pagp-20260630

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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

________________________________________________________________

FORM 10-Q

________________________________________________________________________________________________________________________________

☑ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2026

☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

Commission File Number: 1-36132

________________________________________________________________

PLAINS GP HOLDINGS, L.P.

(Exact name of registrant as specified in its charter)


Delaware						90-1005472
(State or other jurisdiction of incorporation or organization)						(I.R.S. Employer Identification No.)

333 Clay Street, Suite 1600

Houston, Texas 77002

(Address of principal executive offices) (Zip code)

(713) 646-4100

(Registrant’s telephone number, including area code)

________________________________________________________________

Securities registered pursuant to Section 12(b) of the Act:


Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Class A Shares	PAGP	The Nasdaq Global Select Market

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. ☑ Yes ☐ No

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). ☑ Yes ☐ No

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer

☑

Accelerated filer

☐

Non-accelerated filer

☐

Smaller reporting company

☐

Emerging growth company

☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). ☐ Yes ☑ No

As of July 31, 2026, there were 197,904,124 Class A Shares outstanding.

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PLAINS GP HOLDINGS, L.P. AND SUBSIDIARIES

TABLE OF CONTENTS


			Page
PART I. FINANCIAL INFORMATION
Item 1. UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS:
Condensed Consolidated Balance Sheets: As of June 3 0 , 2026 and December 31, 2025			3
Condensed Consolidated Statements of Operations: For the three and six months ended June 3 0 , 2026 and 2025			4
Condensed Consolidated Statements of Comprehensive Income: For the three a nd six months ended June 3 0 , 2026 and 2025			5
Condensed Consolidated Statements of Changes in Accumulated Other Comprehensive Income/(Loss): For the six months ended June 3 0 , 2026 and 2025			5
Condensed Consolidated Statements of Cash Flows: For the six months ended June 3 0 , 2026 and 2025			6
Condensed Consolidated Statements of Changes in Partners’ Capital: For the three and six months ended June 3 0 , 2026 and 2025			7
Notes to the Condensed Consolidated Financial Statements:
1. Organization and Basis of Consolidation and Presentation			8

2. Canadian NGL Business Divestiture and Discontinued Operations			11
3. Revenues and Accounts Receivable			13
4. Net Income Per Class A Share			16
5. Inventory, Linefill and Long-term Inventory			19
6. Debt			20
7. Partners’ Capital and Distributions			22
8. Derivatives and Risk Management Activities			25
9. Related Party Transactions			28
10. Commitments and Contingencies			28
11. Segment Information			31


Item 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS			39
Item 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK			58
Item 4. CONTROLS AND PROCEDURES			59

PART II. OTHER INFORMATION
Item 1. LEGAL PROCEEDINGS			60
Item 1A. RISK FACTORS			60
Item 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS			60
Item 3. DEFAULTS UPON SENIOR SECURITIES			60
Item 4. MINE SAFETY DISCLOSURES			60
Item 5. OTHER INFORMATION			60
Item 6. EXHIBITS			61
SIGNATURES			64

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PART I. FINANCIAL INFORMATION

Item 1. UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

PLAINS GP HOLDINGS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(in millions, except share data)


	June 30, 2026		December 31, 2025
	(unaudited)
ASSETS

CURRENT ASSETS
Cash and cash equivalents	$	1,060	$	329

Trade accounts receivable and other receivables, net	5,267		3,598
Inventory	84		211
Current assets of discontinued operations (Note 2)	—		479
Other current assets	119		87
Total current assets	6,530		4,704

PROPERTY AND EQUIPMENT	22,702		22,536
Accumulated depreciation	(5,921)		(5,676)
Property and equipment, net	16,781		16,860

OTHER ASSETS
Investments in unconsolidated entities	2,817		2,846
Intangible assets, net	1,610		1,754
Deferred tax asset	1,083		1,136
Linefill	892		900
Long-term operating lease right-of-use assets, net	172		198
Long-term inventory	257		214
Long-term assets of discontinued operations (Note 2)	—		2,557
Other long-term assets, net	91		107
Total assets	$	30,233	$	31,276

LIABILITIES AND PARTNERS’ CAPITAL

CURRENT LIABILITIES
Trade accounts payable	$	4,942	$	3,457
Short-term debt	9		563
Current liabilities of discontinued operations (Note 2)	154		382
Other current liabilities	746		500
Total current liabilities	5,851		4,902

LONG-TERM LIABILITIES
Senior notes, net	8,373		9,118
Other long-term debt, net	59		1,578
Long-term operating lease liabilities	194		202
Long-term liabilities of discontinued operations (Note 2)	—		606
Other long-term liabilities and deferred credits	442		654
Total long-term liabilities	9,068		12,158

COMMITMENTS AND CONTINGENCIES (NOTE 10)

PARTNERS’ CAPITAL
Class A shareholders (197,904,124 and 197,904,124 shares outstanding, respectively)	1,580		1,345
Noncontrolling interests	13,734		12,871
Total partners’ capital	15,314		14,216
Total liabilities and partners’ capital	$	30,233	$	31,276

The accompanying notes are an integral part of these condensed consolidated financial statements.

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PLAINS GP HOLDINGS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(in millions, except per share data)


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025
	(unaudited)				(unaudited)
REVENUES
Product sales revenues	$	17,221	$	10,197	$	29,246	$	21,243
Services revenues	472		445		916		876
Total revenues	17,693		10,642		30,162		22,119

COSTS AND EXPENSES
Purchases and related costs	16,556		9,758		28,049		20,277
Field operating costs	328		286		628		585
General and administrative expenses	111		84		195		171
Depreciation and amortization	242		235		486		466
Losses on asset sales, asset impairments and other, net	59		42		6		29
Total costs and expenses	17,296		10,405		29,364		21,528
OPERATING INCOME	397		237		798		591
OTHER INCOME/(EXPENSE)
Equity earnings in unconsolidated entities	89		94		178		196
Gain on investments in unconsolidated entities, net	—		—		—		31
Interest expense (net of capitalized interest of $2, $3, $3 and $5, respectively)	(135)		(110)		(279)		(217)


Other income, net	24		8		8		14

INCOME FROM CONTINUING OPERATIONS BEFORE TAX	375		229		705		615
Current income tax expense from continuing operations	(107)		(1)		(322)		(6)
Deferred income tax (expense)/benefit from continuing operations	(102)		(15)		106		(40)
INCOME FROM CONTINUING OPERATIONS, NET OF TAX	166		213		489		569
INCOME FROM DISCONTINUED OPERATIONS, NET OF TAX (NOTE 2)	1,649		70		1,548		206
NET INCOME	1,815		283		2,037		775
Net income attributable to noncontrolling interests from continuing operations	(240)		(203)		(515)		(513)
Net income attributable to noncontrolling interests from discontinued operations	(1,186)		(50)		(1,114)		(148)
Net income attributable to noncontrolling interests	(1,426)		(253)		(1,629)		(661)
Net income/(loss) attributable to PAGP from continuing operations	(74)		10		(26)		56
Net income attributable to PAGP from discontinued operations	463		20		434		58
NET INCOME ATTRIBUTABLE TO PAGP	$	389	$	30	$	408	$	114

Basic weighted average Class A shared outstanding	198		198		198		198

Basic Net Income/(Loss) per Class A Share:
Continuing operations	$	(0.37)	$	0.05	$	(0.13)	$	0.29
Discontinued operations	2.34		0.10		2.19		0.29
Basic Net Income per Class A Share	$	1.97	$	0.15	$	2.06	$	0.58

Diluted weighted average Class A shares outstanding	198		198		198		233

Diluted Net Income/(Loss) per Class A Share:
Continuing operations	$	(0.37)	$	0.05	$	(0.13)	$	0.29
Discontinued operations	2.34		0.10		2.19		0.28
Diluted net income per Class A Share	$	1.97	$	0.15	$	2.06	$	0.57

The accompanying notes are an integral part of these condensed consolidated financial statements.

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PLAINS GP HOLDINGS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(in millions)


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025
	(unaudited)				(unaudited)
Net income	$	1,815	$	283	$	2,037	$	775
Other comprehensive income/(loss)	(13)		187		(63)		192
Comprehensive income	1,802		470		1,974		967
Comprehensive income attributable to noncontrolling interests	(1,417)		(387)		(1,584)		(799)
Comprehensive income attributable to PAGP	$	385	$	83	$	390	$	168

The accompanying notes are an integral part of these condensed consolidated financial statements.

PLAINS GP HOLDINGS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN

ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS)

(in millions)


	Derivative Instruments		Translation Adjustments		Other		Total
	(unaudited)
Balance at December 31, 2025	$	(29)	$	(872)	$	5	$	(896)

Reclassification adjustments	2		—		—		2

Currency translation adjustments	—		(60)		—		(60)
Other	—		—		(5)		(5)
Total period activity	2		(60)		(5)		(63)
Balance at June 30, 2026	$	(27)	$	(932)	$	—	$	(959)


	Derivative Instruments		Translation Adjustments		Other		Total
	(unaudited)
Balance at December 31, 2024	$	(44)	$	(1,039)	$	—	$	(1,083)

Reclassification adjustments	2		—		—		2
Unrealized gain on hedges	6		—		—		6
Currency translation adjustments	—		183		—		183
Other	—		—		1		1
Total period activity	8		183		1		192
Balance at June 30, 2025	$	(36)	$	(856)	$	1	$	(891)

The accompanying notes are an integral part of these condensed consolidated financial statements.

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PLAINS ALL GP HOLDINGS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(in millions)


	Six Months Ended June 30,
	2026		2025
	(unaudited)
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	2,037	$	775
Reconciliation of net income to net cash provided by operating activities:
Income from discontinued operations, net of tax	(1,548)		(206)
Depreciation and amortization	486		466
Losses on asset sales, asset impairments and other, net	6		29


Deferred income tax expense/(benefit)	(106)		40

(Gain)/loss on foreign currency revaluation	(16)		4


Equity earnings in unconsolidated entities	(178)		(196)
Distributions on earnings from unconsolidated entities	204		256
Gain on investments in unconsolidated entities, net	—		(31)
Other	27		32
Changes in assets and liabilities, net of acquisitions	299		(140)
Cash provided by operating activities - continuing operations	1,211		1,029
Cash provided by operating activities - discontinued operations	159		301
Net cash provided by operating activities	1,370		1,330

CASH FLOWS FROM INVESTING ACTIVITIES
Cash paid in connection with acquisitions, net of cash acquired	(130)		(681)

Additions to property, equipment and other	(268)		(310)
Cash paid for purchases of linefill	(12)		(17)
Proceeds from sales of assets	4		21

Cash received from sales of linefill	37		—
Other investing activities	20		—
Cash used in investing activities - continuing operations	(349)		(987)
Cash provided by/(used in) investing activities - discontinued operations	3,451		(106)
Net cash provided by/(used in) investing activities	3,102		(1,093)

CASH FLOWS FROM FINANCING ACTIVITIES
Net borrowings/(repayments) under PAA commercial paper program (Note 6)	(970)		69



Repayment under PAA term loan (Note 6)	(1,100)		—
Proceeds from the issuance of PAA senior notes (Note 6)	—		998
Repayments of PAA senior notes (Note 6)	(750)		—


Repurchase of common units by a subsidiary	—		(8)
Repurchase of Series A preferred units by a subsidiary (Note 7)	—		(333)
Distributions paid to Class A shareholders (Note 7)	(165)		(150)
Distributions paid to noncontrolling interests (Note 7)	(734)		(731)
Contributions from noncontrolling interests	—		29


Other financing activities	(6)		(19)


Net cash provided by/(used in) financing activities	(3,725)		(145)

Effect of translation adjustment - continuing operations	(16)		8
Effect of translation adjustment - discontinued operations	—		11

Net increase in cash and cash equivalents and restricted cash	731		111
Cash and cash equivalents and restricted cash, beginning of period	329		349
Cash and cash equivalents and restricted cash, end of period	$	1,060	$	460

Cash paid for:
Interest, net of amounts capitalized	$	259	$	216
Income taxes, net of amounts refunded	$	53	$	48

The accompanying notes are an integral part of these condensed consolidated financial statements.

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PLAINS GP HOLDINGS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN PARTNERS’ CAPITAL

(in millions)


	Class A Shareholders		Noncontrolling Interests		Total Partners’ Capital
Balance at December 31, 2025	$	1,345	$	12,871	$	14,216
Net income	408		1,629		2,037
Distributions (Note 7)	(165)		(733)		(898)
Other comprehensive loss	(18)		(45)		(63)



Other	10		12		22
Balance at June 30, 2026	$	1,580	$	13,734	$	15,314

	Class A Shareholders		Noncontrolling Interests		Total Partners’ Capital
Balance at March 31, 2026	$	1,274	$	12,678	$	13,952
Net income	389		1,426		1,815
Distributions (Note 7)	(83)		(366)		(449)
Other comprehensive loss	(4)		(9)		(13)

Other	4		5		9
Balance at June 30, 2026	$	1,580	$	13,734	$	15,314

	Class A Shareholders		Noncontrolling Interests		Total Partners’ Capital
Balance at December 31, 2024	$	1,351	$	12,965	$	14,316
Net income	114		661		775
Distributions	(150)		(724)		(874)
Other comprehensive income	54		138		192
Repurchase of common units by a subsidiary	1		(9)		(8)
Repurchase of Series A preferred units by a subsidiary	(12)		(301)		(313)
Contributions from noncontrolling interests	—		29		29
Other	(4)		12		8
Balance at June 30, 2025	$	1,354	$	12,771	$	14,125

	Class A Shareholders		Noncontrolling Interests		Total Partners’ Capital
Balance at March 31, 2025	$	1,356	$	12,704	$	14,060
Net income	30		253		283
Distributions	(75)		(343)		(418)
Other comprehensive income	53		134		187
Repurchase of common units by a subsidiary	1		(9)		(8)
Contributions from noncontrolling interests	—		25		25
Other	(11)		7		(4)
Balance at June 30, 2025	$	1,354	$	12,771	$	14,125

The accompanying notes are an integral part of these condensed consolidated financial statements.

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PLAINS GP HOLDINGS, L.P. AND SUBSIDIARIES

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Note 1—Organization and Basis of Consolidation and Presentation

Organization

Plains GP Holdings, L.P. (“PAGP”) is a publicly-traded Delaware limited partnership formed in 2013 that has elected to be taxed as a corporation for United States federal income tax purposes. PAGP does not directly own any operating assets; as of June 30, 2026, its sole source of cash flow is derived from an indirect investment in Plains All American Pipeline, L.P. (“PAA”), a publicly-traded Delaware limited partnership. As used in this Form 10-Q and unless the context indicates otherwise (taking into account the fact that PAGP has no operating activities apart from those conducted by PAA and its subsidiaries), the terms “Partnership,” “we,” “us,” “our,” “ours” and similar terms refer to PAGP and its subsidiaries.

As of June 30, 2026, we owned an approximate 85% limited partner interest in Plains AAP, L.P. (“AAP”) through our ownership of approximately 197.9 million Class A units of AAP (“AAP Units”). We also own a 100% managing member interest in Plains All American GP LLC (“GP LLC”), a Delaware limited liability company that holds the non-economic general partner interest in AAP. AAP is a Delaware limited partnership that, as of June 30, 2026, directly owned a limited partner interest in PAA through its ownership of approximately 233.0 million PAA common units (approximately 31% of PAA’s total outstanding common units and Series A preferred units combined). AAP is the sole member of PAA GP LLC (“PAA GP”), a Delaware limited liability company that directly holds the non-economic general partner interest in PAA.

PAA’s business model integrates large-scale supply aggregation capabilities with the ownership and operation of critical midstream infrastructure systems that connect major producing regions to key demand centers and export terminals. As one of the largest crude oil midstream service providers in North America, PAA owns an extensive network of pipeline transportation, terminalling, storage and gathering assets in key crude oil producing basins (including the Permian Basin) and transportation corridors and at major market hubs in the United States and Canada. PAA’s assets and the services it provides are primarily focused on and conducted through two operating segments: Crude Oil and Natural Gas Liquids (“NGL”). See Note 11 for further discussion of our operating segments.

