Transportation				Facilities				Supply andLogistics
Revenues (1)	$	1,039			$	515			$	17,707				$	1,036			$	589			$	10,834
Purchases and related costs (1)	(106		)		(6		)		(17,497		)			(124		)		(10		)		(10,717		)
Field operating costs (1) (2)	(245		)		(151		)		(83		)			(302		)		(159		)		(103		)
Segment general and administrative expenses (2) (3)	(54		)		(41		)		(44		)			(51		)		(46		)		(44		)
Equity earnings in unconsolidated entities	117				4				—					189				2				—
Adjustments: (4)
Depreciation and amortization of unconsolidated entities	87				1				—					32				1				—
(Gains)/losses from derivative activities and inventory valuation adjustments	(1		)		(10		)		(24		)			—				—				121
Long-term inventory costing adjustments	—				—				(68		)			—				—				64
Deficiencies under minimum volume commitments, net	(23		)		(3		)		—					—				6				—
Equity-indexed compensation expense	5				2				2					5				1				2
Net gain on foreign currency revaluation	—				—				(2		)			—				—				(13		)
Significant transaction-related expenses	2				—				1					3				—				—
Segment Adjusted EBITDA	$	821			$	311			$	(8	)			$	788			$	384			$	144
Maintenance capital	$	47			$	20			$	6				$	64			$	29			$	11

(1)   Includes intersegment amounts.

(2)   Field operating costs and Segment general and administrative expenses include equity-indexed compensation expense.

(3)   Segment general and administrative expenses reflect direct costs attributable to each segment and an allocation of other expenses to the segments. The proportional allocations by segment require judgment by management and are based on the business activities that exist during each period.

(4)   Represents adjustments utilized by our CODM in the evaluation of segment results. Many of these adjustments are also considered selected items impacting comparability when calculating consolidated non-GAAP financial measures such as Adjusted EBITDA. See the “Selected Items Impacting Comparability” table for additional discussion.

PLAINS ALL AMERICAN PIPELINE, L.P. AND SUBSIDIARIESFINANCIAL SUMMARY (unaudited)

OPERATING DATA BY SEGMENT (1)

	Three Months EndedJune 30,						Six Months EndedJune 30,
	2021			2020			2021			2020
Transportation segment (average daily volumes in thousands ofbarrels per day):
Tariff activities volumes
Crude oil pipelines (by region):
Permian Basin (2)	4,189			4,161			3,972			4,663
South Texas / Eagle Ford (2)	314			321			317			389
Central (2)	467			355			420			380
Gulf Coast	159			118			152			131
Rocky Mountain (2)	327			244			307			258
Western	256			215			246			209
Canada	294			242			305			285
Crude oil pipelines	6,006			5,656			5,719			6,315
NGL pipelines	181			194			182			190
Tariff activities total volumes	6,187			5,850			5,901			6,505
Trucking volumes	61			64			65			80
Transportation segment total volumes	6,248			5,914			5,966			6,585
Facilities segment (average monthly volumes):
Liquids storage (average monthly capacity in millions of barrels) (3)	100			109			100			110
Natural gas storage (average monthly working capacity in billions of  cubic feet)	70			67			69			65
NGL fractionation (average volumes in thousands of barrels per day)	129			122			136			138
Facilities segment total volumes (average monthly volumes in millions  of barrels) (4)	115			124			115			125
Supply and Logistics segment (average daily volumes in thousandsof barrels per day):
Crude oil lease gathering purchases	1,352			1,077			1,264			1,198
NGL sales	112			94			165			156
Supply and Logistics segment total volumes	1,464			1,171			1,429			1,354

(1)   Average volumes are calculated as the total volumes (attributable to our interest) for the period divided by the number of days or months in the period.  

(2)   Region includes volumes (attributable to our interest) from pipelines owned by unconsolidated entities.

(3)   Includes volumes (attributable to our interest) from facilities owned by unconsolidated entities.

(4)   Facilities segment total volumes are calculated as the sum of: (i) liquids storage capacity; (ii) natural gas storage working capacity divided by 6 to account for the 6:1 mcf of natural gas to crude Btu equivalent ratio and further divided by 1,000 to convert to monthly volumes in millions; and (iii) NGL fractionation volumes multiplied by the number of days in the period and divided by the number of months in the period.

