Document and Entity Information
Document and Entity Information - shares | 9 Months Ended | |
Sep. 30, 2023 | Oct. 19, 2023 | |
Entity Information [Line Items] | ||
Document Type | 10-Q | |
Document Quarterly Report | true | |
Document Fiscal Year Focus | 2023 | |
Document Period End Date | Sep. 30, 2023 | |
Document Transition Report | false | |
Entity File Number | 001-35081 | |
Entity Registrant Name | KINDER MORGAN, INC. | |
Entity Incorporation, State or Country Code | DE | |
Entity Tax Identification Number | 80-0682103 | |
Entity Address, Address Line One | 1001 Louisiana Street | |
Entity Address, Address Line Two | Suite 1000 | |
Entity Address, City or Town | Houston | |
Entity Address, State or Province | TX | |
Entity Address, Postal Zip Code | 77002 | |
City Area Code | 713 | |
Local Phone Number | 369-9000 | |
Entity Current Reporting Status | Yes | |
Entity Interactive Data Current | Yes | |
Entity Filer Category | Large Accelerated Filer | |
Entity Small Business | false | |
Entity Emerging Growth Company | false | |
Entity Shell Company | false | |
Entity Common Stock, Shares Outstanding | 2,222,773,933 | |
Entity Central Index Key | 0001506307 | |
Document Fiscal Period Focus | Q3 | |
Amendment Flag | false | |
Current Fiscal Year End Date | --12-31 | |
Class P Common Stock | ||
Entity Information [Line Items] | ||
Title of 12(b) Security | Class P Common Stock | |
Trading Symbol | KMI | |
Security Exchange Name | NYSE | |
2.250% Senior Notes due 2027 | ||
Entity Information [Line Items] | ||
Title of 12(b) Security | 2.250% Senior Notes due 2027 | |
Trading Symbol | KMI 27 A | |
Security Exchange Name | NYSE |
CONSOLIDATED STATEMENTS OF INCO
CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Millions, $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2023 | Sep. 30, 2022 | Sep. 30, 2023 | Sep. 30, 2022 | |
Revenues | ||||
Revenues | $ 3,907 | $ 5,177 | $ 11,296 | $ 14,621 |
Operating Costs, Expenses and Other | ||||
Costs of sales (exclusive of items shown separately below) | 1,405 | 2,717 | 3,591 | 7,294 |
Operations and maintenance | 738 | 712 | 2,062 | 1,960 |
Depreciation, depletion and amortization | 561 | 551 | 1,683 | 1,632 |
General and administrative | 162 | 162 | 497 | 470 |
Taxes, other than income taxes | 106 | 113 | 319 | 340 |
Gain on divestitures and impairments, net | (3) | (9) | (16) | (30) |
Other income, net | 0 | 0 | (2) | (6) |
Total Operating Costs, Expenses and Other | 2,969 | 4,246 | 8,134 | 11,660 |
Operating Income | 938 | 931 | 3,162 | 2,961 |
Other Income (Expense) | ||||
Earnings from equity investments | 234 | 195 | 607 | 564 |
Amortization of excess cost of equity investments | (18) | (19) | (54) | (57) |
Interest, net | (457) | (399) | (1,345) | (1,087) |
Other, net | 3 | 21 | 7 | 63 |
Total Other Expense | (238) | (202) | (785) | (517) |
Income Before Income Taxes | 700 | 729 | 2,377 | 2,444 |
Income Tax Expense | (145) | (134) | (509) | (512) |
Net Income | 555 | 595 | 1,868 | 1,932 |
Net Income Attributable to Noncontrolling Interests | (23) | (19) | (71) | (54) |
Net Income Attributable to Kinder Morgan, Inc. | $ 532 | $ 576 | $ 1,797 | $ 1,878 |
Class P Common Stock | ||||
Basic Earnings Per Share | $ 0.24 | $ 0.25 | $ 0.80 | $ 0.83 |
Diluted Earnings Per Share | $ 0.24 | $ 0.25 | $ 0.80 | $ 0.83 |
Basic Weighted Average Shares Outstanding | 2,230 | 2,253 | 2,238 | 2,262 |
Diluted Weighted Average Shares Outstanding | 2,230 | 2,253 | 2,238 | 2,262 |
Services | ||||
Revenues | ||||
Revenues | $ 2,087 | $ 2,028 | $ 6,201 | $ 6,089 |
Commodity sales | ||||
Revenues | ||||
Revenues | 1,785 | 3,108 | 4,991 | 8,416 |
Other | ||||
Revenues | ||||
Revenues | $ 35 | $ 41 | $ 104 | $ 116 |
CONSOLIDATED STATEMENTS OF COMP
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2023 | Sep. 30, 2022 | Sep. 30, 2023 | Sep. 30, 2022 | |
Statement of Comprehensive Income [Abstract] | ||||
Net income | $ 555 | $ 595 | $ 1,868 | $ 1,932 |
Other comprehensive (loss) income, net of tax | ||||
Net unrealized (loss) gain from derivative instruments (net of taxes of $45, $(40), $(1) and $109, respectively) | (153) | 123 | 2 | (366) |
Reclassification into earnings of net derivative instruments loss (gain) to net income (net of taxes of $(6), $(29), $9 and $(118), respectively) | 22 | 104 | (29) | 396 |
Benefit plan adjustments (net of taxes of $(2), $(1), $(4) and $(6), respectively) | 3 | 2 | 11 | 18 |
Total other comprehensive (loss) income | (128) | 229 | (16) | 48 |
Comprehensive income | 427 | 824 | 1,852 | 1,980 |
Comprehensive income attributable to noncontrolling interests | (23) | (19) | (71) | (54) |
Comprehensive income attributable to KMI | $ 404 | $ 805 | $ 1,781 | $ 1,926 |
CONSOLIDATED STATEMENTS OF CO_2
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2023 | Sep. 30, 2022 | Sep. 30, 2023 | Sep. 30, 2022 | |
Statement of Comprehensive Income [Abstract] | ||||
Change in fair value of hedge derivatives, tax | $ 45 | $ (40) | $ (1) | $ 109 |
Reclassification of change in fair value of derivatives to net income, tax | (6) | (29) | 9 | (118) |
Benefit plan adjustments, tax | $ (2) | $ (1) | $ (4) | $ (6) |
CONSOLIDATED BALANCE SHEETS
CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions | Sep. 30, 2023 | Dec. 31, 2022 |
Current Assets | ||
Cash and cash equivalents | $ 80 | $ 745 |
Restricted deposits | 17 | 49 |
Accounts receivable | 1,502 | 1,840 |
Fair value of derivative contracts | 79 | 231 |
Inventories | 565 | 634 |
Other current assets | 190 | 304 |
Total current assets | 2,433 | 3,803 |
Property, plant and equipment, net | 35,944 | 35,599 |
Investments | 7,674 | 7,653 |
Goodwill | 19,965 | 19,965 |
Other intangibles, net | 1,652 | 1,809 |
Deferred charges and other assets | 1,194 | 1,249 |
Total Assets | 68,862 | 70,078 |
Current Liabilities | ||
Current portion of debt | 3,130 | 3,385 |
Accounts payable | 1,430 | 1,444 |
Accrued interest | 387 | 515 |
Fair value of derivative contracts | 346 | 465 |
Other current liabilities | 958 | 1,121 |
Total current liabilities | 6,251 | 6,930 |
Long-term debt | ||
Outstanding | 27,863 | 28,288 |
Debt fair value adjustments | 8 | 115 |
Total long-term debt | 27,871 | 28,403 |
Deferred income taxes | 1,112 | 623 |
Other long-term liabilities and deferred credits | 2,047 | 2,008 |
Total long-term liabilities and deferred credits | 31,030 | 31,034 |
Total Liabilities | 37,281 | 37,964 |
Commitments and contingencies (Notes 3 and 9) | ||
Stockholders’ Equity | ||
Class P Common Stock, $0.01 par value, 4,000,000,000 shares authorized, 2,227,817,827 and 2,247,681,626 shares, respectively, issued and outstanding | 22 | 22 |
Additional paid-in capital | 41,306 | 41,673 |
Accumulated deficit | (10,652) | (10,551) |
Accumulated other comprehensive loss | (418) | (402) |
Total Kinder Morgan, Inc.’s stockholders’ equity | 30,258 | 30,742 |
Noncontrolling interests | 1,323 | 1,372 |
Total Stockholders’ Equity | 31,581 | 32,114 |
Total Liabilities and Stockholders’ Equity | $ 68,862 | $ 70,078 |
CONSOLIDATED BALANCE SHEETS (Pa
CONSOLIDATED BALANCE SHEETS (Parenthetical) - $ / shares | Sep. 30, 2023 | Dec. 31, 2022 |
Stockholders’ Equity | ||
Common stock, par value (in dollars per share) | $ 0.01 | $ 0.01 |
Common stock, shares authorized (in shares) | 4,000,000,000 | 4,000,000,000 |
Common stock, shares issued (in shares) | 2,227,817,827 | 2,247,681,626 |
Common stock, shares outstanding (in shares) | 2,227,817,827 | 2,247,681,626 |
CONSOLIDATED STATEMENTS OF CASH
CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions | 9 Months Ended | |
Sep. 30, 2023 | Sep. 30, 2022 | |
Cash Flows From Operating Activities | ||
Net income | $ 1,868 | $ 1,932 |
Adjustments to reconcile net income to net cash provided by operating activities | ||
Depreciation, depletion and amortization | 1,683 | 1,632 |
Deferred income taxes | 495 | 499 |
Amortization of excess cost of equity investments | 54 | 57 |
Change in fair value of derivative contracts | (93) | 45 |
Gain on divestitures and impairments, net | (16) | (30) |
Earnings from equity investments | (607) | (564) |
Distributions from equity investment earnings | 572 | 548 |
Changes in components of working capital | ||
Accounts receivable | 351 | (260) |
Inventories | 130 | (165) |
Other current assets | 89 | (60) |
Accounts payable | (115) | 347 |
Accrued interest, net of interest rate swaps | (131) | (160) |
Other current liabilities | (84) | 29 |
Rate reparations, refunds and other litigation reserve adjustments | (21) | (189) |
Other, net | (6) | (98) |
Net Cash Provided by Operating Activities | 4,169 | 3,563 |
Cash Flows From Investing Activities | ||
Acquisition of assets, net of cash acquired | (13) | (488) |
Capital expenditures | (1,689) | (1,144) |
Contributions to investments | (179) | (60) |
Distributions from equity investments in excess of cumulative earnings | 166 | 126 |
Other, net | (18) | 21 |
Net Cash Used in Investing Activities | (1,733) | (1,545) |
Cash Flows From Financing Activities | ||
Issuances of debt | 4,373 | 8,898 |
Payments of debt | (5,051) | (9,569) |
Debt issue costs | (18) | (21) |
Dividends | (1,898) | (1,876) |
Repurchases of shares | (390) | (333) |
Proceeds from sale of noncontrolling interests | 0 | 557 |
Contributions from noncontrolling interests | 1 | 1 |
Distributions to noncontrolling interests | (121) | (85) |
Other, net | (29) | (14) |
Net Cash Used in Financing Activities | (3,133) | (2,442) |
Net Decrease in Cash, Cash Equivalents and Restricted Deposits | (697) | (424) |
Cash, Cash Equivalents and Restricted Deposits, beginning of period | 794 | 1,147 |
Cash and Cash Equivalents, beginning of period | 745 | 1,140 |
Restricted Deposits, beginning of period | 49 | 7 |
Cash and Cash Equivalents, end of period | 80 | 483 |
Restricted Deposits, end of period | 17 | 240 |
Cash, Cash Equivalents and Restricted Deposits, end of period | 97 | 723 |
Non-cash Investing and Financing Activities | ||
Assets contributed to equity investment | 16 | 0 |
ROU assets and operating lease obligations recognized including adjustments | 38 | 19 |
Increase in property, plant and equipment from both accruals and contractor retainage | 104 | 23 |
Supplemental Disclosures of Cash Flow Information | ||
Cash paid during the period for interest (net of capitalized interest) | 1,505 | 1,278 |
Cash paid during the period for income taxes, net | $ 10 | $ 12 |
CONSOLIDATED STATEMENTS OF STOC
CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY - USD ($) shares in Millions, $ in Millions | Total | Impact of adoption of ASU 2020-06 (Note 4) | Adjusted balance | Common stock | Common stock Adjusted balance | Additional paid-in capital | Additional paid-in capital Impact of adoption of ASU 2020-06 (Note 4) | Additional paid-in capital Adjusted balance | Accumulated deficit | Accumulated deficit Adjusted balance | Accumulated other comprehensive loss | Accumulated other comprehensive loss Adjusted balance | Stockholders’ equity attributable to KMI | Stockholders’ equity attributable to KMI Impact of adoption of ASU 2020-06 (Note 4) | Stockholders’ equity attributable to KMI Adjusted balance | Non-controlling interests | Non-controlling interests Adjusted balance |
Balance at Dec. 31, 2021 | $ 31,921 | $ (11) | $ 31,910 | $ 23 | $ 23 | $ 41,806 | $ (11) | $ 41,795 | $ (10,595) | $ (10,595) | $ (411) | $ (411) | $ 30,823 | $ (11) | $ 30,812 | $ 1,098 | $ 1,098 |
Balance (shares) at Dec. 31, 2021 | 2,267 | 2,267 | |||||||||||||||
Repurchases of shares | (333) | (333) | (333) | ||||||||||||||
Repurchases of shares (shares) | (19) | ||||||||||||||||
EP Trust I Preferred security conversions | 1 | 1 | 1 | ||||||||||||||
Restricted shares | 36 | 36 | 36 | ||||||||||||||
Restricted shares (shares) | 2 | ||||||||||||||||
Net income | 1,932 | 1,878 | 1,878 | 54 | |||||||||||||
Dividends | (1,876) | (1,876) | (1,876) | ||||||||||||||
Distributions | (85) | 0 | (85) | ||||||||||||||
Contributions | 1 | 0 | 1 | ||||||||||||||
Impact of change in ownership interest in subsidiary | 501 | 190 | 190 | 311 | |||||||||||||
Other comprehensive income (loss) | 48 | 48 | 48 | ||||||||||||||
Balance at Sep. 30, 2022 | 32,135 | $ 23 | 41,689 | (10,593) | (363) | 30,756 | 1,379 | ||||||||||
Balance (shares) at Sep. 30, 2022 | 2,250 | ||||||||||||||||
Balance at Jun. 30, 2022 | 31,625 | $ 23 | 41,654 | (10,540) | (592) | 30,545 | 1,080 | ||||||||||
Balance (shares) at Jun. 30, 2022 | 2,257 | ||||||||||||||||
Repurchases of shares | (160) | (160) | (160) | ||||||||||||||
Repurchases of shares (shares) | (9) | ||||||||||||||||
Restricted shares | 5 | 5 | 5 | ||||||||||||||
Restricted shares (shares) | 2 | ||||||||||||||||
Net income | 595 | 576 | 576 | 19 | |||||||||||||
Dividends | (629) | (629) | (629) | ||||||||||||||
Distributions | (32) | 0 | (32) | ||||||||||||||
Contributions | 1 | 0 | 1 | ||||||||||||||
Impact of change in ownership interest in subsidiary | 501 | 190 | 190 | 311 | |||||||||||||
Other comprehensive income (loss) | 229 | 229 | 229 | ||||||||||||||
Balance at Sep. 30, 2022 | 32,135 | $ 23 | 41,689 | (10,593) | (363) | 30,756 | 1,379 | ||||||||||
Balance (shares) at Sep. 30, 2022 | 2,250 | ||||||||||||||||
Balance at Dec. 31, 2022 | 32,114 | $ 22 | 41,673 | (10,551) | (402) | 30,742 | 1,372 | ||||||||||
Balance (shares) at Dec. 31, 2022 | 2,248 | ||||||||||||||||
Repurchases of shares | (390) | (390) | (390) | ||||||||||||||
Repurchases of shares (shares) | (23) | ||||||||||||||||
Restricted shares | 26 | 26 | 26 | ||||||||||||||
Restricted shares (shares) | 3 | ||||||||||||||||
Net income | 1,868 | 1,797 | 1,797 | 71 | |||||||||||||
Dividends | (1,898) | (1,898) | (1,898) | ||||||||||||||
Distributions | (121) | 0 | (121) | ||||||||||||||
Contributions | 1 | 0 | 1 | ||||||||||||||
Other | (3) | (3) | (3) | ||||||||||||||
Other comprehensive income (loss) | (16) | (16) | (16) | ||||||||||||||
Balance at Sep. 30, 2023 | 31,581 | $ 22 | 41,306 | (10,652) | (418) | 30,258 | 1,323 | ||||||||||
Balance (shares) at Sep. 30, 2023 | 2,228 | ||||||||||||||||
Balance at Jun. 30, 2023 | 31,909 | $ 22 | 41,387 | (10,550) | (290) | 30,569 | 1,340 | ||||||||||
Balance (shares) at Jun. 30, 2023 | 2,229 | ||||||||||||||||
Repurchases of shares | (73) | (73) | (73) | ||||||||||||||
Repurchases of shares (shares) | (4) | ||||||||||||||||
Restricted shares | (8) | (8) | (8) | ||||||||||||||
Restricted shares (shares) | 3 | ||||||||||||||||
Net income | 555 | 532 | 532 | 23 | |||||||||||||
Dividends | (634) | (634) | (634) | ||||||||||||||
Distributions | (41) | 0 | (41) | ||||||||||||||
Contributions | 1 | 0 | 1 | ||||||||||||||
Other comprehensive income (loss) | (128) | (128) | (128) | ||||||||||||||
Balance at Sep. 30, 2023 | $ 31,581 | $ 22 | $ 41,306 | $ (10,652) | $ (418) | $ 30,258 | $ 1,323 | ||||||||||
Balance (shares) at Sep. 30, 2023 | 2,228 |
General (Notes)
General (Notes) | 9 Months Ended |
Sep. 30, 2023 | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |
General | 1. General Organization We are one of the largest energy infrastructure companies in North America. We own an interest in or operate approximately 82,000 miles of pipelines, 140 terminals, 700 Bcf of working natural gas storage capacity and 5.4 Bcf per year of RNG generation capacity. Our pipelines transport natural gas, refined petroleum products, crude oil, condensate, CO 2 , 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 2022 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, 2023 evaluation, we grouped our businesses into seven reporting units as follows: (i) Natural Gas Pipelines Regulated; (ii) Natural Gas Pipelines Non-Regulated; (iii) CO 2 ; (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 using market and income approach valuation methodologies, which include assumptions primarily involving management’s significant judgments and estimates with respect to market multiples, comparable sales transactions, general economic conditions and the related demand for products handled or transported by our assets as well as assumptions regarding future cash flows based on production growth assumptions, terminal values and discount rates. Changes to any one or a combination of these factors 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. The results of our May 31, 2023 annual impairment test indicated that for each of our reporting units, the reporting unit’s fair value exceeded the carrying value, with our Terminals reporting unit’s fair value in excess of its carrying value by less than 10% which was impacted by a decline in market multiples. Earnings per Share We calculate earnings per share using the two-class method. Earnings were allocated to Class P common stock and participating securities based on the amount of dividends paid in the current period plus an allocation of the undistributed earnings or excess distributions over earnings to the extent that each security participates in earnings or excess distributions over earnings. Our unvested restricted stock awards, which may be restricted stock or restricted stock units issued to employees and non-employee directors and include dividend equivalent payments, do not participate in excess distributions over earnings. The following table sets forth the allocation of net income available to shareholders of Class P common stock and participating securities: Three Months Ended Nine Months Ended 2023 2022 2023 2022 (In millions, except per share amounts) Net Income Available to Stockholders $ 532 $ 576 $ 1,797 $ 1,878 Participating securities: Less: Net Income Allocated to Restricted Stock Awards(a) (4) (4) (11) (9) Net Income Allocated to Class P Stockholders $ 528 $ 572 $ 1,786 $ 1,869 Basic Weighted Average Shares Outstanding 2,230 2,253 2,238 2,262 Basic Earnings Per Share $ 0.24 $ 0.25 $ 0.80 $ 0.83 (a) As of September 30, 2023, there were 13 million restricted stock awards outstanding. The following table presents the maximum number of potential common stock equivalents which are antidilutive and accordingly are excluded from the determination of diluted earnings per share. As we have no other common stock equivalents, our diluted earnings per share are the same as our basic earnings per share for all periods presented. Three Months Ended Nine Months Ended 2023 2022 2023 2022 (In millions on a weighted average basis) Unvested restricted stock awards 13 13 13 13 Convertible trust preferred securities 3 3 3 3 |
