Companies: 11,396     total market cap: $151.461 T
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Kinder Morgan
KMI
#333
Rank
$75.68 B
Marketcap
๐Ÿ‡บ๐Ÿ‡ธ United States
Country
$33.98
Share price
1.24%
Change (1 day)
30.27%
Change (1 year)
๐Ÿ›ข Oil&Gas๐Ÿšš Transportation โšก Energy๐Ÿ›ฃ๏ธ Infrastructure
Categories
  1. Kinder Morgan
  2. Quarterly Reports (10-Q)
  3. Financial Year FY2026 Q3

Kinder Morgan - 10-Q quarterly report FY2026 Q3


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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 September 30, 2026

or

☐  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
image0a30a07.gif

KINDER MORGAN, INC.
(Exact name of registrant as specified in its charter)
 
Delaware80-0682103
(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 classTrading Symbol(s)Name of each exchange on which registered
Class P Common StockKMINew York Stock Exchange
2.250% Senior Notes due 2027KMI 27 ANew 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 October 22, 2026, the registrant had 2,227,715,229 shares of Class P common stock outstanding.



KINDER MORGAN, INC. AND SUBSIDIARIES
TABLE OF CONTENTS
Page
Number
2
3
Consolidated Statements of Income - Three and Nine Months Ended September 30, 2026 and 2025
4
Consolidated Statements of Comprehensive Income - Three and Nine Months Ended September 30, 2026 and 2025
5
Consolidated Balance Sheets - as of September 30, 2026 and December 31, 2025
6
Consolidated Statements of Cash Flows - Nine Months Ended September 30, 2026 and 2025
7
Consolidated Statements of Stockholders’ Equity - Three and Nine Months Ended September 30, 2026 and 2025
9
Notes to Consolidated Financial Statements
10
Note 1.
10
Note 2.
11
Note 3.
12
Note 4.
14
Note 5.
14
Note 6.
19
Note 7.
22
Note 8.
26
Note 9.
26
Note 10.
30
General and Basis of Presentation
32
Results of Operations
32
Overview
32
Consolidated Earnings Results
35
Non-GAAP Financial Measures
38
Segment Earnings Results
40
Liquidity and Capital Resources
48
Summarized Combined Financial Information for Guarantee of Securities of Subsidiaries
52
53
53
53
53
53
53
53
53
55
56

1


KINDER MORGAN, INC. AND SUBSIDIARIES
GLOSSARY

Company Abbreviations
Citrus=Citrus, LLCKMLT=Kinder Morgan Liquid Terminals, LLC
KMBT=Kinder Morgan Bulk Terminals, Inc.PPL=Products (SE) Pipe Line Company
KMI=Kinder Morgan, Inc. and its majority-owned and/or controlled subsidiariesTGP=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
/d=per dayLNG=liquefied natural gas
Bbl=barrelsMBbl=thousand barrels
BBtu=billion British Thermal Units MMBbl=million barrels
Bcf=billion cubic feetMMtons=million tons
CERCLA=Comprehensive Environmental Response, Compensation and Liability ActNGL=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 AgencyRNG=Renewable natural gas
FASB=Financial Accounting Standards BoardROU=Right-of-Use
GAAP=U.S. Generally Accepted Accounting PrinciplesU.S.=United States of America
IT=Information TechnologyWTI=West Texas Intermediate
LLC=limited liability company


2

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 the regulatory environment for projects and expected costs, 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 in the Middle East, including commodity price volatility and potential adverse effects on financial and economic conditions; our ability to obtain required permits and approvals for pending expansion projects when expected; 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 II, 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.

3

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
September 30,		Nine Months Ended
September 30,
2026202520262025
Revenues
Services$2,492 $2,340 $7,473 $7,026 
Commodity sales1,989 1,758 6,212 5,262 
Other50 48 151 141 
Total Revenues
4,531 4,146 13,836 12,429 
Operating Costs, Expenses, and Other
Costs of sales (exclusive of items shown separately below)1,566 1,395 4,720 4,082 
Operations and maintenance949 786 2,466 2,270 
Depreciation, depletion, and amortization
628 609 1,881 1,835 
General and administrative190 183 566 558 
Taxes, other than income taxes121 111 355 334 
Other income, net(83)(1)(102)(10)
Total Operating Costs, Expenses, and Other
3,371 3,083 9,886 9,069 
Operating Income1,160 1,063 3,950 3,360 
Other Income (Expense)
Earnings from equity investments231 221 710 647 
Interest, net(430)(456)(1,285)(1,359)
Other, net 19 11 59 39 
Total Other Expense
(180)(224)(516)(673)
Income Before Income Taxes980 839 3,434 2,687 
Income Tax Expense (190)(185)(749)(548)
Net Income790 654 2,685 2,139 
Net Income Attributable to Noncontrolling Interests(26)(26)(78)(79)
Net Income Attributable to Kinder Morgan, Inc.$764 $628 $2,607 $2,060 
Class P Common Stock
Basic and Diluted Earnings Per Share$0.34 $0.28 $1.17 $0.92 
Basic and Diluted Weighted Average Shares Outstanding2,227 2,224 2,226 2,223 
The accompanying notes are an integral part of these consolidated financial statements.
4


KINDER MORGAN, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(In millions, unaudited)
Three Months Ended
September 30,		Nine Months Ended
September 30,
2026202520262025
Net income$790 $654 $2,685 $2,139 
Other comprehensive (loss) income, net of tax
Net unrealized (loss) gain from derivative instruments (net of taxes of $41, $(7), $87, and $(44), respectively)
(148)22 (308)145 
Reclassification into earnings of net derivative instruments loss (gain) to net income (net of taxes of $(11), $3, $(32), and $19, respectively)
39 (10)110 (59)
Benefit plan adjustments (net of taxes of $1, $1, $3, and $2, respectively)
(3)(2)(9)(5)
Total other comprehensive (loss) income(112)10 (207)81 
Comprehensive income 678 664 2,478 2,220 
Comprehensive income attributable to noncontrolling interests(26)(26)(78)(79)
Comprehensive income attributable to KMI$652 $638 $2,400 $2,141 
The accompanying notes are an integral part of these consolidated financial statements.
5


KINDER MORGAN, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(In millions, except share and per share amounts, unaudited)

September 30, 2026December 31, 2025
ASSETS
Current Assets
Cash and cash equivalents$918 $63 
Restricted deposits25 46 
Accounts receivable1,596 1,714 
Inventories621 574 
Other current assets310 357 
Total current assets3,470 2,754 
Property, plant, and equipment, net 40,892 39,331 
Investments7,836 7,532 
Goodwill20,075 20,084 
Other intangibles, net1,822 1,730 
Deferred charges and other assets1,302 1,317 
Total Assets$75,397 $72,748 
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current Liabilities
Current portion of debt $1,726 $1,226 
Accounts payable1,587 1,408 
Accrued interest365 534 
Accrued taxes289 256 
Other current liabilities1,212 898 
Total current liabilities5,179 4,322 
Long-term liabilities and deferred credits
Long-term debt
Outstanding
31,445 30,597 
Debt fair value adjustments
(98)180 
Total long-term debt31,347 30,777 
Deferred income taxes3,603 2,891 
Other long-term liabilities and deferred credits2,441 2,309 
Total long-term liabilities and deferred credits37,391 35,977 
Total Liabilities42,570 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, 2,227,712,648 and 2,224,777,750 shares, respectively, issued and outstanding
22 22 
Additional paid-in capital41,293 41,276 
Accumulated deficit(9,558)(10,181)
Accumulated other comprehensive (loss)/income(162)45 
Total Kinder Morgan, Inc.’s stockholders’ equity31,595 31,162 
Noncontrolling interests1,232 1,287 
Total Stockholders’ Equity32,827 32,449 
Total Liabilities and Stockholders’ Equity$75,397 $72,748 
The accompanying notes are an integral part of these consolidated financial statements.
6


KINDER MORGAN, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(In millions, unaudited)
Nine Months Ended September 30,
20262025
Cash Flows From Operating Activities
Net income$2,685 $2,139 
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation, depletion, and amortization
1,881 1,835 
Deferred income taxes770 512 
Change in fair value of derivative contracts25 14 
Gain on divestitures, net (Note 2)(70)(3)
Earnings from equity investments(710)(647)
Distributions of equity investment earnings
575 585 
Changes in components of working capital
Accounts receivable123 75 
Inventories(46)(5)
Other current assets(17)13 
Accounts payable(13)(30)
Accrued interest, net of interest rate swaps(166)(181)
Accrued taxes33 19 
Other current liabilities129 (26)
Other, net(158)(75)
Net Cash Provided by Operating Activities5,041 4,225 
Cash Flows From Investing Activities
Acquisition of assets, net of cash acquired (Note 2)(503)(648)
Capital expenditures(2,831)(2,206)
Net proceeds (cost of removal) from sales of assets (Note 2)54 (14)
Contributions to investments(239)(103)
Distributions from equity investments in excess of cumulative earnings138 269 
Net Cash Used in Investing Activities(3,381)(2,702)
Cash Flows From Financing Activities
Issuances of debt 6,415 8,434 
Payments of debt (5,079)(7,910)
Debt issue costs(26)(18)
Dividends(1,984)(1,950)
Distributions to noncontrolling interests(119)(122)
Other, net(33)(38)
Net Cash Used in Financing Activities(826)(1,604)
Net Increase (Decrease) in Cash, Cash Equivalents, and Restricted Deposits834 (81)
Cash, Cash Equivalents, and Restricted Deposits, beginning of period
109 214 
Cash, Cash Equivalents, and Restricted Deposits, end of period
$943 $133 
7

KINDER MORGAN, INC. AND SUBSIDIARIES (Continued)
CONSOLIDATED STATEMENTS OF CASH FLOWS
(In millions, unaudited)
Nine Months Ended September 30,
20262025
Non-cash Investing and Financing Activities
ROU assets and operating lease obligations recognized including adjustments$91 $17 
Equity investment interest received from sale of assets (Note 2) 55 — 
Net increase in property, plant, and equipment from both accruals and contractor retainage
191 
Supplemental Disclosures of Cash Flow Information
Cash paid during the period for interest (net of capitalized interest)1,463 1,538 
Cash (refund) paid during the period for income taxes, net
(11)43 
The accompanying notes are an integral part of these consolidated financial statements.
8