PLAINS ALL AMERICAN PIPELINE, L.P. AND SUBSIDIARIESFINANCIAL SUMMARY (unaudited)

NON-GAAP SEGMENT RECONCILIATIONS(in millions)

Fee-based Segment Adjusted EBITDA to Adjusted EBITDA Reconciliation:

	Three Months EndedJune 30,								Six Months EndedJune 30,
	2021				2020				2021				2020
Transportation Segment Adjusted EBITDA	$	433			$	346			$	821			$	788
Facilities Segment Adjusted EBITDA	140				174				311				384
Fee-based Segment Adjusted EBITDA	$	573			$	520			$	1,132			$	1,172
Supply and Logistics Segment Adjusted EBITDA	5				3				(8		)		144
Adjusted other income/(expense), net (1)	1				1				1				3
Adjusted EBITDA (2)	$	579			$	524			$	1,125			$	1,319

(1)   Represents “Other income/(expense), net” as reported on our Condensed Consolidated Statements of Operations, adjusted for selected items impacting comparability of $(83) million, $(17) million, $(22) million and $16 million for the three and six months ended June 30, 2021 and 2020, respectively. See the “Selected Items Impacting Comparability” table for additional information.

(2)   See the “Net Income/(Loss) to Adjusted EBITDA and Implied DCF Reconciliation” table for reconciliation to Net Income/(Loss).

Reconciliation of Segment Adjusted EBITDA to Segment Adjusted EBITDA further adjusted for impact of divested assets:

	Three Months EndedJune 30, 2021													Three Months EndedJune 30, 2020
	Transportation				Facilities				Supply andLogistics					Transportation				Facilities				Supply andLogistics
Segment Adjusted EBITDA	$	433			$	140			$	5				$	346			$	174			$	3
Impact of divested assets (1)	—				—				—					—				(15		)		—
Segment Adjusted EBITDA further adjusted for impact of divested assets	$	433			$	140			$	5				$	346			$	159			$	3

	Six Months EndedJune 30, 2021													Six Months EndedJune 30, 2020
	Transportation				Facilities				Supply andLogistics					Transportation				Facilities				Supply andLogistics
Segment Adjusted EBITDA	$	821			$	311			$	(8	)			$	788			$	384			$	144
Impact of divested assets (1)	—				—				—					(1		)		(33		)		—
Segment Adjusted EBITDA further adjusted for impact of divested assets	$	821			$	311			$	(8	)			$	787			$	351			$	144

(1)   Estimated impact of divestitures completed during 2020 and 2021, assuming an effective date of January 1, 2020. Divested assets primarily included certain NGL storage terminals and Los Angeles Basin crude oil storage terminals that were previously included in our Facilities segment and the sale of a portion of our interest in a joint venture pipeline that was previously reported in our Transportation segment.

PLAINS GP HOLDINGS AND SUBSIDIARIESFINANCIAL SUMMARY (unaudited)

CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS(in millions, except per share data)

	Three Months EndedJune 30, 2021													Three Months EndedJune 30, 2020
					Consolidating													Consolidating
	PAA				Adjustments (1)				PAGP					PAA				Adjustments (1)				PAGP
REVENUES	$	9,930			$	—			$	9,930				$	3,225			$	—			$	3,225
COSTS AND EXPENSES
Purchases and related costs	9,277				—				9,277					2,525				—				2,525
Field operating costs	252				—				252					253				—				253
General and administrative expenses	72				2				74					72				2				74
Depreciation and amortization	196				1				197					166				—				166
(Gains)/losses on asset sales and  asset impairments, net	369				—				369					(1		)		—				(1		)
Total costs and expenses	10,166				3				10,169					3,015				2				3,017
OPERATING INCOME/(LOSS)	(236		)		(3		)		(239		)			210				(2		)		208
OTHER INCOME/(EXPENSE)
Equity earnings in unconsolidated  entities	33				—				33					81				—				81
Gain on/(impairment of)  investments in unconsolidated  entities, net	—				—				—					(69		)		—				(69		)
Interest expense, net	(107		)		—				(107		)			(108		)		—				(108		)
Other income/(expense), net	84				—				84					18				—				18
INCOME/(LOSS) BEFORE TAX	(226		)		(3		)		(229		)			132				(2		)		130
Current income tax expense	(1		)		—				(1		)			(15		)		—				(15		)
Deferred income tax benefit	11				7				18					27				(5		)		22
NET INCOME/(LOSS)	(216		)		4				(212		)			144				(7		)		137
Net (income)/loss attributable to  noncontrolling interests	(4		)		147				143					(2		)		(119		)		(121		)
NET INCOME/(LOSS)  ATTRIBUTABLE TO PAGP	$	(220	)		$	151			$	(69	)			$	142			$	(126	)		$	16
BASIC AND DILUTED NET INCOME/(LOSS) PER  CLASS A SHARE									$	(0.35	)											$	0.09
BASIC AND DILUTED WEIGHTED AVERAGE CLASS A  SHARES OUTSTANDING									194													184