Losses on Impairments (Notes)
Losses on Impairments (Notes) | 9 Months Ended |
Sep. 30, 2023 | |
Asset Impairment Charges [Abstract] | |
Losses on Impairments | 2. Losses on Impairments Impairments During the first quarter of 2023, we recognized an impairment of $67 million related to our investment in Double Eagle Pipeline LLC (Double Eagle). The impairment was driven by lower expected renewal rates on contracts that expire in the second half of 2023. The impairment is recognized on our accompanying consolidated statement of income for the nine months ended September 30, 2023 within “Earnings from equity investments.” Our investment in Double Eagle and associated earnings is included within our Products Pipelines business segment. Ruby Chapter 11 Bankruptcy On January 13, 2023, the bankruptcy court confirmed a plan of reorganization satisfactory to all interested parties regarding Ruby, which involved payment of Ruby’s outstanding senior notes with the proceeds from the sale of Ruby to Tallgrass, a settlement by KMI and Pembina of certain potential causes of action relating to the bankruptcy, and cash on hand. Our payment to the bankruptcy estate, net of payments received in respect of a long-term subordinated note receivable from Ruby, was approximately $28.5 million which was accrued for as of December 31, 2022. Consummation of the settlement and the sale of Ruby to Tallgrass occurred on January 13, 2023. We fully impaired our equity investment in Ruby in the fourth quarter of 2019 and fully impaired our investment in Ruby’s subordinated notes in the first quarter of 2021. |
Debt (Notes)
Debt (Notes) | 9 Months Ended |
Sep. 30, 2023 | |
Debt Disclosure [Abstract] | |
Debt | 3. Debt The following table provides information on the principal amount of our outstanding debt balances: September 30, 2023 December 31, 2022 (In millions, unless otherwise stated) Current portion of debt $3.5 billion credit facility due August 20, 2027 $ — $ — $500 million credit facility due November 16, 2023 — — Commercial paper notes(a) 320 — Current portion of senior notes 3.15% due January 2023 — 1,000 Floating rate, due January 2023 — 250 3.45% due February 2023 — 625 3.50% due September 2023 — 600 5.625% due November 2023 750 750 4.15% due February 2024 650 — 4.30% due May 2024 600 — 4.25% due September 2024 650 — Trust I preferred securities, 4.75%, due March 2028(b) 111 111 Current portion of other debt 49 49 Total current portion of debt 3,130 3,385 Long-term debt (excluding current portion) Senior notes 27,232 27,638 EPC Building, LLC, promissory note, 3.967%, due 2023 through 2035 316 330 Trust I preferred securities, 4.75%, due March 2028 109 109 Other 206 211 Total long-term debt 27,863 28,288 Total debt(c) $ 30,993 $ 31,673 (a) Weighted average interest rate on borrowings at September 30, 2023 was 5.50%. (b) 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. (c) Excludes our “Debt fair value adjustments” which, as of September 30, 2023 and December 31, 2022, increased our total debt balances by $8 million and $115 million, respectively. We and substantially all of our wholly owned domestic subsidiaries are parties to a cross guarantee agreement whereby each party to the agreement unconditionally guarantees, jointly and severally, the payment of specified indebtedness of each other party to the agreement. On January 31, 2023, we issued in a registered offering $1,500 million aggregate principal amount of 5.20% senior notes due 2033 for net proceeds of $1,485 million, which were used to repay short-term borrowings, maturing debt and for general corporate purposes. Credit Facilities and Restrictive Covenants As of September 30, 2023, we had no borrowings outstanding under our credit facilities, $320 million borrowings outstanding under our commercial paper program and $81 million in letters of credit. Our availability under our credit facilities as of September 30, 2023 was $3.6 billion. For the period ended September 30, 2023, 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, 2023 December 31, 2022 Carrying Estimated Carrying Estimated (In millions) Total debt $ 31,001 $ 28,451 $ 31,788 $ 30,070 (a) Included in the estimated fair value are amounts for our Trust I Preferred Securities of $199 million and $195 million as of September 30, 2023 and December 31, 2022, respectively. We used Level 2 input values to measure the estimated fair value of our outstanding debt balance as of both September 30, 2023 and December 31, 2022. |
Stockholders' Equity (Notes)
Stockholders' Equity (Notes) | 9 Months Ended |
Sep. 30, 2023 | |
Stockholders' Equity Note [Abstract] | |
Stockholders' Equity | 4. Stockholders’ Equity Class P Common Stock On July 19, 2017, our board of directors approved a $2 billion share buy-back program that began in December 2017. On January 18, 2023, our board of directors approved an increase in our share repurchase authorization to $3 billion. During the nine months ended September 30, 2023, we repurchased 23 million of our shares for $390 million at an average price of $16.62 per share. Subsequent to September 30, 2023 and through October 19, 2023, we repurchased 5 million shares for $83 million at an average price of $16.38 per share. All shares we have repurchased are canceled and are no longer outstanding. Dividends The following table provides information about our per share dividends: Three Months Ended Nine Months Ended 2023 2022 2023 2022 Per share cash dividend declared for the period $ 0.2825 $ 0.2775 $ 0.8475 $ 0.8325 Per share cash dividend paid in the period 0.2825 0.2775 0.8425 0.825 On October 18, 2023, our board of directors declared a cash dividend of $0.2825 per share for the quarterly period ended September 30, 2023, which is payable on November 15, 2023 to shareholders of record as of the close of business on October 31, 2023. Adoption of Accounting Pronouncement On January 1, 2022, we adopted Accounting Standards Update (ASU) No. 2020-06, “ Debt – Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging – Contracts in Entity’s Own Equity (Subtopic 815-40): Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity. ” This ASU (i) simplifies an issuer’s accounting for convertible instruments by eliminating two of the three models in Subtopic 470-20 that require separate accounting for embedded conversion features, (ii) amends diluted earnings per share calculations for convertible instruments by requiring the use of the if-converted method and (iii) simplifies the settlement assessment entities are required to perform on contracts that can potentially settle in an entity’s own equity by removing certain requirements. Using the modified retrospective method, the adoption of this ASU resulted in a pre-tax adjustment of $14 million to unwind the remaining unamortized debt discount within “Debt fair value adjustments” on our consolidated balance sheet and an adjustment of $11 million to unwind the balance of the conversion feature classified in “Additional paid in capital” on our consolidated statement of stockholders’ equity for the nine months ended September 30, 2022. Accumulated Other Comprehensive Loss Changes in the components of our “Accumulated other comprehensive loss” not including noncontrolling interests are summarized as follows: Net unrealized Pension and Total (In millions) Balance as of December 31, 2022 $ (164) $ (238) $ (402) Other comprehensive gain before reclassifications 2 11 13 Gain reclassified from accumulated other comprehensive loss (29) — (29) Net current-period change in accumulated other comprehensive loss (27) 11 (16) Balance as of September 30, 2023 $ (191) $ (227) $ (418) Net unrealized Pension and Total (In millions) Balance as of December 31, 2021 $ (172) $ (239) $ (411) Other comprehensive (loss) gain before reclassifications (366) 18 (348) Loss reclassified from accumulated other comprehensive loss 396 — 396 Net current-period change in accumulated other comprehensive loss 30 18 48 Balance as of September 30, 2022 $ (142) $ (221) $ (363) |
Risk Management (Notes)
Risk Management (Notes) | 9 Months Ended |
Sep. 30, 2023 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
Risk Management | 5. Risk Management Certain of our business activities expose us to risks associated with unfavorable changes in the market price of natural gas, NGL and crude oil. We also have exposure to interest rate and foreign currency risk as a result of the issuance of our debt obligations. Pursuant to our management’s approved risk management policy, we use derivative contracts to hedge or reduce our exposure to some of these risks. Energy Commodity Price Risk Management As of September 30, 2023, 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 (18.2) MMBbl Crude oil basis (1.1) MMBbl Natural gas fixed price (56.2) Bcf Natural gas basis (48.0) Bcf NGL fixed price (0.8) MMBbl Derivatives not designated as hedging contracts Crude oil fixed price (1.6) MMBbl Crude oil basis (6.7) MMBbl Natural gas fixed price (6.9) Bcf Natural gas basis (98.3) Bcf NGL fixed price (1.0) MMBbl As of September 30, 2023, 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 2027. 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, 2023: Notional amount Accounting treatment Maximum term (In millions) Derivatives designated as hedging instruments Fixed-to-variable interest rate contracts(a)(b) $ 6,800 Fair value hedge March 2035 Derivatives not designated as hedging instruments Variable-to-fixed interest rate contracts 3,445 Mark-to-Market December 2023 (a) The principal amount of hedged senior notes consisted of $2,050 million included in “Current portion of debt” and $4,750 million included in “Long-term debt” on our accompanying consolidated balance sheet. (b) During the nine months ended September 30, 2023, certain optional expedients as set forth in Topic 848 – Reference Rate Reform were elected on certain of these contracts to preserve fair value hedge accounting treatment. See Note 10 for further information on Topic 848. 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, 2023: Notional amount Accounting treatment Maximum term (In millions) Derivatives designated as hedging instruments EUR-to-USD cross currency swap contracts(a) $ 543 Cash flow hedge March 2027 (a) These swaps eliminate the foreign currency risk associated with our Euro-denominated debt. Impact of Derivative Contracts on Our Consolidated Financial Statements The following table summarizes the fair values of our derivative contracts included on our accompanying consolidated balance sheets: Fair Value of Derivative Contracts Location Derivatives Asset Derivatives Liability September 30, December 31, September 30, December 31, (In millions) Derivatives designated as hedging instruments Energy commodity derivative contracts Fair value of derivative contracts/(Fair value of derivative contracts) $ 38 $ 150 $ (153) $ (156) Deferred charges and other assets/(Other long-term liabilities and deferred credits) 1 6 (87) (91) Subtotal 39 156 (240) (247) Interest rate contracts Fair value of derivative contracts/(Fair value of derivative contracts) — — (153) (144) Deferred charges and other assets/(Other long-term liabilities and deferred credits) 19 39 (288) (261) Subtotal 19 39 (441) (405) Foreign currency contracts Fair value of derivative contracts/(Fair value of derivative contracts) — — (6) (3) Deferred charges and other assets/(Other long-term liabilities and deferred credits) — — (23) (32) Subtotal — — (29) (35) Total 58 195 (710) (687) Derivatives not designated as hedging instruments Energy commodity derivative contracts Fair value of derivative contracts/(Fair value of derivative contracts) 33 80 (34) (162) Deferred charges and other assets/(Other long-term liabilities and deferred credits) 7 23 (1) (19) Subtotal 40 103 (35) (181) Interest rate contracts Fair value of derivative contracts/(Fair value of derivative contracts) 8 1 — — Total 48 104 (35) (181) Total derivatives $ 106 $ 299 $ (745) $ (868) 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 Contracts available for netting Cash collateral held(a) Level 1 Level 2 Level 3 Gross amount Net amount (In millions) As of September 30, 2023 Energy commodity derivative contracts(b) $ 40 $ 39 $ — $ 79 $ (25) $ — $ 54 Interest rate contracts — 27 — 27 — — 27 As of December 31, 2022 Energy commodity derivative contracts(b) $ 115 $ 144 $ — $ 259 $ (186) $ — $ 73 Interest rate contracts — 40 — 40 — — 40 Balance sheet liability Contracts available for netting Cash collateral posted(a) Level 1 Level 2 Level 3 Gross amount Net amount (In millions) As of September 30, 2023 Energy commodity derivative contracts(b) $ (3) $ (272) $ — $ (275) $ 25 $ (52) $ (302) Interest rate contracts — (442) — (442) — — (442) Foreign currency contracts — (28) — (28) — — (28) As of December 31, 2022 Energy commodity derivative contracts(b) $ (23) $ (405) $ — $ (428) $ 186 $ (30) $ (272) Interest rate contracts — (405) — (405) — — (405) Foreign currency contracts — (35) — (35) — — (35) (a) Any cash collateral paid or received is reflected in this table, but only to the extent that it represents variation margins. Any amount associated with derivative prepayments or initial margins that are not influenced by the derivative asset or liability amounts or those that are determined solely on their volumetric notional amounts are excluded from this table. (b) Level 1 consists primarily of NYMEX natural gas futures. Level 2 consists primarily of OTC WTI swaps, NGL swaps and crude oil basis swaps. The following tables summarize the pre-tax impact of our derivative contracts on our accompanying consolidated statements of income and comprehensive income: Derivatives in fair value hedging relationships Location Gain/(loss) recognized in income Three Months Ended Nine Months Ended 2023 2022 2023 2022 (In millions) Interest rate contracts Interest, net $ (74) $ (278) $ (55) $ (754) Hedged fixed rate debt(a) Interest, net $ 77 $ 279 $ 59 $ 761 (a) As of September 30, 2023, the cumulative amount of fair value hedging adjustments to our hedged fixed rate debt was a decrease of $426 million included in “Debt fair value adjustments” on our accompanying consolidated balance sheet. Derivatives in cash flow hedging relationships Gain/(loss) Location Gain/(loss) reclassified from Accumulated OCI Three Months Ended Three Months Ended 2023 2022 2023 2022 (In millions) (In millions) Energy commodity derivative contracts $ (188) $ 195 Revenues—Commodity sales $ 16 $ (116) Costs of sales (27) 17 Foreign currency contracts (10) (32) Other, net (17) (34) Total $ (198) $ 163 Total $ (28) $ (133) Derivatives in cash flow hedging relationships Gain/(loss) Location Gain/(loss) reclassified from Accumulated OCI Nine Months Ended Nine Months Ended 2023 2022 2023 2022 (In millions) (In millions) Energy commodity derivative contracts $ (3) $ (375) Revenues—Commodity sales $ 98 $ (433) Costs of sales (54) 34 Interest rate contracts — 7 Interest, net — — Foreign currency contracts 6 (107) Other, net (6) (115) Total $ 3 $ (475) Total $ 38 $ (514) (a) We expect to reclassify approximately $145 million of loss associated with cash flow hedge price risk management activities included in our accumulated other comprehensive loss balance as of September 30, 2023 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. (b) During the three and nine months ended September 30, 2022, we recognized approximate gains of $29 million and $34 million associated with a write-down of hedged inventory. All other amounts reclassified were the result of the hedged forecasted transactions actually affecting earnings (i.e., when the forecasted sales and purchases actually occurred). Derivatives not designated as accounting hedges Location Gain/(loss) recognized in income on derivatives Three Months Ended Nine Months Ended 2023 2022 2023 2022 (In millions) Energy commodity derivative contracts Revenues—Commodity sales $ (21) $ 44 $ 11 $ 18 Costs of sales (4) (30) 116 (129) Earnings from equity investments — (7) 1 (11) Interest rate contracts Interest, net (6) (20) 6 28 Total(a) $ (31) $ (13) $ 134 $ (94) (a) The three and nine months ended September 30, 2023 amounts include approximate gains of $9 million and $45 million, respectively, and the three and nine months ended September 30, 2022 amounts include approximate losses of $19 million and $39 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, 2023 and December 31, 2022, we had no outstanding letters of credit supporting our commodity price risk management program. As of September 30, 2023 and December 31, 2022, we had cash margins of $28 million and $1 million, respectively, posted by our counterparties with us as collateral and reported within “Other current liabilities” on our accompanying consolidated balance sheets. The cash margin balance at September 30, 2023 represents our initial margin requirements of $24 million and variation margin requirements of $52 million posted by our counterparties. We also use industry standard commercial agreements that allow for the netting of exposures associated with transactions executed under a single commercial agreement. Additionally, we generally utilize master netting agreements to offset credit exposure across multiple commercial agreements with a single counterparty. We also have agreements with certain counterparties to our derivative contracts that contain provisions requiring the posting of additional collateral upon a decrease in our credit rating. As of September 30, 2023, based on our current mark-to-market positions and posted collateral, we estimate that if our credit rating were downgraded one notch, we would not be required to post additional collateral. If we were downgraded two notches, we estimate that we would be required to post $187 million of additional collateral. |