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

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

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PLAINS GP HOLDINGS, L.P. AND SUBSIDIARIES

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Definitions

Additional defined terms may be 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


CAD	=	Canadian dollar
CODM	=	Chief Operating Decision Maker
EBITDA	=	Earnings before interest, taxes, depreciation and amortization

FASB	=	Financial Accounting Standards Board
GAAP	=	Generally accepted accounting principles in the United States
ICE	=	Intercontinental Exchange
ISDA	=	International Swaps and Derivatives Association

LTIP	=	Long-term incentive plan


NGL	=	Natural gas liquids, including ethane, propane and butane
NYMEX	=	New York Mercantile Exchange

SEC	=	United States Securities and Exchange Commission
SOFR	=	Secured Overnight Financing Rate
TWh	=	Terawatt hour
U.S.	=	United States
USD	=	U.S. dollar

Basis of Consolidation and Presentation

The accompanying unaudited condensed consolidated interim financial statements and related notes thereto should be read in conjunction with our 2025 Annual Report on Form 10-K. The accompanying condensed consolidated financial statements include the accounts of PAGP and all of its wholly owned subsidiaries and those entities that it controls. Investments in entities over which we have significant influence but not control are accounted for by the equity method. We apply proportionate consolidation for pipelines and other assets in which we own undivided joint interests. Our reporting currency is U.S. dollars, and all references to dollars are U.S. dollars, unless stated otherwise.

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, 2025 was derived from audited financial statements, but does not include all disclosures required by GAAP. The results of operations for the three and six months ended June 30, 2026 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 balances and transactions have been eliminated in consolidation, and certain reclassifications have been made to information from previous years to conform to the current presentation. These reclassifications had no impact on net income or total partners’ capital.

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

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PLAINS GP HOLDINGS, L.P. AND SUBSIDIARIES

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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

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

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

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

With the exception of a deferred tax asset of $1.083 billion and $1.136 billion as of June 30, 2026 and December 31, 2025, respectively, substantially all assets and liabilities presented on PAGP’s Condensed Consolidated Balance Sheets are those of PAA. Only the assets of each respective VIE can be used to settle the obligations of that individual VIE, and the creditors of each/either of those VIEs do not have recourse against the general credit of PAGP. PAGP did not provide any financial support to PAA or AAP during the six months ended June 30, 2026 or the year ended December 31, 2025. See Note 17 to our Consolidated Financial Statements included in Part IV of our 2025 Annual Report on Form 10-K for information regarding the Omnibus Agreement entered into by the Plains Entities on November 15, 2016.

On May 12, 2026, we completed the sale of the Canadian NGL Business (as defined and discussed in further detail in Note 2). The operations of the Canadian NGL Business met the criteria for classification as held for sale and for discontinued operations reporting. Accordingly, the balance sheet, results of operations and cash flows of the Canadian NGL Business have been presented as discontinued operations in our condensed consolidated financial statements. Unless otherwise indicated, the disclosures included within the accompanying notes to the condensed consolidated financial statements relate to our continuing operations and exclude amounts related to discontinued operations. Discontinued operations are not presented separately within our Condensed Consolidated Statements of Comprehensive Income, Condensed Consolidated Statements of Changes in Accumulated Other Comprehensive Income/(Loss) or the Condensed Consolidated Statements of Changes in Partners’ Capital. Through the date of the sale, all significant intercompany balances and transactions between the Canadian NGL Business and our continuing operations have been eliminated.

Subsequent Events

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

Recent Accounting Pronouncements, Disclosure Rules and Other Legislation

Except as discussed in our 2025 Annual Report on Form 10-K, there have been no new accounting pronouncements that have become effective or have been issued during the six months ended June 30, 2026 that are of significance or potential significance to us.

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PLAINS GP HOLDINGS, L.P. AND SUBSIDIARIES

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Note 2—Canadian NGL Business Divestiture and Discontinued Operations

On June 17, 2025, we entered into a definitive Share Purchase Agreement (as amended to date, the “SPA”) with Keyera Corp. (“Keyera”), an Alberta corporation, pursuant to which Keyera agreed to acquire all of the issued and outstanding shares of Plains Midstream Canada ULC (“PMC ULC”), our wholly-owned subsidiary that owned substantially all of our NGL business in Canada (the “Canadian NGL Business”). The transaction closed on May 12, 2026, and, pursuant to the SPA, we received cash consideration of approximately CAD$5.328 billion (approximately $3.883 billion), including estimated working capital and other adjustments, subject to certain post-closing adjustments as defined in the SPA. As part of the sale, we divested the Canadian NGL Business, which included substantially all of our NGL assets; the NGL assets that we retained are located in the United States. The divestiture aligns with management’s strategy to focus on its crude oil operations. Prior to its classification as held for sale and presentation as discontinued operations, the Canadian NGL Business was part of our NGL reportable segment.

In June 2025, we entered into a forward currency instrument to hedge currency exchange risk associated with proceeds from the sale of our Canadian NGL Business. See Note 8 for additional information.

In connection with the closing of the Canadian NGL Business divestiture, we and Keyera entered into certain agreements, including:

•a tax matters agreement that governs our and Keyera’s tax rights and obligations after closing. We have recognized a liability of approximately $62 million related to our obligation to indemnify Keyera against any exposure to certain tax assessments by the Canadian tax authorities against PMC ULC, which is reflected within “Current liabilities of discontinued operations” on our Condensed Consolidated Balance Sheet; and

•an agreement for certain hedging arrangements and payments relating to the differential between the price of natural gas and the extracted NGL commodities (“Frac Spread”) for a twelve-month period commencing the first month after the closing date. As a result of this arrangement, we will guarantee a minimum Frac Spread margin on certain volumes. We have recognized a liability of approximately $15 million for the value of the agreement, based on contracts transferred and market conditions at closing, which is reflected within “Current liabilities of discontinued operations” on our Condensed Consolidated Balance Sheet. This agreement was settled and terminated for $15 million in July 2026.

Additionally, we completed certain planning and restructuring activities within our organizational structure in connection with the Canadian NGL Business divestiture. In the first quarter of 2026, PMC ULC contributed its crude oil assets to a newly formed, wholly-owned subsidiary, PCLP. While this transaction was among entities under common control and recorded at a carry-over basis under GAAP, the applicable Canadian tax law recognizes the transaction at fair value, resulting in a new tax basis to PCLP as of the date of the contribution by PMC ULC. These activities created current tax expense of approximately $311 million as a result of basis recapture and capital gains taxed at the applicable rates and withholding taxes on distributions. This also created a partially offsetting $217 million deferred tax benefit primarily resulting from the new tax basis in the assets received by PCLP for the six months ended June 30, 2026. Since the transaction relates to our crude oil business, the tax impacts are presented in “Current income tax expense from continuing operations” and “Deferred income tax (expense)/benefit from continuing operations,” respectively, on our Condensed Consolidated Statements of Operations. Further, we recorded current income tax expense from discontinued operations of $82 million during the six months ended June 30, 2026. As of June 30, 2026, a related liability of $77 million was included in “Current liabilities of discontinued operations” on our Condensed Consolidated Balance Sheet. Management also determined, based on analysis provided by external tax advisors, that there were no liabilities for uncertain tax positions resulting from the restructuring activities.

We determined that in conjunction with entering into the SPA, the operations of the Canadian NGL Business met the criteria for classification as held for sale and for discontinued operations reporting, as the sale represented a strategic shift that had a major effect on our operations and financial results. Depreciation and amortization on the long-lived assets of the Canadian NGL Business disposal group ceased upon meeting the criteria to be classified as assets held for sale. The Canadian NGL Business disposal group was recorded at its historical carrying value, as the fair value of the disposal group, less estimated costs to sell, was greater than the carrying value of the Canadian NGL Business disposal group. Upon the completion of the divestiture on May 12, 2026, we derecognized all assets and liabilities of the Canadian NGL Business. We recognized a gain on sale of approximately $1.637 billion and $1.605 billion for the three and six months ended June 30, 2026, respectively, which is reflected within income from discontinued operations.

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PLAINS GP HOLDINGS, L.P. AND SUBSIDIARIES

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

The following table summarizes the carrying amounts of major classes of assets and liabilities of discontinued operations (in millions):


	June 30, 2026		December 31, 2025
Assets:
Current assets:

Trade accounts receivable and other receivables, net	$	—	$	285
Inventory	—		176
Other current assets	—		18
Total current assets of discontinued operations	$	—	$	479

Long-term assets:
Property and equipment, net (1)	$	—	$	2,191

Linefill	—		70
Long-term operating lease right-of-use assets, net	—		138
Long-term inventory	—		38
Other long-term assets, net	—		120
Total long-term assets of discontinued operations	$	—	$	2,557

Liabilities:
Current liabilities:
Trade accounts payable	$	—	$	295

Other current liabilities	154		87
Total current liabilities of discontinued operations	$	154	$	382

Long-term liabilities:

Long-term operating lease liabilities	$	—	$	96
Other long-term liabilities and deferred credits	—		510
Total long-term liabilities of discontinued operations	$	—	$	606

(1)Amounts are net of accumulated depreciation of $876 million as of December 31, 2025.

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NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

The following table provides a reconciliation of the line items comprising income from discontinued operations before tax to income from discontinued operations, net of tax (in millions):


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025
Revenues:
Product sales	$	35	$	181	$	292	$	679
Services	19		30		58		66
Total revenues	54		211		350		745
Cost and Expenses:
Purchases and related costs	—		10		205		252
Field operating costs	37		53		108		122
General and administrative expenses	3		12		17		26
Depreciation and amortization	—		27		—		57
(Gains)/losses on asset sales and other, net	(1,637)		13		(1,605)		13
Total costs and expenses	(1,597)		115		(1,275)		470

Income from discontinued operations before tax	1,651		96		1,625		275
Current income tax expense	(71)		(14)		(115)		(54)
Deferred income tax (expense)/benefit	69		(12)		38		(15)
Income from discontinued operations, net of tax	$	1,649	$	70	$	1,548	$	206

Note 3—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.

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 June 30,				Six Months Ended June 30,
	2026		2025		2026		2025
Crude Oil segment revenues from contracts with customers
Sales	$	17,267	$	10,228	$	29,278	$	21,236
Transportation	358		340		696		652
Terminalling, Storage and Other	102		87		197		175
Total Crude Oil segment revenues from contracts with customers	$	17,727	$	10,655	$	30,171	$	22,063


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025
NGL segment revenues from contracts with customers
Sales	$	22	$	24	$	59	$	66

Terminalling, Storage and Other	—		2		2		1
Total NGL segment revenues from contracts with customers	$	22	$	26	$	61	$	67

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NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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

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

Terminalling, Storage and Other Revenues. Revenues in this category include (i) fees that are generated when we receive liquids from one connecting source and deliver the applicable product to another connecting carrier, (ii) fees from storage capacity agreements, (iii) fees from loading and unloading services at our terminals and (iv) fees from natural gas and condensate processing services. We generate revenue through a combination of month-to-month and multi-year agreements and processing arrangements. Storage fees are typically recognized in revenue ratably over the term of the contract regardless of the actual storage capacity utilized as our performance obligation is to make available storage capacity for a period of time. Terminal fees (including throughput and loading/unloading fees) are recognized as the liquids enter or exit the terminal and are received from or delivered to the connecting carrier or third-party terminal, as applicable. We recognize loading and unloading fees when the volumes are delivered or received.

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 (as described above for each segment) to total revenues of reportable segments and total revenues as disclosed in our Condensed Consolidated Statements of Operations (in millions):


Three Months Ended June 30, 2026	Crude Oil		NGL		Total
Revenues from contracts with customers	$	17,727	$	22	$	17,749
Other revenues	33		—		33
Total revenues of reportable segments	$	17,760	$	22	$	17,782
Intersegment revenues elimination					(89)
Total revenues					$	17,693

Three Months Ended June 30, 2025	Crude Oil		NGL		Total
Revenues from contracts with customers	$	10,655	$	26	$	10,681
Other revenues	(33)		—		(33)
Total revenues of reportable segments	$	10,622	$	26	$	10,648
Intersegment revenues elimination					(6)
Total revenues					$	10,642

Six Months Ended June 30, 2026	Crude Oil		NGL		Total
Revenues from contracts with customers	$	30,171	$	61	$	30,232
Other revenues	138		—		138
Total revenues of reportable segments	$	30,309	$	61	$	30,370
Intersegment revenues elimination					(208)
Total revenues					$	30,162

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NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS


Six Months Ended June 30, 2025	Crude Oil		NGL		Total
Revenues from contracts with customers	$	22,063	$	67	$	22,130
Other revenues	(2)		—		(2)
Total revenues of reportable segments	$	22,061	$	67	$	22,128
Intersegment revenues elimination					(9)
Total revenues					$	22,119

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	June 30, 2026		December 31, 2025
Billed and collected	Other current liabilities	$	16	$	47

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


	Contract Liabilities
Balance at December 31, 2025	$	87
Amounts recognized as revenue	(22)

Additions	4
Other (1)	(24)
Balance at June 30, 2026	$	45

(1)Amount represents a contract liability that was originally recognized under ASC 606. The underlying contract was subsequently renegotiated and ceased to meet the criteria in ASC 606 for a contract with a customer.

Remaining Performance Obligations. The information below includes the amount of consideration allocated to partially and wholly unsatisfied remaining performance obligations under contracts that existed 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 contracts 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 June 30, 2026 (in millions):


	Remainder of 2026		2027		2028		2029		2030		2031 and Thereafter
Pipeline revenues supported by minimum volume commitments and capacity agreements (1)	$	208	$	392	$	342	$	237	$	154	$	848
Terminalling, storage and other agreement revenues	124		218		158		113		75		426
Total	$	332	$	610	$	500	$	350	$	229	$	1,274

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

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NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

The presentation above does not include (i) expected revenues from legacy shippers not underpinned by minimum volume commitments, (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 Topic 842, Leases; and

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

Trade Accounts Receivable and Other Receivables, Net

At June 30, 2026 and December 31, 2025, 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):


	June 30, 2026		December 31, 2025
Trade accounts receivable arising from revenues from contracts with customers	$	5,135	$	3,639
Other trade accounts receivable and other receivables (1)	11,077		7,357
Impact due to contractual rights of offset with counterparties	(10,945)		(7,398)
Trade accounts receivable and other receivables, net	$	5,267	$	3,598

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

Note 4—Net Income Per Class A Share

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

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

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NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Exchanges of potentially dilutive AAP units are assumed to have occurred at the beginning of the period and the incremental income attributable to PAGP resulting from the assumed exchanges is representative of the incremental income that would have been attributable to PAGP if the assumed exchanges occurred on that date. See Note 12 to our Consolidated Financial Statements included in Part IV of our 2025 Annual Report on Form 10-K for information regarding exchanges of AAP units. PAGP LTIP awards that are deemed to be dilutive are reduced by a hypothetical share repurchase based on the remaining unamortized fair value, as prescribed by the treasury stock method in guidance issued by the FASB. See Note 18 to our Consolidated Financial Statements included in Part IV of our 2025 Annual Report on Form 10-K for information regarding PAGP LTIP awards.

On a weighted-average basis, the possible exchange of 35 million AAP units did not result in dilution for net income/(loss) per Class A share from continuing operations for all periods presented or from discontinued operations for the three and six months ended June 30, 2026 and for the three months ended June 30, 2025. The possible exchange was dilutive for net income per Class A share from discontinued operations for the six months ended June 30, 2025. Accordingly, the effect of the possible exchange of AAP units was included in the computation of diluted net income per Class A share from discontinued operations for the six months ended June 30, 2025 and excluded from the calculation for all other periods. For the three and six months ended June 30, 2026, our PAGP LTIP awards were dilutive for discontinued operations only. For the three and six months ended June 30, 2025, our PAGP LTIP awards were dilutive for both continuing and discontinued operations. Accordingly, the effect of the LTIP awards were only included in the computation of diluted weighted-average Class A shares outstanding for those periods when the awards were dilutive.

