KINDER MORGAN, INC. 10-Q

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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 March 31, 2026

☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from _____to_____

Commission file number: 001-35081

KINDER MORGAN, INC.

(Exact name of registrant as specified in its charter)


Delaware			80-0682103
(State or other jurisdiction of incorporation or organization)			(I.R.S. Employer Identification No.)

1001 Louisiana Street, Suite 1000, Houston, Texas 77002

(Address of principal executive offices)(zip code)

Registrant’s telephone number, including area code: 713-369-9000

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 P Common Stock	KMI	New York Stock Exchange
2.250% Senior Notes due 2027	KMI 27 A	New York Stock Exchange

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 þ 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 (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes þ 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,” “non-accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer þ 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 þ

As of April 23, 2026, the registrant had 2,224,825,757 shares of Class P common stock outstanding.

KINDER MORGAN, INC. AND SUBSIDIARIES

TABLE OF CONTENTS


			Page Number
	Glossary		2
	Information Regarding Forward-Looking Statements		3
	PART I. FINANCIAL INFORMATION
Item 1.	Financial Statements (Unaudited)
	Consolidated Statements of Income - Three Months Ended March 31 , 202 6 and 2025		4
	Consolidated Statements of Comprehensive Income - Thr ee Months Ended March 31 , 202 6 and 2025		5
	Consolidated Balance Sheets - as of March 31, 2026 and December 31, 2025		6
	Consolidated Statements of Cash Flows - Three M onths Ended March 31, 202 6 and 2025		7
	Consolidated Statements of Stockholders’ Equity - Three Months Ended March 31 , 202 6 and 2025		9
	Notes to Consolidated Financial Statements		10
	Note 1 .	General	10
	Note 2.	Acquisitions	11
	Note 3.	Debt	12
	Note 4.	Stockholders’ Equity	13
	Note 5.	Risk Management	14
	Note 6.	Revenue Recognition	18
	Note 7.	Reportable Segments	20
	Note 8.	Income Taxes	22
	Note 9.	Litigation and Environmental	22
	Note 10.	Recent Accounting Pronouncements	26
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations
	General and Basis of Presentation		27
	Results of Operations		27
	Overview		27
	Consolidated Earnings Results		30
	Non-GAAP Financial Measures		32
	Segment Earnings Results		34
	Liquidity and Capital Resources		41
	Summarized Combined Financial Information for Guarantee of Securities of Subsidiaries		45
Item 3.	Quantitative and Qualitative Disclosures About Market Risk		46
Item 4.	Controls and Procedures		46
	PART II. OTHER INFORMATION
Item 1.	Legal Proceedings		46
Item 1A.	Risk Factors		46
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds		46
Item 3.	Defaults Upon Senior Securities		46
Item 4.	Mine Safety Disclosures		46
Item 5.	Other Information		46
Item 6.	Exhibits		47
	Signature		48

KINDER MORGAN, INC. AND SUBSIDIARIES

GLOSSARY

Company Abbreviations

KMBT

Kinder Morgan Bulk Terminals, Inc.

KMLT

Kinder Morgan Liquid Terminals, LLC

KMI

Kinder Morgan, Inc. and its majority-owned and/or controlled subsidiaries

TGP

Tennessee Gas Pipeline Company, L.L.C.

Unless the context otherwise requires, references to “we,” “us,” “our,” or “the Company” are intended to mean Kinder Morgan, Inc. and its majority-owned and/or controlled subsidiaries.

Common Industry and Other Terms

per day

LNG

liquefied natural gas

Bbl

barrels

MBbl

thousand barrels

BBtu

billion British Thermal Units

MMBbl

million barrels

Bcf

billion cubic feet

MMtons

million tons

CERCLA

Comprehensive Environmental Response, Compensation and Liability Act

NGL

natural gas liquids

NYMEX

New York Mercantile Exchange

CO2

carbon dioxide or our CO2 business segment

OTC

over-the-counter

DD&A

depreciation, depletion and amortization

RIN

Renewable Identification Number

EPA

U.S. Environmental Protection Agency

RNG

Renewable natural gas

FASB

Financial Accounting Standards Board

ROU

Right-of-Use

GAAP

U.S. Generally Accepted Accounting Principles

U.S.

United States of America

Information Technology

WTI

West Texas Intermediate

LLC

limited liability company

Information Regarding Forward-Looking Statements

This report includes forward-looking statements. These forward-looking statements are identified as any statement that does not relate strictly to historical or current facts. They use words such as “anticipate,” “believe,” “intend,” “plan,” “projection,” “forecast,” “strategy,” “outlook,” “continue,” “estimate,” “expect,” “may,” “will,” “shall,” or the negative of those terms or other variations of them or comparable terminology. In particular, expressed or implied statements concerning future actions, conditions or events, future operating results or the ability to generate revenues, income or cash flow, service debt or pay dividends, are forward-looking statements. Forward-looking statements in this report include, among others, express or implied statements pertaining to: long-term demand for our assets and services, our business strategy, expected financial results, dividends, sustaining and discretionary/expansion capital expenditures, our cash requirements and our financing and capital allocation strategy, anticipated impacts of litigation and legal or regulatory developments, and our capital projects, including expected completion timing and benefits of those projects.

Important factors that could cause actual results to differ materially from those expressed in or implied by the forward-looking statements in this report include: the timing and extent of changes in the supply of and demand for the products we transport and handle; repercussions of recent armed conflicts between Israel and Hamas and between the U.S., Israel, and Iran, including commodity price volatility and potential adverse effects on financial and economic conditions; the impact of changes in trade policies and tariffs; and the other risks and uncertainties described in Part I, Item 2. “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” and Part I, Item 3. “Quantitative and Qualitative Disclosures About Market Risk” in this report as well as “Information Regarding Forward-Looking Statements,” Part I, Item 1A. “Risk Factors,” and Part I, Item 7. “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources” in our Annual Report on Form 10-K for the year ended December 31, 2025 (2025 Form 10-K) (except to the extent such information is modified or superseded by information in subsequent reports).

You should keep these risk factors in mind when considering forward-looking statements. These risk factors could cause our actual results to differ materially from those contained in any forward-looking statement. Because of these risks and uncertainties, you should not place undue reliance on any forward-looking statement. We disclaim any obligation, other than as required by applicable law, to publicly update or revise any of our forward-looking statements to reflect future events or developments.

PART I. FINANCIAL INFORMATION

Item 1. Financial Statements.

KINDER MORGAN, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF INCOME

(In millions, except per share amounts, unaudited)


	Three Months Ended March 31,
		2026		2025
Revenues
Services		$	2,525	$	2,360
Commodity sales		2,245		1,836
Other		58		45
Total Revenues		4,828		4,241

Operating Costs, Expenses, and Other
Costs of sales (exclusive of items shown separately below)		1,749		1,476
Operations and maintenance		711		711
Depreciation, depletion, and amortization		633		610
General and administrative		184		187
Taxes, other than income taxes		114		112

Other income, net		(7)		—
Total Operating Costs, Expenses, and Other		3,384		3,096

Operating Income		1,444		1,145

Other Income (Expense)
Earnings from equity investments		254		220


Interest, net		(430)		(451)
Other, net		20		15
Total Other Expense		(156)		(216)

Income Before Income Taxes		1,288		929

Income Tax Expense		(287)		(186)

Net Income		1,001		743






Net Income Attributable to Noncontrolling Interests		(25)		(26)

Net Income Attributable to Kinder Morgan, Inc.		$	976	$	717





Class P Common Stock
Basic and Diluted Earnings Per Share		$	0.44	$	0.32

Basic and Diluted Weighted Average Shares Outstanding		2,225		2,222

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

KINDER MORGAN, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(In millions, unaudited)


	Three Months Ended March 31,
		2026		2025
Net income		$	1,001	$	743
Other comprehensive loss, net of tax
Net unrealized loss from derivative instruments (net of taxes of $56 and $3, respectively)		(199)		(7)
Reclassification into earnings of net derivative instruments loss (gain) to net income (net of taxes of $(6) and $1, respectively)		20		(5)

Benefit plan adjustments (net of taxes of $1 and $—, respectively)		(3)		(2)
Total other comprehensive loss		(182)		(14)

Comprehensive income		819		729
Comprehensive income attributable to noncontrolling interests		(25)		(26)
Comprehensive income attributable to KMI		$	794	$	703

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

KINDER MORGAN, INC. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(In millions, except share and per share amounts, unaudited)


	March 31, 2026		December 31, 2025
ASSETS
Current Assets
Cash and cash equivalents	$	72	$	63
Restricted deposits	108		46
Accounts receivable	1,582		1,714

Inventories	593		574


Other current assets	352		357
Total current assets	2,707		2,754

Property, plant, and equipment, net	39,699		39,331
Investments	7,651		7,532
Goodwill	20,084		20,084
Other intangibles, net	1,686		1,730


Deferred charges and other assets	1,245		1,317
Total Assets	$	73,072	$	72,748

LIABILITIES AND STOCKHOLDERS’ EQUITY
Current Liabilities
Current portion of debt	$	2,186	$	1,226
Accounts payable	1,366		1,408

Accrued interest	339		534
Accrued taxes	198		256


Other current liabilities	1,093		898
Total current liabilities	5,182		4,322

Long-term liabilities and deferred credits
Long-term debt
Outstanding	29,719		30,597

Debt fair value adjustments	151		180
Total long-term debt	29,870		30,777
Deferred income taxes	3,120		2,891

Other long-term liabilities and deferred credits	2,317		2,309

Total long-term liabilities and deferred credits	35,307		35,977
Total Liabilities	40,489		40,299
Commitments and contingencies (Notes 3 and 9)
Stockholders’ Equity

Class P Common Stock, $0.01 par value, 4,000,000,000 shares authorized, 2,224,809,827 and 2,224,777,750 shares, respectively, issued and outstanding	22		22
Additional paid-in capital	41,296		41,276
Accumulated deficit	(9,859)		(10,181)
Accumulated other comprehensive (loss)/income	(137)		45
Total Kinder Morgan, Inc.’s stockholders’ equity	31,322		31,162
Noncontrolling interests	1,261		1,287
Total Stockholders’ Equity	32,583		32,449
Total Liabilities and Stockholders’ Equity	$	73,072	$	72,748

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


KINDER MORGAN, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(In millions, unaudited)

	Three Months Ended March 31,
	2026		2025
Cash Flows From Operating Activities
Net income	$	1,001	$	743
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation, depletion, and amortization	633		610
Deferred income taxes	281		167
Change in fair value of derivative contracts	86		82


Earnings from equity investments	(254)		(220)
Distributions of equity investment earnings	150		185
Changes in components of working capital
Accounts receivable	131		45
Inventories	(19)		(22)
Other current assets	(56)		24
Accounts payable	(172)		(57)
Accrued interest, net of interest rate swaps	(192)		(206)
Accrued taxes	(58)		(70)
Other current liabilities	27		(24)


Other, net	(67)		(95)
Net Cash Provided by Operating Activities	1,491		1,162

Cash Flows From Investing Activities
Acquisition of assets (Note 2)	—		(648)
Capital expenditures	(804)		(766)

Contributions to investments	(53)		(42)
Distributions from equity investments in excess of cumulative earnings	46		45
Other, net	8		(3)
Net Cash Used in Investing Activities	(803)		(1,414)

Cash Flows From Financing Activities
Issuances of debt	1,937		2,876
Payments of debt	(1,867)		(1,847)
Debt issue costs	(3)		(3)
Dividends	(654)		(642)



Distributions to noncontrolling interests	(37)		(41)
Other, net	7		(10)
Net Cash (Used in) Provided by Financing Activities	(617)		333


Net Increase in Cash, Cash Equivalents, and Restricted Deposits	71		81
Cash, Cash Equivalents, and Restricted Deposits, beginning of period	109		214
Cash, Cash Equivalents, and Restricted Deposits, end of period	$	180	$	295


KINDER MORGAN, INC. AND SUBSIDIARIES (Continued)
CONSOLIDATED STATEMENTS OF CASH FLOWS
(In millions, unaudited)

	Three Months Ended March 31,
	2026		2025
Non-cash Investing and Financing Activities
ROU assets and operating lease obligations recognized including adjustments	$	33	$	2

Net increase in property, plant, and equipment from both accruals and contractor retainage	133
Supplemental Disclosures of Cash Flow Information
Cash paid during the period for interest (net of capitalized interest)	623		657
Cash (refund) paid during the period for income taxes, net	(3)		3