Revenue Recognition (Notes)
Revenue Recognition (Notes) | 9 Months Ended |
Sep. 30, 2023 | |
Revenue from Contract with Customer [Abstract] | |
Revenue Recognition | 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, 2023 Natural Gas Pipelines Products Pipelines Terminals CO 2 Corporate and Eliminations Total (In millions) Revenues from contracts with customers(a) Services Firm services(b) $ 849 $ 49 $ 211 $ — $ (1) $ 1,108 Fee-based services 268 264 102 9 (1) 642 Total services 1,117 313 313 9 (2) 1,750 Commodity sales Natural gas sales 689 — — 28 (5) 712 Product sales 281 495 10 291 (2) 1,075 Total commodity sales 970 495 10 319 (7) 1,787 Total revenues from contracts with customers 2,087 808 323 328 (9) 3,537 Other revenues(c) Leasing services(d) 120 50 161 15 — 346 Derivatives adjustments on commodity sales 49 (2) — (52) — (5) Other 17 6 — 6 — 29 Total other revenues 186 54 161 (31) — 370 Total revenues $ 2,273 $ 862 $ 484 $ 297 $ (9) $ 3,907 Three Months Ended September 30, 2022 Natural Gas Pipelines Products Pipelines Terminals CO 2 Corporate and Eliminations Total (In millions) Revenues from contracts with customers(a) Services Firm services(b) $ 845 $ 57 $ 199 $ — $ — $ 1,101 Fee-based services 243 247 106 11 — 607 Total services 1,088 304 305 11 — 1,708 Commodity sales Natural gas sales 1,902 — — 24 (7) 1,919 Product sales 389 511 11 353 (1) 1,263 Total commodity sales 2,291 511 11 377 (8) 3,182 Total revenues from contracts with customers 3,379 815 316 388 (8) 4,890 Other revenues(c) Leasing services(d) 120 51 141 16 — 328 Derivatives adjustments on commodity sales (12) — — (60) — (72) Other 18 6 — 7 — 31 Total other revenues 126 57 141 (37) — 287 Total revenues $ 3,505 $ 872 $ 457 $ 351 $ (8) $ 5,177 Nine Months Ended September 30, 2023 Natural Gas Pipelines Products Pipelines Terminals CO 2 Corporate and Eliminations Total (In millions) Revenues from contracts with customers(a) Services Firm services(b) $ 2,615 $ 138 $ 626 $ 1 $ (2) $ 3,378 Fee-based services 752 750 298 29 (1) 1,828 Total services 3,367 888 924 30 (3) 5,206 Commodity sales Natural gas sales 1,972 — — 61 (9) 2,024 Product sales 788 1,211 23 836 (6) 2,852 Total commodity sales 2,760 1,211 23 897 (15) 4,876 Total revenues from contracts with customers 6,127 2,099 947 927 (18) 10,082 Other revenues(c) Leasing services(d) 357 149 476 40 — 1,022 Derivatives adjustments on commodity sales 196 (1) — (86) — 109 Other 50 18 — 15 — 83 Total other revenues 603 166 476 (31) — 1,214 Total revenues $ 6,730 $ 2,265 $ 1,423 $ 896 $ (18) $ 11,296 Nine Months Ended September 30, 2022 Natural Gas Pipelines Products Pipelines Terminals CO 2 Corporate and Eliminations Total (In millions) Revenues from contracts with customers(a) Services Firm services(b) $ 2,633 $ 176 $ 585 $ 1 $ (2) $ 3,393 Fee-based services 690 723 300 35 — 1,748 Total services 3,323 899 885 36 (2) 5,141 Commodity sales Natural gas sales 4,938 — — 68 (17) 4,989 Product sales 1,141 1,577 22 1,105 (4) 3,841 Total commodity sales 6,079 1,577 22 1,173 (21) 8,830 Total revenues from contracts with customers 9,402 2,476 907 1,209 (23) 13,971 Other revenues(c) Leasing services(d) 355 144 430 44 — 973 Derivatives adjustments on commodity sales (132) (3) — (280) — (415) Other 49 17 — 26 — 92 Total other revenues 272 158 430 (210) — 650 Total revenues $ 9,674 $ 2,634 $ 1,337 $ 999 $ (23) $ 14,621 (a) Differences between the revenue classifications presented on the consolidated statements of income and the categories for the disaggregated revenues by type of revenue above are primarily attributable to revenues reflected in the “Other revenues” category above (see note (c)). (b) Includes non-cancellable firm service customer contracts with take-or-pay or minimum volume commitment elements, including those contracts where both the price and quantity amount are fixed. Excludes service contracts with index-based pricing, which along with revenues from other customer service contracts are reported as “Fee-based services.” (c) Amounts recognized as revenue under guidance prescribed in Topics of the ASC other than in Topic 606 were primarily from leases and derivative contracts. See Note 5 for additional information related to our derivative contracts. (d) Our revenues from leasing services are predominantly comprised of specific assets that we lease to customers under operating leases where one customer obtains substantially all of the economic benefit from the asset and has the right to direct the use of that asset. These leases primarily consist of specific tanks, treating facilities, marine vessels and gas equipment and pipelines with separate control locations. We do not lease assets that qualify as sales-type or finance leases. Contract Balances As of September 30, 2023 and December 31, 2022, our contract asset balances were $43 million and $33 million, respectively. Of the contract asset balance at December 31, 2022, $21 million was transferred to accounts receivable during the nine months ended September 30, 2023. As of September 30, 2023 and December 31, 2022, our contract liability balances were $221 million and $204 million, respectively. Of the contract liability balance at December 31, 2022, $61 million was recognized as revenue during the nine months ended September 30, 2023. Subsequent to September 30, 2023, we entered into an agreement with a customer to prepay certain fixed reservation charges under long-term transportation and terminalling contracts. We anticipate receiving $843 million in the fourth quarter of 2023 as part of this agreement. The prepayment, which relates to contracts expiring from 2035 to 2040, was discounted to present value at a rate that is attractive relative to our cost of issuing long-term debt. Revenue Allocated to Remaining Performance Obligations The following table presents our estimated revenue allocated to remaining performance obligations for contracted revenue that has not yet been recognized, representing our “contractually committed” revenue as of September 30, 2023 that we will invoice or transfer from contract liabilities and recognize in future periods: Year Estimated Revenue (In millions) Three months ended December 31, 2023 $ 1,167 2024 4,153 2025 3,423 2026 2,933 2027 2,462 Thereafter 14,057 Total $ 28,195 Our contractually committed revenue, for purposes of the tabular presentation above, is generally limited to service or commodity sale customer contracts which have fixed pricing and fixed volume terms and conditions, generally including contracts with take-or-pay or minimum volume commitment payment obligations. Our contractually committed revenue amounts, based on the practical expedient that we elected to apply, generally exclude remaining performance obligations for contracts with index-based pricing or variable volume attributes in which such variable consideration is allocated entirely to a wholly unsatisfied performance obligation. |
Reportable Segments (Notes)
Reportable Segments (Notes) | 9 Months Ended |
Sep. 30, 2023 | |
Segment Reporting [Abstract] | |
Reportable Segments | 7. Reportable Segments Financial information by segment follows: Three Months Ended Nine Months Ended 2023 2022 2023 2022 (In millions) Revenues Natural Gas Pipelines Revenues from external customers $ 2,268 $ 3,497 $ 6,718 $ 9,653 Intersegment revenues 5 8 12 21 Products Pipelines 862 872 2,265 2,634 Terminals Revenues from external customers 483 457 1,420 1,335 Intersegment revenues 1 — 3 2 CO 2 Revenues from external customers 294 351 893 999 Intersegment revenues 3 — 3 — Corporate and intersegment eliminations (9) (8) (18) (23) Total consolidated revenues $ 3,907 $ 5,177 $ 11,296 $ 14,621 Three Months Ended Nine Months Ended 2023 2022 2023 2022 (In millions) Segment EBDA(a) Natural Gas Pipelines $ 1,179 $ 1,135 $ 3,929 $ 3,453 Products Pipelines 311 257 780 855 Terminals 259 240 774 731 CO 2 163 215 510 619 Total Segment EBDA 1,912 1,847 5,993 5,658 DD&A (561) (551) (1,683) (1,632) Amortization of excess cost of equity investments (18) (19) (54) (57) General and administrative and corporate charges (176) (149) (534) (438) Interest, net (457) (399) (1,345) (1,087) Income tax expense (145) (134) (509) (512) Total consolidated net income $ 555 $ 595 $ 1,868 $ 1,932 September 30, 2023 December 31, 2022 (In millions) Assets Natural Gas Pipelines $ 47,642 $ 47,978 Products Pipelines 8,923 8,985 Terminals 8,250 8,357 CO 2 3,459 3,449 Corporate assets(b) 588 1,309 Total consolidated assets $ 68,862 $ 70,078 (a) Includes revenues, earnings from equity investments, operating expenses, gain on divestitures and impairments, net, oth er income, net, and other, net. Operating expenses include costs of sales, operations and maintenance expenses, and taxes, other than income taxes. (b) Includes cash and cash equivalents, restricted deposits, certain prepaid assets and deferred charges, risk management assets related to derivative contracts, corporate headquarters in Houston, Texas and miscellaneous corporate assets (such as information technology, telecommunications equipment and legacy activity) not allocated to our reportable segments. |
Income Taxes (Notes)
Income Taxes (Notes) | 9 Months Ended |
Sep. 30, 2023 | |
Income Tax Disclosure [Abstract] | |
Income Taxes | 8. Income Taxes Income tax expense included on our accompanying consolidated statements of income is as follows: Three Months Ended Nine Months Ended 2023 2022 2023 2022 (In millions, except percentages) Income tax expense $ 145 $ 134 $ 509 $ 512 Effective tax rate 20.7 % 18.4 % 21.4 % 20.9 % The effective tax rate for the three months ended September 30, 2023 is lower than the statutory federal rate of 21% primarily due to dividend-received deductions from our investments in Florida Gas Pipeline (Citrus), NGPL Holdings and Products (SE) Pipe Line Company (PPL), partially offset by state income taxes. The effective tax rate for the nine months ended September 30, 2023 is higher than the statutory federal rate of 21% primarily due to state income taxes, partially offset by dividend-received deductions from our investments in Citrus, NGPL Holdings and PPL. The effective tax rates for the three and nine months ended September 30, 2022 are lower than the statutory federal rate of 21% primarily due to the recognition of additional 2021 enhanced oil recovery credits from our initial estimate, the adjustment |
Litigation and Environmental (N
Litigation and Environmental (Notes) | 9 Months Ended |
Sep. 30, 2023 | |
Commitments and Contingencies Disclosure [Abstract] | |
Litigation and Environmental | 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 established reserves and insurance, that the ultimate resolution of such items will not have a material adverse impact to our business. We believe we have numerous and substantial defenses to the matters to which we are a party and intend to vigorously defend the Company. When we determine a loss is probable of occurring and is reasonably estimable, we accrue an undiscounted liability for such contingencies based on our best estimate using information available at that time. If the estimated loss is a range of potential outcomes and there is no better estimate within the range, we accrue the amount at the low end of the range. We disclose the following contingencies where an adverse outcome may be material or, in the judgment of management, we conclude the matter should otherwise be disclosed. Gulf LNG Facility Disputes On September 28, 2018, Gulf LNG Energy, LLC and Gulf LNG Pipeline, LLC (GLNG) filed a lawsuit against Eni S.p.A. in the Supreme Court of the State of New York in New York County to enforce a Guarantee Agreement (Guarantee) entered into by Eni S.p.A. on December 10, 2007 in connection with a contemporaneous terminal use agreement entered into by its affiliate, Eni USA Gas Marketing LLC (Eni USA). The suit to enforce the Guarantee against Eni S.p.A. was filed after an arbitration tribunal delivered an award on June 29, 2018 which called for the termination of the terminal use agreement and payment of compensation by Eni USA to GLNG. In response to GLNG’s lawsuit to enforce the Guarantee, Eni S.p.A. filed counterclaims and other claims based on the terminal use agreement and a parent direct agreement with Gulf LNG Energy (Port), LLC. The foregoing counterclaims and other claims asserted by Eni S.p.A sought unspecified damages and involved the same substantive allegations which were dismissed with prejudice in previous separate arbitrations with Eni USA described above and with GLNG’s remaining customer Angola LNG Supply Services LLC (ALSS), a consortium of international oil companies including Eni S.p.A. On January 4, 2022, the trial court granted Eni S.p.A’s motion for summary judgment on GLNG’s claims to enforce the Guarantee. The Appellate Division denied GLNG’s appeal on February 9, 2023 and denied GLNG’s motion for rehearing on July 6, 2023. GLNG elected not to pursue further recourse to the state Court of Appeals, which is the state’s highest appellate court, thereby concluding GLNG’s efforts to enforce the Guarantee.. With respect to the counterclaims and other claims asserted by Eni S.p.A., the trial court granted GLNG’s motion for summary judgment on June 13, 2023 and entered judgment dismissing all of Eni S.p.A.’s claims with prejudice on September 15, 2023. Eni S.p.A. filed a notice of appeal to the state Appellate Division. We intend to vigorously oppose Eni S.p.A’s appeal. 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 November 21, 2022, Freeport filed a notice of appeal to the 14 th Court of Appeals, where the matter remains pending. We believe our declaration of force majeure was proper 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 filed initially in federal court in Michigan, then transferred to the U.S. District Court for the Southern District of Texas (Civil Action No. 4:21-3590), and later amended to include the Kinder Morgan Retirement Plan B, alleges that the series of foregoing transactions resulted in changes to plaintiffs’ retirement benefits which are now contested on a purported class-wide basis in the lawsuit. The complaint asserts six claims that fall within three primary theories of liability. Claims I, II, and III all seek the same plan modification as to how the plans calculate benefits for former participants in the Coastal plan. These claims challenge plan provisions which are alleged to constitute impermissible “backloading” or “cutback” of benefits. 