KINDER MORGAN, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY
(In millions, unaudited)

Common stockAdditional
paid-in
capital		Accumulated
deficit		Accumulated
other
comprehensive
loss		Stockholders’
equity
attributable
to KMI		Non-
controlling
interests		Total
Issued sharesPar value
Balance at June 30, 20262,225 $22 $41,316 $(9,657)$(50)$31,631 $1,248 $32,879 
Stock awards3 (23)(23)(23)
Net income764 764 26 790 
Dividends
(665)(665)(665)
Distributions
— (42)(42)
Other comprehensive loss(112)(112)(112)
Balance at September 30, 20262,228 $22 $41,293 $(9,558)$(162)$31,595 $1,232 $32,827 
Common stockAdditional
paid-in
capital		Accumulated
deficit		Accumulated
other
comprehensive
loss		Stockholders’
equity
attributable
to KMI		Non-
controlling
interests		Total
Issued sharesPar value
Balance at June 30, 20252,222 $22 $41,269 $(10,497)$(24)$30,770 $1,311 $32,081 
Stock awards3 (14)(14)(14)
Net income628 628 26 654 
Dividends(654)(654)(654)
Distributions— (44)(44)
Other comprehensive income10 10 10 
Balance at September 30, 20252,225 $22 $41,255 $(10,523)$(14)$30,740 $1,293 $32,033 

Common stockAdditional
paid-in
capital		Accumulated
deficit
Accumulated
other
comprehensive
income/(loss)
Stockholders’
equity
attributable
to KMI		Non-
controlling
interests		Total
Issued sharesPar value
Balance at December 31, 20252,225 $22 $41,276 $(10,181)$45 $31,162 $1,287 $32,449 
Stock awards3 17 17 17 
Net income2,607 2,607 78 2,685 
Dividends
(1,984)(1,984)(1,984)
Distributions
— (119)(119)
Other
— (14)(14)
Other comprehensive loss(207)(207)(207)
Balance at September 30, 20262,228 $22 $41,293 $(9,558)$(162)$31,595 $1,232 $32,827 
Common stockAdditional
paid-in
capital		Accumulated
deficit		Accumulated
other
comprehensive
loss		Stockholders’
equity
attributable
to KMI		Non-
controlling
interests		Total
Issued sharesPar value
Balance at December 31, 20242,222 $22 $41,237 $(10,633)$(95)$30,531 $1,336 $31,867 
Stock awards3 18 18 18 
Net income2,060 2,060 79 2,139 
Dividends(1,950)(1,950)(1,950)
Distributions— (122)(122)
Other comprehensive income81 81 81 
Balance at September 30, 20252,225 $22 $41,255 $(10,523)$(14)$30,740 $1,293 $32,033 
The accompanying notes are an integral part of these consolidated financial statements.
9

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, more than 130 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.

Goodwill

In addition to periodically evaluating long-lived assets and goodwill for impairment based on changes in market conditions, we evaluate goodwill for impairment on May 31 of each year. For our May 31, 2026 evaluation, we grouped our businesses into seven reporting units as follows: (i) Natural Gas Pipelines Regulated; (ii) Natural Gas Pipelines Non-Regulated; (iii) CO2; (iv) Products Pipelines (excluding associated terminals); (v) Products Pipelines Terminals (evaluated separately from Products Pipelines for goodwill purposes); (vi) Terminals; and (vii) Energy Transition Ventures.

The fair value estimates used in our goodwill impairment test include Level 3 inputs of the fair value hierarchy. The inputs include valuation estimates, which include assumptions primarily involving management’s judgments and estimates. For all reporting units other than the Energy Transition Ventures reporting unit within our CO2 business segment, we estimated fair value based on a market approach utilizing forecasted earnings before interest, income taxes, DD&A expenses (EBITDA), and the enterprise value to estimated EBITDA multiples of comparable companies for each of our reporting units. The value of each reporting unit was determined from the perspective of a market participant in an orderly transaction between market participants at the measurement date. For the Energy Transition Ventures reporting unit, which had a goodwill balance of $114 million as of September 30, 2026, we estimated fair value based on an income approach, which includes assumptions regarding future cash flows based primarily on production growth assumptions, terminal values, and discount rates.

The results of our May 31, 2026 annual impairment test indicated that for each of our reporting units, the reporting unit’s fair value exceeded the carrying value (by at least 10%). We did not identify any triggers requiring further impairment analysis subsequent to our annual goodwill impairment test. Changes to any one or a combination of the factors described above would result in a change to the reporting unit fair values, which could lead to future impairment charges. Such potential non-cash impairments could have a significant effect on our results of operations.

10

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
September 30,		Nine Months Ended
September 30,
2026202520262025
(In millions, except per share amounts)
Net Income Available to Stockholders$764 $628 $2,607 $2,060 
Less: Net Income Allocated to Participating Securities(a)(4)(4)(13)(11)
Net Income Allocated to Common Stockholders$760 $624 $2,594 $2,049 
Basic and Diluted Weighted Average Shares Outstanding2,227 2,224 2,226 2,223 
Basic and Diluted EPS$0.34 $0.28 $1.17 $0.92 
(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.

Our potential common stock equivalents, consisting of outstanding unvested stock awards and convertible trust preferred securities, were excluded from the diluted EPS calculation for all periods presented above, as their inclusion would have been antidilutive.

2. Acquisitions and Divestiture

As of September 30, 2026, our allocations of purchase price by acquisition are detailed below:
Assignment of Purchase Price
RefDateAcquisitionPurchase priceCurrent assets
Property, plant, & equipment
Other long-term assetsCurrent liabilitiesLong-term liabilitiesResulting goodwill
(In millions)
(1)5/26Monument Pipeline$503 $10 $264 $236 $(7)$— $— 
(2)
2/25
Outrigger Energy648 16 497 160 (5)(20)— 

(1) Monument Pipeline System Acquisition

On May 1, 2026, we completed the acquisition of the Monument Pipeline, a natural gas pipeline system serving Houston, Texas and the surrounding metropolitan area, from ARM Energy Holdings for a purchase price of $503 million, including purchase price adjustments for working capital. Other long-term assets within the preliminary purchase price allocation consist of customer relationships intangibles with a weighted average amortization period of approximately 14 years. The acquisition includes approximately 225 miles of pipelines and provides transportation and storage services to gas utilities, LNG shippers, and industrial customers. The acquired assets are included in our Natural Gas Pipelines business segment.

(2) 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 consist of a 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 acquisitions as if they had occurred as of January 1 of each year preceding each transaction is not presented because it would not be materially different from the information presented in our accompanying consolidated statements of income.

11

Divestiture

Terminals Divestiture

On September 1, 2026, in our Terminals business segment, we divested certain terminals and terminal assets located in the Tampa, Florida area in exchange for net consideration of $136 million, after working capital adjustments, consisting of (i) $81 million of cash proceeds, which is reflected as an investing activity within “Net proceeds (cost of removal) from sales of assets” on our consolidated statement of cash flows, and (ii) $55 million additional interests in an equity investment. In conjunction with this transaction, we recorded a net gain of $71 million, reported within “Other income, net” on our consolidated statement of income, which includes a $9 million reduction to goodwill.

3. Debt

The following table provides information on the principal amount of our outstanding debt balances:
September 30, 2026December 31, 2025
(In millions, unless otherwise stated)
Current portion of debt
$3.5 billion credit facility due May 21, 2031
$— $— 
Commercial paper notes(a)— 13 
Current portion of senior notes
4.15%, due August 2026
— 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)
567 — 
7.00%, due March 2027
300 — 
Trust I preferred securities, 4.75%, due March 2028(c)
111 111 
Current portion of other debt41 27 
Total current portion of debt1,726 1,226 
Long-term debt (excluding current portion)
Senior notes30,921 30,065 
EPC Building, LLC, promissory note, 3.967%, due 2026 through 2035
251 268 
Trust I preferred securities, 4.75%, due March 2028
109 110 
Other164 154 
Total long-term debt31,445 30,597 
Total debt(d)$33,171 $31,823 
(a)The weighted average interest rate on borrowings at December 31, 2025 was 3.85%.
(b)Consists of senior notes denominated in Euros that have been converted to U.S. dollars and are respectively reported above at the September 30, 2026 exchange rate of $1.1330 U.S. dollars per Euro and at the December 31, 2025 exchange rate of $1.1746 U.S. dollars per Euro. As of September 30, 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 $24 million and $44 million, respectively. As of September 30, 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 decreased our total debt balance by $98 million as of September 30, 2026 and increased our total debt balance by $180 million as of December 31, 2025.

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. In addition, substantially all of our wholly owned domestic subsidiaries guarantee our obligations under our credit facility pursuant to a guarantee agreement executed in connection with our credit facility.

On August 6, 2026, we issued in a registered offering, two series of senior notes consisting of $1,150 million aggregate principal amount of 5.55% senior notes due 2036 and $600 million aggregate principal amount of 6.15% senior notes due 2056 and received combined net proceeds of $1,730 million.

12

Credit Facilities and Restrictive Covenants

On May 21, 2026, we, as borrower, entered into an Amended and Restated Revolving Credit Agreement (the “Amended Credit Facility”) with Barclays Bank PLC, as administrative agent (“Barclays”), and the lenders listed on the signature pages to such Amended Credit Facility, which amended and restated the Company’s $3.5 billion Revolving Credit Agreement dated August 20, 2021 (as previously amended, the “Existing Credit Facility”).

The Amended Credit Facility amended certain provisions of the Existing Credit Facility to, among other things, (i) extend the stated maturity date from August 20, 2026 to May 21, 2031, and (ii) increase the amount of the facility available for swingline loans from $50 million to $400 million. Substantially all of our wholly owned domestic subsidiaries guarantee our obligations under the Amended Credit Facility pursuant to a guaranty agreement.