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

KINDER MORGAN, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY

(In millions, unaudited)


	Common stock			Additional paid-in capital		Accumulated deficit		Accumulated other comprehensive income/(loss)		Stockholders’ equity attributable to KMI		Non- controlling interests		Total
	Issued shares	Par value
Balance at December 31, 2025	2,225	$	22	$	41,276	$	(10,181)	$	45	$	31,162	$	1,287	$	32,449





Stock awards				20						20				20
Net income						976				976		25		1,001
Dividends						(654)				(654)				(654)
Distributions										—		(37)		(37)


Other										—		(14)		(14)
Other comprehensive loss								(182)		(182)				(182)
Balance at March 31, 2026	2,225	$	22	$	41,296	$	(9,859)	$	(137)	$	31,322	$	1,261	$	32,583


	Common stock			Additional paid-in capital		Accumulated deficit		Accumulated other comprehensive loss		Stockholders’ equity attributable to KMI		Non- controlling interests		Total
	Issued shares	Par value
Balance at December 31, 2024	2,222	$	22	$	41,237	$	(10,633)	$	(95)	$	30,531	$	1,336	$	31,867





Stock awards				13						13				13
Net income						717				717		26		743
Dividends						(642)				(642)				(642)
Distributions										—		(41)		(41)



Other comprehensive loss								(14)		(14)				(14)
Balance at March 31, 2025	2,222	$	22	$	41,250	$	(10,558)	$	(109)	$	30,605	$	1,321	$	31,926

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

KINDER MORGAN, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1. General

Organization

We are one of the largest energy infrastructure companies in North America. We own an interest in or operate approximately 78,000 miles of pipelines, 136 terminals, over 700 Bcf of working natural gas storage capacity, and RNG generation capacity of approximately 6.9 Bcf per year of gross production. Our pipelines transport natural gas, refined petroleum products, crude oil, condensate, CO2, renewable fuels, and other products, and our terminals store and handle various commodities including gasoline, diesel fuel, jet fuel, chemicals, metals, petroleum coke, and ethanol and other renewable fuels and feedstocks.

Basis of Presentation

General

Our accompanying unaudited consolidated financial statements have been prepared under the rules and regulations of the U.S. Securities and Exchange Commission (SEC). These rules and regulations conform to the accounting principles contained in the FASB’s Accounting Standards Codification (ASC), the single source of GAAP. In compliance with such rules and regulations, all significant intercompany items have been eliminated in consolidation.

In our opinion, all adjustments, which are of a normal and recurring nature, considered necessary for a fair statement of our financial position and operating results for the interim periods have been included in the accompanying consolidated financial statements, and certain amounts from prior periods have been reclassified to conform to the current presentation. Interim results are not necessarily indicative of results for a full year; accordingly, you should read these consolidated financial statements in conjunction with our consolidated financial statements and related notes included in our 2025 Form 10-K.

The accompanying unaudited consolidated financial statements include our accounts and the accounts of our subsidiaries over which we have control or are the primary beneficiary. We evaluate our financial interests in business enterprises to determine if they represent variable interest entities where we are the primary beneficiary. If such criteria are met, we consolidate the financial statements of such businesses with those of our own.

Earnings per Share (EPS)

The following table sets forth net income allocated to common stockholders and EPS, calculated using the two-class method:


	Three Months Ended March 31,
		2026		2025
		(In millions, except per share amounts)
Net Income Available to Stockholders		$	976	$	717
Less: Net Income Allocated to Participating Securities(a)		(5)		(4)
Net Income Allocated to Common Stockholders		$	971	$	713

Basic and Diluted Weighted Average Shares Outstanding(b)		2,225		2,222
Basic and Diluted EPS(b)		$	0.44	$	0.32

(a)Participating securities consist of unvested stock awards issued to employees and non-employee directors. These awards receive dividend equivalents but do not share in net losses or distributions in excess of earnings.

(b)For all periods presented, diluted EPS is equal to basic EPS, as our potential common stock equivalents are antidilutive.

The following potential common stock equivalents are excluded from the determination of diluted EPS:


	Three Months Ended March 31,
		2026	2025
		(In millions on a weighted average basis)
Unvested stock awards		12	13
Convertible trust preferred securities		3	3

2. Acquisitions

As of March 31, 2026, our allocation of purchase price by acquisition is detailed below:


					Assignment of Purchase Price
Ref	Date	Acquisition	Purchase price		Current assets		Property, plant, & equipment		Other long-term assets		Current liabilities		Long-term liabilities		Resulting goodwill
			(In millions)
(1)	2/25	Outrigger Energy	$	648	$	16	$	497	$	160	$	(5)	$	(20)	$	—

(1) Outrigger Energy Acquisition

On February 18, 2025, we completed the acquisition of a natural gas gathering and processing system in North Dakota from Outrigger Energy II LLC for a purchase price of $648 million, including purchase price adjustments for working capital. Other long-term assets within the purchase price allocation consists of customer relationships intangible with a weighted average amortization period of approximately 15 years. The acquisition includes a 0.27 Bcf/d processing facility and a 104-mile, large-diameter, high-pressure rich gas gathering header pipeline with 0.35 Bcf/d of capacity connecting supplies from the Williston Basin area to high-demand markets. The acquired assets are included in our Natural Gas Pipelines business segment.

Pro Forma Information

Pro forma consolidated income statement information that gives effect to the above acquisition as if it had occurred as of January 1 of the year preceding the transaction is not presented because it would not be materially different from the information presented in our accompanying consolidated statements of income.

Subsequent Event

On April 22, 2026, we announced that we have entered into an agreement to acquire Monument Pipeline, a natural gas pipeline system serving Houston, Texas and the surrounding metropolitan area, for $505 million in cash consideration, subject to customary purchase price adjustments. The acquisition includes approximately 225 miles of pipelines and provides transportation and storage services to gas utilities, LNG shippers, and industrial customers. The transaction is expected to close in the second quarter of 2026.

3. Debt

The following table provides information on the principal amount of our outstanding debt balances:


	March 31, 2026		December 31, 2025
	(In millions, unless otherwise stated)
Current portion of debt
$3.5 billion credit facility due August 20, 2027	$	—	$	—
Commercial paper notes(a)	88		13
Current portion of senior notes
4.15%, due August 2026	375		375
1.75%, due November 2026	500		500
7.50%, due November 2026	200		200
6.70%, due February 2027	7		—
2.25%, due March 2027(b)	578		—
7.00%, due March 2027	300		—
Trust I preferred securities, 4.75%, due March 2028(c)	111		111
Current portion of other debt	27		27
Total current portion of debt	2,186		1,226

Long-term debt (excluding current portion)
Senior notes	29,170		30,065
EPC Building, LLC, promissory note, 3.967%, due 2026 through 2035	263		268

Trust I preferred securities, 4.75%, due March 2028	110		110
Other	176		154
Total long-term debt	29,719		30,597
Total debt(d)	$	31,905	$	31,823

(a)Weighted average interest rate on borrowings at March 31, 2026 and December 31, 2025 was 3.95% and 3.85%, respectively.

(b)Consists of senior notes denominated in Euros that have been converted to U.S. dollars and are respectively reported above at the March 31, 2026 exchange rate of $1.1553 U.S. dollars per Euro and at the December 31, 2025 exchange rate of $1.1746 U.S. dollars per Euro. As of March 31, 2026 and December 31, 2025, the cumulative changes in the exchange rate of U.S. dollars per Euro since issuance had resulted in an increase of $35 million and $44 million, respectively. As of March 31, 2026, we had outstanding associated cross-currency swap agreements which are designated as cash flow hedges.

(c)Reflects the portion of cash consideration payable if all the outstanding securities as of the end of the reporting period were converted by the holders.

(d)Excludes our “Debt fair value adjustments” which, as of March 31, 2026 and December 31, 2025, increased our total debt balances by $151 million and $180 million, respectively.

We and substantially all of our wholly owned domestic subsidiaries are parties to a cross guarantee agreement whereby each party to the agreement unconditionally guarantees, jointly and severally, the payment of specified indebtedness of each other party to the agreement.

Credit Facilities and Restrictive Covenants

As of March 31, 2026, we had no borrowings outstanding under our credit facility, $88 million borrowings outstanding under our commercial paper program, and $10 million in letters of credit. Our availability under our credit facility as of March 31, 2026 was approximately $3.4 billion. For the periods ended March 31, 2026 and 2025, we were in compliance with all required covenants.

Fair Value of Financial Instruments

The carrying value and estimated fair value of our outstanding debt balances are disclosed below:


	March 31, 2026				December 31, 2025
	Carrying value		Estimated fair value(a)		Carrying value		Estimated fair value(a)
	(In millions)
Total debt	$	32,056	$	31,694	$	32,003	$	31,966

(a)Included in the estimated fair value are amounts for our Trust I Preferred Securities of $217 million as of both March 31, 2026 and December 31, 2025.

We used Level 2 input values to measure the estimated fair value of our outstanding debt balance as of both March 31, 2026 and December 31, 2025.

4. Stockholders’ Equity

Class P Common Stock

Dividends

The following table provides information about our per share dividends:


	Three Months Ended March 31,
		2026		2025
Per share cash dividend declared for the period		$	0.2975	$	0.2925
Per share cash dividend paid in the period		0.2925		0.2875

On April 22, 2026, our board of directors declared a cash dividend of $0.2975 per share for the quarterly period ended March 31, 2026, which is payable on May 15, 2026 to shareholders of record as of the close of business on May 4, 2026.

Accumulated Other Comprehensive Loss

Changes in the components of our “Accumulated other comprehensive loss” not including noncontrolling interests are summarized as follows:


	Net unrealized gains/(losses) on cash flow hedge derivatives		Pension and other postretirement liability adjustments		Total accumulated other comprehensive loss
	(In millions)
Balance as of December 31, 2025	$	67	$	(22)	$	45
Other comprehensive loss before reclassifications	(199)		(3)		(202)
Loss reclassified from accumulated other comprehensive loss	20		—		20
Net current-period change in accumulated other comprehensive loss	(179)		(3)		(182)
Balance as of March 31, 2026	$	(112)	$	(25)	$	(137)


	Net unrealized gains/(losses) on cash flow hedge derivatives		Pension and other postretirement liability adjustments		Total accumulated other comprehensive loss
	(In millions)
Balance as of December 31, 2024	$	(33)	$	(62)	$	(95)
Other comprehensive loss before reclassifications	(7)		(2)		(9)
Gain reclassified from accumulated other comprehensive loss	(5)		—		(5)
Net current-period change in accumulated other comprehensive loss	(12)		(2)		(14)
Balance as of March 31, 2025	$	(45)	$	(64)	$	(109)

5. Risk Management

Certain of our business activities expose us to risks associated with unfavorable changes in the market price of natural gas, NGL, and crude oil. We also have exposure to interest rate and foreign currency risk as a result of the issuance of our debt obligations. Pursuant to our management’s approved risk management policy, we use derivative contracts to hedge or reduce our exposure to some of these risks.

Energy Commodity Price Risk Management

As of March 31, 2026, we had the following outstanding commodity forward contracts to hedge our forecasted energy commodity purchases and sales:


	Net open position long/(short)
Derivatives designated as hedging contracts
Crude oil fixed price	(15.1)	MMBbl




Derivatives not designated as hedging contracts
Crude oil fixed price	(0.9)	MMBbl
Crude oil basis	(3.5)	MMBbl
Natural gas fixed price	(59.5)	Bcf
Natural gas basis	(131.8)	Bcf
NGL fixed price	(1.7)	MMBbl

As of March 31, 2026, the maximum length of time over which we have hedged, for accounting purposes, our exposure to the variability in future cash flows associated with energy commodity price risk is through December 2028.

Interest Rate Risk Management

We utilize interest rate derivatives to hedge our exposure to both changes in the fair value of our fixed rate debt instruments and variability in expected future cash flows attributable to variable interest rate payments. The following table summarizes our outstanding interest rate contracts as of March 31, 2026:

Notional amount

Accounting treatment

Maximum term

(In millions)

Derivatives designated as hedging instruments

Fixed-to-variable interest rate contracts(a)

3,750

Fair value hedge

February 2041

(a)The principal amount of hedged senior notes is included in “Long-term debt” on our accompanying consolidated balance sheets.