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. The complaint alleges that the purported class includes over 10,000 individuals. The lawsuit is in the discovery stage and plaintiffs have moved for class certification. Plaintiffs seek to recover early retirement benefits as well as declaratory and injunctive relief, but have not pleaded, disclosed or otherwise specified a calculation of alleged damages. Accordingly, the extent of potential plan liabilities for past or future benefits, if any, remains to be determined. We believe we have numerous and substantial defenses and intend to vigorously defend this case. 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. Arizona Line 2000 Rupture On August 15, 2021, the 30” EPNG Line 2000 natural gas transmission pipeline ruptured in a rural area in Coolidge, Arizona. The failure resulted in a fire which destroyed a home, resulting in two fatalities and one injury. The National Transportation Safety Board investigated the incident and issued its report on April 27, 2023. EPNG completed the physical work on Line 2000 in accordance with PHMSA’s requirements and returned the pipeline to commercial service in February 2023. We notified our insurers and resolved the claims presented by or on behalf of the residents of the home without litigation or a material adverse impact to our business. General As of September 30, 2023 and December 31, 2022, our total reserve for legal matters was $21 million and $70 million, respectively. 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, CO 2 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 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. 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 business, 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 established a reserve to address the costs associated with the remediation efforts. In addition, we are involved with and have been identified as a potentially responsible party (PRP) in several federal and state Superfund sites. Environmental reserves have been established for those sites where our contribution is probable and reasonably estimable. 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 CO 2 , including natural resource damage (NRD) claims. Portland Harbor Superfund Site, Willamette River, Portland, Oregon On January 6, 2017, the EPA issued a Record of Decision (ROD) that established a final remedy and cleanup plan for an industrialized area on the lower reach of the Willamette River commonly referred to as the Portland Harbor Superfund Site (PHSS). The cost for the final remedy is estimated to be more than $2.8 billion and active cleanup is expected to take more than 10 years to complete. KMLT, KMBT, and some 90 other PRPs identified by the EPA are involved in a non-judicial allocation process to determine each party’s respective share of the cleanup costs related to the final remedy set forth by the ROD. We are participating in the allocation process on behalf of KMLT (in connection with its ownership or operation of two facilities) and KMBT (in connection with its ownership or operation of two facilities). Effective January 31, 2020, KMLT entered into separate Administrative Settlement Agreements and Orders on Consent (ASAOC) to complete remedial design for two distinct areas within the PHSS associated with KMLT’s facilities. The ASAOC obligates KMLT to pay a share of the remedial design costs for cleanup activities related to these two areas as required by the ROD. Our share of responsibility for the PHSS costs will not be determined until the ongoing non-judicial allocation process is concluded or a lawsuit is filed that results in a judicial decision allocating responsibility. At this time we anticipate the non-judicial allocation process will be complete in or around December 2024. Until the allocation process is completed, we are unable to reasonably estimate the extent of our liability for the costs related to the design of the proposed remedy and cleanup of the PHSS. Because costs associated with any remedial plan are expected to be spread over at least several years, we do not anticipate that our share of the costs of the remediation will have a material adverse impact to our business. In addition to CERCLA cleanup costs, we are reviewing and will attempt to settle, if possible, NRD claims in the amount of approximately $5 million asserted by state and federal trustees following their natural resource assessment of the PHSS. Lower Passaic River Study Area of the Diamond Alkali Superfund Site, New Jersey EPEC Polymers, Inc. and EPEC Oil Company Liquidating Trust (collectively EPEC) are identified as PRPs in an administrative action under CERCLA known as the Lower Passaic River Study Area (Site) concerning the lower 17-mile stretch of the Passaic River in New Jersey. On March 4, 2016, the EPA issued a Record of Decision (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 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. We believe our share of the costs to resolve this matter, including our share of the settlement with EPA and the costs to remediate the Site, if any, will not have a material adverse impact to our business. Louisiana Governmental Coastal Zone Erosion Litigation Beginning in 2013, several parishes in Louisiana and the City of New Orleans filed separate lawsuits in state district courts in Louisiana against a number of oil and gas companies, including TGP and SNG. In these cases, the parishes and New Orleans, as Plaintiffs, allege that certain of the defendants’ oil and gas exploration, production and transportation operations were conducted in violation of the State and Local Coastal Resources Management Act of 1978, as amended (SLCRMA) and that those operations caused substantial damage to the coastal waters of Louisiana and nearby lands. The Plaintiffs seek, among other relief, unspecified money damages, attorneys’ fees, interest, and payment of costs necessary to restore the affected areas. There are more than 40 of these cases pending in Louisiana against oil and gas companies, one of which is against TGP and one of which is against SNG, both described further below. On November 8, 2013, the Parish of Plaquemines, Louisiana and others filed a petition for damages in the state district court for Plaquemines Parish, Louisiana against TGP and 17 other energy companies, alleging that the defendants’ operations in Plaquemines Parish violated SLCRMA and Louisiana law, and caused substantial damage to the coastal waters and nearby lands. Plaquemines Parish seeks, among other relief, unspecified money damages, attorney fees, interest, and payment of costs necessary to restore the allegedly affected areas. In May 2018, the case was removed to the U.S. District Court for the Eastern District of Louisiana. The case has been effectively stayed pending the resolution of jurisdictional issues in separate, consolidated cases to which TGP is not a party; The Parish of Plaquemines, et al. vs. Chevron USA, Inc. et al. consolidated with The Parish of Cameron, et al. v. BP America Production Company, et al. Those cases were removed to federal court and subsequently remanded to the state district courts for Plaquemines and Cameron Parishes, respectively. On September 27, 2023, the U.S. District Court ordered the case be stayed and administratively closed pending the resolution of jurisdictional issues. 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. On March 29, 2019, the City of New Orleans and Orleans Parish (collectively, Orleans) filed a petition for damages in the state district court for Orleans Parish, Louisiana against SNG and 10 other energy companies alleging that the defendants’ operations in Orleans Parish violated the SLCRMA and Louisiana law, and caused substantial damage to the coastal waters and nearby lands. Orleans seeks, among other relief, unspecified money damages, attorney fees, interest, and payment of costs necessary to restore the allegedly affected areas. In April 2019, the case was removed to the U.S. District Court for the Eastern District of Louisiana. In January 2020, the U.S. District Court ordered the case to be stayed and administratively closed pending the resolution of issues in a separate case to which SNG is not a party. On May 3, 2023, the U.S. District Court re-opened the case. 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. Products Pipeline Incident, Walnut Creek, California On November 20, 2020, SFPP identified an issue on its Line Section 16 (LS-16) which transports petroleum products in California from Concord to San Jose. We shut down the pipeline and notified the appropriate regulatory agencies of a “threatened release” of gasoline. We investigated the issue and on November 24, 2020, identified a crack in the pipeline and notified the regulatory agencies of a “confirmed release.” The damaged section of the pipeline was removed and replaced, and the pipeline resumed operations on November 26, 2020. We reported the estimated volume of gasoline released to be 8.1 Bbl. On December 2, 2020, complaints of gasoline odors were reported along the LS-16 pipeline corridor in Walnut Creek. A unified response was implemented by us along with the EPA, the California Office of Spill Prevention and Response, the California Fire Marshall, and the San Francisco Regional Water Quality Control Board. On December 8, 2020, we reported an updated estimated spill volume of up to 1,000 Bbl. On October 28, 2021, we were informed by the California Attorney General it was contemplating criminal charges against us asserting the November 2020 discharge of gasoline affected waters of the State of California, and there was a failure to make timely notices of this discharge to appropriate state agencies. On December 16, 2021, we entered into a plea agreement with the State of California to resolve misdemeanor charges of the unintentional, non-negligent discharge of gasoline resulting from the release and the claimed failure to provide timely notices of the discharge to appropriate state agencies. Under the plea agreement, SFPP plead no-contest to two misdemeanors and paid approximately $2.5 million in fines, penalties, restitution, environmental improvement project funding, and for enforcement training in the State of California, and was placed on informal, unsupervised probation for a term of 18 months. On May 8, 2023, the California Attorney General confirmed SFPP had complied with the terms of the plea agreement. Since the November 2020 release, we have cooperated fully with federal and state agencies and worked diligently to remediate the affected areas. There may be civil enforcement actions by federal and state agencies arising from the November 2020 release. Further, we anticipate ongoing monitoring and, where necessary, remediation under the oversight of the San Francisco Regional Water Quality Control Board until site conditions demonstrate no further actions are required. We do not anticipate the costs to resolve those enforcement matters, if any, or the costs to monitor and further remediate the site, will have a material adverse impact to our business. General 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 business. As of September 30, 2023 and December 31, 2022, we have accrued a total reserve for environmental liabilities in the amount of $208 million and $221 million, respectively. In addition, as of September 30, 2023 and December 31, 2022, we had receivables of $11 million and $12 million, respectively, recorded for expected cost recoveries that have been deemed probable. Challenge to Federal “ Good Neighbor Plan ” On July 14, 2023, we filed a Petition for Review against the EPA and others in the U.S. Court of Appeals for the District of Columbia Circuit seeking review of the EPA’s final action promulgating the EPA’s final rule known as the “Good Neighbor Plan” (the Plan). The Plan was published in the Federal Register as a final rule on June 5, 2023. The Plan is 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. We believe that the Plan is deeply flawed and that numerous and substantial bases for challenging the Plan exist. If the Plan were fully implemented, its emission standards would require installation of more stringent air pollution controls on hundreds of existing internal combustion engines used by our Natural Gas Pipelines business segment. If the Plan were to remain in effect in its current form (including full compliance by its May 1, 2026 compliance deadline, and assuming failure of all pending challenges to state implementation plan disapprovals and no successful challenge to the Plan), we anticipate that it would have a material impact on us. On July 27, 2023, we filed a Motion to Stay the Plan Pending Review, and on September 25, 2023, the U.S. Court of Appeals denied the Motion. On October 13, 2023, we filed an Emergency Application for Stay of Final Agency Action in the United States Supreme Court. On July 31, 2023, the EPA published an Interim Final Rule entitled “Federal ‘Good Neighbor Plan’ for the 2015 Ozone National Ambient Air Quality Standards; Response to Judicial Stays of SIP Disapproval Action for Certain States.” On September 29, 2023, we filed a Petition for Review against the EPA and others in the U.S. Court of Appeals for the District of Columbia seeking review of the Interim Final Rule. |
Recent Accounting Pronouncement
Recent Accounting Pronouncements (Notes) | 9 Months Ended |
Sep. 30, 2023 | |
Accounting Standards Update and Change in Accounting Principle [Abstract] | |
Recent Accounting Pronouncements | 10. Recent Accounting Pronouncements Accounting Standards Updates Reference Rate Reform (Topic 848) On March 12, 2020, the FASB issued ASU No. 2020-04, “ Reference Rate Reform – Facilitation of the Effects of Reference Rate Reform on Financial Reporting. ” This ASU provides temporary optional expedients and exceptions to GAAP guidance on contract modifications and hedge accounting to ease the financial reporting burdens of the expected market transition from LIBOR and other interbank offered rates to alternative reference rates, such as the Secured Overnight Financing Rate (SOFR). Entities can elect not to apply certain modification accounting requirements to contracts affected by reference rate reform, if certain criteria are met. An entity that makes this election would not have to remeasure the contracts at the modification date or reassess a previous accounting determination. Entities can also elect various optional expedients that would allow them to continue applying hedge accounting for hedging relationships affected by reference rate reform, if certain criteria are met. On January 7, 2021, the FASB issued ASU No. 2021-01, “ Reference Rate Reform (Topic 848): Scope. ” This ASU clarifies that all derivative instruments affected by changes to the interest rates used for discounting, margining or contract price alignment (the “Discounting Transition”) are in the scope of Topic 848 and therefore qualify for the available temporary optional expedients and exceptions. As such, entities that employ derivatives that are the designated hedged item in a hedge relationship where perfect effectiveness is assumed can continue to apply hedge accounting without de-designating the hedging relationship to the extent such derivatives are impacted by the Discounting Transition. On December 21, 2022, the FASB issued ASU No. 2022-06, “ Reference Rate Reform (Topic 848): Deferral of the Sunset Date of Topic 848 .” This ASU defers the sunset date of Topic 848 from December 31, 2022, to December 31, 2024, after which entities will no longer be permitted to apply the optional expedients and exceptions in Topic 848. The guidance was effective upon issuance. During the nine months ended September 30, 2023 we amended certain of our existing fixed-to-variable interest rate swap agreements, which were designated as fair value hedges, to transition the variable leg of such agreements from LIBOR to SOFR. These agreements contain a combined notional principal amount of $1,225 million and convert a portion of our fixed rate debt to variable rates. Concurrent with these amendments, we elected certain of the optional expedients provided in Topic 848 which allow us to maintain our prior designation of fair value hedge accounting to these agreements. See Note 5 “Risk Management— Interest Rate Risk Management ” for more information on our interest rate risk management activities. |
Pay vs Performance Disclosure
Pay vs Performance Disclosure - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2023 | Sep. 30, 2022 | Sep. 30, 2023 | Sep. 30, 2022 | |
Pay vs Performance Disclosure | ||||
Net Income (Loss) Attributable to Parent | $ 532 | $ 576 | $ 1,797 | $ 1,878 |
Insider Trading Arrangements
Insider Trading Arrangements | 3 Months Ended |
Sep. 30, 2023 | |
Trading Arrangements, by Individual | |
Rule 10b5-1 Arrangement Adopted | false |
Non-Rule 10b5-1 Arrangement Adopted | false |
Rule 10b5-1 Arrangement Terminated | false |
Non-Rule 10b5-1 Arrangement Terminated | false |
General (Policies)
General (Policies) | 9 Months Ended |