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PLAINS GP HOLDINGS, L.P. AND SUBSIDIARIES

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025
Basic Net Income per Class A Share
Net income/(loss) attributable to PAGP from continuing operations	$	(74)	$	10	$	(26)	$	56

Net income attributable to PAGP from discontinued operations	$	463	$	20	$	434	$	58

Basic weighted average Class A shares outstanding	198		198		198		198

Basic Net Income/(Loss) per Class A Share:
Continuing operations	$	(0.37)	$	0.05	$	(0.13)	$	0.29
Discontinued operations	2.34		0.10		2.19		0.29
Basic net income per Class A share	$	1.97	$	0.15	$	2.06	$	0.58

Diluted Net Income per Class A Share
Net income/(loss) attributable to PAGP from continuing operations	$	(74)	$	10	$	(26)	$	56

Net income attributable to PAGP from discontinued operations	$	463	$	20	$	434	$	58
Incremental net income attributable to PAGP resulting from assumed exchange of AAP Management Units	—		—		—		8
Net income attributable to PAGP from discontinued operations including incremental net income from assumed exchange of AAP Management Units	$	463	$	20	$	434	$	66

Basic weighted average Class A shares outstanding	198		198		198		198
Dilutive shares resulting from assumed exchange of AAP Management Units	—		—		—		35
Diluted weighted average Class A shares outstanding	198		198		198		233

Diluted Net Income/(Loss) per Class A Share:
Continuing operations	$	(0.37)	$	0.05	$	(0.13)	$	0.29
Discontinued operations	2.34		0.10		2.19		0.28
Diluted net income per Class A share	$	1.97	$	0.15	$	2.06	$	0.57

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NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Note 5—Inventory, Linefill and Long-term Inventory

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


	June 30, 2026						December 31, 2025
	Volumes	Unit of Measure	Carrying Value		Price/ Unit (1)		Volumes	Unit of Measure	Carrying Value		Price/ Unit (1)
Inventory
Crude oil	722	barrels	$	52	$	72.02	2,948	barrels	$	166	$	56.31
NGL	333	barrels	17		$	51.05	562	barrels	27		$	48.04

Other	N/A		15		N/A		N/A		18		N/A
Inventory subtotal			84						211

Linefill
Crude oil	14,975	barrels	891		$	59.50	15,112	barrels	898		$	59.42
NGL	32	barrels	1		$	31.25	33	barrels	2		$	60.61

Linefill subtotal			892						900

Long-term inventory
Crude oil	3,647	barrels	255		$	69.92	3,724	barrels	213		$	57.20
NGL	51	barrels	2		$	39.22	26	barrels	1		$	38.46
Long-term inventory subtotal			257						214

Total			$	1,233					$	1,325

(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.

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NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Note 6—Debt

Debt consisted of the following (in millions):


	June 30, 2026		December 31, 2025
SHORT-TERM DEBT
PAA commercial paper notes, bearing a weighted-average interest rate of 3.9% (1)	$	—	$	554


Other	9		9
Total short-term debt	9		563

LONG-TERM DEBT
PAA senior notes, net of unamortized discounts and debt issuance costs of $60 and $65, respectively (2)	8,373		9,118
PAA commercial paper notes, bearing a weighted-average interest rate of 3.9% (3)	—		416
PAA term loan, net of debt issuance costs of $1, and bearing a weighted-average interest rate of 5.0%	—		1,099
Other	59		63
Total long-term debt	8,432		10,696
Total debt (4)	$	8,441	$	11,259

(1)We classified these PAA commercial paper notes as short-term as of December 31, 2025, as these notes were primarily designated as working capital borrowings, were required to be repaid within one year and were primarily for hedged inventory and NYMEX and ICE margin deposits.

(2)As of December 31, 2025, PAA classified its $750 million, 4.50% senior notes due December 2026 as long-term based on its ability and intent to refinance the notes on a long-term basis at that time. PAA redeemed these senior notes on June 25, 2026.

(3)As of December 31, 2025, PAA classified a portion of its commercial paper notes as long-term based on its ability and intent to refinance such amounts on a long-term basis.

(4)PAA’s fixed-rate senior notes had a face value of approximately $8.4 billion and $9.2 billion at June 30, 2026 and December 31, 2025, respectively. We estimated the aggregate fair value of these notes as of June 30, 2026 and December 31, 2025 to be approximately $8.2 billion and $9.0 billion, respectively. PAA’s fixed-rate senior notes are traded among institutions, and these trades are routinely published by a reporting service. Our determination of fair value is based on reported trading activity near the end of the reporting period. We estimate that the carrying value of outstanding borrowings under PAA’s commercial paper program and term loan approximate fair value as interest rates reflect current market rates. The fair value estimates for PAA’s senior notes, commercial paper program and term loan are based upon observable market data and are classified in Level 2 of the fair value hierarchy.

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NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Credit Agreements

In June 2026, PAA entered into a new credit agreement that provides for a senior unsecured revolving credit facility with a committed borrowing capacity of $2.7 billion, of which $800 million is available for the issuance of letters of credit and $225 million is available for the swing line loans. The new credit agreement replaced PAA’s previous credit agreements that provided for a $1.35 billion senior secured hedged inventory facility and a $1.35 billion senior unsecured revolving credit facility, which were scheduled to mature in August 2027 and August 2029, respectively. Subject to obtaining additional or increased lender commitments and other terms and conditions, the committed capacity may be increased to $4.0 billion. Borrowings accrue interest based, at our selection, on certain floating rate indices, in each case, plus an applicable margin. The new credit agreement has an initial maturity date of June 2031 and provides for one or more one-year extensions, subject to applicable approval and other terms and conditions. The covenants and events of default under this new credit agreement remain substantially unchanged from the previous agreements.

In conjunction with the closing of the new credit agreement in June 2026, we repaid in full and terminated all outstanding obligations under the $1.35 billion senior secured hedged inventory facility and $1.35 billion senior unsecured revolving credit facility. See Note 11 to our Consolidated Financial Statements included in Part IV of our 2025 Annual Report on Form 10-K for additional information regarding these agreements.

Term Loan Agreement

On November 26, 2025, PAA entered into a term loan agreement that provided for a $1.1 billion senior unsecured term loan. The closing of the Canadian NGL Business divestiture triggered mandatory prepayment of all amounts outstanding under the term loan agreement. See Note 2 for additional information about the Canadian NGL Business divestiture. Effective May 14, 2026, PAA terminated the term loan agreement and repaid all amounts outstanding thereunder.

Senior Notes

On June 25, 2026, PAA redeemed its $750 million, 4.50% senior notes that were due December 2026. PAA repaid these senior notes with proceeds from the sale of the Canadian NGL Business.

Borrowings and Repayments

Total borrowings under the PAA credit facilities and commercial paper program for the six months ended June 30, 2026 and 2025 were approximately $37.1 billion and $27.6 billion, respectively. Total repayments under the PAA credit facilities and the PAA commercial paper program were approximately $38.1 billion and $27.5 billion for the six months ended June 30, 2026 and 2025, respectively. The variance in total gross borrowings and repayments is impacted by various business and financial factors including, but not limited to, the timing, average term and method of general partnership borrowing activities.

Letters of Credit

In connection with our merchant activities, we provide certain suppliers with irrevocable standby letters of credit to secure our obligation for the purchase and transportation of crude oil. Additionally, we issue letters of credit to support insurance programs, derivative transactions, including hedging-related margin obligations, and construction activities. At June 30, 2026 and December 31, 2025, we had outstanding letters of credit of $63 million and $95 million, respectively.

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NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Note 7—Partners’ Capital and Distributions

Shares Outstanding

The following tables present the activity for our Class A, Class B and Class C shares:


	Class A Shares	Class B Shares	Class C Shares
Outstanding at December 31, 2025	197,904,124	35,096,306	530,932,175


Other	—	—	10,986
Outstanding at March 31, 2026	197,904,124	35,096,306	530,943,161

Other	—	—	34,777
Outstanding at June 30, 2026	197,904,124	35,096,306	530,977,938


	Class A Shares	Class B Shares	Class C Shares
Outstanding at December 31, 2024	197,465,699	35,390,231	542,004,838
Exchange Right exercises (1)	277,925	(277,925)	—
Repurchase of Series A preferred units by a subsidiary			(12,678,560)
Other	—	—	5,650
Outstanding at March 31, 2025	197,743,624	35,112,306	529,331,928
Repurchase and cancellation of common units by a subsidiary under the Common Equity Repurchase Program			(476,695)
Other	—	—	5,197
Outstanding at June 30, 2025	197,743,624	35,112,306	528,860,430

(1)See Note 12 to our Consolidated Financial Statements included in Part IV of our 2025 Annual Report on Form 10-K for information regarding conversions of AAP Management Units, Exchange Rights and Redemption Rights.

Distributions to Our Shareholders

The following table details distributions to our Class A shareholders paid during or pertaining to the first six months of 2026 (in millions, except per share data):


			Class A Shareholders
Distribution Payment Date	Record Date (1)	Distribution Period	Cash Distribution		Distribution per Unit

August 14, 2026	July 31, 2026	April 1, 2026 through June 30, 2026	$	83	$	0.4175
May 15, 2026	May 1, 2026	January 1, 2026 through March 31, 2026	$	83	$	0.4175
February 13, 2026	January 30, 2026	October 1, 2025 through December 31, 2025	$	83	$	0.4175

(1)Payable to shareholders of record at the close of business on the applicable Record Date.

Consolidated Subsidiaries

Noncontrolling Interests in Subsidiaries

As of June 30, 2026, noncontrolling interests in our subsidiaries consisted of (i) limited partner interests in PAA including a 69% interest PAA’s common units and PAA’s Series A preferred units combined and 100% of PAA’s Series B preferred units, (ii) an approximate 15% limited partner interest in AAP, (iii) a 35% interest in Plains Oryx Permian Basin LLC (the “Permian JV”), (iv) a 30% interest in Cactus II Pipeline LLC (“Cactus II”) and (v) a 33% interest in Red River Pipeline Company LLC (“Red River”).

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NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Subsidiary Distributions

PAA Series A Preferred Unit Distributions. Distributions on PAA’s Series A preferred units accumulate and are payable quarterly within 45 days following the end of each quarter. See Note 12 to our Consolidated Financial Statements included in Part IV of our 2025 Annual Report on Form 10-K for additional information regarding the PAA Series A preferred unit distributions. The following table details distributions to PAA’s Series A preferred unitholders paid during or pertaining to the first six months of 2026 (in millions, except per unit data):


			PAA Series A Preferred Unitholders
Distribution Payment Date	Record Date (1)	Distribution Period	Cash Distribution		Distribution per Unit

August 14, 2026 (2)	July 31, 2026	April 1, 2026 through June 30, 2026	$	36	$	0.615
May 15, 2026	May 1, 2026	January 1, 2026 through March 31, 2026	$	36	$	0.615
February 13, 2026	January 30, 2026	October 1, 2025 through December 31, 2025	$	36	$	0.615

(1)Payable to unitholders of record at the close of business on the applicable Record Date.

(2)At June 30, 2026, such amount was accrued as distributions payable in “Other current liabilities” on our Condensed Consolidated Balance Sheet.

PAA Series B Preferred Unit Distributions. Distributions on PAA’s Series B preferred units accumulate and are payable quarterly in arrears on the 15th day of February, May, August and November (or the immediately succeeding Business Day). See Note 12 to our Consolidated Financial Statements included in Part IV of our 2025 Annual Report on Form 10-K for additional information regarding the PAA Series B preferred unit distributions. The following table details distributions paid or to be paid to PAA’s Series B preferred unitholders (in millions, except per unit data):


			PAA Series B Preferred Unitholders
Distribution Payment Date	Record Date (1)	Distribution Period	Cash Distribution		Distribution per Unit

August 17, 2026 (2)	August 3, 2026	May 15, 2026 through August 14, 2026	$	16	$	20.50
May 15, 2026	May 1, 2026	February 15, 2026 through May 14, 2026	$	16	$	19.84
February 17, 2026	February 2, 2026	November 15, 2025 through February 14, 2026	$	17	$	21.02

(1)Payable to unitholders of record at the close of business on the applicable Record Date.

(2)At June 30, 2026, approximately $8 million of accrued distributions payable to PAA’s Series B preferred unitholders was included in “Other current liabilities” on our Condensed Consolidated Balance Sheet.

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PAA Common Unit Distributions. The following table details distributions to PAA’s common unitholders paid during or pertaining to the first six months of 2026 (in millions, except per unit data):


			Distributions						Distribution per Common Unit
Distribution Payment Date	Record Date (1)	Distribution Period	PAA Common Unitholders				Total Cash Distribution
			Public		AAP

August 14, 2026	July 31, 2026	April 1, 2026 through June 30, 2026	$	198	$	97	$	295	$	0.4175
May 15, 2026	May 1, 2026	January 1, 2026 through March 31, 2026	$	198	$	97	$	295	$	0.4175
February 13, 2026	January 30, 2026	October 1, 2025 through December 31, 2025	$	198	$	97	$	295	$	0.4175

(1)Payable to unitholders of record at the close of business on the applicable Record Date.

AAP Distributions. The following table details the distributions to AAP’s partners paid during or pertaining to the first six months of 2026 from distributions received from PAA (in millions):


			Distributions to AAP’s Partners
Distribution Payment Date	Record Date (1)	Distribution Period	Noncontrolling Interests		PAGP		Total Cash Distribution

August 14, 2026	July 31, 2026	April 1, 2026 through June 30, 2026	$	14	$	83	$	97
May 15, 2026	May 1, 2026	January 1, 2026 through March 31, 2026	$	14	$	83	$	97
February 13, 2026	January 30, 2026	October 1, 2025 through December 31, 2025	$	14	$	83	$	97

Consolidated Joint Venture Distributions. The following table details distributions paid to noncontrolling interests in consolidated joint ventures during the periods presented (in millions):


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025
Permian JV	$	81	$	78	$	165	$	183
Cactus II	17		16		32		38
Red River	4		3		8		8
	$	102	$	97	$	205	$	229

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Note 8—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 manage our exposure to commodity price risk, interest rate risk and currency exchange rate risk. Our commodity price risk management policies and procedures are designed to help ensure that our hedging activities address our risks by monitoring our derivative positions, as well as physical volumes, grades, locations, delivery schedules and storage capacity. Our interest rate risk 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 June 30, 2026 and December 31, 2025, 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, in certain circumstances, to optimize profits. As of June 30, 2026, net derivative positions related to these activities included:

•A net long position of 8.1 million barrels associated with our crude oil purchases, which will be unwound ratably through September 2026 to match monthly average pricing.

•A net short time spread position of 2.1 million barrels, which hedges a portion of our anticipated crude oil lease gathering purchases through October 2026.

•A net crude oil basis spread position of 2.6 million barrels at multiple locations through March 2027. These derivatives allow us to lock in grade and location basis differentials.

•A net short position of 7.8 million barrels through December 2027 related to anticipated net sales of crude oil inventory.

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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 June 30,				Six Months Ended June 30,
	2026		2025		2026		2025
Product sales revenues	$	17	$	(40)	$	105	$	(41)
Field operating costs	—		5		2		3

Net income/(loss) from commodity derivative activity	$	17	$	(35)	$	107	$	(38)

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 (in millions):


	June 30, 2026		December 31, 2025
Initial margin	$	31	$	16
Variation margin posted	31		4
Letters of credit	(29)		(1)
Net broker receivable	$	33	$	19

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.


	June 30, 2026								December 31, 2025
					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	$	20	$	(12)	$	(7)	$	1	$	18	$	(24)	$	19	$	13
Other long-term assets, net	11		(3)		—		8		1		—		—		1
Derivative Liabilities
Other current liabilities	28		(87)		40		(19)		(1)		—		—		(1)
Other long-term liabilities and deferred credits	—		—		—		—		10		(8)		—		2
Total	$	59	$	(102)	$	33	$	(10)	$	28	$	(32)	$	19	$	15

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NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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.

As of June 30, 2026, there was a net loss of $27 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. We estimate that substantially all of the remaining deferred loss will be reclassified to earnings through 2056 as the underlying hedged transactions impact earnings.

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


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025
Interest rate derivatives, net	$	—	$	7	$	—	$	6

At June 30, 2026 and December 31, 2025, we did not have any interest rate hedges recorded on our Condensed Consolidated Balance Sheets.