(1)   Represents the aggregate consolidating adjustments necessary to produce consolidated financial statements for PAGP. PLAINS GP HOLDINGS AND SUBSIDIARIESFINANCIAL SUMMARY (unaudited)

CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS(in millions, except per share data)

	Six Months EndedJune 30, 2021													Six Months EndedJune 30, 2020
					Consolidating													Consolidating
	PAA				Adjustments (1)				PAGP					PAA				Adjustments (1)				PAGP
REVENUES	$	18,313			$	—			$	18,313				$	11,494			$	—			$	11,494
COSTS AND EXPENSES
Purchases and related costs	16,669				—				16,669					9,893				—				9,893
Field operating costs	471				—				471					557				—				557
General and administrative expenses	139				3				142					141				3				144
Depreciation and amortization	374				1				375					333				2				335
(Gains)/losses on asset sales and  asset impairments, net	370				—				370					618				—				618
Goodwill impairment losses	—				—				—					2,515				—				2,515
Total costs and expenses	18,023				4				18,027					14,057				5				14,062
OPERATING INCOME/(LOSS)	290				(4		)		286					(2,563		)		(5		)		(2,568		)
OTHER INCOME/(EXPENSE)
Equity earnings in unconsolidated  entities	121				—				121					191				—				191
Gain on/(impairment of)  investments in unconsolidated  entities, net	—				—				—					(91		)		—				(91		)
Interest expense, net	(213		)		—				(213		)			(215		)		—				(215		)
Other expense, net	23				—				23					(13		)		—				(13		)
INCOME/(LOSS) BEFORE TAX	221				(4		)		217					(2,691		)		(5		)		(2,696		)
Current income tax expense	(3		)		—				(3		)			(22		)		—				(22		)
Deferred income tax (expense)/benefit	(11		)		(22		)		(33		)			12				150				162
NET INCOME/(LOSS)	207				(26		)		181					(2,701		)		145				(2,556		)
Net (income)/loss attributable to  noncontrolling interests	(5		)		(175		)		(180		)			(4		)		1,995				1,991
NET INCOME/(LOSS)  ATTRIBUTABLE TO PAGP	$	202			$	(201	)		$	1				$	(2,705	)		$	2,140			$	(565	)
BASIC AND DILUTED NET INCOME/(LOSS) PER  CLASS A SHARE									$	—												$	(3.08	)
BASIC AND DILUTED WEIGHTED AVERAGE CLASS A  SHARES OUTSTANDING									194													183

(1)   Represents the aggregate consolidating adjustments necessary to produce consolidated financial statements for PAGP. PLAINS GP HOLDINGS AND SUBSIDIARIESFINANCIAL SUMMARY (unaudited)

CONDENSED CONSOLIDATING BALANCE SHEET DATA(in millions)