Sep. 30, 2023 | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |
Basis of Presentation | 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 2022 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 | 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, 2023 evaluation, we grouped our businesses into seven reporting units as follows: (i) Natural Gas Pipelines Regulated; (ii) Natural Gas Pipelines Non-Regulated; (iii) CO 2 ; (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 using market and income approach valuation methodologies, which include assumptions primarily involving management’s significant judgments and estimates with respect to market multiples, comparable sales transactions, general economic conditions and the related demand for products handled or transported by our assets as well as assumptions regarding future cash flows based on production growth assumptions, terminal values and discount rates. Changes to any one or a combination of these factors 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. |
Earnings per Share | Earnings per Share We calculate earnings per share using the two-class method. Earnings were allocated to Class P common stock and participating securities based on the amount of dividends paid in the current period plus an allocation of the undistributed earnings or excess distributions over earnings to the extent that each security participates in earnings or excess distributions |
General (Tables)
General (Tables) | 9 Months Ended |
Sep. 30, 2023 | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |
Schedule of Net Income for Shareholders and Participating Securities | The following table sets forth the allocation of net income available to shareholders of Class P common stock and participating securities: Three Months Ended Nine Months Ended 2023 2022 2023 2022 (In millions, except per share amounts) Net Income Available to Stockholders $ 532 $ 576 $ 1,797 $ 1,878 Participating securities: Less: Net Income Allocated to Restricted Stock Awards(a) (4) (4) (11) (9) Net Income Allocated to Class P Stockholders $ 528 $ 572 $ 1,786 $ 1,869 Basic Weighted Average Shares Outstanding 2,230 2,253 2,238 2,262 Basic Earnings Per Share $ 0.24 $ 0.25 $ 0.80 $ 0.83 (a) As of September 30, 2023, there were 13 million restricted stock awards outstanding. |
Schedule of Antidilutive Securities | The following table presents the maximum number of potential common stock equivalents which are antidilutive and accordingly are excluded from the determination of diluted earnings per share. As we have no other common stock equivalents, our diluted earnings per share are the same as our basic earnings per share for all periods presented. Three Months Ended Nine Months Ended 2023 2022 2023 2022 (In millions on a weighted average basis) Unvested restricted stock awards 13 13 13 13 Convertible trust preferred securities 3 3 3 3 |
Debt (Tables)
Debt (Tables) | 9 Months Ended |
Sep. 30, 2023 | |
Debt Disclosure [Abstract] | |
Schedule of Debt | The following table provides information on the principal amount of our outstanding debt balances: September 30, 2023 December 31, 2022 (In millions, unless otherwise stated) Current portion of debt $3.5 billion credit facility due August 20, 2027 $ — $ — $500 million credit facility due November 16, 2023 — — Commercial paper notes(a) 320 — Current portion of senior notes 3.15% due January 2023 — 1,000 Floating rate, due January 2023 — 250 3.45% due February 2023 — 625 3.50% due September 2023 — 600 5.625% due November 2023 750 750 4.15% due February 2024 650 — 4.30% due May 2024 600 — 4.25% due September 2024 650 — Trust I preferred securities, 4.75%, due March 2028(b) 111 111 Current portion of other debt 49 49 Total current portion of debt 3,130 3,385 Long-term debt (excluding current portion) Senior notes 27,232 27,638 EPC Building, LLC, promissory note, 3.967%, due 2023 through 2035 316 330 Trust I preferred securities, 4.75%, due March 2028 109 109 Other 206 211 Total long-term debt 27,863 28,288 Total debt(c) $ 30,993 $ 31,673 (a) Weighted average interest rate on borrowings at September 30, 2023 was 5.50%. (b) 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. (c) Excludes our “Debt fair value adjustments” which, as of September 30, 2023 and December 31, 2022, increased our total debt balances by $8 million and $115 million, respectively. |
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments | The carrying value and estimated fair value of our outstanding debt balances are disclosed below: September 30, 2023 December 31, 2022 Carrying Estimated Carrying Estimated (In millions) Total debt $ 31,001 $ 28,451 $ 31,788 $ 30,070 (a) Included in the estimated fair value are amounts for our Trust I Preferred Securities of $199 million and $195 million as of September 30, 2023 and December 31, 2022, respectively. |
Stockholders' Equity (Tables)
Stockholders' Equity (Tables) | 9 Months Ended |
Sep. 30, 2023 | |
Stockholders' Equity Note [Abstract] | |
Schedule of Dividends | The following table provides information about our per share dividends: Three Months Ended Nine Months Ended 2023 2022 2023 2022 Per share cash dividend declared for the period $ 0.2825 $ 0.2775 $ 0.8475 $ 0.8325 Per share cash dividend paid in the period 0.2825 0.2775 0.8425 0.825 |
Schedule of Accumulated Other Comprehensive Income | Changes in the components of our “Accumulated other comprehensive loss” not including noncontrolling interests are summarized as follows: Net unrealized Pension and Total (In millions) Balance as of December 31, 2022 $ (164) $ (238) $ (402) Other comprehensive gain before reclassifications 2 11 13 Gain reclassified from accumulated other comprehensive loss (29) — (29) Net current-period change in accumulated other comprehensive loss (27) 11 (16) Balance as of September 30, 2023 $ (191) $ (227) $ (418) Net unrealized Pension and Total (In millions) Balance as of December 31, 2021 $ (172) $ (239) $ (411) Other comprehensive (loss) gain before reclassifications (366) 18 (348) Loss reclassified from accumulated other comprehensive loss 396 — 396 Net current-period change in accumulated other comprehensive loss 30 18 48 Balance as of September 30, 2022 $ (142) $ (221) $ (363) |
Risk Management (Tables)
Risk Management (Tables) | 9 Months Ended |
Sep. 30, 2023 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
Schedule of Notional Amounts of Outstanding Derivative Positions | As of September 30, 2023, 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 (18.2) MMBbl Crude oil basis (1.1) MMBbl Natural gas fixed price (56.2) Bcf Natural gas basis (48.0) Bcf NGL fixed price (0.8) MMBbl Derivatives not designated as hedging contracts Crude oil fixed price (1.6) MMBbl Crude oil basis (6.7) MMBbl Natural gas fixed price (6.9) Bcf Natural gas basis (98.3) Bcf NGL fixed price (1.0) MMBbl |
Schedule of Interest Rate Derivatives | The following table summarizes our outstanding interest rate contracts as of September 30, 2023: Notional amount Accounting treatment Maximum term (In millions) Derivatives designated as hedging instruments Fixed-to-variable interest rate contracts(a)(b) $ 6,800 Fair value hedge March 2035 Derivatives not designated as hedging instruments Variable-to-fixed interest rate contracts 3,445 Mark-to-Market December 2023 (a) The principal amount of hedged senior notes consisted of $2,050 million included in “Current portion of debt” and $4,750 million included in “Long-term debt” on our accompanying consolidated balance sheet. (b) During the nine months ended September 30, 2023, certain optional expedients as set forth in Topic 848 – Reference Rate Reform were elected on certain of these contracts to preserve fair value hedge accounting treatment. See Note 10 for further information on Topic 848. |
Schedule of Foreign Exchange Contracts, Statement of Financial Position | The following table summarizes our outstanding foreign currency contracts as of September 30, 2023: Notional amount Accounting treatment Maximum term (In millions) Derivatives designated as hedging instruments EUR-to-USD cross currency swap contracts(a) $ 543 Cash flow hedge March 2027 (a) These swaps eliminate the foreign currency risk associated with our Euro-denominated debt. |
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value | The following table summarizes the fair values of our derivative contracts included on our accompanying consolidated balance sheets: Fair Value of Derivative Contracts Location Derivatives Asset Derivatives Liability September 30, December 31, September 30, December 31, (In millions) Derivatives designated as hedging instruments Energy commodity derivative contracts Fair value of derivative contracts/(Fair value of derivative contracts) $ 38 $ 150 $ (153) $ (156) Deferred charges and other assets/(Other long-term liabilities and deferred credits) 1 6 (87) (91) Subtotal 39 156 (240) (247) Interest rate contracts Fair value of derivative contracts/(Fair value of derivative contracts) — — (153) (144) Deferred charges and other assets/(Other long-term liabilities and deferred credits) 19 39 (288) (261) Subtotal 19 39 (441) (405) Foreign currency contracts Fair value of derivative contracts/(Fair value of derivative contracts) — — (6) (3) Deferred charges and other assets/(Other long-term liabilities and deferred credits) — — (23) (32) Subtotal — — (29) (35) Total 58 195 (710) (687) Derivatives not designated as hedging instruments Energy commodity derivative contracts Fair value of derivative contracts/(Fair value of derivative contracts) 33 80 (34) (162) Deferred charges and other assets/(Other long-term liabilities and deferred credits) 7 23 (1) (19) Subtotal 40 103 (35) (181) Interest rate contracts Fair value of derivative contracts/(Fair value of derivative contracts) 8 1 — — Total 48 104 (35) (181) Total derivatives $ 106 $ 299 $ (745) $ (868) |
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis | 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 Contracts available for netting Cash collateral held(a) Level 1 Level 2 Level 3 Gross amount Net amount (In millions) As of September 30, 2023 Energy commodity derivative contracts(b) $ 40 $ 39 $ — $ 79 $ (25) $ — $ 54 Interest rate contracts — 27 — 27 — — 27 As of December 31, 2022 Energy commodity derivative contracts(b) $ 115 $ 144 $ — $ 259 $ (186) $ — $ 73 Interest rate contracts — 40 — 40 — — 40 Balance sheet liability Contracts available for netting Cash collateral posted(a) Level 1 Level 2 Level 3 Gross amount Net amount (In millions) As of September 30, 2023 Energy commodity derivative contracts(b) $ (3) $ (272) $ — $ (275) $ 25 $ (52) $ (302) Interest rate contracts — (442) — (442) — — (442) Foreign currency contracts — (28) — (28) — — (28) As of December 31, 2022 Energy commodity derivative contracts(b) $ (23) $ (405) $ — $ (428) $ 186 $ (30) $ (272) Interest rate contracts — (405) — (405) — — (405) Foreign currency contracts — (35) — (35) — — (35) (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. |
Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance | The following tables summarize the pre-tax impact of our derivative contracts on our accompanying consolidated statements of income and comprehensive income: Derivatives in fair value hedging relationships Location Gain/(loss) recognized in income Three Months Ended Nine Months Ended 2023 2022 2023 2022 (In millions) Interest rate contracts Interest, net $ (74) $ (278) $ (55) $ (754) Hedged fixed rate debt(a) Interest, net $ 77 $ 279 $ 59 $ 761 (a) As of September 30, 2023, the cumulative amount of fair value hedging adjustments to our hedged fixed rate debt was a decrease of $426 million included in “Debt fair value adjustments” on our accompanying consolidated balance sheet. Derivatives in cash flow hedging relationships Gain/(loss) Location Gain/(loss) reclassified from Accumulated OCI Three Months Ended Three Months Ended 2023 2022 2023 2022 (In millions) (In millions) Energy commodity derivative contracts $ (188) $ 195 Revenues—Commodity sales $ 16 $ (116) Costs of sales (27) 17 Foreign currency contracts (10) (32) Other, net (17) (34) Total $ (198) $ 163 Total $ (28) $ (133) Derivatives in cash flow hedging relationships Gain/(loss) Location Gain/(loss) reclassified from Accumulated OCI Nine Months Ended Nine Months Ended 2023 2022 2023 2022 (In millions) (In millions) Energy commodity derivative contracts $ (3) $ (375) Revenues—Commodity sales $ 98 $ (433) Costs of sales (54) 34 Interest rate contracts — 7 Interest, net — — Foreign currency contracts 6 (107) Other, net (6) (115) Total $ 3 $ (475) Total $ 38 $ (514) (a) We expect to reclassify approximately $145 million of loss associated with cash flow hedge price risk management activities included in our accumulated other comprehensive loss balance as of September 30, 2023 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. (b) During the three and nine months ended September 30, 2022, we recognized approximate gains of $29 million and $34 million associated with a write-down of hedged inventory. All other amounts reclassified were the result of the hedged forecasted transactions actually affecting earnings (i.e., when the forecasted sales and purchases actually occurred). Derivatives not designated as accounting hedges Location Gain/(loss) recognized in income on derivatives Three Months Ended Nine Months Ended 2023 2022 2023 2022 (In millions) Energy commodity derivative contracts Revenues—Commodity sales $ (21) $ 44 $ 11 $ 18 Costs of sales (4) (30) 116 (129) Earnings from equity investments — (7) 1 (11) Interest rate contracts Interest, net (6) (20) 6 28 Total(a) $ (31) $ (13) $ 134 $ (94) (a) The three and nine months ended September 30, 2023 amounts include approximate gains of $9 million and $45 million, respectively, and the three and nine months ended September 30, 2022 amounts include approximate losses of $19 million and $39 million, respectively, associated with natural gas, crude and NGL derivative contract settlements. |
Revenue Recognition (Tables)
Revenue Recognition (Tables) | 9 Months Ended |
Sep. 30, 2023 | |
Revenue from Contract with Customer [Abstract] | |
Disaggregation of Revenue | The following tables present our revenues disaggregated by segment, revenue source and type of revenue for each revenue source: Three Months Ended September 30, 2023 Natural Gas Pipelines Products Pipelines Terminals CO 2 Corporate and Eliminations Total (In millions) Revenues from contracts with customers(a) Services Firm services(b) $ 849 $ 49 $ 211 $ — $ (1) $ 1,108 Fee-based services 268 264 102 9 (1) 642 Total services 1,117 313 313 9 (2) 1,750 Commodity sales Natural gas sales 689 — — 28 (5) 712 Product sales 281 495 10 291 (2) 1,075 Total commodity sales 970 495 10 319 (7) 1,787 Total revenues from contracts with customers 2,087 808 323 328 (9) 3,537 Other revenues(c) Leasing services(d) 120 50 161 15 — 346 Derivatives adjustments on commodity sales 49 (2) — (52) — (5) Other 17 6 — 6 — 29 Total other revenues 186 54 161 (31) — 370 Total revenues $ 2,273 $ 862 $ 484 $ 297 $ (9) $ 3,907 Three Months Ended September 30, 2022 Natural Gas Pipelines Products Pipelines Terminals CO 2 Corporate and Eliminations Total (In millions) Revenues from contracts with customers(a) Services Firm services(b) $ 845 $ 57 $ 199 $ — $ — $ 1,101 Fee-based services 243 247 106 11 — 607 Total services 1,088 304 305 11 — 1,708 Commodity sales Natural gas sales 1,902 — — 24 (7) 1,919 Product sales 389 511 11 353 (1) 1,263 Total commodity sales 2,291 511 11 377 (8) 3,182 Total revenues from contracts with customers 3,379 815 316 388 (8) 4,890 Other revenues(c) Leasing services(d) 120 51 141 16 — 328 Derivatives adjustments on commodity sales (12) — — (60) — (72) Other 18 6 — 7 — 31 Total other revenues 126 57 141 (37) — 287 Total revenues $ 3,505 $ 872 $ 457 $ 351 $ (8) $ 5,177 Nine Months Ended September 30, 2023 Natural Gas Pipelines Products Pipelines Terminals CO 2 Corporate and Eliminations Total (In millions) Revenues from contracts with customers(a) Services Firm services(b) $ 2,615 $ 138 $ 626 $ 1 $ (2) $ 3,378 Fee-based services 752 750 298 29 (1) 1,828 Total services 3,367 888 924 30 (3) 5,206 Commodity sales Natural gas sales 1,972 — — 61 (9) 2,024 Product sales 788 1,211 23 836 (6) 2,852 Total commodity sales 2,760 1,211 23 897 (15) 4,876 Total revenues from contracts with customers 6,127 2,099 947 927 (18) 10,082 Other revenues(c) Leasing services(d) 357 149 476 40 — 1,022 Derivatives adjustments on commodity sales 196 (1) — (86) — 109 Other 50 18 — 15 — 83 Total other revenues 603 166 476 (31) — 1,214 Total revenues $ 6,730 $ 2,265 $ 1,423 $ 896 $ (18) $ 11,296 Nine Months Ended September 30, 2022 Natural Gas Pipelines Products Pipelines Terminals CO 2 Corporate and Eliminations Total (In millions) Revenues from contracts with customers(a) Services Firm services(b) $ 2,633 $ 176 $ 585 $ 1 $ (2) $ 3,393 Fee-based services 690 723 300 35 — 1,748 Total services 3,323 899 885 36 (2) 5,141 Commodity sales Natural gas sales 4,938 — — 68 (17) 4,989 Product sales 1,141 1,577 22 1,105 (4) 3,841 Total commodity sales 6,079 1,577 22 1,173 (21) 8,830 Total revenues from contracts with customers 9,402 2,476 907 1,209 (23) 13,971 Other revenues(c) Leasing services(d) 355 144 430 44 — 973 Derivatives adjustments on commodity sales (132) (3) — (280) — (415) Other 49 17 — 26 — 92 Total other revenues 272 158 430 (210) — 650 Total revenues $ 9,674 $ 2,634 $ 1,337 $ 999 $ (23) $ 14,621 (a) Differences between the revenue classifications presented on the consolidated statements of income and the categories for the disaggregated revenues by type of revenue above are primarily attributable to revenues reflected in the “Other revenues” category above (see note (c)). (b) Includes non-cancellable firm service customer contracts with take-or-pay or minimum volume commitment elements, including those contracts where both the price and quantity amount are fixed. Excludes service contracts with index-based pricing, which along with revenues from other customer service contracts are reported as “Fee-based services.” (c) Amounts recognized as revenue under guidance prescribed in Topics of the ASC other than in Topic 606 were primarily from leases and derivative contracts. See Note 5 for additional information related to our derivative contracts. (d) Our revenues from leasing services are predominantly comprised of specific assets that we lease to customers under operating leases where one customer obtains substantially all of the economic benefit from the asset and has the right to direct the use of that asset. These leases primarily consist of specific tanks, treating facilities, marine vessels and gas equipment and pipelines with separate control locations. We do not lease assets that qualify as sales-type or finance leases. |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction | The following table presents our estimated revenue allocated to remaining performance obligations for contracted revenue that has not yet been recognized, representing our “contractually committed” revenue as of September 30, 2023 that we will invoice or transfer from contract liabilities and recognize in future periods: Year Estimated Revenue (In millions) Three months ended December 31, 2023 $ 1,167 2024 4,153 2025 3,423 2026 2,933 2027 2,462 Thereafter 14,057 Total $ 28,195 |