Depending on the type of loan request, our borrowings under our Amended Credit Facility bear interest at either (i) the greatest of (1) the Federal Funds Rate plus 0.5%; (2) the Prime Rate; or (3) the Term SOFR for a one-month period plus 1% or (ii) Term SOFR or (iii) Daily Simple SOFR, plus, in each case, an applicable margin ranging from 0.000% to 1.500% per annum based on our credit rating. Standby fees for the unused portion of the credit facility will be calculated at a rate ranging from 0.075% to 0.200%.

The Amended Credit Facility contains financial and various other covenants that apply to us and our subsidiaries and are common in such agreements, including a maximum ratio of Consolidated Net Indebtedness to Consolidated EBITDA (as defined in the Amended Credit Facility, as amended) of 5.50 to 1.00, for any four-fiscal-quarter period. Other negative covenants include restrictions on our and certain of our subsidiaries’ ability to incur debt, grant liens, make fundamental changes, or engage in certain transactions with affiliates, or in the case of certain material subsidiaries, permit restrictions on dividends, distributions, or making or prepayments of loans to us or any guarantor. The Amended Credit Facility also restricts our ability to make certain restricted payments if an event of default (as defined in the Amended Credit Facility) has occurred and is continuing or would occur and be continuing.

As of September 30, 2026, we had no borrowings outstanding under our credit facility, no borrowings outstanding under our commercial paper program, and $10 million in letters of credit. Our availability under our credit facility as of September 30, 2026 was approximately $3,490 million. For the periods ended September 30, 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:
September 30, 2026December 31, 2025
Carrying
value		Estimated
fair value(a)		Carrying
value		Estimated
fair value(a)
(In millions)
Total debt$33,073 $31,273 $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 September 30, 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 September 30, 2026 and December 31, 2025.

13

4. Stockholders’ Equity

Class P Common Stock

Dividends

The following table provides information about our per share dividends:
Three Months Ended
September 30,		Nine Months Ended
September 30,
2026202520262025
Per share cash dividend declared for the period$0.2975 $0.2925 $0.8925 $0.8775 
Per share cash dividend paid in the period0.2975 0.2925 0.8875 0.8725 

On October 21, 2026, our board of directors declared a cash dividend of $0.2975 per share for the quarterly period ended September 30, 2026, which is payable on November 16, 2026 to shareholders of record as of the close of business on November 2, 2026.

Accumulated Other Comprehensive Income (Loss)

Changes in the components of our “Accumulated other comprehensive income (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 income (loss)
(In millions)
Balance as of December 31, 2025
$67 $(22)$45 
Other comprehensive loss before reclassifications
(308)(9)(317)
Loss reclassified from accumulated other comprehensive loss
110 — 110 
Net current-period change in accumulated other comprehensive loss(198)(9)(207)
Balance as of September 30, 2026$(131)$(31)$(162)
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 gain (loss) before reclassifications145 (5)140 
Gain reclassified from accumulated other comprehensive loss
(59)— (59)
Net current-period change in accumulated other comprehensive loss86 (5)81 
Balance as of September 30, 2025$53 $(67)$(14)

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.

14

Energy Commodity Price Risk Management

As of September 30, 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(14.0)MMBbl
Derivatives not designated as hedging contracts
Crude oil fixed price(0.9)MMBbl
Crude oil basis(1.3)MMBbl
Natural gas fixed price(48.7)Bcf
Natural gas basis(136.7)Bcf
NGL fixed price(1.4)MMBbl

As of September 30, 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 September 30, 2026:
Notional amountAccounting treatmentMaximum term
(In millions)
Derivatives designated as hedging instruments
Fixed-to-variable interest rate contracts(a)
$4,500 Fair value hedgeFebruary 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 September 30, 2026:
Notional amountAccounting treatment
Maturity
(In millions)
Derivatives designated as hedging instruments
EUR-to-USD cross currency swap contracts(a)$543 Cash flow hedgeMarch 2027
(a)These swaps eliminate the foreign currency risk associated with our Euro-denominated debt which matures in March 2027.

15

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
LocationDerivatives AssetDerivatives Liability
September 30,
2026		December 31,
2025		September 30,
2026		December 31,
2025
(In millions)
Derivatives designated as hedging instruments
Energy commodity derivative contracts
Other current assets/(Other current liabilities)$— $56 $(129)$— 
Deferred charges and other assets/(Other long-term liabilities and deferred credits)— 36 (36)— 
Subtotal— 92 (165)— 
Interest rate contracts
Other current assets/(Other current liabilities)2 4 (60)(25)
Deferred charges and other assets/(Other long-term liabilities and deferred credits)1 32 (264)(111)
Subtotal3 36 (324)(136)
Foreign currency contracts
Other current assets/(Other current liabilities)21 — — (2)
Deferred charges and other assets— 41 — — 
Subtotal21 41 — (2)
Total24 169 (489)(138)
Derivatives not designated as hedging instruments
Energy commodity derivative contracts
Other current assets/(Other current liabilities)51 75 (49)(74)
Deferred charges and other assets/(Other long-term liabilities and deferred credits)3 4 (25)(1)
Total54 79 (74)(75)
Total derivatives
$78 $248 $(563)$(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 nettingCash collateral held(a)
Level 1Level 2Level 3Gross amountNet amount
(In millions)
As of September 30, 2026
Energy commodity derivative contracts(b)$41 $13 $— $54 $(41)$— $13 
Interest rate contracts— 3 — 3 — — 3 
Foreign currency contracts— 21 — 21 — — 21 
As of December 31, 2025
Energy commodity derivative contracts(b)$20 $151 $— $171 $(68)$— $103 
Interest rate contracts— 36 — 36 (6)— 30 
Foreign currency contracts— 41 — 41 — — 41 
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Balance sheet liability
fair value measurements by level		Contracts available for nettingCash collateral posted(a)
Level 1Level 2Level 3Gross amountNet amount
(In millions)
As of September 30, 2026
Energy commodity derivative contracts(b)$(6)$(233)$— $(239)$41 $(1)$(199)
Interest rate contracts— (324)— (324)— — (324)
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 relationshipsLocationGain/(loss) recognized in income
 on derivatives and related hedged item
Three Months Ended
September 30,		Nine Months Ended
September 30,
2026202520262025
(In millions)
Interest rate contracts
Interest, net$(170)$15 $(221)$136 
Hedged fixed rate debt(a)
Interest, net$170 $(25)$221 $(145)
(a)As of September 30, 2026, the cumulative amount of fair value hedging adjustments resulted in a decrease of $322 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.

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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
September 30,		Three Months Ended
September 30,
2026202520262025
(In millions)(In millions)
Energy commodity derivative contracts
$(185)$32 
Revenues—Commodity sales
$(45)$17 
Costs of sales
— (1)
Foreign currency contracts
(4)(3)
Other, net
(5)(3)
Total$(189)$29 Total$(50)$13 

Derivatives in cash flow hedging relationships
Gain/(loss) recognized in OCI on derivatives(a)Location
Gain/(loss) reclassified from Accumulated OCI into income
Nine Months Ended
September 30,		Nine Months Ended
September 30,
2026202520262025
(In millions)(In millions)
Energy commodity derivative contracts
$(378)$122 
Revenues—Commodity sales
$(121)$11 
Costs of sales
— (2)
Foreign currency contracts
(17)67 
Other, net
(21)69 
Total$(395)$189 Total$(142)$78 
(a)We expect to reclassify an approximate $101 million loss associated with cash flow hedge price risk management activities included in our accumulated other comprehensive loss balance as of September 30, 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 hedgesLocationGain/(loss) recognized in income on derivatives
Three Months Ended
September 30,		Nine Months Ended
September 30,
2026202520262025
(In millions)
Energy commodity derivative contracts
Revenues—Commodity sales
$(17)$6 $6 $22 
Costs of sales
11 (25)(113)(45)
Earnings from equity investments1 1 2 1 
Interest rate contractsInterest, net— (2)— (4)
Total(a)$(5)$(20)$(105)$(26)
(a)The amounts for the three and nine months ended September 30, 2026 include approximate gains (losses) of $7 million and $(82) million, respectively, and the amounts for the three and nine months ended September 30, 2025 include approximate losses of $4 million and $20 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 September 30, 2026 and December 31, 2025, we had no outstanding letters of credit supporting our commodity price risk management program. As of September 30, 2026 and December 31, 2025, we had cash margins of $14 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 September 30, 2026 represents the initial margin requirements of $15 million, offset by variation margin requirements of $1 million. We also use industry standard commercial agreements that allow for the netting of exposures associated with
18

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 September 30, 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 September 30, 2026
Natural Gas PipelinesProducts PipelinesTerminals
CO2
Corporate and EliminationsTotal
(In millions)
Revenues from contracts with customers(a)
Services
Firm services
$1,088 $68 $228 $— $(1)$1,383 
Fee-based services363 261 115 13 (2)750 
Total services1,451 329 343 13 (3)2,133 
Commodity sales
Natural gas sales993 — — 9 (3)999 
Product sales306 396 24 290 (1)1,015 
Other sales8 — — 32 (2)38 
Total commodity sales1,307 396 24 331 (6)2,052 
Total revenues from contracts with customers2,758 725 367 344 (9)4,185 
Other revenues
Leasing services(b)112 41 195 17 — 365 
Derivatives adjustments on commodity sales(2)— — (60)— (62)
Other31 6 — 6 — 43 
Total other revenues141 47 195 (37)— 346 
Total revenues$2,899 $772 $562 $307 $(9)$4,531 
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Three Months Ended September 30, 2025
Natural Gas PipelinesProducts PipelinesTerminals
CO2
Corporate and EliminationsTotal
(In millions)
Revenues from contracts with customers(a)
Services
Firm services
$1,037 $51 $217 $— $(1)$1,304 
Fee-based services282 282 106 12 (1)681 
Total services1,319 333 323 12 (2)1,985 
Commodity sales
Natural gas sales952 — — 10 (2)960 
Product sales239 292 9 210 (2)748 
Other sales7 — — 24 (1)30 
Total commodity sales1,198 292 9 244 (5)1,738 
Total revenues from contracts with customers2,517 625 332 256 (7)3,723 
Other revenues
Leasing services(b)115 46 186 18 — 365 
Derivatives adjustments on commodity sales18 — — 5 — 23 
Other26 6 — 3 — 35 
Total other revenues159 52 186 26 — 423 
Total revenues$2,676 $677 $518 $282 $(7)$4,146 