Currency Exchange Rate Risk Hedging

In connection with the Canadian NGL Business divestiture, we entered into a forward currency instrument (CAD$4.5 billion notional amount) to hedge currency exchange risk. The instrument was contingent upon the sale of the Canadian NGL Business occurring and settled at closing. The cost of the deal-contingent structure was embedded in the hedge rate. We settled this instrument and received net cash proceeds of $20 million at the closing of the Canadian NGL Business divestiture. As of December 31, 2025, the fair value of the instrument was an asset of $8 million, presented in “Other current assets” on our Condensed Consolidated Balance Sheet. For the three and six months ended June 30, 2026, we recognized a loss of $41 million and a gain of $12 million, respectively, which were included in “Losses on asset sales, asset impairments and other, net” on our Condensed Consolidated Statements of Operations. For each of the three and six months ended June 30, 2025, we recognized a loss of $49 million. See Note 2 for additional information regarding the Canadian NGL Business divestiture.

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 June 30, 2026						Fair Value as of December 31, 2025
Recurring Fair Value Measures (1)	Level 1		Level 2		Total			Level 1		Level 2		Total
Commodity derivatives	$	(50)	$	7	$	(43)		$	(2)	$	(2)	$	(4)

Foreign currency derivatives	—		—		—			—		8		8

Total net derivative asset/(liability)	$	(50)	$	7	$	(43)		$	(2)	$	6	$	4

(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.

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Level 2

Level 2 of the fair value hierarchy includes exchange-cleared commodity derivatives, over-the-counter commodity, foreign exchange and interest rate 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.

Note 9—Related Party Transactions

See Note 17 to our Consolidated Financial Statements included in Part IV of our 2025 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 six months ended June 30, 2026 and 2025, we recognized sales and transportation revenues, purchased petroleum products and utilized transportation and storage services from 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 June 30,				Six Months Ended June 30,
	2026		2025		2026		2025
Revenues from related parties	$	13	$	12	$	26	$	23

Purchases and related costs from related parties	$	80	$	98	$	154	$	196

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


	June 30, 2026		December 31, 2025
Trade accounts receivable and other receivables, net from related parties (1)	$	33	$	49

Trade accounts payable to related parties (1) (2)	$	50	$	64

(1)Primarily includes amounts related to transportation and storage services.

(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.

Note 10—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.

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NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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 liabilities 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.

Our estimated undiscounted reserves for environmental liabilities (excluding liabilities related to the Line 901 incident, as discussed further below) were reflected on our Condensed Consolidated Balance Sheets as follows (in millions):


	June 30, 2026		December 31, 2025
Other current liabilities	$	40	$	13
Other long-term liabilities and deferred credits	70		70
Total	$	110	$	83

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In some cases, the actual cash expenditures associated with these liabilities may not occur for several years. 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 our reserves are 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 such reserves 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 release of crude oil from our Las Flores to Gaviota Pipeline (Line 901) in Santa Barbara County, California. Effective as of June 30, 2026, we estimate that the aggregate total costs we have incurred or will incur with respect to the Line 901 incident will be approximately $870 million, which includes actual emergency response and clean-up costs, natural resource damage assessments, fines and penalties incurred, certain third-party claims settlements, and estimated costs associated with our remaining Line 901 lawsuits and claims as described below, 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 (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.

During the six months ended June 30, 2026 and 2025, we did not recognize any costs related to the Line 901 incident. As of June 30, 2026 and December 31, 2025, we had a remaining undiscounted gross liability of approximately $23 million and $22 million, respectively, related to the Line 901 incident, which aggregate amounts are reflected in “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 liabilities. To date, we have collected approximately $295 million of the $500 million available under our 2015 insurance program. With respect to the Line 901 incident, we do not have any amounts recorded as receivables that are recognized on our Condensed Consolidated Balance Sheets as of June 30, 2026 and December 31, 2025.

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We have completed the required clean-up and remediation work with respect to the Line 901 incident; however, we expect to make payments for additional legal and professional costs during future periods. The only remaining Line 901 lawsuit is pending in California Superior Court in Santa Barbara County, in which a landowner on an adjacent pipeline is alleging property damage from the “stigma” of the Line 901 incident. We are vigorously defending this lawsuit, which has not yet been set for trial, and believe we have strong defenses. 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 lawsuit will have a material adverse effect on our consolidated financial condition, results of operations or cash flows.

L48 Pipeline Release. In March 2025, our subsidiary, Pacific Pipeline System LLC, experienced a crude oil release of approximately 125 barrels on a segment of the Line 48 pipeline in Carson, California. Clean-up and remediation activities were conducted in cooperation with applicable state and federal regulatory agencies. An investigation by the California Office of the State Fire Marshall was initiated. To date no charges, fines or penalties have been assessed against us with respect to this release; however, it is possible that charges, fines or penalties may be assessed against us in the future. We provided notification to our applicable insurance carriers and are subject to a $10 million self-insured retention. Through June 30, 2026, we incurred $13 million in connection with clean-up and remediation activities. We do not currently anticipate any additional costs associated with the site.

Line 63 Pipeline Strike. In May 2026, our subsidiary, Pacific Pipeline System LLC, experienced a crude oil release of approximately 585 barrels on a segment of the Line 63 pipeline in Los Angeles, California, resulting from a strike by a construction crew drilling for a fiber-optic line. Clean-up and remediation activities were conducted in cooperation with applicable state and federal regulatory agencies. Investigations were initiated by the California Office of the State Fire Marshall and the California Underground Safety Board. To date no charges, fines or penalties have been assessed against us with respect to this release; however, it is possible that charges, fines or penalties may be assessed against us in the future. We provided notification to our applicable insurance carriers and are subject to a $10 million self-insured retention. We estimate that the aggregate cost to clean-up and remediate the site will be approximately $40 million.

Canadian Competition Bureau Lawsuit. In connection with the closing of the sale of our Canadian NGL Business to Keyera, on May 5, 2026, the Canadian Commissioner of Competition (“Commissioner”) filed a lawsuit against Keyera, PMC ULC and Plains challenging the transaction on the basis that it allegedly harms competition in the NGL fractionation and storage market at Fort Saskatchewan. Because the lawsuit did not prevent the parties from closing, Keyera and Plains closed the transaction on May 12, 2026. In its lawsuit, the Commissioner seeks remedies that it believes would restore competition at Fort Saskatchewan to pre-transaction levels. As the owner of PMC ULC and the Canadian NGL Business, Keyera is primarily responsible for the lawsuit and we do not believe the ultimate resolution of the lawsuit will have a material adverse effect on our consolidated financial condition, results of operations or cash flows.

Note 11—Segment Information

Our operating segments, Crude Oil and NGL, which are also our reportable segments, are organized by product as our Crude Oil and NGL businesses are generally impacted by different market fundamentals and require the use of different assets and business strategies. The Crude Oil segment includes our crude oil pipelines, crude oil storage and marine terminals and related crude oil marketing activities. Our crude oil marketing activities are included in our Crude Oil reporting segment as its primary purpose is to support the utilization of our assets by entering into transactions that facilitate increased volumes handled by our assets, resulting in additional earnings for the segment. The NGL segment includes our NGL assets located in the United States.

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Our CODM (our Chief Executive Officer) evaluates segment performance based on measures including Segment Adjusted EBITDA (as defined below). The measure of Segment Adjusted EBITDA forms the basis of our internal financial reporting and is the primary performance measure of segment profit/(loss) used by our CODM in assessing performance and allocating resources among our operating segments. We define Segment Adjusted EBITDA as revenues and equity earnings in unconsolidated entities less (a) significant segment expenses including: (i) purchases and related costs, (ii) field operating costs and (iii) segment general and administrative expenses, plus (b) our proportionate share of the depreciation and amortization expense (including write-downs related to cancelled projects and impairments) of unconsolidated entities, further adjusted (c) 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 (d) to exclude the portion of all preceding items that is attributable to noncontrolling interests in consolidated joint venture entities (“Segment amounts attributable to noncontrolling interests in consolidated joint ventures”).

Our CODM uses Segment Adjusted EBITDA to evaluate the performance of each segment, including analyzing actual results compared to budget and guidance, to assess investment opportunities and to optimize and align assets to maximize returns to stakeholders.

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

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PLAINS GP HOLDINGS, L.P. AND SUBSIDIARIES

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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


	Crude Oil		NGL		Intersegment Elimination		Total
Three Months Ended June 30, 2026
Revenues (1):
Product sales	$	17,290	$	20	$	(89)	$	17,221
Services	470		2		—		472
Total revenues	17,760		22		(89)		17,693

Significant segment expenses:
Purchases and related costs (1)	(16,632)		(13)		89		(16,556)
Field operating costs	(325)		(3)		—		(328)
Segment general and administrative expenses	(108)		(2)		—		(110)
Total significant segment expenses	(17,065)		(18)		89		(16,994)

Equity earnings in unconsolidated entities	89		—

Other segment items (2):
Depreciation and amortization of unconsolidated entities (3)	21		—
Derivative activities and inventory valuation adjustments (4)	(74)		—
Long-term inventory costing adjustments (5)	67		—
Deficiencies under minimum volume commitments, net (6)	(4)		—
Equity-indexed compensation expense (7)	10		—
Foreign currency revaluation (8)	(8)		—


Impact from exit of Canadian NGL Business (9)	34		—
Segment amounts attributable to noncontrolling interests in consolidated joint ventures (10)	(140)		—
Total other segment items	(94)		—

Segment Adjusted EBITDA	$	690	$	4

Investment and acquisition capital expenditures (11) (12)	$	155	$	—			$	155
Maintenance capital expenditures (12)	$	38	$	—			$	38

As of June 30, 2026
Investments in unconsolidated entities	$	2,817	$	—			$	2,817

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PLAINS GP HOLDINGS, L.P. AND SUBSIDIARIES

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS


	Crude Oil		NGL		Intersegment Elimination		Total
Six Months Ended June 30, 2026
Revenues (1):
Product sales	$	29,396	$	58	$	(208)	$	29,246
Services	913		3		—		916
Total revenues	30,309		61		(208)		30,162

Significant segment expenses:
Purchases and related costs (1)	(28,211)		(46)		208		(28,049)
Field operating costs	(616)		(12)		—		(628)
Segment general and administrative expenses	(184)		(8)		—		(192)
Total significant segment expenses	(29,011)		(66)		208		(28,869)

Equity earnings in unconsolidated entities	178		—

Other segment items (2):
Depreciation and amortization of unconsolidated entities (3)	42		—
Derivative activities and inventory valuation adjustments (4)	56		—
Long-term inventory costing adjustments (5)	(45)		—
Deficiencies under minimum volume commitments, net (6)	(36)		—
Equity-indexed compensation expense (7)	20		—
Foreign currency revaluation (8)	(13)		—


Impact from exit of Canadian NGL Business (9)	34		—
Segment amounts attributable to noncontrolling interests in consolidated joint ventures (10)	(262)		—
Total other segment items	(204)		—

Segment Adjusted EBITDA	$	1,272	$	(5)

Investment and acquisition capital expenditures (11) (12)	$	326	$	—			$	326
Maintenance capital expenditures (12)	$	72	$	1			$	73

As of June 30, 2026
Investments in unconsolidated entities	$	2,817	$	—			$	2,817

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PLAINS GP HOLDINGS, L.P. AND SUBSIDIARIES

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS


	Crude Oil		NGL		Intersegment Elimination		Total
Three Months Ended June 30, 2025
Revenues (1):
Product sales	$	10,178	$	24	$	(5)	$	10,197
Services	444		2		(1)		445
Total revenues	10,622		26		(6)		10,642

Significant segment expenses:
Purchases and related costs (1)	(9,742)		(22)		6		(9,758)
Field operating costs	(279)		(7)		—		(286)
Segment general and administrative expenses	(75)		(7)		—		(82)
Total significant segment expenses	(10,096)		(36)		6		(10,126)

Equity earnings in unconsolidated entities	94		—

Other segment items (2):
Depreciation and amortization of unconsolidated entities (3)	20		—
Derivative activities and inventory valuation adjustments (4)	52		—
Long-term inventory costing adjustments (5)	17		—
Deficiencies under minimum volume commitments, net (6)	(9)		—
Equity-indexed compensation expense (7)	8		—
Foreign currency revaluation (8)	9		—

Transaction-related expenses (13)	3		—
Segment amounts attributable to noncontrolling interests in consolidated joint ventures (10)	(140)		—
Total other segment items	(40)		—

Segment Adjusted EBITDA	$	580	$	(10)

Investment and acquisition capital expenditures (11) (12)	$	218	$	—			$	218
Maintenance capital expenditures (12)	$	43	$	1			$	44

As of December 31, 2025
Investments in unconsolidated entities	$	2,846	$	—			$	2,846

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PLAINS GP HOLDINGS, L.P. AND SUBSIDIARIES

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS


	Crude Oil		NGL		Intersegment Elimination		Total
Six Months Ended June 30, 2025
Revenues (1):
Product sales	$	21,185	$	66	$	(8)	$	21,243
Services	876		1		(1)		876
Total revenues	22,061		67		(9)		22,119

Significant segment expenses:
Purchases and related costs (1)	(20,231)		(55)		9		(20,277)
Field operating costs	(571)		(14)		—		(585)
Segment general and administrative expenses	(155)		(13)		—		(168)
Total significant segment expenses	(20,957)		(82)		9		(21,030)

Equity earnings in unconsolidated entities	196		—

Other segment items (2):
Depreciation and amortization of unconsolidated entities (3)	40		—
Derivative activities and inventory valuation adjustments (4)	28		—
Long-term inventory costing adjustments (5)	18		—
Deficiencies under minimum volume commitments, net (6)	(16)		—
Equity-indexed compensation expense (7)	18		—
Foreign currency revaluation (8)	9		—

Transaction-related expenses (13)	8		—
Segment amounts attributable to noncontrolling interests in consolidated joint ventures (10)	(265)		—
Total other segment items	(160)		—

Segment Adjusted EBITDA	$	1,140	$	(15)

Investment and acquisition capital expenditures (11) (12)	$	1,002	$	—			$	1,002
Maintenance capital expenditures (12)	$	74	$	3			$	77

As of December 31, 2025
Investments in unconsolidated entities	$	2,846	$	—			$	2,846

(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.

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

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

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PLAINS GP HOLDINGS, L.P. AND SUBSIDIARIES

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(4)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.

(5)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.

(6)We, and certain of our equity method investees, 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 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 or equity earnings, 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.

(7)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 be settled in cash is not excluded in determining Segment Adjusted EBITDA. See Note 18 to our Consolidated Financial Statements included in Part IV of our 2025 Annual Report on Form 10-K for a discussion regarding our equity-indexed compensation plans.

(8)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.

(9)Represents the acceleration of certain general and administrative expenses associated with exit activities related to the Canadian NGL Business divestiture in May 2026. Such costs are not integral to our core operating performance and were therefore excluded in determining Segment Adjusted EBITDA. See Note 2 for additional information regarding the Canadian NGL Business divestiture.

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

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

(12)These amounts combined represent total capital expenditures.

(13)Primarily related to deal-specific costs incurred during the periods presented.

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PLAINS GP HOLDINGS, L.P. AND SUBSIDIARIES

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Segment Adjusted EBITDA Reconciliation

The following table reconciles Segment Adjusted EBITDA to Income from continuing operations, net of tax (in millions):


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025
Segment Adjusted EBITDA	$	694	$	570	$	1,267	$	1,125
Total other segment items (1)	94		40		204		160
Unallocated general and administrative expenses (2)	(1)		(2)		(3)		(3)
Depreciation and amortization	(242)		(235)		(486)		(466)
Losses on asset sales, asset impairments and other, net	(59)		(42)		(6)		(29)
Gain on investments in unconsolidated entities, net	—		—		—		31
Interest expense, net	(135)		(110)		(279)		(217)
Other income, net	24		8		8		14
Income from continuing operations before tax	375		229		705		615
Income tax expense from continuing operations	(209)		(16)		(216)		(46)
Income from continuing operations, net of tax	$	166	$	213	$	489	$	569

(1)See footnotes to the segment financial data tables above for a more detailed discussion of Other segment items.

(2)Represents general and administrative expenses incremental to those of PAA, which are not allocated to our reporting segments in determining Segment Adjusted EBITDA.