Reportable Segments (Tables)
Reportable Segments (Tables) | 9 Months Ended |
Sep. 30, 2023 | |
Segment Reporting [Abstract] | |
Schedule of Segment Reporting Information, by Segment | Financial information by segment follows: Three Months Ended Nine Months Ended 2023 2022 2023 2022 (In millions) Revenues Natural Gas Pipelines Revenues from external customers $ 2,268 $ 3,497 $ 6,718 $ 9,653 Intersegment revenues 5 8 12 21 Products Pipelines 862 872 2,265 2,634 Terminals Revenues from external customers 483 457 1,420 1,335 Intersegment revenues 1 — 3 2 CO 2 Revenues from external customers 294 351 893 999 Intersegment revenues 3 — 3 — Corporate and intersegment eliminations (9) (8) (18) (23) Total consolidated revenues $ 3,907 $ 5,177 $ 11,296 $ 14,621 Three Months Ended Nine Months Ended 2023 2022 2023 2022 (In millions) Segment EBDA(a) Natural Gas Pipelines $ 1,179 $ 1,135 $ 3,929 $ 3,453 Products Pipelines 311 257 780 855 Terminals 259 240 774 731 CO 2 163 215 510 619 Total Segment EBDA 1,912 1,847 5,993 5,658 DD&A (561) (551) (1,683) (1,632) Amortization of excess cost of equity investments (18) (19) (54) (57) General and administrative and corporate charges (176) (149) (534) (438) Interest, net (457) (399) (1,345) (1,087) Income tax expense (145) (134) (509) (512) Total consolidated net income $ 555 $ 595 $ 1,868 $ 1,932 September 30, 2023 December 31, 2022 (In millions) Assets Natural Gas Pipelines $ 47,642 $ 47,978 Products Pipelines 8,923 8,985 Terminals 8,250 8,357 CO 2 3,459 3,449 Corporate assets(b) 588 1,309 Total consolidated assets $ 68,862 $ 70,078 (a) Includes revenues, earnings from equity investments, operating expenses, gain on divestitures and impairments, net, oth er income, net, and other, net. Operating expenses include costs of sales, operations and maintenance expenses, and taxes, other than income taxes. (b) Includes cash and cash equivalents, restricted deposits, certain prepaid assets and deferred charges, risk management assets related to derivative contracts, corporate headquarters in Houston, Texas and miscellaneous corporate assets (such as information technology, telecommunications equipment and legacy activity) not allocated to our reportable segments. |
Income Taxes (Tables)
Income Taxes (Tables) | 9 Months Ended |
Sep. 30, 2023 | |
Income Tax Disclosure [Abstract] | |
Schedule of Income Taxes | Income tax expense included on our accompanying consolidated statements of income is as follows: Three Months Ended Nine Months Ended 2023 2022 2023 2022 (In millions, except percentages) Income tax expense $ 145 $ 134 $ 509 $ 512 Effective tax rate 20.7 % 18.4 % 21.4 % 20.9 % |
General - Organization and Basi
General - Organization and Basis of Presentation (Details) mi in Thousands | May 31, 2023 segment | Sep. 30, 2023 Bcf Terminals mi |
General [Line Items] | ||
Miles of pipeline | mi | 82 | |
Number of pipeline terminals owned interest in and/or operated | Terminals | 140 | |
Working capacity | 700 | |
Number of reporting units | segment | 7 | |
Terminals | Maximum | ||
General [Line Items] | ||
Reporting Unit, Percentage of Fair Value in Excess of Carrying Amount | 10% | |
Renewable Natural Gas | ||
General [Line Items] | ||
Gross production | 5.4 |
General - Schedule of Net Incom
General - Schedule of Net Income Available to Shareholders (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2023 | Sep. 30, 2022 | Sep. 30, 2023 | Sep. 30, 2022 | |
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items] | ||||
Net Income Available to Stockholders | $ 532 | $ 576 | $ 1,797 | $ 1,878 |
Less: Net Income Allocated to Restricted Stock Awards(a) | $ (4) | $ (4) | $ (11) | $ (9) |
Basic Weighted Average Common Shares Outstanding | 2,230 | 2,253 | 2,238 | 2,262 |
Basic Earnings Per Share | $ 0.24 | $ 0.25 | $ 0.80 | $ 0.83 |
Class P Common Stock | ||||
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items] | ||||
Net Income Available to Stockholders | $ 528 | $ 572 | $ 1,786 | $ 1,869 |
Unvested restricted stock awards | Class P Common Stock | ||||
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items] | ||||
Restricted stock awards outstanding | 13 | 13 |
General - Schedule of Antidilut
General - Schedule of Antidilutive Securities (Details) - shares shares in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2023 | Sep. 30, 2022 | Sep. 30, 2023 | Sep. 30, 2022 | |
Unvested restricted stock awards | ||||
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items] | ||||
Antidilutive securities | 13 | 13 | 13 | 13 |
Convertible trust preferred securities | ||||
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items] | ||||
Antidilutive securities | 3 | 3 | 3 | 3 |
Losses on Impairments - Impairm
Losses on Impairments - Impairments (Details) $ in Millions | 3 Months Ended |
Mar. 31, 2023 USD ($) | |
Double Eagle Pipeline LLC | Products Pipelines | |
Schedule of Equity Method Investments [Line Items] | |
Impairment on equity investment | $ 67 |
Losses on Impairments - Investm
Losses on Impairments - Investment in Ruby (Details) $ in Millions | Dec. 31, 2022 USD ($) |
Ruby Pipeline Holding Company LLC | Ruby Chapter 11 Bankruptcy Filing | |
Schedule of Equity Method Investments [Line Items] | |
Estimated litigation payment, current | $ 28.5 |
Debt - Schedule of Debt Outstan
Debt - Schedule of Debt Outstanding (Details) - USD ($) $ in Millions | 9 Months Ended | |||
Jan. 31, 2023 | Sep. 30, 2023 | Sep. 30, 2022 | Dec. 31, 2022 | |
Debt Instrument [Line Items] | ||||
Current portion of debt | $ 3,130 | $ 3,385 | ||
Long-term debt | 27,863 | 28,288 | ||
Total debt(c) | 30,993 | 31,673 | ||
Debt fair value adjustments | 8 | 115 | ||
Proceeds from issuances of debt | 4,373 | $ 8,898 | ||
$3.5 billion credit facility due August 20, 2027 | ||||
Debt Instrument [Line Items] | ||||
Current portion of debt | 0 | 0 | ||
Line of Credit Facility, Maximum Borrowing Capacity | 3,500 | |||
$500 million credit facility due November 16, 2023 | ||||
Debt Instrument [Line Items] | ||||
Current portion of debt | 0 | 0 | ||
Line of Credit Facility, Maximum Borrowing Capacity | 500 | |||
Commercial paper notes(a) | ||||
Debt Instrument [Line Items] | ||||
Current portion of debt | $ 320 | 0 | ||
Weighted average interest rate on borrowings outstanding | 5.50% | |||
Current portion of other debt | ||||
Debt Instrument [Line Items] | ||||
Current portion of debt | $ 49 | 49 | ||
Trust I preferred securities, 4.75%, due March 2028(b) | Capital Trust I | ||||
Debt Instrument [Line Items] | ||||
Current portion of debt | 111 | 111 | ||
Long-term debt | $ 109 | 109 | ||
Interest rate | 4.75% | |||
EPC Building, LLC, promissory note, 3.967%, due 2023 through 2035 | EPC Building LLC | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 316 | 330 | ||
Interest rate | 3.967% | |||
Other | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 206 | 211 | ||
Senior notes | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | 27,232 | 27,638 | ||
Senior notes | 3.15% due January 2023 | ||||
Debt Instrument [Line Items] | ||||
Current portion of debt | 0 | $ 1,000 | ||
Interest rate | 3.15% | |||
Senior notes | Floating rate, due January 2023 | ||||
Debt Instrument [Line Items] | ||||
Current portion of debt | 0 | $ 250 | ||
Senior notes | 3.45% due February 2023 | ||||
Debt Instrument [Line Items] | ||||
Current portion of debt | 0 | $ 625 | ||
Interest rate | 3.45% | |||
Senior notes | 3.50% due September 2023 | ||||
Debt Instrument [Line Items] | ||||
Current portion of debt | 0 | $ 600 | ||
Interest rate | 3.50% | |||
Senior notes | 5.625% due November 2023 | ||||
Debt Instrument [Line Items] | ||||
Current portion of debt | $ 750 | $ 750 | ||
Interest rate | 5.625% | |||
Senior notes | 4.15% due February 2024 | ||||
Debt Instrument [Line Items] | ||||
Current portion of debt | $ 650 | 0 | ||
Interest rate | 4.15% | |||
Senior notes | 4.30% due May 2024 | ||||
Debt Instrument [Line Items] | ||||
Current portion of debt | $ 600 | 0 | ||
Interest rate | 4.30% | |||
Senior notes | 4.25% due September 2024 | ||||
Debt Instrument [Line Items] | ||||
Current portion of debt | $ 650 | $ 0 | ||
Interest rate | 4.25% | |||
Senior notes | 5.20% due June 2033 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 1,500 | |||
Interest rate | 5.20% | |||
Proceeds from issuances of debt | $ 1,485 |
Debt - Credit Facilities (Detai
Debt - Credit Facilities (Details) - USD ($) $ in Millions | Sep. 30, 2023 | Dec. 31, 2022 |
Line of Credit Facility [Line Items] | ||
Current portion of debt | $ 3,130 | $ 3,385 |
Commercial paper program | ||
Line of Credit Facility [Line Items] | ||
Current portion of debt | 320 | $ 0 |
Credit Facilities | ||
Line of Credit Facility [Line Items] | ||
Current portion of debt | 0 | |
Letters of Credit Outstanding, Amount | 81 | |
Line of Credit Facility, Remaining Borrowing Capacity | $ 3,600 |
Debt - Fair Value of Financial
Debt - Fair Value of Financial Instruments (Details) - USD ($) $ in Millions | Sep. 30, 2023 | Dec. 31, 2022 |
Carrying value | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Total debt | $ 31,001 | $ 31,788 |
Estimated fair value(a) | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Total debt | 28,451 | 30,070 |
Estimated fair value(a) | Capital Trust I | Trust I preferred securities, 4.75%, due March 2028(b) | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Convertible debt | $ 199 | $ 195 |
Stockholders' Equity - Common E
Stockholders' Equity - Common Equity (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions | 1 Months Ended | 3 Months Ended | 9 Months Ended | |||||
Oct. 18, 2023 | Oct. 19, 2023 | Sep. 30, 2023 | Sep. 30, 2022 | Sep. 30, 2023 | Sep. 30, 2022 | Jan. 18, 2023 | Jul. 19, 2017 | |
Class of Stock [Line Items] | ||||||||
Common share buy-back program, amount | $ 3,000 | $ 2,000 | ||||||
Common share buy-back program, average price per share | $ 16.62 | |||||||
Value of shares repurchased | $ 73 | $ 160 | $ 390 | $ 333 | ||||
Per share cash dividend declared for the period | $ 0.2825 | $ 0.2775 | $ 0.8475 | $ 0.8325 | ||||
Per share cash dividend paid in the period | $ 0.2825 | $ 0.2775 | $ 0.8425 | $ 0.825 | ||||
Subsequent Event | ||||||||
Class of Stock [Line Items] | ||||||||
Common share buy-back program, average price per share | $ 16.38 | |||||||
Value of shares repurchased | $ 83 | |||||||
Per share cash dividend declared for the period | $ 0.2825 | |||||||
Common stock | ||||||||
Class of Stock [Line Items] | ||||||||
Shares repurchased | 4 | 9 | 23 | 19 | ||||
Common stock | Subsequent Event | ||||||||
Class of Stock [Line Items] | ||||||||
Shares repurchased | 5 |
Stockholders' Equity - Adoption
Stockholders' Equity - Adoption of Accounting Pronouncement (Details) - USD ($) $ in Millions | Sep. 30, 2023 | Jun. 30, 2023 | Dec. 31, 2022 | Sep. 30, 2022 | Jun. 30, 2022 | Dec. 31, 2021 |
New Accounting Pronouncements or Change in Accounting Principle [Line Items] | ||||||
Stockholders' equity | $ 31,581 | $ 31,909 | $ 32,114 | $ 32,135 | $ 31,625 | $ 31,921 |
Additional paid-in capital | ||||||
New Accounting Pronouncements or Change in Accounting Principle [Line Items] | ||||||
Stockholders' equity | $ 41,306 | $ 41,387 | $ 41,673 | $ 41,689 | $ 41,654 | 41,806 |
Impact of Adoption of ASU | ||||||
New Accounting Pronouncements or Change in Accounting Principle [Line Items] | ||||||
Stockholders' equity | (11) | |||||
Impact of Adoption of ASU | Accounting Standards Update 2020-06 | ||||||
New Accounting Pronouncements or Change in Accounting Principle [Line Items] | ||||||
Unamortized debt discount | 14 | |||||
Impact of Adoption of ASU | Additional paid-in capital | ||||||
New Accounting Pronouncements or Change in Accounting Principle [Line Items] | ||||||
Stockholders' equity | (11) | |||||
Impact of Adoption of ASU | Additional paid-in capital | Accounting Standards Update 2020-06 | ||||||
New Accounting Pronouncements or Change in Accounting Principle [Line Items] | ||||||
Stockholders' equity | $ (11) |
Stockholders' Equity - Accumula
Stockholders' Equity - Accumulated Other Comprehensive Loss (Details) - USD ($) $ in Millions | 9 Months Ended | |
Sep. 30, 2023 | Sep. 30, 2022 | |
Accumulated Other Comprehensive Loss [Line Items] | ||
Balance | $ 32,114 | $ 31,921 |
Balance | 31,581 | 32,135 |
Net unrealized gains/(losses) on cash flow hedge derivatives | ||
Accumulated Other Comprehensive Loss [Line Items] | ||
Balance | (164) | (172) |
Other comprehensive (loss) gain before reclassifications | 2 | (366) |
(Gain) loss reclassified from accumulated other comprehensive loss | (29) | 396 |
Net current-period change in accumulated other comprehensive loss | (27) | 30 |
Balance | (191) | (142) |
Pension and other postretirement liability adjustments | ||
Accumulated Other Comprehensive Loss [Line Items] | ||
Balance | (238) | (239) |
Other comprehensive (loss) gain before reclassifications | 11 | 18 |
(Gain) loss reclassified from accumulated other comprehensive loss | 0 | 0 |
Net current-period change in accumulated other comprehensive loss | 11 | 18 |
Balance | (227) | (221) |
Total accumulated other comprehensive loss | ||
Accumulated Other Comprehensive Loss [Line Items] | ||
Balance | (402) | (411) |
Other comprehensive (loss) gain before reclassifications | 13 | (348) |
(Gain) loss reclassified from accumulated other comprehensive loss | (29) | 396 |
Net current-period change in accumulated other comprehensive loss | (16) | 48 |
Balance | $ (418) | $ (363) |
Risk Management - Energy Commod
Risk Management - Energy Commodity Price Risk Management (Details) - Short - Energy commodity derivative contracts | 9 Months Ended |
Sep. 30, 2023 Bcf MMBbls | |
Derivatives designated as hedging instruments | Crude oil fixed price | |
Derivative [Line Items] | |
Net open position | (18.2) |
Derivatives designated as hedging instruments | Crude oil basis | |
Derivative [Line Items] | |
Net open position | (1.1) |
Derivatives designated as hedging instruments | Natural gas fixed price | |
Derivative [Line Items] | |
Net open position | Bcf | (56.2) |
Derivatives designated as hedging instruments | Natural gas basis | |
Derivative [Line Items] | |
Net open position | Bcf | (48) |
Derivatives designated as hedging instruments | NGL fixed price | |
Derivative [Line Items] | |
Net open position | (0.8) |
Derivatives not designated as hedging instruments | Crude oil fixed price | |
Derivative [Line Items] | |
Net open position | (1.6) |
Derivatives not designated as hedging instruments | Crude oil basis | |