Foreign Currency Risk Management

We utilize foreign currency derivatives to hedge our exposure to variability in foreign exchange rates. The following table summarizes our outstanding foreign currency contracts as of March 31, 2026:

Notional amount

Accounting treatment

Maturity

(In millions)

Derivatives designated as hedging instruments

EUR-to-USD cross currency swap contracts(a)

543

Cash flow hedge

March 2027

(a)These swaps eliminate the foreign currency risk associated with our Euro-denominated debt which matures in March 2027.

Impact of Derivative Contracts on Our Consolidated Financial Statements

The following table summarizes the fair values of our derivative contracts included on our accompanying consolidated balance sheets:


Fair Value of Derivative Contracts
	Location	Derivatives Asset				Derivatives Liability
		March 31, 2026		December 31, 2025		March 31, 2026		December 31, 2025
		(In millions)
Derivatives designated as hedging instruments
Energy commodity derivative contracts
	Other current assets/(Other current liabilities)	$	—	$	56	$	(110)	$	—
	Deferred charges and other assets/(Other long-term liabilities and deferred credits)	—		36		(28)		—
	Subtotal	—		92		(138)		—
Interest rate contracts
	Other current assets/(Other current liabilities)	4		4		(37)		(25)
	Deferred charges and other assets/(Other long-term liabilities and deferred credits)	27		32		(112)		(111)
	Subtotal	31		36		(149)		(136)
Foreign currency contracts
	Other current assets/(Other current liabilities)	29		—		—		(2)
	Deferred charges and other assets/(Other long-term liabilities and deferred credits)	—		41		—		—
	Subtotal	29		41		—		(2)
	Total	60		169		(287)		(138)

Derivatives not designated as hedging instruments
Energy commodity derivative contracts
	Other current assets/(Other current liabilities)	45		75		(116)		(74)
	Deferred charges and other assets/(Other long-term liabilities and deferred credits)	4		4		(13)		(1)





	Total	49		79		(129)		(75)
	Total derivatives	$	109	$	248	$	(416)	$	(213)

The following two tables summarize the fair value measurements of our derivative contracts based on the three levels established by the ASC. The tables also identify the impact of derivative contracts which we have elected to present on our accompanying consolidated balance sheets on a gross basis that are eligible for netting under master netting agreements.


	Balance sheet asset fair value measurements by level								Contracts available for netting		Cash collateral held(a)
	Level 1		Level 2		Level 3		Gross amount						Net amount
	(In millions)
As of March 31, 2026
Energy commodity derivative contracts(b)	$	30	$	19	$	—	$	49	$	(40)	$	—	$	9
Interest rate contracts	—		31		—		31		(7)		—		24
Foreign currency contracts	—		29		—		29		—		—		29
As of December 31, 2025
Energy commodity derivative contracts(b)	$	20	$	151	$	—	$	171	$	(68)	$	—	$	103
Interest rate contracts	—		36		—		36		(6)		—		30
Foreign currency contracts	—		41		—		41		—		—		41


	Balance sheet liability fair value measurements by level								Contracts available for netting		Cash collateral posted(a)
	Level 1		Level 2		Level 3		Gross amount						Net amount
	(In millions)
As of March 31, 2026
Energy commodity derivative contracts(b)	$	(10)	$	(257)	$	—	$	(267)	$	40	$	52	$	(175)
Interest rate contracts	—		(149)		—		(149)		7		—		(142)

As of December 31, 2025
Energy commodity derivative contracts(b)	$	(12)	$	(63)	$	—	$	(75)	$	68	$	(2)	$	(9)
Interest rate contracts	—		(136)		—		(136)		6		—		(130)
Foreign currency contracts	—		(2)		—		(2)		—		—		(2)

(a)Any cash collateral paid or received is reflected in this table, but only to the extent that it represents variation margins. Any amount associated with derivative prepayments or initial margins that are not influenced by the derivative asset or liability amounts or those that are determined solely on their volumetric notional amounts are excluded from this table.

(b)Level 1 consists primarily of NYMEX natural gas futures. Level 2 consists primarily of OTC WTI swaps, NGL swaps, and crude oil basis swaps.

The following tables summarize the pre-tax impact of our derivative contracts on our accompanying consolidated statements of income and comprehensive income:


Derivatives in fair value hedging relationships	Location		Gain/(loss) recognized in income on derivatives and related hedged item
		Three Months Ended March 31,
			2026		2025
			(In millions)
Interest rate contracts	Interest, net		$	(17)	$	80

Hedged fixed rate debt(a)	Interest, net		$	16	$	(79)

(a)As of March 31, 2026, the cumulative amount of fair value hedging adjustments resulted in a decrease of $117 million in the carrying value of our hedged fixed rate debt balance and is included in “Debt fair value adjustments” on our accompanying consolidated balance sheet.


Derivatives in cash flow hedging relationships	Gain/(loss) recognized in OCI on derivatives(a)				Location	Gain/(loss) reclassified from Accumulated OCI into income
	Three Months Ended March 31,					Three Months Ended March 31,
	2026		2025			2026		2025
	(In millions)					(In millions)
Energy commodity derivative contracts	$	(246)	$	(30)	Revenues—Commodity sales	$	(16)	$	(16)

					Costs of sales	—		(1)


Foreign currency contracts	(9)		20		Other, net	(10)		23
Total	$	(255)	$	(10)	Total	$	(26)	$	6

(a)We expect to reclassify an approximate $70 million loss associated with cash flow hedge price risk management activities included in our accumulated other comprehensive loss balance as of March 31, 2026 into earnings during the next twelve months (when the associated forecasted transactions are also expected to impact earnings); however, actual amounts reclassified into earnings could vary materially as a result of changes in market prices.


Derivatives not designated as accounting hedges	Location		Gain/(loss) recognized in income on derivatives
		Three Months Ended March 31,
			2026		2025
			(In millions)
Energy commodity derivative contracts	Revenues—Commodity sales		$	(11)	$	3
	Costs of sales		(105)		(84)
	Earnings from equity investments		1		(2)
Interest rate contracts	Interest, net		—		(2)
Total(a)			$	(115)	$	(85)

(a)The amounts for the three months ended March 31, 2026 and 2025 include approximate losses of $31 million and $1 million, respectively, associated with natural gas, crude, and NGL derivative contract settlements.

Credit Risks

In conjunction with certain derivative contracts, we are required to provide collateral to our counterparties, which may include posting letters of credit or placing cash in margin accounts. As of March 31, 2026 and December 31, 2025, we had no outstanding letters of credit supporting our commodity price risk management program. As of March 31, 2026 and December 31, 2025, we had cash margins of $94 million and $24 million, respectively, posted with our counterparties by us and reported within “Restricted deposits” on our accompanying consolidated balance sheets. The cash margin balance at March 31, 2026 represents the initial margin requirements of $42 million and variation margin requirements of $52 million. We also use industry standard commercial agreements that allow for the netting of exposures associated with transactions executed under a single commercial agreement. Additionally, we generally utilize master netting agreements to offset credit exposure across multiple commercial agreements with a single counterparty.

We also have agreements with certain counterparties to our derivative contracts that contain provisions requiring the posting of additional collateral upon a decrease in our credit rating. As of March 31, 2026, based on our current mark-to-market positions and posted collateral, we estimate that if our credit rating were downgraded one or two notches, we would not be required to post additional collateral.

6. Revenue Recognition

Disaggregation of Revenues

The following tables present our revenues disaggregated by segment, revenue source, and type of revenue for each revenue source:


	Three Months Ended March 31, 2026
	Natural Gas Pipelines		Products Pipelines		Terminals		CO2		Corporate and Eliminations		Total
	(In millions)
Revenues from contracts with customers(a)
Services
Firm services	$	1,147	$	61	$	253	$	—	$	(1)	$	1,460
Fee-based services	330		264		101		14		(2)		707
Total services	1,477		325		354		14		(3)		2,167
Commodity sales
Natural gas sales	1,437		—		—		19		(2)		1,454
Product sales	215		312		18		243		(2)		786
Other sales	16		—		—		29		(1)		44
Total commodity sales	1,668		312		18		291		(5)		2,284
Total revenues from contracts with customers	3,145		637		372		305		(8)		4,451
Other revenues
Leasing services(b)	110		44		193		17		—		364
Derivatives adjustments on commodity sales	12		(1)		—		(38)		—		(27)
Other	29		7		—		4		—		40
Total other revenues	151		50		193		(17)		—		377
Total revenues	$	3,296	$	687	$	565	$	288	$	(8)	$	4,828


	Three Months Ended March 31, 2025
	Natural Gas Pipelines		Products Pipelines		Terminals		CO2		Corporate and Eliminations		Total
	(In millions)
Revenues from contracts with customers(a)
Services
Firm services	$	1,073	$	53	$	217	$	—	$	(1)	$	1,342
Fee-based services	301		257		101		10		(1)		668
Total services	1,374		310		318		10		(2)		2,010
Commodity sales
Natural gas sales	980		—		—		16		(2)		994
Product sales	262		301		16		243		(2)		820
Other sales	7		—		—		31		—		38
Total commodity sales	1,249		301		16		290		(4)		1,852
Total revenues from contracts with customers	2,623		611		334		300		(6)		3,862
Other revenues
Leasing services(b)	112		45		184		17		—		358
Derivatives adjustments on commodity sales	(3)		—		—		(10)		—		(13)
Other	22		7		—		5		—		34
Total other revenues	131		52		184		12		—		379
Total revenues	$	2,754	$	663	$	518	$	312	$	(6)	$	4,241

(a)Differences between the revenue presentation on the consolidated statements of income and the disaggregated revenues by type above are primarily attributable to revenues reflected in the “Other revenues” category above.

(b)Our revenues from leasing services are comprised of operating leases whereby we convey the right to control the use of an identified asset to a customer, including tanks, treating facilities, marine vessels, and gas equipment and pipelines with separate control locations.

Contract Balances

As of March 31, 2026 and December 31, 2025, our contract asset balances were $23 million and $30 million, respectively, and our contract liability balances were $526 million and $459 million, respectively. Of the December 31, 2025 contract asset and liability balances, $14 million was transferred to accounts receivable and $50 million was recognized as revenue during the three months ended March 31, 2026, respectively.

In addition, we had a lease contract liability balance associated with prepaid fixed reservation charges relating to contracts expiring from 2035 to 2040, under a long-term terminal services contract totaling $517 million and $531 million as of March 31, 2026 and December 31, 2025, respectively.

Revenue Allocated to Remaining Performance Obligations

The following table presents our estimated revenue related to unsatisfied performance obligations representing fixed consideration primarily related to commodity sales or service contracts with take-or-pay or minimum volume commitments that we expect to recognize in future periods:

Based on the practical expedient we elected to apply, the amounts presented in the table above exclude remaining performance obligations for variable consideration related to contracts with index-based pricing or variable volume attributes in which such variable consideration is allocated entirely to a wholly unsatisfied performance obligation.

7. Reportable Segments

Our reportable segments are strategic business units that offer different products and services, have different marketing strategies, and are managed separately. The Company’s chief operating decision maker (CODM) is represented by the Office of the Chairman which consists of our Executive Chairman, Chief Executive Officer, and President. Our CODM evaluates performance principally based on each reportable segment’s earnings before DD&A expenses (EBDA), which excludes general and administrative expenses and corporate charges, interest expense, net, and income tax expense. The CODM uses budgeted Segment EBDA compared to actual results to evaluate performance and allocate certain resources for each segment.

We consider each period’s earnings before all non-cash DD&A expenses to be an important measure of business segment performance for our reporting segments. We account for intersegment sales at market prices, while we account for asset transfers at book value.