Nine Months Ended September 30, 2026
Natural Gas PipelinesProducts PipelinesTerminals
CO2
Corporate and EliminationsTotal
(In millions)
Revenues from contracts with customers(a)
Services
Firm services
$3,313 $192 $705 $1 $(3)$4,208 
Fee-based services1,036 797 324 38 (6)2,189 
Total services4,349 989 1,029 39 (9)6,397 
Commodity sales
Natural gas sales3,229 — — 36 (6)3,259 
Product sales808 1,225 70 869 (9)2,963 
Other sales25 — — 92 (2)115 
Total commodity sales4,062 1,225 70 997 (17)6,337 
Total revenues from contracts with customers8,411 2,214 1,099 1,036 (26)12,734 
Other revenues
Leasing services(b)334 128 586 47 — 1,095 
Derivatives adjustments on commodity sales34 (1)— (148)— (115)
Other87 20 — 15 — 122 
Total other revenues455 147 586 (86)— 1,102 
Total revenues$8,866 $2,361 $1,685 $950 $(26)$13,836 
20

Nine Months Ended September 30, 2025
Natural Gas PipelinesProducts PipelinesTerminals
CO2
Corporate and EliminationsTotal
(In millions)
Revenues from contracts with customers(a)
Services
Firm services
$3,128 $151 $662 $1 $(3)$3,939 
Fee-based services864 817 306 32 (4)2,015 
Total services3,992 968 968 33 (7)5,954 
Commodity sales
Natural gas sales2,802 — — 37 (6)2,833 
Product sales712 898 41 663 (6)2,308 
Other sales21 — — 77 (2)96 
Total commodity sales3,535 898 41 777 (14)5,237 
Total revenues from contracts with customers7,527 1,866 1,009 810 (21)11,191 
Other revenues
Leasing services(b)
340 146 560 53 — 1,099 
Derivatives adjustments on commodity sales24 — — 9 — 33 
Other75 19 — 12 — 106 
Total other revenues439 165 560 74 — 1,238 
Total revenues$7,966 $2,031 $1,569 $884 $(21)$12,429 
(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 September 30, 2026 and December 31, 2025, our contract asset balances were $33 million and $30 million, respectively, and our contract liability balances were $488 million and $459 million, respectively. Of the December 31, 2025 contract asset and liability balances, $19 million was transferred to accounts receivable and $112 million was recognized as revenue during the nine months ended September 30, 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 $489 million and $531 million as of September 30, 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:
Remaining 202620272028 and thereafter
(In billions)
Estimated revenue as of September 30, 2026
$1 $5 $31 
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.
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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 September 30, 2026
Reportable Segments
Natural Gas PipelinesProducts PipelinesTerminals
CO2
Corporate and EliminationsTotal
(In millions)
Revenues
Revenues from external customers$2,894 $772 $560 $305 $— $4,531 
Intersegment revenues5 — 2 2 (9)— 
Total revenues2,899 772 562 307 (9)4,531 
Costs of sales(1,163)(364)(19)(26)
Labor(88)(33)(73)(14)
Fuel and power(27)(23)(5)(37)
Field - non-labor(a)(252)(190)(136)(65)
Taxes, other than income taxes(78)(10)(19)(13)
Earnings from equity investments201 19 4 6 
Other segment items(b)9 1 71 14 
Total Segment EBDA(c)(d)$1,501 $172 $385 $172 2,230 
DD&A(628)
General and administrative and corporate charges(192)
Interest, net(e)(430)
Income tax expense(190)
Net income$790 
Other segment activity information:
DD&A$314 $88 $128 $90 $8 $628 
Capital expenditures812 34 107 75 17 1,045 
22

Three Months Ended September 30, 2025
Reportable Segments
Natural Gas PipelinesProducts PipelinesTerminals
CO2
Corporate and EliminationsTotal
(In millions)
Revenues
Revenues from external customers$2,672 $677 $516 $281 $— $4,146 
Intersegment revenues4 — 2 1 (7)— 
Total revenues2,676 677 518 282 (7)4,146 
Costs of sales(1,089)(281)(9)(22)
Labor(84)(34)(70)(13)
Fuel and power(23)(25)(4)(42)
Field - non-labor(a)(237)(52)(135)(64)
Taxes, other than income taxes(70)(10)(16)(12)
Earnings (loss) from equity investments212 13 (10)6 
Other segment items(b)6 — — — 
Total Segment EBDA(f)$1,391 $288 $274 $135 2,088 
DD&A(609)
General and administrative and corporate charges(184)
Interest, net(e)(456)
Income tax expense(185)
Net income$654 
Other segment activity information:
DD&A$294 $81 $130 $98 $6 $609 
Capital expenditures572 53 79 79 10 793 
23

Nine Months Ended September 30, 2026
Reportable Segments
Natural Gas PipelinesProducts PipelinesTerminals
CO2
Corporate and EliminationsTotal
(In millions)
Revenues
Revenues from external customers$8,849 $2,361 $1,678 $948 $— $13,836 
Intersegment revenues17 — 7 2 (26)— 
Total revenues8,866 2,361 1,685 950 (26)13,836 
Costs of sales(3,500)(1,109)(55)(78)
Labor(262)(101)(213)(41)
Fuel and power(78)(64)(15)(95)
Field - non-labor(a)(709)(279)(414)(186)
Taxes, other than income taxes(235)(30)(46)(39)
Earnings from equity investments619 55 11 24 
Other segment items(b)31 2 71 31 
Total Segment EBDA(c)(d)$4,732 $835 $1,024 $566 7,157 
DD&A(1,881)
General and administrative and corporate charges(557)
Interest, net(e)(1,285)
Income tax expense(749)
Net income$2,685 
Other segment activity information:
DD&A$916 $257 $389 $298 $21 $1,881 
Capital expenditures2,219 110 246 206 50 2,831 

24


Nine Months Ended September 30, 2025
Reportable Segments
Natural Gas PipelinesProducts PipelinesTerminals
CO2
Corporate and EliminationsTotal
(In millions)
Revenues
Revenues from external customers$7,953 $2,031 $1,563 $882 $— $12,429 
Intersegment revenues13 — 6 2 (21)— 
Total revenues7,966 2,031 1,569 884 (21)12,429 
Costs of sales(3,124)(866)(38)(70)
Labor(248)(99)(209)(39)
Fuel and power(62)(68)(15)(108)
Field - non-labor(a)(659)(160)(411)(181)
Taxes, other than income taxes(215)(33)(43)(37)
Earnings (loss) from equity investments593 44 (6)16 
Other segment items(b)29 1 2 1 
Total Segment EBDA(f)$4,280 $850 $849 $466 6,445 
DD&A(1,835)
General and administrative and corporate charges(564)
Interest, net(e)(1,359)
Income tax expense(548)
Net income$2,139 
Other segment activity information:
DD&A$875 $274 $388 $279 $19 $1,835 
Capital expenditures1,474 192 232 264 44 2,206 

Reportable Segments
Natural Gas PipelinesProducts PipelinesTerminals
CO2
Corporate and EliminationsTotal
(In millions)
Segment balance sheet information:
As of September 30, 2026
Investments$7,196 $389 $180 $69 $2 $7,836 
Other intangibles, net1,075 355 11 381 — 1,822 
Total assets(g)54,672 7,969 7,827 3,488 1,441 75,397 
As of December 31, 2025
Investments$6,962 $381 $122 $67 $— $7,532 
Other intangibles, net900 403 13 414 — 1,730 
Total assets(g)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 for the three and nine months ended September 30, 2026 of $10 million and $(5) million, $(3) million and $(4) million, and $(12) million and $(14) million, respectively, for our Natural Gas Pipelines, Products Pipelines, and CO2 business segments, respectively.
(d)Includes non-cash legal, environmental, and other expense accruals for each of the three and nine months ended September 30, 2026 of $138 million for our Products Pipelines business segment.
(e)We do not attribute interest and debt expense to any of our reportable business segments.
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(f)Includes non-cash risk management activities amounts for the three and nine months ended September 30, 2025 of $(12) million and $(3) million, none and $(1) million, and $(1) million and $3 million, respectively, for our Natural Gas Pipelines, Products Pipelines, and CO2 business segments, respectively.
(g)Corporate assets include 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
September 30,		Nine Months Ended
September 30,
2026202520262025
(In millions, except percentages)
Income tax expense$190 $185 $749 $548 
Effective tax rate19.4 %22.0 %21.8 %20.4 %

The effective tax rate for the three months ended September 30, 2026 is lower than the statutory federal rate of 21% primarily due to (i) an adjustment to our deferred tax liability as a result of the reduction in the state effective tax rates; (ii) tax benefits from equity based compensation; and (iii) dividend-received deductions from our investments in Citrus, NGPL Holdings LLC, and PPL, partially offset by state taxes.

The effective tax rate for the nine months ended September 30, 2026 is higher than the statutory federal rate of 21% primarily due to (i) an adjustment to Texas Margin Tax as a result of the enactment of bonus depreciation provisions; and (ii) state income taxes, partially offset by (i) an adjustment to our deferred tax liability as a result of the reduction in the state effective tax rates; (ii) tax benefits from equity based compensation; and (iii) dividend-received deductions from our investments in Citrus, NGPL Holdings LLC, and PPL.

The effective tax rate for the three months ended September 30, 2025 is higher than the statutory federal tax rate of 21% primarily due to state income taxes, partially offset by dividend-received deductions from our investments in Citrus, NGPL Holdings LLC, and PPL.

The effective tax rate for the nine months ended September 30, 2025 is lower than the statutory federal tax rate of 21% primarily due to (i) the recognition of investment tax credits generated by a biogas project; (ii) an adjustment to our deferred tax liability as a result of modified income allocations; and (iii) 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.