Derivative [Line Items] | |
Net open position | (6.7) |
Derivatives not designated as hedging instruments | Natural gas fixed price | |
Derivative [Line Items] | |
Net open position | Bcf | (6.9) |
Derivatives not designated as hedging instruments | Natural gas basis | |
Derivative [Line Items] | |
Net open position | Bcf | (98.3) |
Derivatives not designated as hedging instruments | NGL fixed price | |
Derivative [Line Items] | |
Net open position | (1) |
Risk Management - Interest Rate
Risk Management - Interest Rate Risk Management (Details) $ in Millions | Sep. 30, 2023 USD ($) |
Fixed-to-Variable Interest Rate Contracts | Designated as Hedging Instrument | Fair value hedge | |
Derivative [Line Items] | |
Notional amount | $ 6,800 |
Variable-to-Fixed Interest Rate Contracts | Derivatives not designated as hedging instruments | Fair value hedge | |
Derivative [Line Items] | |
Notional amount | 3,445 |
Current Portion Of Debt | Fixed-to-Variable Interest Rate Contracts | Designated as Hedging Instrument | |
Derivative [Line Items] | |
Derivative, Amount of Hedged Item | 2,050 |
Long-term Debt | Fixed-to-Variable Interest Rate Contracts | Designated as Hedging Instrument | |
Derivative [Line Items] | |
Derivative, Amount of Hedged Item | $ 4,750 |
Risk Management - Foreign Curre
Risk Management - Foreign Currency Risk Management (Details) $ in Millions | Sep. 30, 2023 USD ($) |
Cash flow hedge | Cross-currency contracts | Designated as Hedging Instrument | |
Derivative [Line Items] | |
Notional amount | $ 543 |
Risk Management - Fair Value of
Risk Management - Fair Value of Derivative Contracts (Details) - USD ($) $ in Millions | Sep. 30, 2023 | Dec. 31, 2022 |
Derivatives, Fair Value [Line Items] | ||
Derivatives Asset | $ 106 | $ 299 |
Derivatives Liability | (745) | (868) |
Energy commodity derivative contracts | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives Asset | 79 | 259 |
Derivatives Liability | (275) | (428) |
Interest rate contracts | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives Asset | 27 | 40 |
Derivatives Liability | (442) | (405) |
Foreign currency contracts | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives Liability | (28) | (35) |
Derivatives designated as hedging instruments | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives Asset | 58 | 195 |
Derivatives Liability | (710) | (687) |
Derivatives designated as hedging instruments | Energy commodity derivative contracts | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives Asset | 39 | 156 |
Derivatives Liability | (240) | (247) |
Derivatives designated as hedging instruments | Energy commodity derivative contracts | Fair value of derivative contracts - current assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives Asset | 38 | 150 |
Derivatives designated as hedging instruments | Energy commodity derivative contracts | Fair value of derivative contracts - current liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives Liability | (153) | (156) |
Derivatives designated as hedging instruments | Energy commodity derivative contracts | Deferred charges and other assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives Asset | 1 | 6 |
Derivatives designated as hedging instruments | Energy commodity derivative contracts | Other long-term liabilities and deferred credits | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives Liability | (87) | (91) |
Derivatives designated as hedging instruments | Interest rate contracts | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives Asset | 19 | 39 |
Derivatives Liability | (441) | (405) |
Derivatives designated as hedging instruments | Interest rate contracts | Fair value of derivative contracts - current assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives Asset | 0 | 0 |
Derivatives designated as hedging instruments | Interest rate contracts | Fair value of derivative contracts - current liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives Liability | (153) | (144) |
Derivatives designated as hedging instruments | Interest rate contracts | Deferred charges and other assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives Asset | 19 | 39 |
Derivatives designated as hedging instruments | Interest rate contracts | Other long-term liabilities and deferred credits | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives Liability | (288) | (261) |
Derivatives designated as hedging instruments | Foreign currency contracts | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives Asset | 0 | 0 |
Derivatives Liability | (29) | (35) |
Derivatives designated as hedging instruments | Foreign currency contracts | Fair value of derivative contracts - current assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives Asset | 0 | 0 |
Derivatives designated as hedging instruments | Foreign currency contracts | Fair value of derivative contracts - current liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives Liability | (6) | (3) |
Derivatives designated as hedging instruments | Foreign currency contracts | Deferred charges and other assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives Asset | 0 | 0 |
Derivatives designated as hedging instruments | Foreign currency contracts | Other long-term liabilities and deferred credits | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives Liability | (23) | (32) |
Derivatives not designated as hedging instruments | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives Asset | 48 | 104 |
Derivatives Liability | (35) | (181) |
Derivatives not designated as hedging instruments | Energy commodity derivative contracts | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives Asset | 40 | 103 |
Derivatives Liability | (35) | (181) |
Derivatives not designated as hedging instruments | Energy commodity derivative contracts | Fair value of derivative contracts - current assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives Asset | 33 | 80 |
Derivatives not designated as hedging instruments | Energy commodity derivative contracts | Fair value of derivative contracts - current liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives Liability | (34) | (162) |
Derivatives not designated as hedging instruments | Energy commodity derivative contracts | Deferred charges and other assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives Asset | 7 | 23 |
Derivatives not designated as hedging instruments | Energy commodity derivative contracts | Other long-term liabilities and deferred credits | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives Liability | (1) | (19) |
Derivatives not designated as hedging instruments | Interest rate contracts | Fair value of derivative contracts - current assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives Asset | 8 | 1 |
Derivatives not designated as hedging instruments | Interest rate contracts | Fair value of derivative contracts - current liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives Liability | $ 0 | $ 0 |
Risk Management - Derivative As
Risk Management - Derivative Assets Input Level (Details) - USD ($) $ in Millions | Sep. 30, 2023 | Dec. 31, 2022 |
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Gross amount | $ 106 | $ 299 |
Energy commodity derivative contracts | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Gross amount | 79 | 259 |
Contracts available for netting | (25) | (186) |
Cash collateral held | 0 | 0 |
Net amount | 54 | 73 |
Energy commodity derivative contracts | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Gross amount | 40 | 115 |
Energy commodity derivative contracts | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Gross amount | 39 | 144 |
Energy commodity derivative contracts | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Gross amount | 0 | 0 |
Interest rate contracts | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Gross amount | 27 | 40 |
Contracts available for netting | 0 | 0 |
Cash collateral held | 0 | 0 |
Net amount | 27 | 40 |
Interest rate contracts | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Gross amount | 0 | 0 |
Interest rate contracts | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Gross amount | 27 | 40 |
Interest rate contracts | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Gross amount | $ 0 | $ 0 |
Risk Management - Derivative Li
Risk Management - Derivative Liabilities Input Level (Details) - USD ($) $ in Millions | Sep. 30, 2023 | Dec. 31, 2022 |
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Gross amount | $ (745) | $ (868) |
Energy commodity derivative contracts | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Gross amount | (275) | (428) |
Contracts available for netting | 25 | 186 |
Cash collateral posted | (52) | (30) |
Net amount | (302) | (272) |
Energy commodity derivative contracts | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Gross amount | (3) | (23) |
Energy commodity derivative contracts | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Gross amount | (272) | (405) |
Energy commodity derivative contracts | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Gross amount | 0 | 0 |
Interest rate contracts | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Gross amount | (442) | (405) |
Contracts available for netting | 0 | 0 |
Cash collateral posted | 0 | 0 |
Net amount | (442) | (405) |
Interest rate contracts | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Gross amount | 0 | 0 |
Interest rate contracts | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Gross amount | (442) | (405) |
Interest rate contracts | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Gross amount | 0 | 0 |
Foreign currency contracts | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Gross amount | (28) | (35) |
Contracts available for netting | 0 | 0 |
Cash collateral posted | 0 | 0 |
Net amount | (28) | (35) |
Foreign currency contracts | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Gross amount | 0 | 0 |
Foreign currency contracts | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Gross amount | (28) | (35) |
Foreign currency contracts | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Gross amount | $ 0 | $ 0 |
Risk Management - Effect of Der
Risk Management - Effect of Derivative Contracts on the Income Statement (Details) - Derivatives designated as hedging instruments - Derivatives in fair value hedging relationships - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2023 | Sep. 30, 2022 | Sep. 30, 2023 | Sep. 30, 2022 | |
Interest rate contracts | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Location | Interest, net | Interest, net | Interest, net | Interest, net |
Gain/(loss) recognized in income on derivatives | $ (74) | $ (278) | $ (55) | $ (754) |
Hedged fixed rate debt | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Location | Interest, net | Interest, net | Interest, net | Interest, net |
Gain/(loss) recognized in income on derivatives | $ 77 | $ 279 | $ 59 | $ 761 |
Cumulative amount of fair value hedging adjustments to hedged fixed rate debt | $ (426) | $ (426) |
Risk Management - CF Hedging Ef
Risk Management - CF Hedging Effect on the Income Statements (Details) - Designated as Hedging Instrument - Cash flow hedge - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2023 | Sep. 30, 2022 | Sep. 30, 2023 | Sep. 30, 2022 | |
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Gain/(loss) recognized in OCI on derivative | $ (198) | $ 163 | $ 3 | $ (475) |
Gain/(Loss) reclassified from Accumulated OCI into income | (28) | (133) | 38 | (514) |
Loss to be reclassified within twelve months | (145) | |||
Energy commodity derivative contracts | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Gain/(loss) recognized in OCI on derivative | (188) | 195 | (3) | (375) |
Energy commodity derivative contracts | Revenues—Commodity sales | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Gain/(Loss) reclassified from Accumulated OCI into income | 16 | (116) | 98 | (433) |
Energy commodity derivative contracts | Costs of sales | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Gain/(Loss) reclassified from Accumulated OCI into income | (27) | 17 | (54) | 34 |
Energy commodity derivative contracts | Write-Down Of Hedged Inventory | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Gain/(Loss) reclassified from Accumulated OCI into income | 29 | 34 | ||
Interest rate contracts | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Gain/(loss) recognized in OCI on derivative | 0 | 7 | ||
Interest rate contracts | Interest, net | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Gain/(Loss) reclassified from Accumulated OCI into income | 0 | 0 | ||
Foreign currency contracts | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Gain/(loss) recognized in OCI on derivative | (10) | (32) | 6 | (107) |
Foreign currency contracts | Other, net | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Gain/(Loss) reclassified from Accumulated OCI into income | $ (17) | $ (34) | $ (6) | $ (115) |
Risk Management - Effect on Inc
Risk Management - Effect on Income Statement Not Designated (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2023 | Sep. 30, 2022 | Sep. 30, 2023 | Sep. 30, 2022 | |
Derivative [Line Items] | ||||
Gain/(loss) on settlement of derivative contracts | $ (31) | $ (13) | $ 134 | $ (94) |
Energy commodity derivative contracts | ||||
Derivative [Line Items] | ||||
Gain/(loss) on derivative Instruments | 9 | (19) | 45 | (39) |
Revenues—Commodity sales | Energy commodity derivative contracts | ||||
Derivative [Line Items] | ||||
Gain/(loss) on settlement of derivative contracts | (21) | 44 | 11 | 18 |
Costs of sales | Energy commodity derivative contracts | ||||
Derivative [Line Items] | ||||
Gain/(loss) on settlement of derivative contracts | (4) | (30) | 116 | (129) |
Earnings from equity investments | Energy commodity derivative contracts | ||||
Derivative [Line Items] | ||||
Gain/(loss) on settlement of derivative contracts | 0 | (7) | 1 | (11) |
Interest, net | Interest rate contracts | ||||
Derivative [Line Items] | ||||
Gain/(loss) on settlement of derivative contracts | $ (6) | $ (20) | $ 6 | $ 28 |
Risk Management - Credit Risks
Risk Management - Credit Risks (Details) - USD ($) $ in Millions | Sep. 30, 2023 | Dec. 31, 2022 |
Credit Derivatives [Line Items] | ||
Additional collateral, aggregate fair value if downgrade two notches | $ 187 | |
Energy commodity derivative contracts | ||
Credit Derivatives [Line Items] | ||
Letter of credits outstanding, amount | 0 | $ 0 |
Initial Margin Requirements | 24 | |
Cash collateral posted | 52 | 30 |
Other current liabilities | Cash collateral held | Energy commodity derivative contracts | ||
Credit Derivatives [Line Items] | ||
Collateral posted | $ 28 | $ 1 |
Revenue Recognition - Disaggreg
Revenue Recognition - Disaggregation of Revenue (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2023 | Sep. 30, 2022 | Sep. 30, 2023 | Sep. 30, 2022 | |
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | $ 3,537 | $ 4,890 | $ 10,082 | $ 13,971 |
Leasing services | 346 | 328 | 1,022 | 973 |
Derivatives adjustments on commodity sales | (5) | (72) | 109 | (415) |
Other | 29 | 31 | 83 | 92 |
Total other revenues | 370 | 287 | 1,214 | 650 |
Total revenues | 3,907 | 5,177 | 11,296 | 14,621 |
Natural Gas Pipelines | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues | 2,268 | 3,497 | 6,718 | 9,653 |
Products Pipelines | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues | 862 | 872 | 2,265 | 2,634 |
Terminals | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues | 483 | 457 | 1,420 | 1,335 |
CO2 | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues | 294 | 351 | 893 | 999 |
Operating Segments | Natural Gas Pipelines | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 2,087 | 3,379 | 6,127 | 9,402 |
Leasing services | 120 | 120 | 357 | 355 |
Derivatives adjustments on commodity sales | 49 | (12) | 196 | (132) |
Other | 17 | 18 | 50 | 49 |
Total other revenues | 186 | 126 | 603 | 272 |
Total revenues | 2,273 | 3,505 | 6,730 | 9,674 |
Operating Segments | Products Pipelines | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 808 | 815 | 2,099 | 2,476 |
Leasing services | 50 | 51 | 149 | 144 |
Derivatives adjustments on commodity sales | (2) | 0 | (1) | (3) |
Other | 6 | 6 | 18 | 17 |
Total other revenues | 54 | 57 | 166 | 158 |
Total revenues | 862 | 872 | 2,265 | 2,634 |
Operating Segments | Terminals | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 323 | 316 | 947 | 907 |
Leasing services | 161 | 141 | 476 | 430 |
Derivatives adjustments on commodity sales | 0 | 0 | 0 | 0 |
Other | 0 | 0 | 0 | 0 |
Total other revenues | 161 | 141 | 476 | 430 |
Total revenues | 484 | 457 | 1,423 | 1,337 |
Operating Segments | CO2 | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 328 | 388 | 927 | 1,209 |
Leasing services | 15 | 16 | 40 | 44 |