Financial information by segment follows:


	Three Months Ended March 31, 2026
	Reportable Segments
	Natural Gas Pipelines		Products Pipelines		Terminals		CO2		Corporate and Eliminations		Total
	(In millions)
Revenues
Revenues from external customers	$	3,291	$	687	$	562	$	288	$	—	$	4,828
Intersegment revenues	5		—		3		—		(8)		—
Total revenues	3,296		687		565		288		(8)		4,828
Costs of sales	(1,431)		(281)		(16)		(28)
Labor	(86)		(34)		(69)		(13)
Fuel and power	(26)		(20)		(5)		(25)
Field - non-labor(a)	(199)		(40)		(137)		(57)

Taxes, other than income taxes	(79)		(10)		(12)		(11)
Earnings (loss) from equity investments	225		18		3		8
Other segment items(b)	11		—		—		6

Total Segment EBDA(c)	$	1,711	$	320	$	329	$	168			2,528
DD&A											(633)

General and administrative and corporate charges											(177)
Interest, net(d)											(430)
Income tax expense											(287)
Net income											$	1,001

Other segment activity information:
DD&A	$	297	$	84	$	131	$	114	$	7	$	633
Capital expenditures	610		38		70		63		23		804


	Three Months Ended March 31, 2025
	Reportable Segments
	Natural Gas Pipelines		Products Pipelines		Terminals		CO2		Corporate and Eliminations		Total
	(In millions)
Revenues
Revenues from external customers	$	2,750	$	663	$	516	$	312	$	—	$	4,241
Intersegment revenues	4		—		2		—		(6)		—
Total revenues	2,754		663		518		312		(6)		4,241
Costs of sales	(1,145)		(293)		(15)		(27)
Labor	(80)		(32)		(70)		(12)
Fuel and power	(19)		(21)		(6)		(32)
Field - non-labor(a)	(191)		(48)		(140)		(53)

Taxes, other than income taxes	(72)		(12)		(13)		(13)
Earnings from equity investments	196		16		2		6
Other segment items(b)	10		—		(1)		—

Total Segment EBDA(e)	$	1,453	$	273	$	275	$	181			2,182
DD&A											(610)

General and administrative and corporate charges											(192)
Interest, net(d)											(451)
Income tax expense											(186)
Net income											$	743

Other segment activity information:
DD&A	$	287	$	96	$	129	$	93	$	5	$	610
Capital expenditures	493		81		76		97		19		766


	Reportable Segments
	Natural Gas Pipelines		Products Pipelines		Terminals		CO2		Corporate and Eliminations		Total
	(In millions)
Segment balance sheet information:
As of March 31, 2026
Investments	$	7,080	$	381	$	122	$	68	$	—	$	7,651
Other intangibles, net	884		387		12		403		—		1,686
Total assets(f)	52,934		8,073		7,871		3,500		694		73,072
As of December 31, 2025
Investments	$	6,962	$	381	$	122	$	67	$	—	$	7,532
Other intangibles, net	900		403		13		414		—		1,730
Total assets(f)	52,546		8,044		7,917		3,608		633		72,748

(a)Includes outside services, pipeline integrity maintenance, materials and supplies, and other operating costs.

(b)Includes miscellaneous operating and non-operating items primarily related to allowance for equity funds used during construction.

(c)Includes non-cash risk management activities amounts of $(75) million, $(5) million, $(1) million, and $(21) million for our Natural Gas Pipelines, Products Pipelines, Terminals, and CO2 business segments, respectively.

(d)We do not attribute interest and debt expense to any of our reportable business segments.

(e)Includes non-cash risk management activities amounts of $(80) million, $(1) million, and $(1) million for our Natural Gas Pipelines, Products Pipelines, and CO2 business segments, respectively.

(f)Corporate includes cash and cash equivalents, restricted deposits, certain prepaid assets and deferred charges, risk management assets related to derivative contracts, corporate headquarters in Houston, Texas, and miscellaneous corporate assets (such as IT, telecommunications equipment, and legacy activity) not allocated to our reportable segments.

8. Income Taxes

Income tax expense included on our accompanying consolidated statements of income is as follows:


	Three Months Ended March 31,
		2026			2025
		(In millions, except percentages)
Income tax expense		$	287		$	186
Effective tax rate		22.3		%	20.0		%

The effective tax rate for the three months ended March 31, 2026 is higher than the statutory federal rate of 21% primarily due to state income taxes, partially offset by dividend-received deductions from our investments in Florida Gas Pipeline (Citrus), NGPL Holdings LLC, and Products (SE) Pipe Line Company (PPL).

The effective tax rate for the three months ended March 31, 2025 is lower than the statutory federal rate of 21% primarily due to (i) the recognition of investment tax credits generated by a biogas project and (ii) dividend-received deductions from our investments in Citrus, NGPL Holdings LLC, and PPL, partially offset by state income taxes.

9. Litigation and Environmental

We and our subsidiaries are parties to various legal, regulatory, and other matters arising from the day-to-day operations of our businesses or certain predecessor operations that may result in claims against the Company. Although no assurance can be given, we believe, based on our experiences to date and taking into account accrued liabilities and insurance, that the ultimate resolution of such items will not have a material adverse impact to our financial position, cash flows, or operating results, unless otherwise indicated below. We believe we have numerous and substantial defenses to the matters to which we are a party and intend to vigorously defend the Company. When we determine a loss is probable of occurring and is reasonably estimable, we accrue an undiscounted liability for such contingencies based on our best estimate using information available at that time. If the estimated loss is a range of potential outcomes and there is no better estimate within the range, we accrue the amount at the low end of the range. We disclose the following contingencies where an adverse outcome may be material or, in the judgment of management, we conclude the matter should otherwise be disclosed.

Gulf LNG Facility Disputes

Gulf LNG Energy, LLC and Gulf LNG Pipeline, LLC (GLNG) filed a lawsuit in 2018 against Eni S.p.A. in the Supreme Court of the State of New York to enforce a Guarantee Agreement (Guarantee) entered into by Eni S.p.A. in 2007 in connection with a contemporaneous terminal use agreement entered into by its affiliate, Eni USA Gas Marketing LLC (Eni USA). GLNG filed suit to enforce the Guarantee after an arbitration tribunal delivered an award which called for the termination of the terminal use agreement and payment of compensation by Eni USA to GLNG. In response, Eni S.p.A. filed counterclaims seeking unspecified damages based on the same substantive allegations that were dismissed with prejudice in previous separate arbitrations. In 2022, the trial court granted Eni S.p.A.’s motion for summary judgment on GLNG’s claims to enforce the Guarantee. The Appellate Division denied GLNG’s appeal. GLNG elected not to pursue further recourse on appeal, thereby concluding GLNG’s efforts to enforce the Guarantee. With respect to the counterclaims asserted by Eni S.p.A., the trial court granted GLNG’s motion for summary judgment and dismissed Eni S.p.A.’s claims with prejudice on September 15, 2023. The Appellate Division affirmed the entry of summary judgment in GLNG’s favor. On September 16, 2025, the Court of Appeals denied Eni S.p.A.’s motion for leave to appeal, thereby terminating Eni S.p.A.’s recourse in state court against GLNG. On February 23, 2026, the United States Supreme Court denied Eni S.p.A.’s petition for writ of certiorari, thereby concluding this case.

Freeport LNG Winter Storm Litigation

On September 13, 2021, Freeport LNG Marketing, LLC (Freeport) filed a lawsuit against Kinder Morgan Texas Pipeline LLC and Kinder Morgan Tejas Pipeline LLC in the 133rd District Court of Harris County, Texas (Case No. 2021-58787) alleging that defendants breached the parties’ base contract for sale and purchase of natural gas by failing to repurchase natural

gas nominated by Freeport between February 10-22, 2021 during Winter Storm Uri. We deny that we were obligated to repurchase natural gas from Freeport given our declaration of force majeure during the storm and our compliance with emergency orders issued by the Railroad Commission of Texas providing heightened priority for the delivery of gas to human needs customers. Freeport alleges that it is owed approximately $104 million, plus attorney fees and interest. On October 24, 2022, the trial court granted our motion for summary judgment on all of Freeport’s claims. On April 15, 2025, the 14th Court of Appeals reversed and remanded the case to the trial court for further proceedings to resolve disputed issues of material fact. We believe we have numerous and substantial defenses and intend to continue to vigorously defend this case.

Pension Plan Litigation

On February 22, 2021, Kinder Morgan Retirement Plan A participants Curtis Pedersen and Beverly Leutloff filed a purported class action lawsuit under the Employee Retirement Income Security Act of 1974 (ERISA). The named plaintiffs were hired initially by the ANR Pipeline Company (ANR) in the late 1970s. Following a series of corporate acquisitions, plaintiffs became participants in pension plans sponsored by the Coastal Corporation (Coastal), El Paso Corporation (El Paso) and our company by virtue of our acquisition of El Paso in 2012 and our assumption of certain of El Paso’s pension plan obligations. The complaint, which was transferred to the U.S. District Court for the Southern District of Texas (Civil Action No. 4:21-3590) and amended to include the Kinder Morgan Retirement Plan B, alleges that the series of foregoing transactions resulted in changes to plaintiffs’ retirement benefits that are now contested on a class-wide basis. The complaint asserts six claims that fall within three primary theories of liability. Claims I, II, and III challenge plan provisions that are alleged to constitute impermissible “backloading” or “cutback” of benefits and seek the same plan modification as to how the plans calculate benefits for former participants in the Coastal plan. Claims IV and V allege that former participants in the ANR plans should be eligible for unreduced benefits at younger ages than the plans currently provide. Claim VI asserts that actuarial assumptions used to calculate reduced early retirement benefits for current or former ANR employees are outdated and therefore unreasonable. On February 8, 2024, the Court certified a class defined as any and all persons who participated in the Kinder Morgan Retirement Plan A or B who are current or former employees of ANR or Coastal, and participated in the El Paso pension plan after El Paso acquired Coastal in 2001, and are members of at least one of three subclasses of individuals who are allegedly due benefits. On July 25, 2024, the Court granted our motion for summary judgment with respect to Claims I and II based on the Court’s determination that the formula used to calculate projected service was neither backloaded nor a violation of ERISA’s anti-cutback rule. The Court granted plaintiffs’ motion for partial summary judgment with respect to Claim III because the Court found that the summary plan description did not include any clarifying examples or illustrations of accrued benefits using the applicable formula. The Court granted plaintiffs’ motion for partial summary judgment as to Claim IV based on its finding that an amendment to the plan in 2007 violated ERISA’s anti-cutback protection by terminating the accrual of early retirement benefits in connection with the sale of ANR. The Court granted plaintiffs’ motion for partial summary judgment as to Claim V based on its finding that the plan administrator used an inconsistent interpretation to calculate benefits for some retirees. The Court dismissed Claim VI without prejudice based on its finding that the claim is moot given the Court’s rulings on Claims IV and V. The Court’s decision on partial summary judgment did not address the extent of potential plan liabilities for past or future benefits or other potential damages or equitable relief. On March 11, 2025, the case was mediated without resolution, after which the parties filed summary judgment motions to address potential remedies for the remaining claims. Plaintiffs seek equitable and other relief including early retirement benefits, monetary damages, or other equitable relief estimated to be in excess of $100 million. We vigorously oppose the form and scope of relief sought by the plaintiffs and believe we have numerous and substantial defenses to support our vigorous defense at the trial or appellate levels if necessary. On April 22, 2025, the case was referred to a Magistrate Judge to conduct all pretrial proceedings including recommended rulings on plaintiffs’ motion for equitable remedies. On February 10, 2026, the Magistrate Judge issued a Memorandum and Recommendation that plaintiffs’ motion for equitable relief should be granted in part and denied in part. The Memorandum and Recommendation rejected or significantly narrowed a number of plaintiffs’ theories of recovery. The presiding U.S. District Court Judge may adopt, modify, or reject the Memorandum and Recommendation. To the extent an adverse judgment or settlement results in an increase in plan liabilities, we may elect as the sponsor of the plans to address them in accordance with applicable ERISA provisions, including provisions that allow for contributions to the plans over multiple years.

Pipeline Integrity and Releases

From time to time, despite our best efforts, our pipelines experience leaks and ruptures. These leaks and ruptures may cause explosions, fire, and damage to the environment, damage to property, and/or personal injury or death. In connection with these incidents, we may be sued for damages caused by an alleged failure to properly mark the locations of our pipelines and/or to properly maintain our pipelines. Depending upon the facts and circumstances of a particular incident, state and federal regulatory authorities may seek civil and/or criminal fines and penalties.