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Item 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Introduction

The following discussion is intended to provide investors with an understanding of our financial condition and results of our operations and should be read in conjunction with our historical Consolidated Financial Statements and accompanying notes and Management’s Discussion and Analysis of Financial Condition and Results of Operations as presented in our 2025 Annual Report on Form 10-K. For more detailed information regarding the basis of presentation for the following financial information, see the Condensed Consolidated Financial Statements and related notes that are contained in Part I, Item 1 of this Quarterly Report on Form 10-Q.

Our discussion and analysis includes the following:

•Executive Summary

•Results of Operations

•Liquidity and Capital Resources

•Recent Accounting Pronouncements

•Forward-Looking Statements

Executive Summary

Company Overview

We are a publicly-traded Delaware limited partnership that has elected to be taxed as a corporation for United States federal income tax purposes. As of June 30, 2026, our sole cash-generating assets consisted of an approximate 85% limited partner interest in AAP. We also own a 100% managing member interest in GP LLC, which holds the non-economic general partner interest in AAP. As of June 30, 2026, AAP directly owned a limited partner interest in PAA through its ownership of approximately 233.0 million PAA common units (approximately 31% of PAA’s total outstanding common units and Series A preferred units combined). AAP is the sole member of PAA GP, which holds the non-economic general partner interest in PAA.

Sale of Canadian NGL Business

On May 12, 2026, we completed the sale of our Canadian NGL Business, pursuant to a definitive SPA with Keyera entered into on June 17, 2025. We determined that in conjunction with entering into the SPA, the operations of the Canadian NGL Business met the criteria for classification as held for sale and for discontinued operations reporting, as the sale represented a strategic shift that had a major effect on our operations and financial results. See Note 1 and Note 2 to our Condensed Consolidated Financial Statements for additional information.

Unless otherwise indicated, the discussion below relates to our continuing operations and excludes amounts related to discontinued operations.

Overview of Operating Results

We recognized net income of $2.037 billion for the six months ended June 30, 2026 compared to net income of $775 million for the first six months of 2025. See the “—Results of Operations” section below for discussion of significant drivers of our results from continuing operations.

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Results of Operations

Consolidated Results

The following table sets forth an overview of our consolidated financial results calculated in accordance with GAAP (in millions, except per share data):


	Three Months Ended June 30,				Variance				Six Months Ended June 30,				Variance
	2026		2025		$		%		2026		2025		$		%
Product sales revenues	$	17,221	$	10,197	$	7,024	69	%	$	29,246	$	21,243	$	8,003	38	%
Services revenues	472		445		27		6	%	916		876		40		5	%
Purchases and related costs	(16,556)		(9,758)		(6,798)		(70)	%	(28,049)		(20,277)		(7,772)		(38)	%
Field operating costs	(328)		(286)		(42)		(15)	%	(628)		(585)		(43)		(7)	%
General and administrative expenses	(111)		(84)		(27)		(32)	%	(195)		(171)		(24)		(14)	%
Depreciation and amortization	(242)		(235)		(7)		(3)	%	(486)		(466)		(20)		(4)	%
Losses on asset sales, asset impairments and other, net	(59)		(42)		(17)		(40)	%	(6)		(29)		23		79	%
Equity earnings in unconsolidated entities	89		94		(5)		(5)	%	178		196		(18)		(9)	%
Gain on investments in unconsolidated entities, net	—		—		—		N/A		—		31		(31)		(100)	%
Interest expense, net	(135)		(110)		(25)		(23)	%	(279)		(217)		(62)		(29)	%
Other income, net	24		8		16		200	%	8		14		(6)		(43)	%
Income tax expense from continuing operations	(209)		(16)		(193)		**		(216)		(46)		(170)		(370)	%
Income from continuing operations, net of tax	166		213		(47)		(22)	%	489		569		(80)		(14)	%
Income from discontinued operations, net of tax (1)	1,649		70		1,579		**		1,548		206		1,342		**
Net income	1,815		283		1,532		**		2,037		775		1,262		163	%
Net income attributable to noncontrolling interests	(1,426)		(253)		(1,173)		(464)	%	(1,629)		(661)		(968)		(146)	%
Net income attributable to PAGP	$	389	$	30	$	359	**		$	408	$	114	$	294	258	%

Basic net income/(loss) per Class A share:
Continuing operations	$	(0.37)	$	0.05	$	(0.42)	**		$	(0.13)	$	0.29	$	(0.42)	(145)	%
Discontinued operations	2.34		0.10		2.24		**		2.19		0.29		1.90		**
Basic net income per Class A share	$	1.97	$	0.15	$	1.82	**		$	2.06	$	0.58	$	1.48	255	%
Basic weighted average Class A shares outstanding	198		198		—		—	%	198		198		—		—	%

Diluted net income/(loss) per Class A share:
Continuing operations	$	(0.37)	$	0.05	$	(0.42)	**		$	(0.13)	$	0.29	$	(0.42)	(145)	%
Discontinued operations	2.34		0.10		2.24		**		2.19		0.28		1.91		**
Diluted net income per Class A share	$	1.97	$	0.15	$	1.82	**		$	2.06	$	0.57	$	1.49	261	%
Diluted weighted average Class A shares outstanding	198		198		—		—	%	198		233		(35)		(15)	%

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

(1)See Note 2 to our Condensed Consolidated Financial Statements for a reconciliation of the line items comprising income from discontinued operations, net of tax.

Continuing Operations

The following discussion of our results of operations focuses on PAA’s continuing operations.

Revenues and Purchases

Fluctuations in our revenues and purchases and related costs are primarily associated with our merchant activities and are generally explained by changes in commodity prices and the impact of gains and losses related to derivative instruments used to manage our commodity price exposure. Because both product sales revenues and purchases and related costs are generally based off of the same pricing indices, the market price of the commodities will not necessarily have an impact on the absolute margins related to those sales and purchases.

A majority of our crude oil sales and purchases are indexed to the prompt month price of the NYMEX Light, Sweet crude oil futures contract (“NYMEX Price”). The following table presents the range of the NYMEX Price over the last two years (in dollars per barrel):


	NYMEX Price
	Low		High		Average
Three Months Ended June 30, 2026	$	69	$	113	$	93
Three Months Ended June 30, 2025	$	57	$	75	$	64

Six Months Ended June 30, 2026	$	56	$	113	$	83
Six Months Ended June 30, 2025	$	57	$	80	$	68

Product sales revenues (including the impact of derivative mark-to-market valuations) and purchases increased for the three and six months ended June 30, 2026 compared to the same periods in 2025 primarily due to higher crude oil sales volumes and commodity prices in the 2026 period.

Services revenues for the three and six months ended June 30, 2026 increased compared to the same periods in 2025 primarily due to the impact of our acquisition of the Cactus III pipeline in the fourth quarter of 2025, partially offset by the impact from certain Permian long-haul pipeline contract rates resetting to market during 2025.

See further discussion of net revenues (defined as revenues less purchases and related costs) in the “—Analysis of Operating Segments” section below.

Field Operating Costs

See discussion of field operating costs in the “—Analysis of Operating Segments” section below.

General and Administrative Expenses

The increase in general and administrative expenses for the three and six months ended June 30, 2026 compared to the same periods in 2025 was primarily due to the acceleration of certain expenses during the second quarter of 2026 resulting from exit costs associated with the Canadian NGL Business. This increase was partially offset by the impact of (i) the recognition in the 2025 period of acquisition-related transaction costs and (ii) lower information systems costs in the 2026 periods primarily due to the completion of certain systems conversion and integration work in the second quarter of 2025. The exit costs associated with the Canadian NGL Business are excluded from our Non-GAAP, adjusted results. See “Non-GAAP Financial Measures” below for additional information.

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Depreciation and Amortization

The increase in depreciation and amortization for the three and six months ended June 30, 2026 compared to the same periods in 2025 was largely driven by recently completed acquisitions.

Losses on Asset Sales, Asset Impairments and Other, Net

In anticipation of the closing of the sale of the Canadian NGL Business, which was completed on May 12, 2026, we entered into a deal-contingent forward currency instrument to hedge the currency exchange risk associated with the sale in CAD. The periods presented were impacted by the mark-to-market of this instrument. See Note 8 to our Condensed Consolidated Financial Statements for additional information regarding this instrument and our derivatives and hedging activities. See Note 2 to our Condensed Consolidated Financial Statements for additional information regarding the sale of the Canadian NGL Business.

Equity Earnings

See discussion of Equity earnings in unconsolidated entities in the “—Analysis of Operating Segments” section below.

Gain on Investments in Unconsolidated Entities, Net

In the first quarter of 2025, we recognized a gain of $31 million related to our acquisition of the remaining 50% interest in Cheyenne Pipeline LLC through a non-monetary transaction.

Interest Expense, Net

The following table summarizes the components impacting Interest expense, net (in millions):


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025
Interest expense on borrowings (1)	$	137	$	113	$	282	$	222
Capitalized interest	(2)		(3)		(3)		(5)
	$	135	$	110	$	279	$	217

(1)The increase in interest expense for the three and six-month 2026 periods compared to the same periods in 2025 was primarily driven by higher weighted-average debt outstanding in the 2026 periods. See Note 6 to our Condensed Consolidated Financial Statements for additional information regarding outstanding debt.

Other Income, Net


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025
Net gain on foreign currency revaluation (1)	$	15	$	3	$	3	$	2
Contingent consideration fair value adjustment (2)	—		—		(6)		—
Other	9		5		11		12
	$	24	$	8	$	8	$	14

(1)The activity during the periods presented was primarily related to the impact from the change in the CAD to USD exchange rate on the portion of our intercompany net investment that is not long-term in nature.

(2)Represents the change in the estimated fair value during the period of certain potential earnout payments primarily associated with our Cactus III acquisition.

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Income Tax Expense from Continuing Operations

The net unfavorable income tax variance from continuing operations for the three and six months ended June 30, 2026 compared to the same periods in 2025 was primarily due to tax impacts from certain planning and restructuring activities within our organizational structure in connection with the Canadian NGL Business divestiture. For the three months ended June 30, 2026, these included current income tax expense of approximately $95 million primarily related to withholding taxes on distributions. For the six months ended June 30, 2026, these included (i) current income tax expense of $311 million as a result of basis recapture and capital gains taxed at the applicable rates and withholding taxes on distributions and (ii) a partially offsetting $217 million deferred tax benefit primarily resulting from the transfer of the crude oil assets from PMC ULC to PCLP. See Note 2 to our Condensed Consolidated Financial Statements for additional information regarding the Canadian NGL Business divestiture.

Non-GAAP Financial Measures

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. The primary additional measures used by management are Adjusted EBITDA and Adjusted EBITDA attributable to PAA.

Our definition and calculation of certain non-GAAP financial measures may not be comparable to similarly-titled measures of other companies. Adjusted EBITDA and Adjusted EBITDA attributable to PAA are reconciled to Net Income, the most directly comparable measures as reported in accordance with GAAP, and should be viewed in addition to, and not in lieu of, our Condensed Consolidated Financial Statements and accompanying notes.

Non-GAAP Financial Performance Measures

Adjusted EBITDA is defined as earnings from continuing operations and discontinued operations before (i) interest expense, (ii) income tax (expense)/benefit from continuing operations and discontinued operations, (iii) depreciation and amortization (including our proportionate share of depreciation and amortization, including write-downs related to cancelled projects and impairments, of unconsolidated entities) from continuing operations and discontinued operations, (iv) gains and losses on asset sales, asset impairments and other, net from continuing operations and discontinued operations, (v) gains on investments in unconsolidated entities, net and (vi) adjusted for certain selected items impacting comparability. Adjusted EBITDA attributable to PAA excludes the portion of Adjusted EBITDA that is attributable to noncontrolling interests in consolidated joint venture entities.

Management believes that the presentation of such additional financial measures 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 operating performance, (ii) provide investors with the same financial analytical framework upon which management bases financial, operational, compensation and planning/budgeting decisions and (iii) present measures that investors, rating agencies and debt holders have indicated are useful in assessing us and our results of operations. These non-GAAP financial performance 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 either related to investing activities (such as the purchase of linefill) or purchases of long-term inventory, and inventory valuation adjustments, as applicable, (iii) long-term inventory costing adjustments, (iv) items that are not indicative of our operating results and/or (v) other items that we believe should be excluded in understanding our operating performance. These measures may further be 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. Such amounts are presented net of applicable amounts subsequently recognized into revenue. We have defined all such items as “selected items impacting comparability.” 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.

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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 as discussed, as applicable, in “—Analysis of Operating Segments.”

Discontinued Operations. From June 17, 2025, the date we entered into the SPA with Keyera to sell the Canadian NGL Business, through the closing of the divestiture on May 12, 2026, management reviewed such business as a component of our overall company performance. As such, certain Non-GAAP financial performance measures, such as Adjusted EBITDA and Adjusted EBITDA attributable to PAA, are presented on a consolidated basis (e.g., the aggregate of continuing operations and discontinued operations) to provide relevant and useful information regarding our historical performance and results of operations and to assist in reconciling results presented in historical periods.

The following table sets forth the reconciliation of the non-GAAP financial performance measures Adjusted EBITDA and Adjusted EBITDA attributable to PAA to Net Income (in millions):

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	Three Months Ended June 30,				Variance				Six Months Ended June 30,				Variance
	2026		2025		$		%		2026		2025		$		%
Net income (1)	$	1,815	$	283	$	1,532	**		$	2,037	$	775	$	1,262	163	%
Interest expense, net	135		110		25		23	%	279		217		62		29	%


Income tax expense from continuing operations	209		16		193		**		216		46		170		370	%
Income tax expense from discontinued operations (2)	2		26		(24)		(92)	%	77		69		8		12	%
Depreciation and amortization from continuing operations	242		235		7		3	%	486		466		20		4	%
Depreciation and amortization from discontinued operations (2)	—		27		(27)		(100)	%	—		57		(57)		(100)	%
Losses on asset sales, asset impairments and other, net from continuing operations	59		42		17		40	%	6		29		(23)		(79)	%
(Gains)/losses on asset sales and other, net from discontinued operations (2)	(1,637)		13		(1,650)		**		(1,605)		13		(1,618)		**
Gain on investments in unconsolidated entities, net	—		—		—		N/A		—		(31)		31		100	%
Depreciation and amortization of unconsolidated entities (3)	21		20		1		5	%	42		40		2		5	%
Unallocated general and administrative expenses (4)	1		2		(1)		(50)	%	3		3		—		—	%
Selected Items Impacting Comparability (1):
Derivative activities and inventory valuation adjustments	(47)		8		(55)		**		242		(27)		269		**
Long-term inventory costing adjustments	64		19		45		**		(49)		17		(66)		**
Deficiencies under minimum volume commitments, net	(4)		(9)		5		**		(36)		(16)		(20)		**
Rail fleet amortization expense related to discontinued operations (5)	(3)		—		(3)		**		(11)		—		(11)		**
Equity-indexed compensation expense	10		8		2		**		20		18		2		**
Foreign currency revaluation	(7)		12		(19)		**		(13)		11		(24)		**

Impact from exit of Canadian NGL Business	34		—		34		**		34		—		34		**
Transaction-related expenses	—		3		(3)		**		—		8		(8)		**
Selected Items Impacting Comparability - Segment Adjusted EBITDA (1) (6)	47		41		6		**		187		11		176		**

Foreign currency revaluation (7)	(15)		(3)		(12)		**		(3)		(2)		(1)		**
Contingent consideration fair value adjustment (8)	—		—		—		**		6		—		6		**
Selected Items Impacting Comparability - Adjusted EBITDA (1) (9)	32		38		(6)		**		190		9		181		**
Adjusted EBITDA (1) (9)	$	879	$	812	$	67	8	%	$	1,731	$	1,693	$	38	2	%
Adjusted EBITDA attributable to noncontrolling interests in consolidated joint ventures (10)	(141)		(140)		(1)		(1)	%	(263)		(267)		4		1	%
Adjusted EBITDA attributable to PAA (1)	$	738	$	672	$	66	10	%	$	1,468	$	1,426	$	42	3	%

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

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(1)Includes results from continuing operations and discontinued operations.

(2)See Note 2 to our Condensed Consolidated Financial Statements for additional information.