Derivatives adjustments on commodity sales | (52) | (60) | (86) | (280) |
Other | 6 | 7 | 15 | 26 |
Total other revenues | (31) | (37) | (31) | (210) |
Total revenues | 297 | 351 | 896 | 999 |
Corporate and Eliminations | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | (9) | (8) | (18) | (23) |
Leasing services | 0 | 0 | 0 | 0 |
Derivatives adjustments on commodity sales | 0 | 0 | 0 | 0 |
Other | 0 | 0 | 0 | 0 |
Total other revenues | 0 | 0 | 0 | 0 |
Total revenues | (9) | (8) | (18) | (23) |
Corporate and Eliminations | Natural Gas Pipelines | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues | (5) | (8) | (12) | (21) |
Corporate and Eliminations | Terminals | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues | (1) | 0 | (3) | (2) |
Corporate and Eliminations | CO2 | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues | (3) | 0 | (3) | 0 |
Firm services | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 1,108 | 1,101 | 3,378 | 3,393 |
Firm services | Operating Segments | Natural Gas Pipelines | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 849 | 845 | 2,615 | 2,633 |
Firm services | Operating Segments | Products Pipelines | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 49 | 57 | 138 | 176 |
Firm services | Operating Segments | Terminals | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 211 | 199 | 626 | 585 |
Firm services | Operating Segments | CO2 | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 0 | 0 | 1 | 1 |
Firm services | Corporate and Eliminations | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | (1) | 0 | (2) | (2) |
Fee-based services | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 642 | 607 | 1,828 | 1,748 |
Fee-based services | Operating Segments | Natural Gas Pipelines | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 268 | 243 | 752 | 690 |
Fee-based services | Operating Segments | Products Pipelines | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 264 | 247 | 750 | 723 |
Fee-based services | Operating Segments | Terminals | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 102 | 106 | 298 | 300 |
Fee-based services | Operating Segments | CO2 | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 9 | 11 | 29 | 35 |
Fee-based services | Corporate and Eliminations | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | (1) | 0 | (1) | 0 |
Total services | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 1,750 | 1,708 | 5,206 | 5,141 |
Total services | Operating Segments | Natural Gas Pipelines | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 1,117 | 1,088 | 3,367 | 3,323 |
Total services | Operating Segments | Products Pipelines | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 313 | 304 | 888 | 899 |
Total services | Operating Segments | Terminals | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 313 | 305 | 924 | 885 |
Total services | Operating Segments | CO2 | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 9 | 11 | 30 | 36 |
Total services | Corporate and Eliminations | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | (2) | 0 | (3) | (2) |
Natural gas sales | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 712 | 1,919 | 2,024 | 4,989 |
Natural gas sales | Operating Segments | Natural Gas Pipelines | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 689 | 1,902 | 1,972 | 4,938 |
Natural gas sales | Operating Segments | Products Pipelines | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 0 | 0 | 0 | 0 |
Natural gas sales | Operating Segments | Terminals | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 0 | 0 | 0 | 0 |
Natural gas sales | Operating Segments | CO2 | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 28 | 24 | 61 | 68 |
Natural gas sales | Corporate and Eliminations | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | (5) | (7) | (9) | (17) |
Product sales | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 1,075 | 1,263 | 2,852 | 3,841 |
Product sales | Operating Segments | Natural Gas Pipelines | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 281 | 389 | 788 | 1,141 |
Product sales | Operating Segments | Products Pipelines | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 495 | 511 | 1,211 | 1,577 |
Product sales | Operating Segments | Terminals | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 10 | 11 | 23 | 22 |
Product sales | Operating Segments | CO2 | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 291 | 353 | 836 | 1,105 |
Product sales | Corporate and Eliminations | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | (2) | (1) | (6) | (4) |
Total commodity sales | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 1,787 | 3,182 | 4,876 | 8,830 |
Total revenues | 1,785 | 3,108 | 4,991 | 8,416 |
Total commodity sales | Operating Segments | Natural Gas Pipelines | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 970 | 2,291 | 2,760 | 6,079 |
Total commodity sales | Operating Segments | Products Pipelines | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 495 | 511 | 1,211 | 1,577 |
Total commodity sales | Operating Segments | Terminals | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 10 | 11 | 23 | 22 |
Total commodity sales | Operating Segments | CO2 | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | 319 | 377 | 897 | 1,173 |
Total commodity sales | Corporate and Eliminations | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from customers | $ (7) | $ (8) | $ (15) | $ (21) |
Revenue Recognition - Contract
Revenue Recognition - Contract Balances (Details) - USD ($) $ in Millions | 9 Months Ended | ||
Sep. 30, 2023 | Oct. 20, 2023 | Dec. 31, 2022 | |
Contract Assets | |||
Contract assets balances | $ 43 | $ 33 | |
Transfer to Accounts receivable | 21 | ||
Contract Liabilities | |||
Contract liabilities balances | 221 | $ 204 | |
Transfer to Revenues | $ 61 | ||
Pro Forma | Subsequent Event | |||
Contract Liabilities | |||
Contract liabilities balances | $ 843 |
Revenue Recognition - Revenue A
Revenue Recognition - Revenue Allocated to Remaining Performance Obligations (Details) $ in Millions | Sep. 30, 2023 USD ($) |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue allocated to remaining performance obligations for contracted revenue | $ 28,195 |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Year [Axis]: 2023-10-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue allocated to remaining performance obligations for contracted revenue | $ 1,167 |
Performance obligation, period of recognition | 3 months |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Year [Axis]: 2024-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue allocated to remaining performance obligations for contracted revenue | $ 4,153 |
Performance obligation, period of recognition | 1 year |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Year [Axis]: 2025-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue allocated to remaining performance obligations for contracted revenue | $ 3,423 |
Performance obligation, period of recognition | 1 year |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Year [Axis]: 2026-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue allocated to remaining performance obligations for contracted revenue | $ 2,933 |
Performance obligation, period of recognition | 1 year |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Year [Axis]: 2027-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue allocated to remaining performance obligations for contracted revenue | $ 2,462 |
Performance obligation, period of recognition | 1 year |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Year [Axis]: 2028-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue allocated to remaining performance obligations for contracted revenue | $ 14,057 |
Performance obligation, period of recognition |
Reportable Segments - Revenues
Reportable Segments - Revenues (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2023 | Sep. 30, 2022 | Sep. 30, 2023 | Sep. 30, 2022 | |
Segment Reporting Information [Line Items] | ||||
Revenues | $ 3,907 | $ 5,177 | $ 11,296 | $ 14,621 |
Intersegment Eliminations | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | (9) | (8) | (18) | (23) |
Natural Gas Pipelines | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 2,268 | 3,497 | 6,718 | 9,653 |
Natural Gas Pipelines | Intersegment Eliminations | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | (5) | (8) | (12) | (21) |
Natural Gas Pipelines | Operating Segments | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 2,273 | 3,505 | 6,730 | 9,674 |
Products Pipelines | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 862 | 872 | 2,265 | 2,634 |
Products Pipelines | Operating Segments | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 862 | 872 | 2,265 | 2,634 |
Terminals | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 483 | 457 | 1,420 | 1,335 |
Terminals | Intersegment Eliminations | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | (1) | 0 | (3) | (2) |
Terminals | Operating Segments | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 484 | 457 | 1,423 | 1,337 |
CO2 | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 294 | 351 | 893 | 999 |
CO2 | Intersegment Eliminations | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | (3) | 0 | (3) | 0 |
CO2 | Operating Segments | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | $ 297 | $ 351 | $ 896 | $ 999 |
Reportable Segments - EBDA (Det
Reportable Segments - EBDA (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2023 | Sep. 30, 2022 | Sep. 30, 2023 | Sep. 30, 2022 | |
Segment Reporting Information [Line Items] | ||||
DD&A | $ (561) | $ (551) | $ (1,683) | $ (1,632) |
Amortization of excess cost of equity investments | (18) | (19) | (54) | (57) |
Income Tax Expense | (145) | (134) | (509) | (512) |
Net income | 555 | 595 | 1,868 | 1,932 |
Operating Segments | ||||
Segment Reporting Information [Line Items] | ||||
Net income | 1,912 | 1,847 | 5,993 | 5,658 |
Operating Segments | Natural Gas Pipelines | ||||
Segment Reporting Information [Line Items] | ||||
Net income | 1,179 | 1,135 | 3,929 | 3,453 |
Operating Segments | Products Pipelines | ||||
Segment Reporting Information [Line Items] | ||||
Net income | 311 | 257 | 780 | 855 |
Operating Segments | Terminals | ||||
Segment Reporting Information [Line Items] | ||||
Net income | 259 | 240 | 774 | 731 |
Operating Segments | CO2 | ||||
Segment Reporting Information [Line Items] | ||||
Net income | 163 | 215 | 510 | 619 |
Segment Reconciling Items | ||||
Segment Reporting Information [Line Items] | ||||
DD&A | (561) | (551) | (1,683) | (1,632) |
Amortization of excess cost of equity investments | (18) | (19) | (54) | (57) |
General and administrative and corporate charges | (176) | (149) | (534) | (438) |
Interest, net | (457) | (399) | (1,345) | (1,087) |
Income Tax Expense | $ (145) | $ (134) | $ (509) | $ (512) |
Reportable Segments - Assets (D
Reportable Segments - Assets (Details) - USD ($) $ in Millions | Sep. 30, 2023 | Dec. 31, 2022 |
Segment Reporting Information [Line Items] | ||
Assets | $ 68,862 | $ 70,078 |
Corporate, Non-segment | ||
Segment Reporting Information [Line Items] | ||
Assets | 588 | 1,309 |
Natural Gas Pipelines | Operating Segments | ||
Segment Reporting Information [Line Items] | ||
Assets | 47,642 | 47,978 |
Products Pipelines | Operating Segments | ||
Segment Reporting Information [Line Items] | ||
Assets | 8,923 | 8,985 |
Terminals | Operating Segments | ||
Segment Reporting Information [Line Items] | ||
Assets | 8,250 | 8,357 |
CO2 | Operating Segments | ||
Segment Reporting Information [Line Items] | ||
Assets | $ 3,459 | $ 3,449 |
Income Taxes (Details)
Income Taxes (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2023 | Sep. 30, 2022 | Sep. 30, 2023 | Sep. 30, 2022 | |
Income Tax Disclosure [Abstract] | ||||
Income tax expense | $ 145 | $ 134 | $ 509 | $ 512 |
Effective tax rate | 20.70% | 18.40% | 21.40% | 20.90% |
Statutory federal rate | 21% | 21% | 21% | 21% |
Litigation and Environmental -
Litigation and Environmental - Other Commercial Matters (Details) - Pending Litigation $ in Millions | 9 Months Ended |
Sep. 30, 2023 USD ($) Claims individual | |
Freeport LNG Marketing, LLC Case | |
Loss Contingencies [Line Items] | |
Loss Contingency, Damages Sought, Value | $ | $ 104 |
Pension Plan Litigation | |
Loss Contingencies [Line Items] | |
Loss Contingency, Pending Claims, Number | Claims | 6 |
Purported Class | individual | 10,000 |
Litigation and Environmental _2
Litigation and Environmental - General (Details) - USD ($) $ in Millions | Sep. 30, 2023 | Dec. 31, 2022 |
Commitments and Contingencies Disclosure [Abstract] | ||
Estimated Litigation Liability | $ 21 | $ 70 |
Litigation and Environmental _3
Litigation and Environmental - Portland Harbor (Details) - Portland Harbor Superfund Site, Willamette River, Portland, Oregon $ in Millions | 9 Months Ended |
Sep. 30, 2023 USD ($) Terminals Parties | |
Environmental Protection Agency | KMLT | |
Site Contingency [Line Items] | |
Number of Parties Involved In Site Cleanup Allocation Negotiations | Parties | 90 |
Number of Liquid Terminals | Terminals | 2 |
Environmental Protection Agency | KMLT | Pro Forma | |
Site Contingency [Line Items] | |
Estimated Remedy Implementation Period | 10 years |
Environmental Remediation Expense | $ | $ 2,800 |
Environmental Protection Agency | KMBT | |
Site Contingency [Line Items] | |
Number of Liquid Terminals | Terminals | 2 |
State and Federal Trustees | KMLT | |
Site Contingency [Line Items] | |
Loss Contingency, Damages Sought, Value | $ | $ 5 |
Litigation and Environmental _4
Litigation and Environmental - Lower Passaic River (Details) - Environmental Protection Agency $ in Millions | 9 Months Ended | |||
Dec. 16, 2022 USD ($) Parties | Oct. 04, 2021 USD ($) | Mar. 04, 2016 USD ($) | Sep. 30, 2023 | |
Lower Passaic River Study Area | EPA Proposed Consent Decree | ||||
Site Contingency [Line Items] | ||||
Loss Contingency, Number of Defendants | Parties | 85 | |||
Proposed Environmental Remediation Settlement | $ 150 | |||
Lower Passaic River Study Area | Pending Litigation | EPA preferred alternative estimate | ||||
Site Contingency [Line Items] | ||||
Environmental Remediation Expense | $ 1,700 | |||
Lower Passaic River Study Area | Pending Litigation | Clean Up Implementation | ||||
Site Contingency [Line Items] | ||||
Estimated Remedy Implementation Period | 6 years | |||
Upper Passaic River Study Area, Upper Portion | Pending Litigation | Pro Forma | ||||
Site Contingency [Line Items] | ||||
Environmental Remediation Expense | $ 440 |
Litigation and Environmental _5
Litigation and Environmental - Louisiana Governmental Coastal Zone Erosion Litigation (Details) - Coastal Zone | Mar. 29, 2019 Parties | Nov. 08, 2013 Parties | Sep. 30, 2023 cases |
Judicial District of Louisiana | |||
Loss Contingencies [Line Items] | |||
Loss Contingency, Pending Claims, Number | 40 | ||
Judicial District of Louisiana | TGP | |||
Loss Contingencies [Line Items] | |||
Loss Contingency, Pending Claims, Number | 1 | ||
Judicial District of Louisiana | SNG | |||
Loss Contingencies [Line Items] | |||
Loss Contingency, Pending Claims, Number | 1 | ||
Parish of Plaquemines, Louisiana | TGP | |||
Loss Contingencies [Line Items] | |||
Loss Contingency, Number of Defendants | Parties | 17 | ||
Parish Orleans, Louisiana | SNG | |||
Loss Contingencies [Line Items] | |||
Loss Contingency, Number of Defendants | Parties | 10 |
Litigation and Environmental _6
Litigation and Environmental - Walnut Creek (Details) - State of California - SFPP $ in Millions | Dec. 16, 2021 USD ($) misdemeanors | Dec. 08, 2020 bbl | Nov. 20, 2020 bbl |
Environmental Remediation Estimated Spill Volume | bbl | 1,000 | 8.1 | |
Environmental Remediation Expense | $ | $ 2.5 | ||
Unsupervised Probation Period | 18 months | ||
Number Of Misdemeanors, Plead No Contest | misdemeanors | 2 |
Litigation and Environmental _7
Litigation and Environmental - Environmental Matters General (Details) - USD ($) $ in Millions | Sep. 30, 2023 | Dec. 31, 2022 |
Commitments and Contingencies Disclosure [Abstract] | ||
Accrual for Environmental Loss Contingencies | $ 208 | $ 221 |
Recorded Third-Party Environmental Recoveries Receivable | $ 11 | $ 12 |
Recent Accounting Pronounceme_2
Recent Accounting Pronouncements (Details) - Fixed-to-Variable Interest Rate Contracts - Derivatives in fair value hedging relationships - Designated as Hedging Instrument $ in Millions | Sep. 30, 2023 USD ($) |
New Accounting Pronouncements or Change in Accounting Principle [Line Items] | |
Notional amount | $ 6,800 |
SOFR | |
New Accounting Pronouncements or Change in Accounting Principle [Line Items] | |
Notional amount | $ 1,225 |
Uncategorized Items - kmi-20230
Label | Element | Value |
Accounting Standards Update [Extensible Enumeration] | us-gaap_AccountingStandardsUpdateExtensibleList | Accounting Standards Update 2020-06 [Member] |