Environmental Matters

We and our subsidiaries are subject to environmental cleanup and enforcement actions from time to time. In particular, CERCLA generally imposes joint and several liability for cleanup and enforcement costs on current and predecessor owners and operators of a site, among others, without regard to fault or the legality of the original conduct, subject to the right of a liable party to establish a “reasonable basis” for apportionment of costs. Our operations are also subject to local, state, and federal laws and regulations relating to protection of the environment. Although we believe our operations are in substantial compliance with applicable environmental laws and regulations, risks of additional costs and liabilities are inherent in pipeline, terminal, CO2 field and oil field, and our other operations, and there can be no assurance that we will not incur significant costs and liabilities. Moreover, it is possible that other developments could result in substantial costs and liabilities to us, such as increasingly stringent state environmental laws, regulations and enforcement policies under the terms of authority of those laws, and claims for damages to property or persons resulting from our operations. Although it is not possible to predict the ultimate outcomes, we believe that the resolution of the environmental matters set forth in this note, and other matters to which we and our subsidiaries are a party, will not have a material adverse effect on our financial position, cash flows, or operating results.

We are currently involved in several governmental proceedings involving alleged violations of local, state, and federal environmental and safety regulations. As we receive notices of non-compliance, we attempt to negotiate and settle such matters where appropriate. These alleged violations may result in fines and penalties, but except as disclosed herein we do not believe any such fines and penalties will be material to our financial position, cash flows, or operating results, individually or in the aggregate. We are also currently involved in several governmental proceedings involving groundwater and soil remediation efforts under state or federal administrative orders or related remediation programs. We have accrued for costs associated with the remediation efforts as described below.

In addition, we are involved with and have been identified as a potentially responsible party (PRP) in several federal and state Superfund sites. Environmental liabilities have been established for those sites where our contribution is probable and reasonably estimable. Because costs associated with remedial plans are generally expected to be spread over at least several years, we do not anticipate that our share of the cost of remediation will have a material adverse impact to our financial position, cash flows, or operating results. In addition, we are from time to time involved in civil proceedings relating to damages alleged to have occurred as a result of accidental leaks or spills of refined petroleum products, crude oil, NGL, natural gas, or CO2, including natural resource damage (NRD) claims.

Portland Harbor Superfund Site, Willamette River, Portland, Oregon

On January 6, 2017, the EPA issued a Record of Decision (ROD) that established a final remedy and cleanup plan for an industrialized area on the lower reach of the Willamette River commonly referred to as the Portland Harbor Superfund Site (PHSS). The cost for the final remedy is estimated to be more than $2.8 billion and active cleanup is expected to take more than 10 years to complete. KMLT, KMBT, and some 90 other PRPs identified by the EPA are involved in a non-judicial allocation process to determine each party’s respective share of the cleanup costs related to the final remedy set forth by the ROD. We are participating in the allocation process on behalf of KMLT (in connection with its ownership or operation of two facilities) and KMBT (in connection with its ownership or operation of two facilities). Effective January 31, 2020, KMLT entered into separate Administrative Settlement Agreements and Orders on Consent (ASAOC) to complete remedial design for two distinct areas within the PHSS associated with KMLT’s facilities. The ASAOC obligates KMLT to pay a share of the remedial design costs for cleanup activities related to these two areas as required by the ROD. Our share of responsibility for the PHSS costs will not be determined until the ongoing non-judicial allocation process is concluded or a lawsuit is filed that results in a judicial decision allocating responsibility. At this time, we anticipate the non-judicial allocation process will be complete by December 31, 2026. Until the allocation process is completed, we are unable to reasonably estimate the extent of our liability for the costs related to the design of the proposed remedy and cleanup of the PHSS. In August 2024, we reached an agreement to settle claims first made in January 2021 asserted by state and federal trustees following their natural resource assessment of the PHSS.

Lower Passaic River Study Area of the Diamond Alkali Superfund Site, New Jersey

EPEC Polymers, Inc. and EPEC Oil Company Liquidating Trust (collectively EPEC) are identified as PRPs in an administrative action under CERCLA known as the Lower Passaic River Study Area (Site) concerning the lower 17-mile stretch of the Passaic River in New Jersey. On March 4, 2016, the EPA issued a ROD for the lower eight miles of the Site. At that time the cleanup plan in the ROD was estimated to cost $1.7 billion. The cleanup is expected to take at least six years to complete once it begins. In addition, the EPA and numerous PRPs, including EPEC, engaged in an allocation process for the implementation of the remedy for the lower eight miles of the Site. That process was completed December 28, 2020 and certain PRPs, including EPEC, engaged in discussions with the EPA as a result thereof. On October 4, 2021, the EPA issued a ROD for

the upper nine miles of the Site. At that time, the cleanup plan in the ROD was estimated to cost $440 million. No timeline for the cleanup has been established. On December 16, 2022, the United States Department of Justice (DOJ) and the EPA announced a settlement and proposed consent decree with 85 PRPs, including EPEC, to resolve their collective liability at the Site. The total amount of the settlement is $150 million. Also on December 16, 2022, the DOJ on behalf of the EPA filed a Complaint against the 85 PRPs, including EPEC, a Notice of Lodging of Consent Decree, and a Consent Decree in the U.S. District Court for the District of New Jersey in a case captioned USA v. Alden Leeds, et al. On January 17, 2024, the DOJ on behalf of the EPA voluntarily dismissed its Complaint against 3 PRPs, filed an Amended Complaint against 82 PRPs, including EPEC, and a modified Consent Decree in the U.S. District Court. On January 31, 2024, the DOJ on behalf of the EPA filed a Motion to Enter Consent Decree in the U.S. District Court. On January 16, 2025, the U.S. District Court entered the Consent Decree, after which time, the Consent Decree was appealed to the U.S. Court of Appeals for the Third Circuit by two PRPs including Occidental Chemical Corporation (OCC), alleging, inter alia, that the Consent Decree is not procedurally and substantively fair, reasonable, and consistent with the purpose of CERCLA. On February 6, 2026, certain corporate parties who are PRPs and parties to the Consent Decree filed BASF Catalysts LLC, et al. v. Occidental Chemical Corporation (OCC) in U.S. District Court for the District of New Jersey alleging that OCC’s recent attempt to contractually transfer environmental liabilities through a corporate reorganization process violated CERCLA. Plaintiffs seek a declaratory judgment that (1) any purported transfer or allocation of CERCLA liability through the reorganization is precluded by CERCLA, and (2) that the Occidental entity that holds the assets of the former OCC is jointly and severally liable for the former OCC’s CERCLA liabilities. While we are not a party to the most recent lawsuit, the results could potentially impact the amount we and other PRPs ultimately are required to contribute to this CERCLA site.

Louisiana Governmental Coastal Zone Erosion Litigation

On November 8, 2013, the Parish of Plaquemines, Louisiana and others filed petitions in the state district court for Plaquemines Parish against TGP and 17 other energy companies, alleging that the defendants’ operations in Plaquemines Parish violated the State and Local Coastal Resources Management Act of 1978, as amended and Louisiana law and caused substantial damage to the coastal waters and nearby lands. Plaintiffs seek, among other relief, unspecified money damages, attorney fees, interest, and restoration costs. In 2018, the case was removed to the U.S. District Court for the Eastern District of Louisiana and then stayed. We expect the case will proceed in federal court given the resolution of federal officer jurisdictional issues in separate consolidated cases to which TGP is not a party. At this time, we are not able to reasonably estimate the extent of our potential liability, if any. We intend to vigorously defend this case.

General

As of March 31, 2026 and December 31, 2025, we had liabilities of $175 million and $176 million, respectively, recorded for environmental matters. In addition, as of both March 31, 2026 and December 31, 2025, we had receivables of $9 million and $10 million, respectively, recorded for expected cost recoveries that have been deemed probable.

Challenge to Federal “Good Neighbor Plan”

On July 14, 2023, we filed a Petition for Review against the EPA and others in the U.S. Court of Appeals for the District of Columbia Circuit (the DC Circuit) seeking review of the EPA’s final action promulgating a federal implementation plan to address certain interstate transport requirements of the Clean Air Act for the 2015 8-hour Ozone National Ambient Air Quality Standards (NAAQS), known as the “Good Neighbor Plan” (the Plan) (Kinder Morgan, Inc., et al. v. EPA, et al. consolidated into Utah, et al. v. EPA, et al.). On October 13, 2023, in combination with other parties, we filed an Emergency Application for Stay of Final Agency Action in the United States Supreme Court (Kinder Morgan, Inc., et al. v. EPA, et al. consolidated into Ohio, et al. v. EPA, et al.), which the court granted on June 27, 2024, ruling that enforcement of the Plan shall be stayed pending the disposition of the case on the merits by the DC Circuit and any subsequent timely appeals.

Subsequently, the EPA filed a Motion for Remand asking the DC Circuit to remand without vacatur the Plan to the EPA for voluntary reconsideration, explaining that the “EPA has identified specific issues with the Rule that make reconsideration appropriate, including issues raised by Petitioners in this litigation.” On April 14, 2025, the DC Circuit held the case in abeyance pending further order of the court and ordered the parties to file periodic status reports until the EPA completes its review of the Plan. On January 27, 2026, the EPA proposed approving eight state implementation plans to address ozone emissions which were originally disapproved by the EPA. If finalized, those states would be removed from the EPA’s federal Good Neighbor Plan and its requirements would not apply to our facilities.

10. Recent Accounting Pronouncements

Accounting Standards Updates (ASU)

ASU No. 2024-03

On November 4, 2024, the FASB issued ASU No. 2024-03, “Income Statement—Reporting Comprehensive Income—Expense Disaggregation Disclosures (Subtopic 220-40).” This ASU improves financial reporting by requiring that public business entities disclose additional information about specific expense categories in the notes to financial statements at interim and annual reporting periods. This ASU will be effective for annual periods beginning after December 15, 2026, for interim reporting periods beginning after December 15, 2027, and early adoption is permitted. Management is currently evaluating this ASU to determine its impact on the Company’s disclosures.

ASU No. 2025-06

On September 18, 2025, the FASB issued ASU No. 2025-06, “Intangibles—Goodwill and Other—Internal-Use Software (Subtopic 350-40): Targeted Improvements to the Accounting for Internal-Use Software.” This ASU modernizes the accounting guidance for the costs to develop software for internal use by removing outdated stage-based cost capitalization rules and replacing them with a probability-based cost-capitalization framework that aligns better with current software development methods. This ASU will be effective for annual periods beginning after December 15, 2027, for interim reporting periods beginning within those annual periods, and early adoption is permitted. Management is currently evaluating this ASU to determine its impact on the Company’s financial statements.

ASU No. 2025-09

On November 25, 2025, the FASB issued ASU No. 2025-09, “Derivatives and Hedging (Topic 815): Hedge Accounting Improvements.” This ASU makes targeted improvements to Topic 815 to better align hedge accounting with the economics of an entity’s risk-management activities. This ASU will be effective for annual periods beginning after December 15, 2026, for interim reporting periods beginning within those annual periods, and early adoption is permitted. Management is currently evaluating this ASU to determine its impact on the Company’s financial statements.

ASU No. 2025-10

On December 4, 2025, the FASB issued ASU No. 2025-10, “Government Grants (Topic 832): Accounting for Government Grants Received by Business Entities.” This ASU establishes guidance on the recognition, measurement, and presentation of government grants received by business entities, an area not previously addressed under US GAAP. This ASU will be effective for annual periods beginning after December 15, 2028, for interim reporting periods beginning within those annual periods, and early adoption is permitted. Management is currently evaluating this ASU as it relates to certain tax credits to determine its impact on the Company’s financial statements.

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations.

General and Basis of Presentation

The following discussion and analysis should be read in conjunction with our accompanying interim consolidated financial statements and related notes included elsewhere in this report, and in conjunction with (i) our consolidated financial statements and related notes in our 2025 Form 10-K; (ii) our management’s discussion and analysis of financial condition, and results of operations included in our 2025 Form 10-K; (iii) “Information Regarding Forward-Looking Statements” at the beginning of this report, and in our 2025 Form 10-K; and (iv) “Risk Factors” in Part I, Item 1A in our 2025 Form 10-K.

Acquisition

Following is a recently announced acquisition.


Event	Description	Business Segment
Monument Pipeline acquisition $505 million (Estimated to close second quarter 2026)	Natural gas pipeline system (Monument Pipeline) serving Houston, Texas and the surrounding metropolitan area which includes approximately 225 miles of pipelines and provides transportation and storage services to gas utilities, LNG shippers, and industrial customers.	Natural Gas Pipelines (Midstream)

2026 Dividends and Discretionary Capital

We expect to declare dividends of $1.19 per share for 2026, a 2% increase from the 2025 declared dividends of $1.17 per share. We expect to invest $3.9 billion in expansion projects, acquisitions, and contributions to joint ventures during 2026.