SFPP California Public Utilities Commission (CPUC) Proceeding

SFPP submitted five applications at the CPUC over the period covering 2021 through 2026 seeking to increase SFPP’s intrastate pipeline transportation rates. Shippers protested each of SFPP’s applications on the basis of their assertion that the requested rate increases are not just and reasonable. SFPP’s first four rate applications were consolidated (A.24-01-020) in August 2024, and an evidentiary hearing on the consolidated applications was held in June 2025. On July 10, 2026, the presiding administrative law judge issued an interim proposed decision concluding that SFPP’s connected destination terminals are subject to CPUC jurisdiction but made no finding as to how those terminals should be considered when evaluating SFPP’s
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pipeline rates. If adopted by the CPUC, the interim proposed decision would require SFPP to provide supplemental testimony with respect to the consolidated applications to address the revenues and costs associated with all CPUC-jurisdictional assets, including the connected destination terminals. SFPP disagrees with the interim proposed decision and intends to continue to vigorously defend its position. The interim proposed decision remains subject to review and approval by the CPUC. If and to the extent that the shippers prevail in these proceedings, SFPP may be required to provide refunds and could be required to reduce certain rates prospectively. Although the ultimate outcome of these matters is uncertain, including whether any refunds or prospective rate adjustments may be required, it is not expected to have a material impact to our financial position, cash flows, or operating results.

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 $150 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. On August 10, 2026, the presiding U.S. District Court Judge rejected and modified the Magistrate’s Memorandum and Recommendation in substantial part and awarded equitable relief for Claims III, IV, and V. The Court ordered the formula for benefit accrual to be
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reformed and amended in a manner generally consistent with the scope of relief sought by the plaintiffs and further ordered and enjoined defendants to enforce the plans as reformed by the Court’s order. We disagree respectfully and strongly with the Court’s order to reform and amend a common legacy plan benefit formula that was determined previously by the Court to comply with ERISA. We believe that the Court’s equitable remedy departs significantly from governing precedent and have filed a notice of appeal to the U.S. Court of Appeals for the 5th Circuit and a motion to stay the decision pending appeal. 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 was estimated to be more than $2.8 billion at the time that the EPA finalized the Record of Decision, however remedial costs are expected to rise significantly based on the expanded scope of the remedy. The work has been divided between more than 20 separate project areas spanning 11 river miles, 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 confidential 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
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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 sometime in 2027. At this time, 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 other claims first made in January 2021 asserted by natural resource state and federal trustees relating to natural resource damages at 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 remain in federal court. 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 September 30, 2026 and December 31, 2025, we had liabilities of $397 million and $261 million, respectively, recorded for legal and environmental matters. In addition, as of September 30, 2026 and December 31, 2025, we had receivables of $9 million and $10 million, respectively, recorded for expected cost recoveries associated with environmental matters 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
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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.

ASU No. 2026-02

On May 19, 2026, the FASB issued ASU No. 2026-02, “Environmental Credits and Environmental Credit Obligations (Topic 818).” This ASU establishes guidance on the recognition, measurement, presentation, and disclosure of environmental credits and compliance obligations that may be settled by using environmental credits. US GAAP did not previously address
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how to account for these items. The 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.


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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 and Divestiture

The following divestiture and acquisition were made during the 2026 period. See Note 2 “Acquisitions and Divestiture” to our consolidated financial statements for further information on these transactions.
EventDescriptionBusiness Segment
Terminals disposition and acquisition of additional equity investment interests
$136 million
(September 2026)
We divested certain terminals and terminal assets located in Florida for mixed consideration of cash and additional interests in an equity investment.
Terminals
(Other)
Monument Pipeline system acquisition
$503 million
(May 2026)
Natural gas pipeline system 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 $4.2 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 and nine months ended September 30, 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.

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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 and nine months ended September 30, 2026 and 2025, which are also described in more detail in the footnotes to tables included in “—Segment Earnings Results” below.

Three Months Ended
September 30,		Nine Months Ended
September 30,
2026202520262025
(In millions)
Certain Items
Legal, environmental, and other accruals $138 $— $138 $— 
Risk management activities(a)(b)3 24 33 13 
Gain on divestiture, net(c)(71)— (71)— 
Income tax Certain Items(d)(42)(4)(31)(41)
Other— — — 1 
Total Certain Items(e)(f)$28 $20 $69 $(27)
(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)Amounts for the three and nine-month periods ended September 30, 2026, reflect a gain recognized on the sale of certain assets in our Terminals business segment.
(d)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.
(e)Amounts for the periods ended September 30, 2026 and 2025 include $(1) million for each of the three-month periods and $(2) million and $(1) million for the nine-month periods, respectively, reported within “Earnings from equity investments” on the accompanying consolidated statement of income of “Risk management activities.”
(f)2025 amounts for the three and nine-month periods include $11 million and $12 million, respectively, 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
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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.

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Net Debt

Net Debt is calculated, based on amounts as of September 30, 2026, by subtracting the following amounts from our debt balance of $33,073 million: (i) cash and cash equivalents of $918 million; (ii) debt fair value adjustments of $(98) million; and (iii) the foreign exchange impact on Euro-denominated bonds of $24 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
September 30,
20262025Earnings
increase/(decrease)
(In millions, except per share amounts and percentages)
Revenues$4,531 $4,146 $385 9 %
Operating Costs, Expenses and Other
Costs of sales (exclusive of items shown separately below)(1,566)(1,395)(171)(12)%
Operations and maintenance(949)(786)(163)(21)%
DD&A(628)(609)(19)(3)%
General and administrative(190)(183)(7)(4)%
Taxes, other than income taxes(121)(111)(10)(9)%
Other income, net83 1 82 8,200 %
Total Operating Costs, Expenses and Other(3,371)(3,083)(288)(9)%
Operating Income1,160 1,063 97 9 %
Other Income (Expense)
Earnings from equity investments231 221 10 5 %
Interest, net(430)(456)26 6 %
Other, net19 11 8 73 %
Total Other Expense(180)(224)44 20 %
Income Before Income Taxes980 839 141 17 %
Income Tax Expense(190)(185)(5)(3)%
Net Income790 654 136 21 %
Net Income Attributable to Noncontrolling Interests(26)(26)— — %
Net Income Attributable to Kinder Morgan, Inc.$764 $628 $136 22 %
Basic and diluted earnings per share$0.34 $0.28 $0.06 21 %
Basic and diluted weighted average shares outstanding 2,227 2,224 3 — %
Declared dividends per share$0.2975 $0.2925 $0.005 2 %

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Nine Months Ended
September 30,
20262025Earnings
increase/(decrease)
(In millions, except per share amounts and percentages)
Revenues$13,836 $12,429 $1,407 11 %
Operating Costs, Expenses and Other
Costs of sales (exclusive of items shown separately below)(4,720)(4,082)(638)(16)%
Operations and maintenance(2,466)(2,270)(196)(9)%
DD&A(1,881)(1,835)(46)(3)%
General and administrative(566)(558)(8)(1)%
Taxes, other than income taxes(355)(334)(21)(6)%
Other income, net102 10 92 920 %
Total Operating Costs, Expenses and Other(9,886)(9,069)(817)(9)%
Operating Income3,950 3,360 590 18 %
Other Income (Expense)
Earnings from equity investments710 647 63 10 %
Interest, net(1,285)(1,359)74 5 %
Other, net59 39 20 51 %
Total Other Expense(516)(673)157 23 %
Income Before Income Taxes3,434 2,687 747 28 %
Income Tax Expense(749)(548)(201)(37)%
Net Income2,685 2,139 546 26 %
Net Income Attributable to Noncontrolling Interests(78)(79)1 1 %
Net Income Attributable to Kinder Morgan, Inc.$2,607 $2,060 $547 27 %
Basic and diluted earnings per share$1.17 $0.92 $0.25 27 %
Basic and diluted weighted average shares outstanding 2,226 2,223 3 — %
Declared dividends per share$0.8925 $0.8775 $0.015 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 and nine-month periods ended September 30, 2026 and 2025:

Revenues

Revenues increased $385 million and $1,407 million for the three and nine months ended September 30, 2026, respectively, as compared to the respective prior year periods. These increases were primarily due to (i) increases in product sales of $267 million and $655 million, respectively, driven by higher commodity prices, and in the nine-month period, higher volumes; (ii) increases in services revenues of $148 million and $443 million, respectively, resulting from higher volumes, including expansion projects placed into service, primarily in our Natural Gas Pipelines business segment; and (iii) an increase in natural gas sales of $39 million and $426 million, respectively, due to higher volumes, and in the nine-month period, higher commodity prices, partially offset in the three-month period by lower commodity prices. These increases in revenues were partially offset by $85 million and $148 million, respectively, for the impacts of derivative contracts used to hedge commodity
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sales. The increases in sales revenues were partially offset by corresponding increases 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 $171 million and $638 million for the three and nine months ended September 30, 2026, respectively, as compared to the respective prior year periods. The increases were primarily due to (i) increases of $158 million and $334 million, respectively, in costs of sales for products driven by higher commodity prices, and in the nine-month period, higher volumes; (ii) an increase in the nine-month period of $66 million related to derivative contracts used to hedge commodity purchases; and (iii) increases of $38 million and $225 million, respectively, in costs of sales for natural gas due to higher volumes partially offset, in the nine-month period, by lower commodity prices. The increase in the three-month period was partially offset by a decrease of $37 million related to derivative contracts used to hedge commodity purchases.

Operations and Maintenance

Operations and maintenance increased $163 million and $196 million for the three and nine months ended September 30, 2026, respectively, as compared to the respective prior year periods. The increases were primarily driven by increased legal, environmental, and other expense accruals which we treated as a Certain Item, along with greater activity, including labor costs, and inflation.

Other Income, net

Other income, net increased $82 million and $92 million for the three and nine months ended September 30, 2026, respectively, as compared to the respective prior year periods. The increases were primarily due to a $71 million net gain on the sale of certain terminals and terminal assets located in Florida for mixed consideration of cash and additional interests in an equity investment, which we treated as a Certain Item.

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 $26 million and $74 million for the three and nine months ended September 30, 2026, respectively, compared to the respective prior year periods. These decreases were primarily due to higher capitalized interest and lower interest rates associated with our fixed-to-variable interest rate swap agreements, partially offset by higher interest rates on our long-term debt.