(3)We exclude our proportionate share of the depreciation and amortization expense (including write-downs related to cancelled projects and impairments) of unconsolidated entities when reviewing Adjusted EBITDA, similar to our consolidated assets.

(4)Represents general and administrative expenses incremental to those of PAA, which are not allocated to our reporting segments in determining Segment Adjusted EBITDA and are excluded in the non-GAAP financial performance measures utilized by management.

(5)Depreciation and amortization on the long-lived assets of the Canadian NGL Business disposal group ceased upon meeting the criteria to be classified as assets held for sale. Management believes that the presentation of Adjusted EBITDA on a consolidated basis (e.g., the aggregate of continuing operations and discontinued operations) provides more relevant and useful information regarding our performance and results of operations than presenting such metrics only on a continuing operations or discontinued operations basis. We therefore include an adjustment for the impact of amortization of the rail fleet associated with the Canadian NGL Business in our calculation of Adjusted EBITDA. See Note 2 to our Condensed Consolidated Financial Statements for additional information regarding the sale of the Canadian NGL Business. Also see the “—Non-GAAP Financial Measures” section above.

(6)For a more detailed discussion of these selected items impacting comparability, see the footnotes to the segment financial data tables in Note 11 to our Condensed Consolidated Financial Statements.

(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. The associated gains and losses are not integral to our results and were thus classified as a selected item impacting comparability.

(8)We agreed to potential earnout payments associated with recently completed acquisitions, primarily our Cactus III acquisition. We consider the non-cash change in the estimated fair value of such earnout payments as a selected item impacting comparability.

(9)“Other income, net” on our Condensed Consolidated Statements of Operations, adjusted for selected items impacting comparability (“Adjusted other income, net”) is included in Adjusted EBITDA and excluded from Segment Adjusted EBITDA.

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

Analysis of Operating Segments

We manage our operations through two operating segments: Crude Oil and NGL. Our CODM (our Chief Executive Officer) evaluates segment performance based on measures including Segment Adjusted EBITDA. See Note 11 to our Condensed Consolidated Financial Statements for our definition of Segment Adjusted EBITDA and a reconciliation of Segment Adjusted EBITDA to Income from Continuing Operations, Net of Tax. See Note 20 to our Consolidated Financial Statements included in Part IV of our 2025 Annual Report on Form 10-K for our definition of maintenance capital.

Crude Oil Segment

Our Crude Oil segment operations generally consist of gathering and transporting crude oil using pipelines (including gathering systems), trucks and, at times, on barges or railcars, in addition to providing terminalling, storage and other related services utilizing our integrated assets across the United States and Canada. Our assets provide services to third parties as well as to our merchant activities. Our merchant activities include the purchase of crude oil supply and the movement of this supply on our assets or third-party assets to sales locations, including our terminals, third-party connecting carriers, regional hubs or to refineries. Our merchant activities are governed by our risk management policies.

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Our Crude Oil segment generates revenue through a combination of tariffs, pipeline capacity agreements and other transportation fees, month-to-month and multi-year storage and terminalling agreements and the sale of gathered and bulk-purchased crude oil. Tariffs and other fees on our pipeline systems are typically based on volumes transported and vary by receipt point and delivery point. Fees for our terminalling and storage services are based on capacity leases and throughput volumes. Generally, results from our merchant activities are impacted by (i) increases or decreases in our lease gathering crude oil purchases volumes and (ii) volatility in commodity price differentials, particularly grade and location differentials, as well as time spreads. The segment results also include the direct fixed and variable field costs of operating the crude oil assets, as well as an allocation of indirect operating and general and administrative costs.

The following tables set forth our operating results from our Crude Oil segment:


Operating Results (1)	Three Months Ended June 30,				Variance				Six Months Ended June 30,				Variance
(in millions)	2026		2025		$		%		2026		2025		$		%
Revenues	$	17,760	$	10,622	$	7,138	67	%	$	30,309	$	22,061	$	8,248	37	%
Purchases and related costs	(16,632)		(9,742)		(6,890)		(71)	%	(28,211)		(20,231)		(7,980)		(39)	%
Field operating costs	(325)		(279)		(46)		(16)	%	(616)		(571)		(45)		(8)	%
Segment general and administrative expenses (2)	(108)		(75)		(33)		(44)	%	(184)		(155)		(29)		(19)	%
Equity earnings in unconsolidated entities	89		94		(5)		(5)	%	178		196		(18)		(9)	%

Other segment items (3):
Depreciation and amortization of unconsolidated entities	21		20		1		**		42		40		2		**
Derivative activities and inventory valuation adjustments	(74)		52		(126)		**		56		28		28		**
Long-term inventory costing adjustments	67		17		50		**		(45)		18		(63)		**
Deficiencies under minimum volume commitments, net	(4)		(9)		5		**		(36)		(16)		(20)		**
Equity-indexed compensation expense	10		8		2		**		20		18		2		**
Foreign currency revaluation	(8)		9		(17)		**		(13)		9		(22)		**

Impact from exit of Canadian NGL Business	34		—		34		**		34		—		34		**
Transaction-related expenses	—		3		(3)		**		—		8		(8)		**
Segment amounts attributable to noncontrolling interests in consolidated joint ventures	(140)		(140)		—		**		(262)		(265)		3		**
Segment Adjusted EBITDA	$	690	$	580	$	110	19	%	$	1,272	$	1,140	$	132	12	%

Maintenance capital expenditures	$	38	$	43	$	(5)	(12)	%	$	72	$	74	$	(2)	(3)	%


	Three Months Ended June 30,		Variance			Six Months Ended June 30,		Variance
Average Volumes	2026	2025	Volumes	%		2026	2025	Volumes	%

Crude oil pipeline tariff (by region) (4) (5)
Permian Basin	8,045	7,223	822	11	%	7,910	7,047	863	12	%
South Texas / Eagle Ford	527	542	(15)	(3)	%	521	517	4	1	%
Mid-Continent	575	537	38	7	%	525	477	48	10	%
Other	1,448	1,357	91	7	%	1,362	1,333	29	2	%
Total crude oil pipeline tariff	10,595	9,659	936	10	%	10,318	9,374	944	10	%

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

(1)Revenues and costs and expenses include intersegment amounts.

(2)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.

(3)Represents adjustments included in the performance measure utilized by our CODM in the evaluation of segment results. See Note 11 to our Condensed Consolidated Financial Statements for additional discussion of such adjustments.

(4)Average daily volumes in thousands of barrels per day calculated as the total volumes (attributable to our interest for assets owned by unconsolidated entities or through undivided joint interests) for the period divided by the number of days in the period. Volumes associated with acquisitions represent total volumes for the number of days we actually owned the assets divided by the number of days in the period.

(5)Includes volumes (attributable to our interest) from assets owned by unconsolidated entities.

Segment Adjusted EBITDA

Crude Oil Segment Adjusted EBITDA for the three and six months ended June 30, 2026 increased versus comparable results for the three and six months ended June 30, 2025. The benefit to the 2026 period results from (i) contributions from recently completed acquisitions, (ii) volume growth across our pipeline systems and (iii) market opportunities and optimization initiatives was partially offset by (iii) the impact from certain Permian long-haul contract rates resetting to market in 2025.

The following is a more detailed discussion of the significant factors impacting Segment Adjusted EBITDA for the three and six months ended June 30, 2026 compared to the same periods in 2025.

Net Revenues and Equity Earnings. Our results were favorably impacted by (i) contributions from the Cactus III acquisition completed in the fourth quarter of 2025, (ii) volume growth across our pipeline systems largely driven by increased production in the Permian Basin region and (iii) market opportunities and optimization initiatives. These favorable impacts were partially offset by (iv) the impact from certain Permian long-haul contract rates resetting to market in 2025, including rates on certain of our equity method investments.

Field Operating Costs. Field operating costs increased for the three and six months ended June 30, 2026 compared to the same periods in 2025. The 2026 periods were primarily impacted by recently completed acquisitions, with recurring period-over-period cost increases being driven by (i) higher volumes, (ii) higher property taxes and (iii) higher environmental remediation costs, all partially offset by (iv) lower employee-related costs associated with the divestiture of certain trucking operations.

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NGL Segment

Our NGL segment operations involve NGL storage and terminalling from our NGL assets located in the United States. Our NGL segment revenues are primarily derived from (i) providing storage and/or terminalling services at these facilities to third-party customers for a fee and (ii) the transport, storage and sale of specification NGL products. The segment results also include the direct fixed and variable field costs of operating our four NGL facilities, as well as an allocation of indirect operating costs and general and administrative expenses.

The following table sets forth our operating results from our NGL segment:


Operating Results (1)	Three Months Ended June 30,				Variance				Six Months Ended June 30,				Variance
(in millions)	2026		2025		$		%		2026		2025		$		%
Revenues	$	22	$	26	$	(4)	(15)	%	$	61	$	67	$	(6)	(9)	%
Purchases and related costs	(13)		(22)		9		41	%	(46)		(55)		9		16	%
Field operating costs (2)	(3)		(7)		4		57	%	(12)		(14)		2		14	%
Segment general and administrative expenses (2) (3)	(2)		(7)		5		71	%	(8)		(13)		5		38	%







Segment Adjusted EBITDA	$	4	$	(10)	$	14	140	%	$	(5)	$	(15)	$	10	67	%

Maintenance capital expenditures	$	—	$	1	$	(1)	(100)	%	$	1	$	3	$	(2)	(67)	%

(1)Revenues and costs and expenses include intersegment amounts.

(2)Field operating costs and segment general and administrative expenses include certain costs that are part of the overhead of continuing operations.

(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.

Segment Adjusted EBITDA

NGL Segment Adjusted EBITDA for the periods presented was largely driven by costs that are part of the overhead of our NGL activities and are included in continuing operations as they are not related to contracts or arrangements included in the sale of the Canadian NGL Business. These costs include information technology, insurance and other shared services costs.

Liquidity and Capital Resources

General

Our primary sources of liquidity are (i) cash flow from operating activities and (ii) borrowings under PAA’s credit facility or commercial paper program. In addition, we may supplement these primary sources of liquidity with proceeds from asset sales, and in the past have utilized funds received from sales of equity and debt securities. Our primary cash requirements include, but are not limited to, (i) ordinary course of business uses, such as the payment of amounts related to the purchase of crude oil and other products, payment of other expenses and interest payments on outstanding debt, (ii) investment and maintenance capital activities, (iii) acquisitions of assets or businesses, (iv) repayment of principal on our long-term debt and (v) distributions to our Class A shareholders and noncontrolling interests. In addition, we may use cash for repurchases of common equity. We generally expect to fund our short-term cash requirements through cash flow generated from operating activities and/or borrowings under PAA’s credit facility or commercial paper program. In addition, we generally expect to fund our long-term needs, such as those resulting from investment capital activities, acquisitions or refinancing our long-term debt, through a variety of sources, which may include any or a combination of the sources listed above.

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As of June 30, 2026, we had a working capital surplus of $679 million and approximately $3.7 billion of liquidity available to meet our ongoing operating, investing and financing needs, subject to continued covenant compliance, as noted below (in millions):


	As of June 30, 2026
Availability under PAA senior unsecured revolving credit facility (1) (2)	$	2,671

Amounts outstanding under PAA commercial paper program	—
Subtotal	2,671
Cash and cash equivalents	1,060
Total	$	3,731

(1)Represents availability prior to giving effect to borrowings outstanding under the PAA commercial paper program, which reduce available capacity under the credit facility.

(2)Available capacity under the PAA credit facility was reduced by outstanding letters of credit issued under the facility of $29 million.

In June 2026, PAA entered into a new credit agreement to facilitate the renewal and extension of its credit facilities. The PAA $1.35 billion senior secured hedged inventory facility with maturity date of August 2027 and the PAA $1.35 billion senior unsecured revolving credit facility with maturity date of August 2029 were replaced with a $2.7 billion senior unsecured revolving credit facility with an initial maturity in June 2031. The new credit agreement provides for one or more one-year extensions and have accordion features which, subject to receipt of incremental lender approval and other terms and conditions, permit PAA to increase borrowing capacity to $4.0 billion. The covenants and events of default under the new credit agreement remain substantially unchanged from the previous agreements. See Note 6 to our Condensed Consolidated Financial Statements for additional information.

Usage of PAA’s credit facility, and, in turn, its commercial paper program, is subject to ongoing compliance with covenants. The credit agreement for PAA’s revolving credit facility (which impact PAA’s ability to access its commercial paper program because it provides the financial backstop that supports its short-term credit ratings) and the indentures governing its senior notes contain cross-default provisions. A default under PAA’s credit agreement or indentures would permit the lenders to accelerate the maturity of the outstanding debt. As long as PAA is in compliance with the provisions in its credit agreement, its ability to make distributions of available cash is not restricted. PAA was in compliance with the covenants contained in its credit agreement and indentures as of June 30, 2026.

We believe that we have, and will continue to have, the ability to access the PAA commercial paper program and credit facility, which we use to meet our short-term cash needs. We believe that our financial position remains strong and we have sufficient liquid assets, cash flow from operating activities and borrowing capacity under the credit agreements to meet our financial commitments, debt service obligations, contingencies and anticipated capital expenditures. We are, however, subject to business and operational risks that could adversely affect our cash flow, including extended disruptions in the financial markets and/or energy price volatility resulting from current macroeconomic and geopolitical conditions, including actions by the Organization of Petroleum Exporting Countries (OPEC). A prolonged material decrease in our cash flows would likely produce an adverse effect on our borrowing capacity and cost of borrowing. Our borrowing capacity and borrowing costs are also impacted by PAA’s credit rating. See Item 1A. “Risk Factors” included in our 2025 Annual Report on Form 10-K for further discussion regarding risks that may impact our liquidity and capital resources.

Cash Flow from Operating Activities

For a comprehensive discussion of the primary drivers of cash flow from operating activities, including the impact of varying market conditions and the timing of settlement of our derivatives, see Item 7. “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources—Cash Flow from Operating Activities” included in our 2025 Annual Report on Form 10-K.

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Net cash provided by operating activities from continuing operations for the first six months of 2026 and 2025 was $1.211 billion and $1.029 billion, respectively, and primarily resulted from earnings from our operations. In addition, both periods were also impacted by changes in net operating working capital items, while the 2026 period was impacted by higher margin requirements related to our hedging activities.

Investing Activities

Capital Expenditures

In addition to our operating needs, we also use cash for our investment capital projects, maintenance capital activities and acquisition activities. We fund these expenditures with cash generated by operating activities, financing activities and/or proceeds from asset sales. In the near term, we do not plan to issue common equity to fund such expenditures. The following table summarizes our investment, maintenance and acquisition capital expenditures related to continuing operations and discontinued operations (in millions):


	Net to PAA (1) (2)				Consolidated (2)				Continuing Operations
	Six Months Ended June 30,				Six Months Ended June 30,				Six Months Ended June 30,
Capital Expenditures (3) (4)	2026		2025		2026		2025		2026		2025
Crude Oil:
Investment capital	$	147	$	215	$	196	$	280	$	196	$	280
Maintenance capital	62		66		72		74		72		74
Acquisition capital	129		651		130		722		130		722
	$	338	$	932	$	398	$	1,076	$	398	$	1,076

NGL:
Investment capital	$	10	$	68	$	10	$	68	$	—	$	—
Maintenance capital	21		31		21		31		1		3

	$	31	$	99	$	31	$	99	$	1	$	3

Total:
Investment capital	$	157	$	283	$	206	$	348	$	196	$	280
Maintenance capital	83		97		93		105		73		77
Acquisition capital	129		651		130		722		130		722
	$	369	$	1,031	$	429	$	1,175	$	399	$	1,079

(1)Excludes expenditures attributable to noncontrolling interests, which primarily relate to the Permian JV. Includes results from continuing operations and discontinued operations for all periods presented.

(2)Includes results from continuing operations and discontinued operations for all periods presented. Capital expenditures related to discontinued operations were $10 million and $20 million for investment and maintenance capital for the six months ended June 30, 2026, respectively. Capital expenditures for investment and maintenance capital related to discontinued operations were $68 million and $28 million for the six months ended June 30, 2025, respectively. There was no acquisition capital related to discontinued operations for any period presented.