	June 30, 2021													December 31, 2020
					Consolidating													Consolidating
	PAA				Adjustments (1)				PAGP					PAA				Adjustments (1)				PAGP
ASSETS
Current assets	$	5,676			$	2			$	5,678				$	3,665			$	3			$	3,668
Property and equipment, net	13,451				7				13,458					14,611				9				14,620
Investments in unconsolidated  entities	3,745				—				3,745					3,764				—				3,764
Deferred tax asset	—				1,414				1,414					—				1,444				1,444
Linefill and base gas	909				—				909					982				—				982
Long-term operating lease right-of-  use assets, net	344				—				344					378				—				378
Long-term inventory	210				—				210					130				—				130
Other long-term assets, net	1,056				(2		)		1,054					967				(2		)		965
Total assets	$	25,391			$	1,421			$	26,812				$	24,497			$	1,454			$	25,951
LIABILITIES AND PARTNERS’ CAPITAL
Current liabilities	$	6,163			$	—			$	6,163				$	4,253			$	2			$	4,255
Senior notes, net	8,326				—				8,326					9,071				—				9,071
Other long-term debt, net	63				—				63					311				—				311
Long-term operating lease liabilities	289				—				289					317				—				317
Other long-term liabilities and  deferred credits	910				—				910					807				—				807
Total liabilities	15,751				—				15,751					14,759				2				14,761
Partners’ capital excluding  noncontrolling interests	9,495				(8,074		)		1,421					9,593				(8,129		)		1,464
Noncontrolling interests	145				9,495				9,640					145				9,581				9,726
Total partners’ capital	9,640				1,421				11,061					9,738				1,452				11,190
Total liabilities and partners’  capital	$	25,391			$	1,421			$	26,812				$	24,497			$	1,454			$	25,951

(1)   Represents the aggregate consolidating adjustments necessary to produce consolidated financial statements for PAGP.

PLAINS GP HOLDINGS AND SUBSIDIARIESFINANCIAL SUMMARY (unaudited)

COMPUTATION OF BASIC AND DILUTED NET INCOME/(LOSS) PER CLASS A SHARE (1)(in millions, except per share data)

	Three Months EndedJune 30,								Six Months EndedJune 30,
	2021				2020				2021				2020
Basic and Diluted Net Income/(Loss) per Class A Share
Net income/(loss) attributable to PAGP	$	(69	)		$	16			$	1			$	(565	)
Basic and diluted weighted average Class A shares outstanding	194				184				194				183
Basic and diluted net income/(loss) per Class A share	$	(0.35	)		$	0.09			$	—			$	(3.08	)

(1)   For the three and six months ended June 30, 2021 and 2020, the possible exchange of AAP units and AAP Management units would not have had a dilutive effect on basic net income/(loss) per Class A share.

Forward-Looking Statements

Except for the historical information contained herein, the matters discussed in this release consist of forward-looking statements that involve certain risks and uncertainties that could cause actual results or outcomes to differ materially from results or outcomes anticipated in the forward-looking statements. These risks and uncertainties include, among other things, the following:

• declines in global crude oil demand and crude oil prices (whether due to the COVID-19 pandemic, future pandemics or other factors) that correspondingly lead to a significant reduction of North American crude oil, natural gas liquids (“NGL”) and natural gas production (whether due to reduced producer cash flow to fund drilling activities or the inability of producers to access capital, or both, the unavailability of pipeline and/or storage capacity, the shutting-in of production by producers, government-mandated pro-ration orders, or other factors), which in turn could result in significant declines in the actual or expected volume of crude oil and NGL shipped, processed, purchased, stored, fractionated and/or gathered at or through the use of our assets and/or the reduction of commercial opportunities that might otherwise be available to us;
• the effects of competition and capacity overbuild in areas where we operate, including contract renewal risk and the risk of loss of business to other midstream operators who are willing or under pressure to aggressively reduce transportation rates in order to capture or preserve customers;
• negative societal sentiment regarding the hydrocarbon energy industry and the continued development and consumption of hydrocarbons, which could influence consumer preferences and governmental or regulatory actions that adversely impact our business;
• unanticipated changes in crude oil and NGL market structure, grade differentials and volatility (or lack thereof);
• environmental liabilities or events that are not covered by an indemnity, insurance or existing reserves;
• fluctuations in refinery capacity in areas supplied by our mainlines and other factors affecting demand for various grades of crude oil, NGL and natural gas and resulting changes in pricing conditions or transportation throughput requirements;
• the availability of, and our ability to consummate, divestitures, joint ventures, acquisitions or other strategic opportunities;
• maintenance of our credit rating and ability to receive open credit from our suppliers and trade counterparties;
• the occurrence of a natural disaster, catastrophe, terrorist attack (including eco-terrorist attacks) or other event that materially impacts our operations, including cyber or other attacks on our electronic and computer systems;
• weather interference with business operations or project construction, including the impact of extreme weather events or conditions;
• the refusal or inability of our customers or counterparties to perform their obligations under their contracts with us (including commercial contracts, asset sale agreements and other agreements), whether justified or not and whether due to financial constraints (such as reduced creditworthiness, liquidity issues or insolvency), market constraints, legal constraints (including governmental orders or guidance), the exercise of contractual or common law rights that allegedly excuse their performance (such as force majeure or similar claims) or other factors;
• our inability to perform our obligations under our contracts, whether due to non-performance by third parties, including our customers or counterparties, market constraints, third-party constraints, legal constraints (including governmental orders or guidance), or other factors;
• the incurrence of costs and expenses related to unexpected or unplanned capital expenditures, third-party claims or other factors;
• the successful operation of joint ventures and joint operating arrangements we enter into from time to time, whether relating to assets operated by us or by third parties, and the successful integration and future performance of acquired assets or businesses;
• failure to implement or capitalize, or delays in implementing or capitalizing, on investment capital projects, whether due to permitting delays, permitting withdrawals or other factors;
• disruptions to futures markets for crude oil, NGL and other petroleum products, which may impair our ability to execute our commercial or hedging strategies;
• shortages or cost increases of supplies, materials or labor;
• the impact of current and future laws, rulings, governmental regulations, trade policies, accounting standards and statements, and related interpretations, including legislation or regulatory initiatives that prohibit, restrict or regulate hydraulic fracturing or that prohibit the development of oil and gas resources and the related infrastructure on lands dedicated to or served by our pipelines;
• tightened capital markets or other factors that increase our cost of capital or limit our ability to obtain debt or equity financing on satisfactory terms to fund additional acquisitions, investment capital projects, working capital requirements and the repayment or refinancing of indebtedness;
• inability of producers, who have made commitments to our pipelines, to access capital to fund their drilling and completion activities;
• general economic, market or business conditions in the United States and elsewhere (including the potential for a recession or significant slowdown in economic activity levels and the timing, pace and extent of economic recovery) that impact demand for crude oil, drilling and production activities and therefore the demand for the midstream services we provide and commercial opportunities available to us;
• the amplification of other risks caused by volatile financial markets, capital constraints, liquidity concerns and inflation;
• the use or availability of third-party assets upon which our operations depend and over which we have little or no control;
• the currency exchange rate of the Canadian dollar to the United States dollar;
• inability to recognize current revenue attributable to deficiency payments received from customers who fail to ship or move more than minimum contracted volumes until the related credits expire or are used;
• significant under-utilization of our assets and facilities;
• increased costs, or lack of availability, of insurance;
• the effectiveness of our risk management activities;
• fluctuations in the debt and equity markets, including the price of our units at the time of vesting under our long-term incentive plans;
• risks related to the development and operation of our assets; and
• other factors and uncertainties inherent in the transportation, storage, terminalling and marketing of crude oil, as well as in the storage of natural gas and the processing, transportation, fractionation, storage and marketing of NGL as discussed in the Partnerships’ filings with the Securities and Exchange Commission.        

PAA is a publicly traded master limited partnership that owns and operates midstream energy infrastructure and provides logistics services for crude oil, NGL and natural gas. PAA owns an extensive network of pipeline transportation, terminalling, storage and gathering assets in key crude oil and NGL producing basins and transportation corridors and at major market hubs in the United States and Canada. On average, PAA handles more than 5 million barrels per day of crude oil and NGL in its Transportation segment. PAA is headquartered in Houston, Texas. More information is available at www.plainsallamerican.com.

PAGP is a publicly traded entity that owns an indirect, non-economic controlling general partner interest in PAA and an indirect limited partner interest in PAA, one of the largest energy infrastructure and logistics companies in North America. PAGP is headquartered in Houston, Texas. More information is available at www.plainsallamerican.com.

Contacts:

Roy Lamoreaux

Vice President, Investor Relations, Communications and Government Relations

(866) 809-1291

Brett Magill

Director, Investor Relations

(866) 809-1291