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Non-GAAP Financial Measures
Reconciliations from Net Income Attributable to Kinder Morgan, Inc.
Three Months Ended
September 30,		Nine Months Ended
September 30,
2026202520262025
(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.$764 $628 $2,607 $2,060 
Certain Items(a)
Legal, environmental, and other accruals 138 — 138 — 
Risk management activities3 24 33 13 
Gain on divestiture, net(71)— (71)— 
Income tax Certain Items(42)(4)(31)(41)
Other— — — 1 
Total Certain Items28 20 69 (27)
Adjusted Net Income Attributable to Kinder Morgan, Inc.$792 $648 $2,676 $2,033 
Reconciliation of Net Income Attributable to Kinder Morgan, Inc. to Adjusted Net Income Attributable to Common Stock
Net income attributable to Kinder Morgan, Inc.$764 $628 $2,607 $2,060 
Total Certain Items(b)28 20 69 (27)
Net income allocated to participating securities and other(c)(4)(4)(13)(11)
Adjusted Net Income Attributable to Common Stock$788 $644 $2,663 $2,022 
Adjusted EPS$0.35 $0.29 $1.20 $0.91 
Reconciliation of Net Income Attributable to Kinder Morgan, Inc. to Adjusted EBITDA
Net income attributable to Kinder Morgan, Inc. $764 $628 $2,607 $2,060 
Total Certain Items(b)28 20 69 (27)
DD&A628 609 1,881 1,835 
Income tax expense(d)232 189 780 589 
Interest, net(e)430 445 1,285 1,347 
Amounts associated with joint ventures
Unconsolidated joint venture DD&A(f)92 96 275 296 
Remove consolidated joint venture partners’ DD&A(16)(16)(47)(47)
Unconsolidated joint venture income tax expense(g)22 20 68 67 
Adjusted EBITDA$2,180 $1,991 $6,918 $6,120 
(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 for each of the periods ended September 30, 2026 and 2025 includes Adjusted net income in excess of distributions for participating securities of less than $1 million.
(d)To avoid duplication, adjustments for income tax expense for the periods ended September 30, 2026 and 2025 exclude $(42) million and $(4) million for the three-month periods, respectively, and $(31) million and $(41) million for the nine-month periods, 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 the three and nine-month periods ended September 30, 2025 exclude $11 million and $12 million, respectively, 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.
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(g)Includes the tax provision on Certain Items recognized by the investees that are taxable entities associated with our Citrus, NGPL Holdings LLC, and PPL. 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
September 30,		Nine Months Ended
September 30,
2026202520262025
(In millions)
Adjusted Net Income Attributable to Kinder Morgan, Inc.$792 $648 $2,676 $2,033 
Adjusted EBITDA2,180 1,991 6,918 6,120 
Change from prior periodIncrease/(Decrease)
Adjusted Net Income Attributable to Kinder Morgan, Inc.$144 $643 
Adjusted EBITDA$189 $798 

Adjusted Net Income Attributable to Kinder Morgan, Inc. increased $144 million and $643 million for the three and nine months ended September 30, 2026, respectively, as compared to the respective prior year periods. The increases resulted primarily from favorable contributions across all of our business segments, which were also the primary drivers of the increase in Adjusted EBITDA of $189 million and $798 million, respectively.

General and Administrative and Corporate Charges

Three Months Ended
September 30,		Nine Months Ended
September 30,
2026202520262025
(In millions)
General and administrative$(190)$(183)$(566)$(558)
Corporate benefit (charges)(2)(1)9 (6)
Certain Items(a)— — — 1 
General and administrative and corporate charges$(192)$(184)$(557)$(563)
Change from prior periodEarnings increase/(decrease)
General and administrative$(7)$(8)
Corporate charges(1)15 
Total$(8)$7 

General and administrative expenses increased $7 million and $8 million, and corporate charges increased $1 million and decreased $15 million for the three and nine months ended September 30, 2026, respectively, when compared with the respective prior year periods. The combined changes for the three and nine-month periods include higher benefit-related and labor costs, which in the nine-month period were more than offset by lower pension, corporate office facility and legal costs.
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Segment Earnings Results

Natural Gas Pipelines (including reconciliation of Segment EBDA to Adjusted Segment EBDA)
Three Months Ended
September 30,		Nine Months Ended
September 30,
2026202520262025
(In millions, except operating statistics)
Revenues$2,899 $2,676 $8,866 $7,966 
Costs of sales(1,163)(1,089)(3,500)(3,124)
Other operating expenses(a)
(445)(414)(1,284)(1,184)
Other income— 1 2 8 
Earnings from equity investments201 212 619 593 
Other, net9 5 29 21 
Segment EBDA1,501 1,391 4,732 4,280 
Certain Items:
Risk management activities(12)12 15 3 
Certain Items(b)
(12)12 15 3 
Adjusted Segment EBDA$1,489 $1,403 $4,747 $4,283 
Change from prior periodIncrease/(Decrease)
Segment EBDA$110 $452 
Adjusted Segment EBDA$86 $464 
Volumetric data(c)
Natural gas transport (BBtu/d)
49,273 47,918 49,032 46,377 
Natural gas sales (BBtu/d)
4,131 3,712 3,978 3,051 
Gathering (BBtu/d)4,722 4,129 4,561 3,861 
NGL transport (MBbl/d)
58 39 51 37 
(a)Other operating expenses include operations and maintenance expenses and taxes, other than income taxes.
(b)For the periods ending September 30, 2026 and 2025, Certain Items of (i) $(10) million and $13 million for the three-month periods, respectively, and $12 million and $4 million for the nine-month periods, respectively, are associated with our Midstream business and (ii) $(2) million and $(1) million for the three-month periods, respectively, and $3 million and $(1) million for the nine-month periods, respectively, are associated with our East business. See table included in “—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.

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Below are the changes in Natural Gas Pipelines Segment EBDA:

Three Months Ended
September 30,		Nine Months Ended
September 30,
2026202520262025
(In millions)
Midstream$548 $483 $1,773 $1,452 
West252 221 782 716 
East701 687 2,177 2,112 
Total Natural Gas Pipelines $1,501 $1,391 $4,732 $4,280 
Change from prior periodIncrease/(Decrease)
Midstream$65 $321 
West$31 $66 
East$14 $65 

The changes in Natural Gas Pipelines Segment EBDA in the comparable three and nine-month periods ended September 30, 2026 and 2025 are explained by the following discussion:

•The $65 million (13%) and $321 million (22%) increases, respectively, in Midstream were primarily driven by higher volumes on KinderHawk Field Services LLC and, on our Texas intrastate systems, increased demand for our services and contributions from the acquired Monument assets. The increase in the nine-month period was further driven by (i) higher performance from acquired assets on our Hiland Midstream assets; (ii) higher commodity prices and volumes on KM Gas Marketing LLC; and (iii) higher volumes on Kinder Morgan Altamont LLC, partially offset by the divestiture of an equity interest in EagleHawk in 2025. Overall, Midstream’s revenue changes are partially offset by corresponding changes in costs of sales.

In addition, Midstream includes favorable and unfavorable effects, for the three and nine-month periods, respectively,
from 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, which we treated as a Certain Item.

•The $31 million (14%) and $66 million (9%) increases, respectively, in West resulted primarily from higher capacity sales, contributions from expansion projects, and higher park and loan activity due to favorable pricing driven by market volatility. The increase in the nine-month period was partially offset by higher pipeline maintenance costs.

•The $14 million (2%) and $65 million (3%) increases, respectively, in East were primarily driven by (i) increased demand for our services primarily due to weather and (ii) completed expansion projects, partially offset by lower pricing on short-term firm service contracts driven by a decrease in market volatility. The increase in the nine-month period was also due to lower pipeline maintenance costs.


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Products Pipelines (including reconciliation of Segment EBDA to Adjusted Segment EBDA)
Three Months Ended
September 30,		Nine Months Ended
September 30,
2026202520262025
(In millions, except operating statistics)
Revenues$772 $677 $2,361 $2,031 
Costs of sales(364)(281)(1,109)(866)
Other operating expenses(a)
(256)(121)(474)(360)
Other income— — 1 1 
Earnings from equity investments19 13 55 44 
Other, net1 — 1 — 
Segment EBDA172 288 835 850 
Certain Items:
Risk management activities3 — 4 1 
Legal, environmental, and other accruals138 — 138 — 
Certain Items(b)
141 — 142 1 
Adjusted Segment EBDA$313 $288 $977 $851 
Change from prior periodIncrease/(Decrease)
Segment EBDA$(116)$(15)
Adjusted Segment EBDA$25 $126 
Volumetric data(c)
Gasoline(d)
940 978 941 976 
Diesel fuel363 373 354 359 
Jet fuel293 301 294 309 
Total refined product volumes1,596 1,652 1,589 1,644 
Crude and condensate410 459 417 479 
Total delivery volumes (MBbl/d)2,006 2,111 2,006 2,123 
(a)Other operating expenses include operations and maintenance expenses and taxes, other than income taxes.
(b)For the periods ending September 30, 2026 and 2025, Certain Items of (i) $138 million for each of the 2026 three-month and nine-month periods is associated with our West Coast Refined Products business and (ii) $3 million and none for the three-month periods, respectively, and $4 million and $1 million for the nine-month periods, respectively, are associated with our Southeast Refined Products business. See table included in “—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.

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Below are the changes in Products Pipelines Segment EBDA:

Three Months Ended
September 30,		Nine Months Ended
September 30,
2026202520262025
(In millions)
West Coast Refined Products$7 $158 $326 $462 
Southeast Refined Products104 71 307 220 
Crude and Condensate61 59 202 168 
Total Products Pipelines$172 $288 $835 $850 
Change from prior periodIncrease (Decrease)
West Coast Refined Products$(151)$(136)
Southeast Refined Products$33 $87 
Crude and Condensate$2 $34 

The changes in Products Pipelines Segment EBDA in the comparable three and nine-month periods ended September 30, 2026 and 2025 are explained by the following discussion:

•The $(151) million (96%) and $(136) million (29%) decreases, respectively, in West Coast Refined Products were driven by an increase in legal, environmental, and other expense accruals, which we treated as a Certain Item.