The expectations for 2026 discussed above involve risks, uncertainties, and assumptions, and are not guarantees of performance. Many of the factors that will determine these expectations are beyond our ability to control or predict, and because of these uncertainties, it is advisable not to put undue reliance on any forward-looking statement.

Results of Operations

Overview

As described in further detail below, our management evaluates our performance primarily using Net income attributable to Kinder Morgan, Inc. and Segment earnings before DD&A expenses (EBDA) (as presented in Note 7 “Reportable Segments”), along with the non-GAAP financial measures of Adjusted Net Income Attributable to Common Stock, in the aggregate and per share, Adjusted Segment EBDA, Adjusted Net Income Attributable to Kinder Morgan, Inc., Adjusted earnings before interest, income taxes, DD&A expenses (EBITDA), and Net Debt.

GAAP Financial Measures

Our Consolidated Earnings Results for the three months ended March 31, 2026 and 2025 present Net income attributable to Kinder Morgan, Inc., as prepared and presented in accordance with GAAP, and Segment EBDA, which is disclosed in Note 7 “Reportable Segments” pursuant to FASB ASC 280. The composition of Segment EBDA is not addressed nor prescribed by generally accepted accounting principles. Segment EBDA is a useful measure of our operating performance because it measures the operating results of our segments before DD&A and certain expenses that are generally not controllable by our business segment operating managers, such as general and administrative expenses and corporate charges, interest expense, net, and income taxes. Our general and administrative expenses and corporate charges include such items as unallocated employee benefits, insurance, rentals, unallocated litigation and environmental expenses, and shared corporate services including accounting, IT, human resources, and legal services.

Non-GAAP Financial Measures

Our non-GAAP financial measures described below should not be considered alternatives to GAAP Net income attributable to Kinder Morgan, Inc. or other GAAP measures and have important limitations as analytical tools. Our computations of these non-GAAP financial measures may differ from similarly titled measures used by others. You should not consider these non-GAAP financial measures in isolation or as substitutes for an analysis of our results as reported under GAAP. Management compensates for the limitations of our consolidated non-GAAP financial measures by reviewing our

comparable GAAP measures identified in the descriptions of consolidated non-GAAP measures below, understanding the differences between the measures and taking this information into account in its analysis and its decision-making processes.

Certain Items

Certain Items, as adjustments used to calculate our non-GAAP financial measures, are items that are required by GAAP to be reflected in Net income attributable to Kinder Morgan, Inc., but typically (i) do not have a cash impact (for example, unsettled commodity hedges and asset impairments), (ii) by their nature are separately identifiable from our normal business operations and in most cases are likely to occur only sporadically (for example, certain legal settlements, enactment of new tax legislation, and casualty losses), or (iii) align the timing of cash impacts from natural gas inventory hedges with the future associated physical withdrawals from inventory. (See the tables included in “—Non-GAAP Financial Measures—Reconciliation of Net Income Attributable to Kinder Morgan, Inc. to Adjusted Net Income Attributable to Kinder Morgan, Inc.,” “—Non-GAAP Financial Measures—Reconciliation of Net Income Attributable to Kinder Morgan, Inc. to Adjusted Net Income Attributable to Common Stock,” and “—Non-GAAP Financial Measures—Reconciliation of Net Income Attributable to Kinder Morgan, Inc. to Adjusted EBITDA” below). We also include adjustments related to joint ventures (see “—Amounts associated with Joint Ventures” below). The following table summarizes our Certain Items for the three months ended March 31, 2026 and 2025, which are also described in more detail in the footnotes to tables included in “—Segment Earnings Results” below.


	Three Months Ended March 31,
		2026		2025
		(In millions)
Certain Items


Risk management activities(a)(b)		$	113	$	84


Income tax Certain Items(c)		(26)		(35)

Total Certain Items(d)(e)		$	87	$	49

(a)Includes changes in fair value of unsettled derivatives, of which gains or losses are reflected within non-GAAP financial measures when realized.

(b)Includes natural gas inventory hedges of which gains or losses are reflected within non-GAAP financial measures when the associated physical gas is withdrawn from inventory.

(c)Represents the income tax provision on Certain Items plus discrete income tax items. Includes the impact of KMI’s income tax provision on Certain Items affecting earnings from equity investments and is separate from the related tax provision recognized at the investees by the joint ventures which are also taxable entities.

(d)2025 amount includes $2 million reported within “Earnings from equity investments” on the accompanying consolidated statement of income of “Risk management activities.”

(e)2025 amount includes $2 million reported within “Interest, net” on the accompanying consolidated statement of income of “Risk management activities.”

Adjusted Net Income Attributable to Kinder Morgan, Inc.

Adjusted Net Income Attributable to Kinder Morgan, Inc. is calculated by adjusting Net income attributable to Kinder Morgan, Inc. for Certain Items. Adjusted Net Income Attributable to Kinder Morgan, Inc. is used by us, investors, and other external users of our financial statements as a supplemental measure that provides decision-useful information regarding our period-over-period performance and ability to generate earnings that are core to our ongoing operations. We believe the GAAP measure most directly comparable to Adjusted Net Income Attributable to Kinder Morgan, Inc. is Net income attributable to Kinder Morgan, Inc. See “—Non-GAAP Financial Measures—Reconciliation of Net Income Attributable to Kinder Morgan, Inc. to Adjusted Net Income Attributable to Kinder Morgan, Inc.” below.

Adjusted Net Income Attributable to Common Stock and Adjusted EPS

Adjusted Net Income Attributable to Common Stock is calculated by adjusting Net income attributable to Kinder Morgan, Inc., the most comparable GAAP measure, for Certain Items, and further for net income allocated to participating securities and adjusted net income in excess of distributions for participating securities. We believe Adjusted Net Income Attributable to Common Stock allows for calculation of adjusted earnings per share (Adjusted EPS) on the most comparable basis with earnings per share, the most comparable GAAP measure to Adjusted EPS. Adjusted EPS is calculated as Adjusted Net Income Attributable to Common Stock divided by our weighted average shares outstanding. Adjusted EPS applies the same two-class method used in arriving at basic earnings per share. Adjusted EPS is used by us, investors, and other external users of our financial statements as a per-share supplemental measure that provides decision-useful information regarding our period-over-

period performance and ability to generate earnings that are core to our ongoing operations. See “—Non-GAAP Financial Measures—Reconciliation of Net Income Attributable to Kinder Morgan, Inc. to Adjusted Net Income Attributable to Common Stock” below.

Adjusted Segment EBDA

Adjusted Segment EBDA is calculated by adjusting segment earnings before DD&A, general and administrative expenses and corporate charges, interest expense, and income taxes (Segment EBDA) for Certain Items attributable to the segment. Adjusted Segment EBDA is used by management in its analysis of segment performance and management of our business. We believe Adjusted Segment EBDA is a useful performance metric because it provides management, investors, and other external users of our financial statements additional insight into performance trends across our business segments, our segments’ relative contributions to our consolidated performance, and the ability of our segments to generate earnings on an ongoing basis. Adjusted Segment EBDA is also used as a factor in determining compensation under our annual incentive compensation program for our business segment presidents and other business segment employees. We believe it is useful to investors because it is a measure that management uses to allocate resources to our segments and assess each segment’s performance. See “—Segment Earnings Results” below.

Adjusted EBITDA

Adjusted EBITDA is calculated by adjusting Net income attributable to Kinder Morgan, Inc. for Certain Items and further for DD&A, including the amortization of basis differences related to our joint ventures, income tax expense, and interest. We also include amounts from joint ventures for income taxes and DD&A (see “—Amounts associated with Joint Ventures” below). Adjusted EBITDA is used by management, investors, and other external users, in conjunction with our Net Debt (as described further below), to evaluate our leverage. Management and external users also use Adjusted EBITDA as an important metric to compare the valuations of companies across our industry. Our ratio of Net Debt-to-Adjusted EBITDA is used as a supplemental performance target for purposes of our annual incentive compensation program. We believe the GAAP measure most directly comparable to Adjusted EBITDA is Net income attributable to Kinder Morgan, Inc. See “—Non-GAAP Financial Measures—Reconciliation of Net Income Attributable to Kinder Morgan, Inc. to Adjusted EBITDA” below.

Amounts associated with Joint Ventures

Certain Items and Adjusted EBITDA reflect amounts from unconsolidated joint ventures and consolidated joint ventures utilizing the same recognition and measurement methods used to record “Earnings from equity investments” and “Noncontrolling interests,” respectively. The calculation of Adjusted EBITDA related to our unconsolidated and consolidated joint ventures includes the same adjustments (DD&A, including the amortization of basis differences related to joint ventures only, and income tax expense) with respect to the joint ventures as those included in the calculation of Adjusted EBITDA for our wholly-owned consolidated subsidiaries; further, we remove the portion of these adjustments attributable to non-controlling interests. (See “—Non-GAAP Financial Measures—Reconciliation of Net Income Attributable to Kinder Morgan, Inc. to Adjusted EBITDA” below.) Although these amounts related to our unconsolidated joint ventures are included in the calculation of Adjusted EBITDA, such inclusion should not be understood to imply that we have control over the operations and resulting revenues, expenses, or cash flows of such unconsolidated joint ventures.

Net Debt

Net Debt is calculated, based on amounts as of March 31, 2026, by subtracting the following amounts from our debt balance of $32,056 million: (i) cash and cash equivalents of $72 million; (ii) debt fair value adjustments of $151 million; and (iii) the foreign exchange impact on Euro-denominated bonds of $35 million for which we have entered into currency swaps to convert that debt to U.S. dollars. Net Debt, on its own and in conjunction with our Adjusted EBITDA as part of a ratio of Net Debt-to-Adjusted EBITDA, is a non-GAAP financial measure that is used by management, investors, and other external users of our financial information to evaluate our leverage. Our ratio of Net Debt-to-Adjusted EBITDA is also used as a supplemental performance target for purposes of our annual incentive compensation program. We believe the most comparable measure to Net Debt is total debt.

Consolidated Earnings Results

The following tables summarize the key components of our consolidated earnings results.


	Three Months Ended March 31,
	2026		2025		Earnings increase/(decrease)
	(In millions, except per share amounts and percentages)
Revenues	$	4,828	$	4,241	$	587	14	%
Operating Costs, Expenses and Other
Costs of sales (exclusive of items shown separately below)	(1,749)		(1,476)		(273)		(18)	%
Operations and maintenance	(711)		(711)		—		—	%
DD&A	(633)		(610)		(23)		(4)	%
General and administrative	(184)		(187)		3		2	%
Taxes, other than income taxes	(114)		(112)		(2)		(2)	%

Other income, net	7		—		7		—	%
Total Operating Costs, Expenses and Other	(3,384)		(3,096)		(288)		(9)	%
Operating Income	1,444		1,145		299		26	%
Other Income (Expense)
Earnings from equity investments	254		220		34		15	%

Interest, net	(430)		(451)		21		5	%
Other, net	20		15		5		33	%
Total Other Expense	(156)		(216)		60		28	%
Income Before Income Taxes	1,288		929		359		39	%
Income Tax Expense	(287)		(186)		(101)		(54)	%
Net Income	1,001		743		258		35	%
Net Income Attributable to Noncontrolling Interests	(25)		(26)		1		4	%
Net Income Attributable to Kinder Morgan, Inc.	$	976	$	717	$	259	36	%
Basic and diluted earnings per share	$	0.44	$	0.32	$	0.12	38	%
Basic and diluted weighted average shares outstanding	2,225		2,222		3		—	%
Declared dividends per share	$	0.2975	$	0.2925	$	0.005	2	%

Our consolidated revenues primarily consist of services and sales revenue. Our services revenues include fees for transportation and other midstream services that we perform. Fluctuations in our consolidated services revenue largely reflect changes in volumes and/or in the rates we charge. Our consolidated sales revenues include sales of natural gas (includes natural gas and RNG), products (includes NGL, crude oil, CO2, and transmix), and other (includes RINs). Our consolidated sales revenue will fluctuate with commodity prices and volumes, and the costs of sales associated with purchases will usually have a commensurate and offsetting impact, except for the CO2 segment, which produces, instead of purchases, the crude oil, CO2, and RINs it sells. Additionally, fluctuations in revenues and costs of sales may be further impacted by gains or losses from derivative contracts that we use to manage our commodity price risk.