(3)Capital expenditures made to expand the existing operating and/or earnings capacity of our assets are classified as “Investment capital.” Capital expenditures made to replace and/or refurbish partially or fully depreciated assets in order to maintain the operating and/or earnings capacity of our existing assets are classified as “Maintenance capital.”

(4)Contributions to unconsolidated entities, accounted for under the equity method of accounting, that are related to investment capital projects by such entities are recognized in “Investment capital.” Acquisitions of initial investments or additional interests in unconsolidated entities are included in “Acquisition capital.”

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Projected 2026 Capital Expenditures. Total investment capital for the year ending December 31, 2026 is currently projected to be approximately $535 million ($425 million net to our interest), which includes approximately $10 million related to discontinued operations of the Canadian NGL Business prior to the completion of the divestiture in May 2026. Approximately half of our projected investment capital expenditures are expected to be invested in the Permian JV assets. Additionally, maintenance capital for 2026 is currently projected to be approximately $195 million ($175 million net to our interest), which includes approximately $20 million related to discontinued operations of the Canadian NGL Business prior to the completion of the divestiture in May 2026. Note that potential variation to current capital cost estimates may result from (i) changes to project design, (ii) final cost of materials and labor and (iii) timing of incurrence of costs due to uncontrollable factors such as receipt of permits or regulatory approvals and weather.

Sale of Canadian NGL Business

On June 17, 2025, we entered into a definitive SPA with Keyera, pursuant to which Keyera agreed to acquire all of the issued and outstanding shares of PMC ULC, our wholly-owned subsidiary that owned the Canadian NGL Business. The transaction closed on May 12, 2026, and, pursuant to the SPA, we received cash consideration of approximately CAD$5.328 billion (approximately $3.883 billion, or approximately $3.483 billion, net of cash divested), including estimated working capital and other adjustments, subject to certain post-closing adjustments as defined in the SPA that are expected in the third quarter of 2026. We used the net proceeds to reduce leverage, which included the repayment of outstanding borrowings under PAA’s commercial paper program and term loan, as well as the repayment of its $750 million, 4.50% senior notes that were due December 2026. See Note 2 to our Condensed Consolidated Financial Statements for additional information regarding the sale of the Canadian NGL Business.

Ongoing Activities Related to Strategic Transactions

We are continuously engaged in the evaluation of potential transactions that support our business strategy. In the past, such transactions have included the acquisition of assets that complement our existing footprint, the sale of non-core assets, the sale of partial interests in assets to strategic joint venture partners, and large investment capital projects. With respect to a potential acquisition or divestiture, we may conduct an auction process or participate in an auction process conducted by a third-party or we may negotiate a transaction with one or a limited number of potential sellers (in the case of an acquisition) or buyers (in the case of a divestiture). Such transactions could have a material effect on our financial condition and results of operations.

We typically do not announce a transaction until after we have executed a definitive agreement. In certain cases, in order to protect our business interests or for other reasons, we may defer public announcement of a transaction until closing or a later date. Past experience has demonstrated that discussions and negotiations regarding a potential transaction can advance or terminate in a short period of time. Moreover, the closing of any transaction for which we have entered into a definitive agreement may be subject to customary and other closing conditions, which may not ultimately be satisfied or waived. Accordingly, we can give no assurance that our current or future efforts with respect to any such transactions will be successful, and we can provide no assurance that our financial expectations with respect to such transactions will ultimately be realized. See Item 1A. “Risk Factors—Risks Related to PAA’s Business—Acquisitions and divestitures involve risks that may adversely affect PAA’s business” included in our 2025 Annual Report on Form 10-K.

Financing Activities

Our financing activities primarily relate to funding investment capital projects, acquisitions and refinancing of our debt maturities, as well as short-term working capital (including borrowings for NYMEX and ICE margin deposits) and hedged inventory borrowings related to our NGL business and contango market activities, and the payment of distributions to our shareholders and noncontrolling interests.

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Borrowings and Repayments Under Credit Agreements and Term Loan

During the six months ended June 30, 2026, we had net repayments under the PAA credit facilities and commercial paper program of $970 million. The net repayments resulted primarily from cash flow from operating activities and proceeds from the sale of the Canadian NGL Business, which offset borrowings during the period related to funding needs for capital investments, inventory purchases and other general partnership purposes.

During the six months ended June 30, 2025, we had net borrowings under the PAA commercial paper program of $69 million. The net borrowings resulted primarily from funding needs for capital investments, inventory purchases and other general partnership purposes.

On May 14, 2026, in connection with the closing of the Canadian NGL Business divestiture, PAA terminated the senior unsecured term loan agreement and repaid the outstanding borrowings of $1.1 billion. We used a portion of the proceeds from the sale of the Canadian NGL Business to fund the repayment. See Note 2 and Note 6 to our Condensed Consolidated Financial Statements for additional information regarding the Canadian NGL Business divestiture and the term loan agreement, respectively.

Senior Notes

On June 25, 2026, PAA redeemed its $750 million, 4.50% senior notes that were due December 2026. We repaid these senior notes with proceeds from the sale of the Canadian NGL Business.

Common Equity Repurchase Program

There were no repurchases under the Common Equity Repurchase Program (the “Program”) during the six months ended June 30, 2026. PAA repurchased approximately 0.5 million common units under the Program through open market purchases that settled during the six months ended June 30, 2025 for a total purchase price of $8 million, including commissions and fees. The repurchased PAA common units were canceled immediately upon acquisition, as were the Class C shares held by PAA associated with the repurchased common units. At June 30, 2026, the remaining available capacity under the Program was $190 million. See Note 12 to our Consolidated Financial Statements included in Part IV of our 2025 Annual Report on Form 10-K for additional information regarding the Program.

Registration Statements

PAGP Registration Statements. We have filed with the SEC a shelf registration statement that, subject to effectiveness at the time of use, allows us to issue up to a specified amount of equity securities (“PAGP Traditional Shelf”). At June 30, 2026, we had approximately $939 million of unsold securities available. We also have access to a universal shelf registration statement (“PAGP WKSI Shelf”), which provides us with the ability to offer and sell an unlimited amount of equity securities, subject to market conditions and our capital needs. We did not conduct any offerings under the PAGP Traditional Shelf or PAGP WKSI Shelf during the six months ended June 30, 2026.

PAA Registration Statements. PAA periodically accesses the capital markets for both equity and debt financing. PAA has filed with the SEC a shelf registration statement that, subject to effectiveness at the time of use, allows PAA to issue up to a specified amount of debt or equity securities (“PAA Traditional Shelf”), under which PAA had approximately $1.1 billion of unsold securities available at June 30, 2026. PAA also has access to a universal shelf registration statement (“PAA WKSI Shelf”), which provides it with the ability to offer and sell an unlimited amount of debt and equity securities, subject to market conditions and its capital needs. PAA did not conduct any offerings under the PAA Traditional Shelf or PAA WKSI Shelf during the six months ended June 30, 2026.

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Distributions to Our Class A Shareholders

On August 14, 2026, we will pay a quarterly cash distribution of $0.4175 per Class A share ($1.67 per Class A share on an annualized basis) to shareholders of record at the close of business on July 31, 2026 for the period from April 1, 2026 through June 30, 2026.

See Note 7 to our Condensed Consolidated Financial Statements for details of distributions paid during or pertaining to the first six months of 2026.

Distributions to Noncontrolling Interests

Distributions to noncontrolling interests represent amounts paid on interests in consolidated entities that are not owned by us. As of June 30, 2026, noncontrolling interests in our subsidiaries consisted of (i) limited partner interests in PAA including a 69% interest in PAA’s common units and PAA’s Series A preferred units combined and 100% of PAA’s Series B preferred units, (ii) an approximate 15% limited partner interest in AAP, (iii) a 35% interest in the Permian JV, (iv) a 30% interest in Cactus II and (v) a 33% interest in Red River.

Distributions to PAA’s Series A preferred unitholders. On August 14, 2026, PAA will pay a quarterly cash distribution of approximately $0.615 per unit to its Series A preferred unitholders of record at the close of business on July 31, 2026 for the period from April 1, 2026 through June 30, 2026.

Distributions to PAA’s Series B preferred unitholders. On August 17, 2026, PAA will pay a quarterly cash distribution of approximately $20.50 per unit to its Series B preferred unitholders of record at the close of business on August 3, 2026 for the period from May 15, 2026 through August 14, 2026.

Distributions to PAA’s common unitholders. On August 14, 2026, PAA will pay a quarterly cash distribution of $0.4175 per common unit ($1.67 per unit on an annualized basis) to its common unitholders of record at the close of business on July 31, 2026 for the period from April 1, 2026 through June 30, 2026.

See Note 7 to our Condensed Consolidated Financial Statements for details of distributions paid during or pertaining to the first six months of 2026, including distributions to PAA’s preferred unitholders.

Contingencies

For a discussion of contingencies that may impact us, see Note 10 to our Condensed Consolidated Financial Statements.

Commitments

Purchase Obligations. In the ordinary course of doing business, we purchase crude oil from third parties under contracts, the majority of which range in term from thirty-day evergreen to five years, with a limited number of contracts with remaining terms extending up to 10 years. We establish a margin for these purchases by entering into various types of physical and financial sale and exchange transactions through which we seek to maintain a position that is substantially balanced between purchases on the one hand and sales and future delivery obligations on the other. We do not expect to use a significant amount of internal capital to meet these obligations, as the obligations will be funded by corresponding sales to entities that we deem creditworthy or who have provided credit support we consider adequate.

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The following table includes our best estimate of the amount and timing of these payments as of June 30, 2026 (in millions):


	Remainder of 2026		2027		2028		2029		2030		2031 and Thereafter		Total
Crude oil and other purchases (1)	$	16,882	$	28,083	$	24,621	$	22,752	$	19,068	$	39,534	$	150,940

(1)Amounts are primarily based on estimated volumes and market prices based on average activity during June 2026. The actual physical volume purchased and actual settlement prices will vary from the assumptions used in the table. Uncertainties involved in these estimates include levels of production at the wellhead, weather conditions, changes in market prices and other conditions beyond our control.

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. Our liabilities with respect to these purchase obligations are recorded in accounts payable on our balance sheet in the month the product is purchased. Generally, these letters of credit are issued for periods of up to seventy days and are terminated upon completion of each transaction. Additionally, we issue letters of credit to support insurance programs, derivative transactions, including hedging-related margin obligations, and construction activities. At June 30, 2026 and December 31, 2025, we had outstanding letters of credit of approximately $63 million and $95 million, respectively.

Recent Accounting Pronouncements

See Note 1 to our Condensed Consolidated Financial Statements.

FORWARD-LOOKING STATEMENTS

All statements included in this report, other than statements of historical fact, are forward-looking statements, including but not limited to statements incorporating the words “anticipate,” “believe,” “estimate,” “expect,” “plan,” “intend” and “forecast,” as well as similar expressions and statements regarding our business strategy, plans and objectives for future operations. The absence of such words, expressions or statements, however, does not mean that the statements are not forward-looking. Any such forward-looking statements reflect our current views with respect to future events, based on what we believe to be reasonable assumptions. Certain factors could cause actual results or outcomes to differ materially from the results or outcomes anticipated in the forward-looking statements. The most important of these factors include, but are not limited to:

•our expected receipt of, and amounts of, distributions from Plains AAP, L.P., and the effect thereof on our ability to pay distributions to our Class A shareholders;

•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, the risk of persistently high inflation and supply chain issues, the impact of global public health events, such as pandemics, on demand and growth, and the timing, pace and extent of economic recovery) that impact (i) demand for crude oil, drilling and production activities and therefore the demand for the midstream services we provide and (ii) commercial opportunities available to us;

•declines in global crude oil demand and/or crude oil prices or other factors that correspondingly lead to a significant reduction of North American crude oil 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 shipped, processed, purchased, stored, fractionated and/or gathered at or through the use of our assets and/or the reduction of the margins we can earn or the commercial opportunities that might otherwise be available to us;

•impacts of global geopolitical events, including conflicts in the Middle East and elsewhere, on commodity price volatility and crude oil supply and demand, as well as broader impacts on financial markets and the global macroeconomic environment;

•fluctuations in refinery capacity and other factors affecting demand for various grades of crude oil and resulting changes in pricing conditions or transportation throughput requirements;

•unanticipated changes in crude oil market structure, grade differentials and volatility (or lack thereof);

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•the effects of competition and capacity overbuild in areas where we operate, including downward pressure on rates, volumes and margins, 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;

•the availability of, and PAA’s ability to consummate, acquisitions, divestitures, joint ventures or other strategic opportunities and realize benefits therefrom;

•the successful operation of joint ventures and joint operating arrangements PAA enters into from time to time, whether relating to assets operated by PAA or by third parties, and the successful integration and future performance of acquired assets or businesses;

•environmental liabilities, litigation or other events that are not covered by an indemnity, insurance or existing reserves;

•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;

•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 or our service providers’ electronic and computer systems;

•weather interference with business operations or project construction, including the impact of extreme weather events or conditions (including hurricanes, floods, wildfires and drought);

•the impact of current and future laws, rulings, legislation, governmental regulations, executive orders, trade policies, trade tariffs, accounting standards and statements, and related interpretations that (i) prohibit, restrict or regulate the development of oil and gas resources and the related infrastructure on lands dedicated to or served by our pipelines, (ii) negatively impact our ability to develop, operate or repair midstream assets, or (iii) otherwise negatively impact our business or increase our exposure to risk;

•negative impacts on production levels in the Permian Basin or elsewhere due to issues associated with (or laws, rules or regulations relating to) hydraulic fracturing and related activities (including wastewater injection or disposal), including earthquakes, subsidence, expansion or other issues;

•the pace of development of natural gas or other infrastructure and its impact on expected crude oil production growth in the Permian Basin;

•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;

•loss of key personnel and inability to attract and retain new talent;

•disruptions to futures markets for crude oil and other petroleum products, which may impair our ability to execute our commercial or hedging strategies;

•the effectiveness of our risk management activities;

•shortages or cost increases of supplies, materials or labor;

•maintenance of PAA’s credit ratings and ability to receive open credit from our suppliers and trade counterparties;

•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, supply chain issues, legal constraints (including governmental orders or guidance), or other factors or events;

•the incurrence of costs and expenses related to unexpected or unplanned capital or maintenance expenditures, third-party claims or other factors;

•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;

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•failure to implement or realize anticipated benefits from operational and organizational streamlining and efficiency efforts and initiatives;

•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;

•the amplification of other risks caused by volatile or closed 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;

•the deferral of current revenue recognition attributable to deficiency payments received from customers who fail to ship or move their minimum contracted volumes;

•significant under-utilization of our assets and facilities;

•increased costs, or lack of availability, of insurance;

•fluctuations in the debt and equity markets, including the price of PAA’s units at the time of vesting under its 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 and other petroleum products.

Other factors described herein, as well as factors that are unknown or unpredictable, could also have a material adverse effect on future results. Please read “Risk Factors” discussed in Item 1A of our 2025 Annual Report on Form 10-K. Except as required by applicable securities laws, we do not intend to update these forward-looking statements and information.

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Item 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

We are exposed to various market risks, including commodity price risk, interest rate risk and currency exchange rate risk. We use various derivative instruments to manage such risks and, in certain circumstances, to realize incremental margin during volatile market conditions. Our risk management policies and procedures are designed to help ensure that our hedging activities address our risks by monitoring our exchange-cleared and over-the-counter positions, as well as physical volumes, grades, locations, delivery schedules and storage capacity. We have a risk management function that has direct responsibility and authority for our risk policies, related controls around commercial activities and certain aspects of corporate risk management. Our risk management function also approves all new risk management strategies through a formal process. The following discussion addresses each category of risk.

Commodity Price Risk

We use derivative instruments to hedge price risk associated with the following:

•Crude oil

We utilize crude oil derivatives to hedge commodity price risk inherent in our pipeline, terminalling and merchant activities. Our objectives for these derivatives include hedging changes in inventory positions associated with our lease gathering activities, anticipated purchases and sales, stored inventory and basis differentials. We manage these exposures with various instruments including futures, forwards, swaps and options.

See Note 8 to our Condensed Consolidated Financial Statements for further discussion regarding our hedging strategies and objectives.