In addition, the West Coast Refined Products decreases include lower rates and lower volumes on our Pacific operations and, in the nine-month period was further decreased by net product losses, which was more than offset by lower pipeline maintenance costs and increased butane blending activity on our Pacific operations.

•The $33 million (46%) and $87 million (40%) increases, respectively, in Southeast Refined Products were primarily the result of favorable commodity prices at our Transmix processing operations and higher butane blending activity on our Southeast Terminals. The increase in the nine-month period was further driven by increased product gains on our Southeast Terminals.

•The $34 million (20%) nine-month 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, lower operating costs, and retroactive rate increases, partially offset by lower gathering volumes.


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Terminals (including reconciliation of Segment EBDA to Adjusted Segment EBDA)
Three Months Ended
September 30,		Nine Months Ended
September 30,
2026202520262025
(In millions, except operating statistics)
Revenues$562$518$1,685$1,569
Costs of sales(19)(9)(55)(38)
Other operating expenses(a)(233)(225)(688)(678)
Other income70—69—
Earnings (loss) from equity investments4(10)11(6)
Other, net1—22
Segment EBDA$385$274$1,024$849
Certain Items:
Gain on divestiture, net(71)—(71)—
Certain Items(b)(71)—(71)—
Adjusted Segment EBDA$314$274$953$849
Change from prior periodIncrease/(Decrease)
Segment EBDA$111$175
Adjusted Segment EBDA$40$104
Volumetric data(c)
Liquids leasable capacity (MMBbl)78.7 78.7 78.7 78.7 
Liquids utilization %(d)
92.6 %94.6 %93.0 %94.4 %
Bulk transload tonnage (MMtons)13.5 11.5 37.5 34.8 
(a)Other operating expenses include operations and maintenance expenses and taxes, other than income taxes.
(b)The 2026 Certain Items are associated with our Other group. See table included in “—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.

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For purposes of the following tables and related discussions, the results of operations of our terminals held for sale or divested, including any associated gain or loss on sale, are adjusted for all periods presented from the historical business grouping and included within the Other group.

Below are the changes in Terminals Segment EBDA:

Three Months Ended
September 30,		Nine Months Ended
September 30,
2026202520262025
(In millions)
Liquids$178 $157 $561 $485 
Bulk66 52 188 172 
Jones Act tankers67 60 195 179 
Other74 5 80 13 
Total Terminals $385 $274 $1,024 $849 
Change from prior periodIncrease/(Decrease)
Liquids$21 $76 
Bulk$14 $16 
Jones Act tankers$7 $16 
Other$69 $67 

The changes in Terminals Segment EBDA in the comparable three and nine-month periods ended September 30, 2026 and 2025 are explained by the following discussion:

•The $21 million (13%) and $76 million (16%) increases, respectively, in Liquids were driven by (i) an equity investment impairment in 2025; (ii) expansion projects placed into service; and (iii) favorable commodity pricing, partially offset by the effects of a customer’s closure of its refinery in 2025 at our Houston Ship Channel facilities. The increase in the nine-month period was also driven by the recognition of payments being received in connection with the early termination of certain storage agreements in 2026 related to the refinery closure, and higher rates and ancillaries at our Houston Ship Channel facilities, partially offset by higher maintenance costs.

•The $14 million (27%) and $16 million (9%) increases, respectively, in Bulk were driven by increased volumes and handling activities for petroleum coke and coal. The increase in the nine-month period was also impacted by higher operating costs.

•The $7 million (12%) and $16 million (9%) increases, respectively, in Jones Act tankers were primarily due to higher average charter rates.

•The $69 million (1380%) and $67 million (515%) increases, respectively, in Other include a $71 million net gain on sale of certain terminals and terminal assets located in Florida for mixed consideration of cash and additional interests in an equity investment, which we treated as a Certain Item.




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CO2 (including reconciliation of Segment EBDA to Adjusted Segment EBDA)
Three Months Ended
September 30,		Nine Months Ended
September 30,
2026202520262025
(In millions, except operating statistics)
Revenues$307 $282 $950 $884 
Costs of sales(26)(22)(78)(70)
Other operating expenses(a)
(129)(131)(361)(365)
Other income14 — 31 1 
Earnings from equity investments6 6 24 16 
Segment EBDA172 135 566 466 
Certain Items:
Risk management activities12 1 14 (3)
Certain Items(b)
12 1 14 (3)
Adjusted Segment EBDA$184 $136 $580 $463 
Change from prior periodIncrease/(Decrease)
Segment EBDA$37 $100 
Adjusted Segment EBDA$48 $117 
Volumetric data
SACROC oil production
20.05 18.01 20.47 18.56 
Yates oil production6.00 5.90 5.85 5.95 
Other1.02 1.13 1.04 1.11 
Total oil production, net (MBbl/d)(c)27.07 25.04 27.36 25.62 
NGL sales volumes, net (MBbl/d)(c)9.88 9.03 9.81 9.11 
CO2 sales volumes, net (Bcf/d)
0.267 0.274 0.295 0.292 
RNG sales volumes (BBtu/d)13 11 13 10 
Realized weighted average oil price ($ per Bbl)$68.65 $67.74 $69.35 $67.91 
Realized weighted average NGL price ($ per Bbl)$34.48 $31.09 $32.65 $32.85 
(a)Other operating expenses include operations and maintenance expenses and taxes, other than income taxes.
(b)The 2026 and 2025 Certain Items are associated with our Oil and Gas Producing activities. See table included in “—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.

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Below are the changes in CO2 Segment EBDA:

Three Months Ended
September 30,		Nine Months Ended
September 30,
2026202520262025
(In millions)
Source and Transportation activities$48 $36 $152 $121 
Oil and Gas Producing activities100 92 340 314 
Subtotal148 128 492 435 
Energy Transition Ventures24 7 74 31 
Total CO2
$172 $135 $566 $466 
Change from prior periodIncrease/(Decrease)
Source and Transportation activities$12 $31 
Oil and Gas Producing activities$8 $26 
Energy Transition Ventures$17 $43 

The changes in CO2 Segment EBDA in the comparable three and nine-month periods ended September 30, 2026 and 2025 are explained by the following discussion:

•The $12 million (33%) and $31 million (26%) increases, respectively, in Source and Transportation activities were primarily due to higher realized CO2 sales prices.

•The $8 million (9%) and $26 million (8%) increases, respectively, in Oil and Gas Producing activities were driven by higher crude oil volumes and lower power costs, primarily resulting from lower prices. The increase in the nine-month period was also due to higher realized crude oil prices offset by higher other operating costs.

In addition, Oil and Gas Producing activities includes decreased revenues associated with non-cash mark-to-market sales derivative hedge contracts, which we treated as a Certain Item.

•The $17 million (243%) and $43 million (139%) increases, respectively, in Energy Transition Ventures include greater RNG production. The increase in the nine-month period also includes higher RIN sales.

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 September 30, 2026:

Remaining 202620272028
Crude Oil(a)
Price ($ per Bbl)$64.54 $64.73 $67.72 
Volume (MBbl/d)23.15 19.22 13.30 
NGLs
Price ($ per Bbl)$43.40 $48.48 
Volume (MBbl/d)3.88 2.06 
(a)Includes WTI hedges.

47

Liquidity and Capital Resources

General

As of September 30, 2026, we had $918 million of “Cash and cash equivalents,” an increase of $855 million from December 31, 2025. Additionally, as of September 30, 2026, we had borrowing capacity of approximately $3,490 million 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 $5,041 million and $4,225 million in the first nine 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:
September 30, 2026December 31, 2025
(In millions)
Variable rate debt(a)
$— $13 
Notional principal amount of fixed-to-variable interest rate swap agreements4,500 3,500 
Debt balances subject to variable interest rates
$4,500 $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 September 30, 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 $3,490 million, 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 September 30, 2026, our $1,726 million of short-term debt consisted primarily of 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 $1,709 million and $1,568 million as of September 30, 2026 and December 31, 2025, respectively. The overall $141 million unfavorable change from year-end 2025 was primarily due to (i) a $499 million increase in senior notes that mature in the next twelve months; (ii) a $297 million net unfavorable change in our accounts receivables and payables; (iii) a $198 million unfavorable change in the fair value of our short-term derivative contracts assets and liabilities; and (iv) a $170 million increase in legal, environmental, and other expense accruals, partially offset by (i) a $855 million increase in cash and cash equivalents primarily due to unused proceeds from new senior notes issued in August 2026; and (ii) a $169 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.
48


Capital Expenditures

We account for our capital expenditures in accordance with GAAP. Additionally, we distinguish between capital expenditures as follows:
Type of ExpenditurePhysical 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 initially and 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 nine months ended September 30, 2026, and the amount we expect to spend for the remainder of 2026 to sustain our assets and expand our business are as follows:
Nine Months Ended
September 30, 2026
2026 Remaining
Expected 2026
(In millions)
Capital expenditures:
Sustaining capital expenditures$630 $307 $937 
Expansion capital expenditures2,414 831 3,245 
Accrued capital expenditures, contractor retainage, and other(213)— — 
Capital expenditures$2,831 $1,138 $4,182 
Add:
Sustaining capital expenditures of unconsolidated joint ventures(a)$122 $61 $183 
Investments in unconsolidated joint ventures(b)326 175 501 
Less: Consolidated joint venture partners’ sustaining capital expenditures(5)(3)(8)
Less: Consolidated joint venture partners’ expansion capital expenditures(6)— (6)
Less: Insurance reimbursement related to a sustaining capital expenditure(17)— (17)
Acquisition505 — 505 
Accrued capital expenditures, contractor retainage, and other213 — — 
Total capital investments$3,969 $1,371 $5,340 
(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.
49


Our capital investments consist of the following:
Nine Months Ended
September 30, 2026
2026 Remaining
Expected 2026
(In millions)
Sustaining capital investments
Capital expenditures for property, plant, and equipment
$630 $307 $937 
Sustaining capital expenditures of unconsolidated joint ventures(a)122 61 183 
Less: Consolidated joint venture partners’ sustaining capital expenditures(5)(3)(8)
Less: Insurance reimbursement related to a sustaining capital expenditure(17)— (17)
Total sustaining capital investments730 365 1,095 
Expansion capital investments
Capital expenditures for property, plant, and equipment
2,414 831 3,245 
Investments in unconsolidated joint ventures(b)326 175 501 
Less: Consolidated joint venture partners’ expansion capital expenditures(6)— (6)
Acquisition505 — 505 
Total expansion capital investments3,239 1,006 4,245 
Total capital investments$3,969 $1,371 $5,340 
(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.