Below is a discussion of significant changes in our Consolidated Earnings Results for the comparable three-month periods ended March 31, 2026 and 2025:

Revenues

Revenues increased $587 million in 2026 compared to 2025. The increase was primarily due to (i) an increase in natural gas sales of $460 million due to higher commodity prices and volumes; and (ii) an increase in services revenues of $157 million resulting from higher volumes, primarily driven by increased demand for services and expansion projects placed into service, and higher rates partially offset by a decrease in product sales of $34 million driven primarily by lower commodity prices. The

increase in sales revenues was partially offset by a corresponding increase in our costs of sales as described below under “Operating Costs, Expenses and Other—Costs of sales.”

Operating Costs, Expenses and Other

Costs of sales

Costs of sales increased $273 million in 2026 compared to 2025. The increase was primarily due to (i) an increase of $300 million of costs of sales for natural gas primarily due to higher volumes and commodity prices; and (ii) an increase of $20 million related to derivative contracts used to hedge commodity purchases. The increase was partially offset by a decrease of $69 million of costs of sales for products driven by lower commodity prices.

Other Income (Expense)

Interest, net

In the table above, we report our interest expense as “net,” meaning that we have subtracted interest income and capitalized interest from our total interest expense to arrive at one interest amount. Interest, net decreased $21 million in 2026 compared to 2025. The decrease was primarily due to lower interest rates associated with our fixed-to-variable interest rate swap agreements and lower average short-term debt balances partially offset by higher interest rates and average balances on our long-term debt.

Non-GAAP Financial Measures

Reconciliations from Net Income Attributable to Kinder Morgan, Inc.


	Three Months Ended March 31,
		2026		2025
		(In millions, except per share amounts)
Reconciliation of Net Income Attributable to Kinder Morgan, Inc. to Adjusted Net Income Attributable to Kinder Morgan, Inc.
Net income attributable to Kinder Morgan, Inc.		$	976	$	717
Certain Items(a)


Risk management activities		113		84


Income tax Certain Items		(26)		(35)

Total Certain Items		87		49
Adjusted Net Income Attributable to Kinder Morgan, Inc.		$	1,063	$	766

Reconciliation of Net Income Attributable to Kinder Morgan, Inc. to Adjusted Net Income Attributable to Common Stock
Net income attributable to Kinder Morgan, Inc.		$	976	$	717
Total Certain Items(b)		87		49
Net income allocated to participating securities and other(c)		(6)		(4)

Adjusted Net Income Attributable to Common Stock		$	1,057	$	762

Adjusted EPS		$	0.48	$	0.34

Reconciliation of Net Income Attributable to Kinder Morgan, Inc. to Adjusted EBITDA
Net income attributable to Kinder Morgan, Inc.		$	976	$	717








Total Certain Items(b)		87		49
DD&A		633		610

Income tax expense(d)		313		221
Interest, net(e)		430		449
Amounts associated with joint ventures
Unconsolidated joint venture DD&A(f)		91		100
Remove consolidated joint venture partners’ DD&A		(16)		(15)
Unconsolidated joint venture income tax expense(g)		25		26
Adjusted EBITDA		$	2,539	$	2,157

(a)See table included in “—Overview—Non-GAAP Financial Measures—Certain Items” above.

(b)See “—Non-GAAP Financial Measures—Reconciliation of Net Income Attributable to Kinder Morgan, Inc. to Adjusted Net Income Attributable to Kinder Morgan, Inc.” for a detailed listing.

(c)Other includes Adjusted net income in excess of distributions for participating securities of $1 million for the 2026 period.

(d)To avoid duplication, adjustments for income tax expense for 2026 and 2025 exclude $(26) million and $(35), respectively, which amounts are already included within “Certain Items.” See table included in “—Overview—Non-GAAP Financial Measures—Certain Items” above.

(e)To avoid duplication, adjustments for interest, net for 2025 exclude $2 million which amounts are already included within “Certain Items.” See table included in “—Overview—Non-GAAP Financial Measures—Certain Items,” above.

(f)Includes amortization of basis differences related to our joint ventures.

(g)Includes the tax provision on Certain Items recognized by the investees that are taxable entities associated with our Citrus, NGPL Holdings LLC, and Products (SE) Pipe Line equity investments. The impact of KMI’s income tax provision on Certain Items affecting earnings from equity investments is included within “Certain Items” above.

Below is a discussion of significant changes in our Adjusted Net Income Attributable to Kinder Morgan, Inc. and Adjusted EBITDA:


	Three Months Ended March 31,
		2026		2025
		(In millions)
Adjusted Net Income Attributable to Kinder Morgan, Inc.		$	1,063	$	766
Adjusted EBITDA		2,539		2,157

Change from prior period		Increase/(Decrease)
Adjusted Net Income Attributable to Kinder Morgan, Inc.		$	297
Adjusted EBITDA		$	382

Adjusted Net Income Attributable to Kinder Morgan, Inc. increased $297 million in 2026 compared to 2025. The increase resulted primarily from favorable earnings in our Natural Gas Pipelines, Terminals, and Products Pipelines business segments, which were also the primary drivers of the increase in Adjusted EBITDA of $382 million.

General and Administrative and Corporate Charges


	Three Months Ended March 31,
		2026		2025
		(In millions)
General and administrative		$	(184)	$	(187)
Corporate benefit (charges)		7		(5)

General and administrative and corporate charges		$	(177)	$	(192)

Change from prior period		Earnings increase/(decrease)
General and administrative		$	3
Corporate charges		12
Total		$	15

General and administrative expenses decreased $3 million, and corporate charges decreased $12 million in 2026 compared to 2025. The combined changes primarily include lower legal, corporate development and pension costs partially offset by higher benefit-related and labor costs.

Segment Earnings Results

Natural Gas Pipelines (including reconciliation of Segment EBDA to Adjusted Segment EBDA)


	Three Months Ended March 31,
		2026		2025
		(In millions, except operating statistics)
Revenues		$	3,296	$	2,754
Costs of sales		(1,431)		(1,145)
Other operating expenses(a)		(390)		(362)

Other income		1		1
Earnings from equity investments		225		196

Other, net		10		9
Segment EBDA		1,711		1,453
Certain Items:

Risk management activities		86		80


Certain Items(b)		86		80
Adjusted Segment EBDA		$	1,797	$	1,533

Change from prior period		Increase/(Decrease)
Segment EBDA		$	258
Adjusted Segment EBDA		$	264

Volumetric data(c)
Natural gas transport (BBtu/d)		49,475		45,978
Natural gas sales (BBtu/d)		3,893		2,598
Gathering (BBtu/d)		4,319		3,758
NGL transport (MBbl/d)		44		32

(a)Other operating expenses include operations and maintenance expenses and taxes, other than income taxes.

(b)See table included in “—Overview—Non-GAAP Financial Measures—Certain Items” above. 2026 and 2025 Certain Items of (i) $79 million and $78 million, respectively, are associated with our Midstream business and (ii) $7 million and $2 million, respectively, are associated with our East business. See “—Overview—Non-GAAP Financial Measures—Certain Items” above. For more detail of significant Certain Items, see the discussion of changes in Segment EBDA below.

(c)Joint venture throughput is reported at our ownership share. Volumes for acquired assets are included for all periods presented. However, EBDA contributions from acquisitions are included only for the periods subsequent to their acquisition. Volumes for assets sold are excluded for all periods presented.

Below are the changes in Natural Gas Pipelines Segment EBDA:


	Three Months Ended March 31,
		2026		2025		Increase/ (Decrease)
		(In millions)
Midstream		$	647	$	445	$	202
East		781		746		35
West		283		262		21
Total Natural Gas Pipelines		$	1,711	$	1,453	$	258

The changes in Natural Gas Pipelines Segment EBDA in the comparable three-month periods ended March 31, 2026 and 2025 are explained by the following discussion:

•The $202 million (45%) increase in Midstream was primarily driven by (i) increased sales margin resulting from higher commodity prices and volumes and increased demand for our services due to colder winter weather on our Texas intrastate systems; (ii) higher volumes on KinderHawk Field Services LLC; and (iii) contributions from the acquired Outrigger Energy assets on our Hiland Midstream assets. Overall, Midstream’s revenue changes are partially offset by corresponding changes in costs of sales.

In addition, Midstream includes decreased revenues offset by decreased costs of sales associated with risk management activities related to non-cash changes in fair value of unsettled derivative contracts and realized gains and losses on settled natural gas inventory hedge contracts, all of which we treated as Certain Items.

•The $35 million (5%) increase in East was primarily driven by increased demand for our services due to colder winter weather and completed expansion projects.

•The $21 million (8%) increase in West resulted primarily from higher capacity sales on multiple assets.

Products Pipelines (including reconciliation of Segment EBDA to Adjusted Segment EBDA)


	Three Months Ended March 31,
		2026		2025
		(In millions, except operating statistics)
Revenues		$	687	$	663
Costs of sales		(281)		(293)
Other operating expenses(a)		(104)		(113)


Earnings from equity investments		18		16


Segment EBDA		320		273
Certain Items:
Risk management activities		5		1

Certain Items(b)		5		1
Adjusted Segment EBDA		$	325	$	274

Change from prior period		Increase/(Decrease)
Segment EBDA		$	47
Adjusted Segment EBDA		$	51

Volumetric data(c)
Gasoline(d)		912		933
Diesel fuel		340		336
Jet fuel		293		302
Total refined product volumes		1,545		1,571
Crude and condensate		420		476
Total delivery volumes (MBbl/d)		1,965		2,047

(a)Other operating expenses include operations and maintenance expenses and taxes, other than income taxes.

(b)See table included in “—Overview—Non-GAAP Financial Measures—Certain Items” above. 2026 and 2025 Certain Items of (i) $4 million and $1 million, respectively are associated with our Southeast Refined Products business and (ii) $1 million and none, respectively, are associated with our Crude and Condensate business. See “—Overview—Non-GAAP Financial Measures—Certain Items” above. For more detail of significant Certain Items, see the discussion of changes in Segment EBDA below.

(c)Joint venture throughput is reported at our ownership share.

(d)Volumes include ethanol pipeline volumes.

Below are the changes in Products Pipelines Segment EBDA:


	Three Months Ended March 31,
		2026		2025		Increase/ (Decrease)
		(In millions)
Crude and Condensate		$	77	$	53	$	24
Southeast Refined Products		87		73		14
West Coast Refined Products		156		147		9
Total Products Pipelines		$	320	$	273	$	47

The changes in Products Pipelines Segment EBDA in the comparable three-month periods ended March 31, 2026 and 2025 are explained by the following discussion:

•The $24 million (45%) increase in Crude and Condensate was driven by (i) higher margin from our Crude and Condensate business resulting primarily from increased spreads; (ii) a turnaround in the first quarter of 2025 at our KM Condensate Processing facility; and (iii) on our Bakken Crude assets, higher gathering rates and retroactive rate increases partially offset by decreases related to the conversion of the Double H pipeline to NGL service.

•The $14 million (19%) increase in Southeast Refined Products was primarily the result of higher commodity prices at our Transmix processing operations.

Terminals (including reconciliation of Segment EBDA to Adjusted Segment EBDA)


	Three Months Ended March 31,
		2026			2025
		(In millions, except operating statistics)
Revenues		$	565		$	518
Costs of sales		(16)			(15)
Other operating expenses(a)		(223)			(229)

Other expense		—			(1)
Earnings from equity investments		3			2

Segment EBDA		$	329		$	275
Certain Items:
Risk management activities		1			—
Certain Items(b)		1			—
Adjusted Segment EBDA		$	330		$	275

Change from prior period		Increase/(Decrease)
Segment EBDA		$	54
Adjusted Segment EBDA		55

Volumetric data(c)
Liquids leasable capacity (MMBbl)		78.7			78.8
Liquids utilization %(d)		93.5		%	94.3		%
Bulk transload tonnage (MMtons)		12.1			12.2

(a)Other operating expenses include operations and maintenance expenses and taxes, other than income taxes.

(b)See table included in “—Overview—Non-GAAP Financial Measures—Certain Items” above. 2026 Certain Items of $1 million are associated with our Liquids business. See “—Overview—Non-GAAP Financial Measures—Certain Items” above. For more detail of significant Certain Items, see the discussion of changes in Segment EBDA below.

(c)Volumes for facilities divested, idled and/or held for sale are excluded for all periods presented.

(d)The ratio of our tankage capacity in service to liquids leasable capacity.