The fair value of our commodity derivatives and the change in fair value as of June 30, 2026 that would be expected from a 10% price increase or decrease is shown in the table below (in millions):


	Fair Value		Effect of 10% Price Increase		Effect of 10% Price Decrease
Crude oil	$	(43)	$	2	$	(2)


Total fair value	$	(43)

The fair values presented in the table above reflect the sensitivity of the derivative instruments only and do not include the effect of the underlying hedged commodity. Price-risk sensitivities were calculated by assuming an across-the-board 10% increase or decrease in price regardless of term or historical relationships between the contractual price of the instruments and the underlying commodity price. In the event of an actual 10% change in near-term commodity prices, the fair value of our derivative portfolio would typically change less than that shown in the table as changes in near-term prices are not typically mirrored in delivery months further out.

Interest Rate Risk

Debt. Our use of variable rate debt and any forecasted issuances of fixed rate debt expose us to interest rate risk. Therefore, from time to time, we use interest rate derivatives to hedge interest rate risk associated with anticipated interest payments and, in certain cases, outstanding debt instruments. PAA did not have any interest rate derivatives as of June 30, 2026. All of PAA’s senior notes are fixed rate notes and thus are not subject to interest rate risk. PAA did not have any variable rate debt outstanding as of June 30, 2026. The average interest rate on PAA’s variable rate debt that was outstanding during the six months ended June 30, 2026 was approximately 4.4%, based upon rates in effect during such period. See Note 6 to our Condensed Consolidated Financial Statements for additional information regarding our debt arrangements.

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Series B Preferred Units. Distributions on PAA’s Series B preferred units accumulate and are payable quarterly in arrears on the 15th day of February, May, August and November. Distributions on PAA’s Series B preferred units accumulate based on the applicable three-month SOFR, plus certain adjustments. Based upon the Series B preferred units outstanding at June 30, 2026 and the liquidation preference of $1,000 per unit, a change of 100 basis points in interest rates would increase or decrease the annual distributions on PAA’s Series B preferred units by approximately $8 million. See Note 12 to our Consolidated Financial Statements included in Part IV of our 2025 Annual Report on Form 10-K for additional information regarding PAA’s Series B preferred unit distributions.

Item 4. CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

We maintain written disclosure controls and procedures, which we refer to as our “DCP.” Our DCP is designed to ensure that information required to be disclosed by us in reports that we file under the Securities Exchange Act of 1934 (the “Exchange Act”) is (i) recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and (ii) accumulated and communicated to management, including our Chief Executive Officer and Chief Financial Officer, to allow for timely decisions regarding required disclosure.

Applicable SEC rules require an evaluation of the effectiveness of our DCP. Management, under the supervision and with the participation of our Chief Executive Officer and Chief Financial Officer, has evaluated the effectiveness of our DCP as of June 30, 2026, the end of the period covered by this report, and, based on such evaluation, our Chief Executive Officer and Chief Financial Officer have concluded that our DCP is effective.

Changes in Internal Control over Financial Reporting

There were no changes in our internal control over financial reporting during the second quarter of 2026 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

Certifications

The certifications of our Chief Executive Officer and Chief Financial Officer pursuant to Exchange Act Rules 13a-14(a) and 15d-14(a) are filed with this report as Exhibits 31.1 and 31.2. The certifications of our Chief Executive Officer and Chief Financial Officer pursuant to 18 U.S.C. 1350 are furnished with this report as Exhibits 32.1 and 32.2.

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PART II. OTHER INFORMATION

Item 1. LEGAL PROCEEDINGS

The information required by this item is included in Note 10 to our Condensed Consolidated Financial Statements, and is incorporated herein by reference thereto.

Item 1A. RISK FACTORS

For a discussion of our risk factors, see Item 1A. of our 2025 Annual Report on Form 10-K. Those risks and uncertainties are not the only ones facing us and there may be additional matters of which we are unaware or that we currently consider immaterial. All of those risks and uncertainties could adversely affect our business, financial condition and/or results of operations.

Item 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

Sales of Unregistered Securities

None.

Issuer Purchases of Equity Securities

None.

Item 3. DEFAULTS UPON SENIOR SECURITIES

None.

Item 4. MINE SAFETY DISCLOSURES

Not applicable.

Item 5. OTHER INFORMATION

During the quarter ended June 30, 2026, none of our directors or officers (as defined in Rule 16a-1(f) of the Exchange Act) adopted or terminated any Rule 10b5-1 trading arrangement or any non-Rule 10b5-1 trading arrangement (as defined in Item 408 of Regulation S-K).

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Item 6. EXHIBITS


Exhibit No.		Description

2.1 *	—	Share Purchase Agreement, dated as of June 17, 2025, by and between Plains Midstream Luxembourg S.A.R.L. and Keyera Corp. (portions of this exhibit have been omitted pursuant to Item 601(b)(2) of Regulation S-K) (incorporated by reference to Exhibit 2.1 to our Quarterly Report on Form 10-Q for the quarter ended June 30, 2025).

2.2 *	—	First Amendment to Share Purchase Agreement, dated as of May 11, 2026, by and between Plains Midstream Luxembourg S.A.R.L. and Keyera Corp. (portions of this exhibit have been omitted pursuant to Item 601(b)(2) of Regulation S-K) (incorporated by reference to Exhibit 2.2 to our Current Report on Form 8-K filed May 12, 2026).

2.3 *	—	Second Amendment to Share Purchase Agreement, dated as of May 12, 2026, by and between Plains Midstream Luxembourg S.A.R.L. and Keyera Corp. (portions of this exhibit have been omitted pursuant to Item 601(b)(2) of Regulation S-K) (incorporated by reference to Exhibit 2.3 to our Current Report on Form 8-K filed May 12, 2026).

2.4 *	—	Third Amendment to Share Purchase Agreement, dated as of May 12, 2026, by and between Plains Midstream Luxembourg S.A.R.L. and Keyera Corp. (portions of this exhibit have been omitted pursuant to Item 601(b)(2) of Regulation S-K) (incorporated by reference to Exhibit 2.4 to our Current Report on Form 8-K filed May 12, 2026).

3.1	—	Certificate of Limited Partnership of Plains GP Holdings, L.P. (incorporated by reference to Exhibit 3.1 to our Registration Statement on Form S-1 (333-190227) filed July 29, 2013).

3.2	—	Second Amended and Restated Agreement of Limited Partnership of Plains GP Holdings, L.P. dated as of November 15, 2016 (incorporated by reference to Exhibit 3.2 to our Current Report on Form 8-K filed November 21, 2016).

3.3	—	Amendment No. 1 dated April 6, 2020 to the Second Amended and Restated Agreement of Limited Partnership of Plains GP Holdings, L.P. (incorporated by reference to Exhibit 3.1 to our Current Report on Form 8-K filed April 9, 2020).

3.4	—	Certificate of Formation of PAA GP Holdings LLC (incorporated by reference to Exhibit 3.3 to our Registration Statement on Form S-1 (333-190227) filed July 29, 2013).

3.5	—	Fourth Amended and Restated Limited Liability Company Agreement of PAA GP Holdings LLC dated effective as of August 19, 2021 (incorporated by reference to Exhibit 3.11 to our Annual Report on Form 10-K for the year ended December 31, 2021).

3.6	—	Seventh Amended and Restated Agreement of Limited Partnership of Plains All American Pipeline, L.P., dated as of October 10, 2017 (incorporated by reference to Exhibit 3.1 to PAA’s Current Report on Form 8-K filed October 12, 2017).

3.7	—	Seventh Amended and Restated Limited Liability Company Agreement of Plains All American GP LLC dated November 15, 2016 (incorporated by reference to Exhibit 3.3 to our Current Report on Form 8-K filed November 21, 2016).

3.8	—	Eighth Amended and Restated Limited Partnership Agreement of Plains AAP, L.P. dated November 15, 2016 (incorporated by reference to Exhibit 3.4 to our Current Report on Form 8-K filed November 21, 2016).

3.9	—	Amendment No. 1 dated September 26, 2018 to the Eighth Amended and Restated Limited Partnership Agreement of Plains AAP, L.P. (incorporated by reference to Exhibit 3.1 to our Current Report on Form 8-K filed October 2, 2018).

3.10	—	Amendment No. 2 dated May 23, 2019 to the Eighth Amended and Restated Limited Partnership Agreement of Plains AAP, L.P. (incorporated by reference to Exhibit 3.1 to our Current Report on Form 8-K filed May 30, 2019).

3.11	—	Amendment No. 3 dated August 17, 2023 to the Eighth Amended and Restated Limited Partnership Agreement of Plains AAP, L.P. (incorporated by reference to Exhibit 3.1 to our Current Report on Form 8-K filed August 21, 2023).

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3.12	—	Limited Liability Company Agreement of PAA GP LLC dated December 28, 2007 (incorporated by reference to Exhibit 3.3 to PAA’s Current Report on Form 8-K filed January 4, 2008).

4.1	—	Indenture dated September 25, 2002 among Plains All American Pipeline, L.P., PAA Finance Corp. and Wachovia Bank, National Association, as trustee (incorporated by reference to Exhibit 4.1 to PAA’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2002).

4.2	—	Sixth Supplemental Indenture (Series A and Series B 6.70% Senior Notes due 2036) dated May 12, 2006 among Plains All American Pipeline, L.P., PAA Finance Corp., the Subsidiary Guarantors named therein and Wachovia Bank, National Association, as trustee (incorporated by reference to Exhibit 4.1 to PAA’s Current Report on Form 8-K filed May 12, 2006).

4.3	—	Tenth Supplemental Indenture (Series A and Series B 6.650% Senior Notes due 2037) dated October 30, 2006 among Plains All American Pipeline, L.P., PAA Finance Corp., the Subsidiary Guarantors named therein and U.S. Bank National Association, as trustee (incorporated by reference to Exhibit 4.2 to PAA’s Current Report on Form 8-K filed October 30, 2006).

4.4	—	Twenty-First Supplemental Indenture (5.15% Senior Notes due 2042) dated March 22, 2012 among Plains All American Pipeline, L.P., PAA Finance Corp and U.S. Bank National Association, as trustee (incorporated by reference to Exhibit 4.3 to PAA’s Current Report on Form 8-K filed March 26, 2012).

4.5	—	Twenty-Third Supplemental Indenture (4.30% Senior Notes due 2043) dated December 10, 2012, by and among Plains All American Pipeline, L.P., PAA Finance Corp. and U.S. Bank National Association, as trustee (incorporated by reference to Exhibit 4.3 to PAA’s Current Report on Form 8-K filed December 12, 2012).

4.6	—	Twenty-Fifth Supplemental Indenture (4.70% Senior Notes due 2044) dated April 23, 2014, by and among Plains All American Pipeline, L.P., PAA Finance Corp. and U.S. Bank National Association, as trustee (incorporated by reference to Exhibit 4.1 to our Current Report on Form 8-K filed April 29, 2014).

4.7	—	Twenty-Eighth Supplemental Indenture (4.90% Senior Notes due 2045) dated December 9, 2014, by and among Plains All American Pipeline, L.P., PAA Finance Corp., and U.S. Bank National Association, as trustee (incorporated by reference to Exhibit 4.3 to our Current Report on Form 8-K filed December 11, 2014).

4.8	—	Thirty-First Supplemental Indenture (3.55% Senior Notes due 2029) dated September 16, 2019, by and among Plains All American Pipeline, L.P., PAA Finance Corp. and U.S. Bank National Association, as trustee (incorporated by reference to Exhibit 4.1 to PAA’s Current Report on Form 8-K filed September 17, 2019).

4.9	—	Thirty-Second Supplemental Indenture (3.80% Senior Notes due 2030) dated June 11, 2020, by and among Plains All American Pipeline, L.P., PAA Finance Corp. and U.S. Bank National Association, as trustee (incorporated by reference to Exhibit 4.1 to PAA’s Current Report on Form 8-K filed June 11, 2020).

4.10	—	Thirty-Third Supplemental Indenture (5.70% Senior Notes due 2034) dated June 27, 2024, by and among Plains All American Pipeline, L.P., PAA Finance Corp. and U.S. Bank Trust Company, National Association, as trustee (incorporated by reference to Exhibit 4.1 to PAA’s Current Report on Form 8-K filed June 27, 2024).

4.11	—	Thirty-Fourth Supplemental Indenture (5.950% Senior Notes due 2035) dated January 15, 2025, by and among Plains All American Pipeline, L.P., PAA Finance Corp. and U.S. Bank Trust Company, National Association, as trustee (incorporated by reference to Exhibit 4.1 to PAA’s Current Report on Form 8-K filed January 15, 2025).

4.12	—	Thirty-Fifth Supplemental Indenture (4.70% Senior Notes due 2031) dated September 8, 2025, by and among Plains All American Pipeline, L.P., PAA Finance Corp. and U.S. Bank Trust Company, National Association, as trustee (incorporated by reference to Exhibit 4.1 to PAA’s Current Report on Form 8-K filed September 8, 2025).

4.13	—	Thirty-Sixth Supplemental Indenture (5.60% Senior Notes due 2036) dated September 8, 2025, by and among Plains All American Pipeline, L.P., PAA Finance Corp. and U.S. Bank Trust Company, National Association, as trustee (incorporated by reference to Exhibit 4.3 to PAA’s Current Report on Form 8-K filed September 8, 2025).

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4.14	—	Shareholder and Registration Rights Agreement dated October 21, 2013 by and among Plains GP Holdings, L.P. and the other parties signatory thereto (incorporated by reference to Exhibit 4.1 to our Current Report on Form 8-K filed October 25, 2013).

4.15	—	Description of Our Securities (incorporated by reference to Exhibit 4.15 to our Annual Report on Form 10-K for the year ended December 31, 2024).

10.1	—	Credit Agreement dated as of June 12, 2026, among Plains All American Pipeline, L.P., Plains Marketing, L.P. and Plains Canada Liquid Pipelines ULC, as Borrowers; certain subsidiaries of Plains All American Pipeline, L.P. from time to time party thereto, as Designated Borrowers; Bank of America, N.A., as Administrative Agent and Swing Line Lender; Bank of America, N.A., PNC Bank, National Association and Wells Fargo Bank, National Association, as L/C Issuers; and the other Lenders party thereto (incorporated by reference to Exhibit 10.1 to our Current Report on Form 8-K filed June 17, 2026).

31.1 †	—	Certification of Principal Executive Officer pursuant to Exchange Act Rules 13a-14(a) and 15d-14(a).

31.2 †	—	Certification of Principal Financial Officer pursuant to Exchange Act Rules 13a-14(a) and 15d-14(a).

32.1 ††	—	Certification of Principal Executive Officer pursuant to 18 U.S.C. 1350.

32.2 ††	—	Certification of Principal Financial Officer pursuant to 18 U.S.C. 1350.

101.INS†	—	XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.

101.SCH†	—	Inline XBRL Taxonomy Extension Schema Document

101.CAL†	—	Inline XBRL Taxonomy Extension Calculation Linkbase Document

101.DEF†	—	Inline XBRL Taxonomy Extension Definition Linkbase Document

101.LAB†	—	Inline XBRL Taxonomy Extension Label Linkbase Document

101.PRE†	—	Inline XBRL Taxonomy Extension Presentation Linkbase Document

104†	—	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)

* Certain information has been omitted from this exhibit as such omitted information is both (i) not material and (ii) the

type of information that the registrant treats as private or confidential.

† Filed herewith.

†† Furnished herewith.

Table of Contents

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.


	PLAINS GP HOLDINGS, L.P.

	By:	PAA GP HOLDINGS LLC,
		its general partner

	By:	/s/ Willie Chiang
		Willie Chiang,
		Chairman of the Board, Chief Executive Officer and President of PAA GP Holdings LLC
		(Principal Executive Officer)

August 7, 2026

	By:	/s/ Al Swanson
		Al Swanson,
		Executive Vice President and Chief Financial Officer of PAA GP Holdings LLC
		(Principal Financial Officer)

August 7, 2026

	By:	/s/ Chris Herbold
		Chris Herbold,
		Senior Vice President, Finance and Chief Accounting Officer of PAA GP Holdings LLC
		(Principal Accounting Officer)

August 7, 2026