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 September 30, 2026 and December 31, 2025 were $1,471 million and $2,020 million, respectively, a decrease of $549 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:
Nine Months Ended
September 30,
20262025Changes
(In millions)
Net Cash Provided by (Used in)
Operating activities$5,041 $4,225 $816 
Investing activities(3,381)(2,702)(679)
Financing activities(826)(1,604)778 
Net Increase (Decrease) in Cash, Cash Equivalents, and Restricted Deposits$834 $(81)$915 

Operating Activities

Net cash provided by operating activities was higher for the comparable nine-month periods ended September 30, 2026 and 2025 primarily driven by greater contributions from our Natural Gas Pipelines, Terminals, and CO2 business segments.
50


Investing Activities

$679 million more cash used in investing activities in the comparable nine-month periods ended September 30, 2026 and 2025 is explained by the following discussion.

•a $625 million increase in capital expenditures primarily driven by expansion projects in our Natural Gas Pipelines business segment, partially offset by decreases in our Products Pipelines and CO2 business segments;
•a $136 million increase in cash used for contributions to equity investees driven primarily by higher contributions to Southern Natural Gas Company, L.L.C. (SNG) for our proportional share of expansion project contributions; and
•a $131 million decrease in distribution from equity investments in excess of cumulative earnings primarily due to the receipt in 2025 of our proportional share of SNG’s debt refinancing;

The above increased uses of cash were partially offset by:
•a $145 million reduction in cash used for acquisitions of assets, net of cash acquired, driven by $503 million of net cash used for the acquisition of the Monument Pipeline system in the 2026 period, compared with $648 million of net cash used for the Outrigger Energy acquisition in the 2025 period; See Note 2 “Acquisitions and Divestiture” to our consolidated financial statements for further information regarding these two acquisitions; and
•a $68 million increase in cash related to asset sales primarily driven by proceeds received from our terminals divestiture in the 2026 period. See Note 2 “Acquisitions and Divestiture” to our consolidated financial statements for further information regarding this divestiture.

Financing Activities

$778 million less cash used in financing activities in the comparable nine-month periods ended September 30, 2026 and 2025 primarily driven by a net increase in cash related to debt activity.

Dividends

We expect to declare dividends of $1.19 per share on our stock for 2026. The table below reflects our 2026 dividends declared:
Three months endedTotal quarterly dividend per share for the periodDate of declarationDate of recordDate of dividend
March 31, 2026$0.2975 April 22, 2026May 4, 2026May 15, 2026
June 30, 20260.2975 July 22, 2026August 3, 2026August 17, 2026
September 30, 20260.2975 October 21, 2026November 2, 2026November 16, 2026

The actual amount of dividends to be paid on our capital stock will depend on many factors, including our financial condition and results of operations, liquidity requirements, business prospects, capital requirements, legal, regulatory and contractual constraints, tax laws, Delaware laws, and other factors. See Item 1A. “Risk Factors—Risks Related to Ownership of Our Capital Stock—The guidance we provide for our anticipated dividends is based on estimates. Circumstances may arise that lead to conflicts between using funds to pay anticipated dividends or to invest in our business.” of our 2025 Form 10-K. All of these matters will be taken into consideration by our board of directors when declaring dividends.

Our dividends are not cumulative. Consequently, if dividends on our stock are not paid at the intended levels, our stockholders are not entitled to receive those payments in the future. Our dividends generally will be paid on or about the 15th day of each February, May, August, and November.
51

Summarized Combined Financial Information for Guarantee of Securities of Subsidiaries

KMI and certain subsidiaries (Subsidiary Issuers) are issuers of certain debt securities. KMI and substantially all of KMI’s wholly owned domestic subsidiaries (Subsidiary Guarantors), 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. Accordingly, with the exception of certain subsidiaries identified as subsidiary non-guarantors (Subsidiary Non-Guarantors), the parent issuer, Subsidiary Issuers, and Subsidiary Guarantors (the “Obligated Group”) are all guarantors of each series of our guaranteed debt (Guaranteed Notes). As a result of the cross guarantee agreement, holders of any of the Guaranteed Notes issued by KMI or a Subsidiary Issuer are in the same position with respect to the net assets and income of KMI and the Subsidiary Issuers and Guarantors.

In lieu of providing separate financial statements for the Obligated Group, we have presented the accompanying supplemental summarized combined income statement and balance sheet information for the Obligated Group based on Rule 13-01 of the SEC’s Regulation S-X. Also, see Exhibit 10.1 to this report “Cross Guarantee Agreement, dated as of November 26, 2014, among KMI and certain of its subsidiaries, with schedules updated as of September 30, 2026.”

All significant intercompany items among the Obligated Group have been eliminated in the supplemental summarized combined financial information. The Obligated Group’s investment balances in Subsidiary Non-Guarantors have been excluded from the supplemental summarized combined financial information. Significant intercompany balances and activity for the Obligated Group with other related parties, including Subsidiary Non-Guarantors (referred to as “affiliates”), are presented separately in the accompanying supplemental summarized combined financial information.

Excluding fair value adjustments, as of September 30, 2026 and December 31, 2025, the Obligated Group had $32,494 million and $31,153 million, respectively, of Guaranteed Notes outstanding.

Summarized combined balance sheet and income statement information for the Obligated Group follows:
Summarized Combined Balance Sheet InformationSeptember 30, 2026December 31, 2025
(In millions)
Current assets$3,175 $2,460 
Current assets - affiliates912 779 
Noncurrent assets66,132 64,470 
Noncurrent assets - affiliates757 782 
Total Assets$70,976 $68,491 
Current liabilities$4,653 $4,015 
Current liabilities - affiliates883 766 
Noncurrent liabilities37,032 35,589 
Noncurrent liabilities - affiliates2,033 1,807 
Total Liabilities44,601 42,177 
Kinder Morgan, Inc.’s stockholders’ equity26,375 26,314 
Total Liabilities and Stockholders’ Equity$70,976 $68,491 
Summarized Combined Income Statement InformationThree Months Ended
September 30, 2026		Nine Months Ended
September 30, 2026
(In millions)
Revenues$4,123 $12,687 
Operating income1,163 3,659 
Net income784 2,373 

52

Item 3.  Quantitative and Qualitative Disclosures About Market Risk.

There have been no material changes in market risk exposures that would affect the quantitative and qualitative disclosures presented as of December 31, 2025, in Part II, Item 7A in our 2025 Form 10-K. For more information on our risk management activities, refer to Item 1, Note 5 “Risk Management” to our consolidated financial statements.

Item 4.  Controls and Procedures.

As of September 30, 2026, our management, including our Chief Executive Officer and Chief Financial Officer, has evaluated the effectiveness of the design and operation of our disclosure controls and procedures pursuant to Rule 13a-15(b) under the Securities Exchange Act of 1934. There are inherent limitations to the effectiveness of any system of disclosure controls and procedures, including the possibility of human error and the circumvention or overriding of the controls and procedures. Accordingly, even effective disclosure controls and procedures can only provide reasonable assurance of achieving their control objectives. Based upon and as of the date of the evaluation, our Chief Executive Officer and our Chief Financial Officer concluded that the design and operation of our disclosure controls and procedures were effective to provide reasonable assurance that information required to be disclosed in the reports we file and submit under the Securities Exchange Act of 1934 is recorded, processed, summarized, and reported as and when required, and is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure. There has been no change in our internal control over financial reporting during the quarter ended September 30, 2026 that materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

PART II.  OTHER INFORMATION

Item 1.  Legal Proceedings.

See Part I, Item 1, Note 9 to our consolidated financial statements entitled “Litigation and Environmental” which is incorporated in this item by reference.

Item 1A. Risk Factors.

There have been no material changes in the risk factors disclosed in Part I, Item 1A in our 2025 Form 10-K.

Item 2.  Unregistered Sales of Equity Securities and Use of Proceeds.

None.

Item 3.  Defaults Upon Senior Securities.

None.

Item 4.  Mine Safety Disclosures.

We do not own or operate mines for which reporting requirements apply under the mine safety disclosure requirements of the Dodd-Frank Act. We have not received any specified health and safety violations, orders or citations, related assessments or legal actions, mining-related fatalities, or similar events requiring disclosure pursuant to the mine safety disclosure requirements of Dodd-Frank Act for the quarter ended September 30, 2026.

Item 5.  Other Information.

Rule 10b5-1 Plans

On July 30, 2026, John Schlosser, Vice President (President, Terminals) of KMI, adopted a trading plan that is intended to satisfy the affirmative defense of Rule 10b5-1(c) providing for the sale of up to 74,400 shares of KMI common stock. The expiration date for Mr. Schlosser’s plan is October 6, 2027.

On August 26, 2026, Sital Mody, Vice President (President, Natural Gas Pipelines) of KMI, adopted a trading plan that is intended to satisfy the affirmative defense of Rule 10b5-1(c) providing for the sale of up to (i) 70,196 shares of KMI common
53

stock and (ii) all shares delivered, after tax withholding, upon vesting of an aggregate 59,289 of restricted stock units. The expiration date for Mr. Mody’s plan is November 30, 2028.


54

Item 6.  Exhibits.

Exhibit NumberDescription
4.1 
10.1 
22.1 
31.1 
31.2 
32.1 
32.2 
101 Interactive data files (formatted as Inline XBRL).
104 Cover page interactive data file (formatted as Inline XBRL and contained in Exhibit 101).


55

SIGNATURE

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

KINDER MORGAN, INC.
Registrant
Date:October 23, 2026By:/s/ David P. Michels
David P. Michels
Vice President and Chief Financial Officer
(principal financial and accounting officer)
56

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