Below are the changes in Terminals Segment EBDA:


	Three Months Ended March 31,
		2026		2025		Increase/ (Decrease)
		(In millions)
Liquids		$	201	$	158	$	43
Bulk		64		57		7
Jones Act tankers		64		60		4




Total Terminals		$	329	$	275	$	54

The changes in Terminals Segment EBDA in the comparable three-month periods ended March 31, 2026 and 2025 are explained by the following discussion:

•The $43 million (27%) increase in Liquids was driven by (i) the recognition of payments to be received in connection with the early termination of certain storage agreements in 2026 related to and partially offset by the effects of a customer’s closure of its Houston refinery in 2025; (ii) contributions from expansion projects; and (iii) higher rates and ancillary fees at our Houston Ship Channel facilities.

•The $7 million (12%) increase in Bulk was primarily the result of higher petroleum coke volumes.

CO2 (including reconciliation of Segment EBDA to Adjusted Segment EBDA)


	Three Months Ended March 31,
		2026		2025
		(In millions, except operating statistics)
Revenues		$	288	$	312
Costs of sales		(28)		(27)
Other operating expenses(a)		(106)		(110)

Other income		6		—
Earnings from equity investments		8		6

Segment EBDA		168		181
Certain Items:
Risk management activities		21		1

Certain Items(b)		21		1
Adjusted Segment EBDA		$	189	$	182

Change from prior period		Increase/(Decrease)
Segment EBDA		$	(13)
Adjusted Segment EBDA		$	7

Volumetric data
SACROC oil production		20.24		19.26
Yates oil production		5.66		5.94
Other		1.05		1.10
Total oil production, net (MBbl/d)(c)		26.95		26.30
NGL sales volumes, net (MBbl/d)(c)		9.73		9.28

CO2 sales volumes, net (Bcf/d)		0.313		0.310
RNG sales volumes (BBtu/d)		13		8
Realized weighted average oil price ($ per Bbl)		$	65.42	$	68.38
Realized weighted average NGL price ($ per Bbl)		$	30.02	$	35.36

(a)Other operating expenses include operations and maintenance expenses and taxes, other than income taxes.

(b)See table included in “—Overview—Non-GAAP Financial Measures—Certain Items” above. The 2026 and 2025 Certain Items are associated with our Oil and Gas Producing activities. See “—Overview—Non-GAAP Financial Measures—Certain Items” above. For more detail of significant Certain Items, see the discussion of changes in Segment EBDA below.

(c)Net of royalties and outside working interests.

Below are the changes in CO2 Segment EBDA:


	Three Months Ended March 31,
		2026		2025		Increase/ (Decrease)
		(In millions)
Oil and Gas Producing activities		$	93	$	117	$	(24)
Source and Transportation activities		50		47		3

Subtotal		143		164		(21)
Energy Transition Ventures		25		17		8
Total CO2		$	168	$	181	$	(13)

The changes in CO2 Segment EBDA in the comparable three-month periods ended March 31, 2026 and 2025 are explained by the following discussion:

•The $24 million (21%) decrease in Oil and Gas Producing activities was driven by non-cash mark-to-market sales derivative hedge contracts, which decreased revenues, and which we treated as a Certain Item.

In addition, Oil and Gas Producing activities includes the effects of lower power costs offset by lower realized crude oil prices.

•The $8 million (47%) increase in Energy Transition Ventures includes greater RIN production partially offset by 2025 sales of RINs produced in 2024.

We believe that our existing hedge contracts in place within our CO2 business segment substantially mitigate commodity price exposure in the near-term and to a lesser extent over the following few years. Below is a summary of our CO2 business segment hedges outstanding as of March 31, 2026:


	Remaining 2026		2027		2028
Crude Oil(a)
Price ($ per Bbl)	$	64.54	$	63.63	$	65.37
Volume (MBbl/d)	23.15		17.30		6.50
NGLs
Price ($ per Bbl)	$	42.61	$	45.80
Volume (MBbl/d)	3.97		0.25

(a)Includes WTI hedges.

Liquidity and Capital Resources

General

As of March 31, 2026, we had $72 million of “Cash and cash equivalents,” an increase of $9 million from December 31, 2025. Additionally, as of March 31, 2026, we had borrowing capacity of approximately $3.4 billion under our credit facility (discussed below in “—Short-term Liquidity”). As discussed further below, we believe our cash flows from operating activities, cash position, and remaining borrowing capacity on our credit facility is more than adequate to allow us to manage our day-to-day cash requirements and anticipated obligations.

We have consistently generated substantial cash flows from operations, providing a source of funds of $1,491 million and $1,162 million in the first three months of 2026 and 2025, respectively. The period-to-period increase is discussed below in “—Cash Flows—Operating Activities.” We primarily rely on cash provided by operations to fund our operations as well as our debt service, sustaining capital expenditures, dividend payments, and our growth capital expenditures; however, we may access the debt capital markets from time to time to refinance our maturing long-term debt and finance incremental investments, if any. From time to time, short-term borrowings are used to fund working capital and finance incremental capital investments, if any. Incremental capital investments initially funded through short-term borrowings may periodically be replaced with long-term financing and/or paid down using retained cash from operations.

We use interest rate swap agreements to convert a portion of the underlying cash flows related to our long-term fixed-rate debt securities (senior notes) into variable-rate debt in order to achieve our desired mix of fixed and variable rate debt, as detailed below:


	March 31, 2026		December 31, 2025

	(In millions)


Variable rate debt(a)	$	88		$	13
Notional principal amount of fixed-to-variable interest rate swap agreements	3,750			3,500

Debt balances subject to variable interest rates	$	3,838		$	3,513

(a)Reflects outstanding commercial paper notes.

In March 2026, Moody’s Investor Services upgraded our long-term debt rating from Baa2 with a positive outlook to Baa1 with a stable outlook.

Short-term Liquidity

As of March 31, 2026, our principal sources of short-term liquidity are (i) cash from operations and (ii) our $3.5 billion credit facility, with an available capacity of approximately $3.4 billion, and an associated $3.5 billion commercial paper program. The loan commitments under our credit facility can be used for working capital and other general corporate purposes and as a backup to our commercial paper program. Commercial paper borrowings and letters of credit reduce borrowings allowed under our credit facility. We provide for liquidity by maintaining a sizable amount of excess borrowing capacity under our credit facility and, as previously discussed, have consistently generated strong cash flows from operations.

As of March 31, 2026, our $2,186 million of short-term debt consisted primarily of commercial paper borrowings and senior notes that mature in the next twelve months. We intend to fund our debt as it becomes due, primarily through credit facility borrowings, commercial paper borrowings, cash flows from operations, and/or issuing new long-term debt. Our short-term debt as of December 31, 2025 was $1,226 million.

We had working capital (defined as current assets less current liabilities) deficits of $2,475 million and $1,568 million as of March 31, 2026 and December 31, 2025, respectively. The overall $907 million unfavorable change from year-end 2025 was primarily due to (i) an $885 million increase in senior notes that mature in the next twelve months; (ii) a $162 million increase in the fair value of our derivative contracts liabilities; and (iii) a $90 million net unfavorable change in our accounts receivables and payables, partially offset by a $195 million decrease in accrued interest. Generally, our working capital varies due to factors such as the timing of scheduled debt payments, timing differences in the collection and payment of receivables and payables, the change in fair value of our derivative contracts, and changes in our cash and cash equivalents as a result of excess cash from operations after payments for investing and financing activities.

Capital Expenditures

We account for our capital expenditures in accordance with GAAP. Additionally, we distinguish between capital expenditures as follows:


Type of Expenditure						Physical Determination of Expenditure
Sustaining capital expenditures						•Investments to maintain the operational integrity and extend the useful life of our assets
Expansion capital expenditures (discretionary capital expenditures)						•Investments to expand throughput or capacity from that which existed immediately prior to the making or acquisition of additions or improvements

Budgeting of maintenance capital expenditures, which we refer to as sustaining capital expenditures, is done annually on a bottom-up basis. For each of our assets, we budget for and make those sustaining capital expenditures that are necessary to maintain safe and efficient operations, meet customer needs, and comply with our operating policies and applicable law. We may budget for and make additional sustaining capital expenditures that we expect to produce economic benefits such as increasing efficiency and/or lowering future expenses. Budgeting and approval of expansion capital expenditures generally occurs periodically throughout the year on a project-by-project basis in response to specific investment opportunities identified by our business segments from which we generally expect to receive sufficient returns to justify the expenditures. Assets comprising expansion capital projects could result in additional sustaining capital expenditures over time. The need for sustaining capital expenditures in respect of newly constructed assets tends to be minimal but tends to increase over time as such assets age and experience wear and tear. Regardless of whether assets result from sustaining or expansion capital expenditures, once completed, the addition of such assets to our depreciable asset base will impact our calculation of depreciation, depletion and amortization over the remaining useful lives of the impacted or resulting assets.

Generally, the determination of whether a capital expenditure is classified as sustaining or as expansion capital expenditures is made on a project level. The classification of our capital expenditures as expansion capital expenditures or as sustaining capital expenditures is made consistent with our accounting policies and is generally a straightforward process, but in certain circumstances can be a matter of management judgment and discretion.

Our capital expenditures for the three months ended March 31, 2026, and the amount we expect to spend for the remainder of 2026 to sustain our assets and expand our business are as follows:


	Three Months Ended March 31, 2026		2026 Remaining		Expected 2026
	(In millions)
Capital expenditures:
Sustaining capital expenditures	$	126	$	818	$	944
Expansion capital expenditures	805		2,170		2,975
Accrued capital expenditures, contractor retainage, and other	(127)		—		—
Capital expenditures	$	804	$	2,988	$	3,919
Add:
Sustaining capital expenditures of unconsolidated joint ventures(a)	$	37	$	140	$	177
Investments in unconsolidated joint ventures(b)	90		286		376
Less: Consolidated joint venture partners’ sustaining capital expenditures	(1)		(8)		(9)
Less: Consolidated joint venture partners’ expansion capital expenditures	(3)		(3)		(6)
Less: Insurance reimbursement related to a sustaining capital expenditure	(17)		—		(17)
Acquisition(c)	—		505		505
Accrued capital expenditures, contractor retainage, and other	127		—		—
Total capital investments	$	1,037	$	3,908	$	4,945

(a)Sustaining capital expenditures by our joint ventures generally do not require cash outlays by us.

(b)Reflects cash contributions to unconsolidated joint ventures. Also includes contributions to an unconsolidated joint venture that are netted within the amount the joint venture declares as a distribution to us.

(c)Includes recently announced agreement to acquire Monument Pipeline.

Our capital investments consist of the following:


	Three Months Ended March 31, 2026		2026 Remaining		Expected 2026
	(In millions)
Sustaining capital investments
Capital expenditures for property, plant, and equipment	$	126	$	818	$	944
Sustaining capital expenditures of unconsolidated joint ventures(a)	37		140		177
Less: Consolidated joint venture partners’ sustaining capital expenditures	(1)		(8)		(9)
Less: Insurance reimbursement related to a sustaining capital expenditure	(17)		—		(17)
Total sustaining capital investments	145		950		1,095
Expansion capital investments
Capital expenditures for property, plant, and equipment	805		2,170		2,975
Investments in unconsolidated joint ventures(b)	90		286		376
Less: Consolidated joint venture partners’ expansion capital expenditures	(3)		(3)		(6)
Acquisition(c)	—		505		505
Total expansion capital investments	892		2,958		3,850
Total capital investments	$	1,037	$	3,908	$	4,945

(a)Sustaining capital expenditures by our joint ventures generally do not require cash outlays by us.

(c)Includes recently announced agreement to acquire Monument Pipeline.

Off Balance Sheet Arrangements

There have been no material changes in our obligations with respect to other entities that are not consolidated in our financial statements that would affect the disclosures presented as of December 31, 2025 in our 2025 Form 10-K.

Commitments for the purchase of property, plant, and equipment as of March 31, 2026 and December 31, 2025 were $1,879 million and $2,020 million, respectively, decreasing $141 million primarily related to projects advancing in our Natural Gas Pipelines business segment.

Cash Flows

The following table summarizes our net cash flows provided by (used in) operating, investing, and financing activities between 2026 and 2025:


Three Months Ended March 31,
2026	2025	Changes
(In millions)

Remaining 2026

2028 and thereafter

(In billions)

Estimated revenue as of March 31, 2026