The Williams Companies, Inc. (WMB) 10-Q 5 Aug 24 2024 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2024	Aug. 01, 2024
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2024
Document Transition Report	false
Entity File Number	1-4174
Entity Registrant Name	WILLIAMS COMPANIES, INC.
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	73-0569878
Entity Address, Address Line One	One Williams Center
Entity Address, City or Town	Tulsa
Entity Address, State or Province	OK
Entity Address, Postal Zip Code	74172-0172
City Area Code	800
Local Phone Number	945-5426
Title of 12(b) Security	Common Stock, $1.00 par value
Trading Symbol	WMB
Security Exchange Name	NYSE
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		1,218,931,191
Entity Central Index Key	0000107263
Amendment Flag	false
Document Fiscal Year Focus	2024
Document Fiscal Period Focus	Q2
Current Fiscal Year End Date	--12-31

Consolidated Statement of Incom

Consolidated Statement of Income - USD ($) shares in Thousands, $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Revenues:
Revenues		$ 2,336	$ 2,483	$ 5,107	$ 5,564
Costs and expenses:
Operating and maintenance expenses		522	481	1,033	944
Depreciation and amortization expenses		540	515	1,088	1,021
Selling, general, and administrative expenses		164	161	350	337
Other (income) expense – net		(27)	(9)	(44)	(40)
Total costs and expenses		1,640	1,613	3,399	3,334
Operating income (loss)		696	870	1,708	2,230
Equity earnings (losses)		147	160	284	307
Other investing income (loss) – net		18	13	42	21
Interest expense		(339)	(306)	(688)	(600)
Other income (expense) – net		33	19	64	39
Income (loss) before income taxes		555	756	1,410	1,997
Less: Provision (benefit) for income taxes		129	175	322	459
Income (Loss) from Continuing Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest		426	581	1,088	1,538
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest		0	(87)	0	(87)
Net income (loss)		426	494	1,088	1,451
Less: Net income (loss) attributable to noncontrolling interests		25	34	55	64
Net income (loss) attributable to The Williams Companies, Inc.		401	460	1,033	1,387
Less: Preferred stock dividends		0	0	1	1
Net income (loss) available to common stockholders		401	460	1,032	1,386
Amounts attributable to The Williams Companies, Inc. available to common stockholders:
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent		$ 401	$ 547	$ 1,032	$ 1,473
Basic earnings (loss) per common share:
Income (Loss) from Continuing Operations, Per Basic Share		$ 0.33	$ 0.45	$ 0.85	$ 1.21
Income (Loss) from Discontinued Operations and Disposal of Discontinued Operations, Net of Tax, Per Basic Share		0	(0.07)	0	(0.07)
Net income (loss)		$ 0.33	$ 0.38	$ 0.85	$ 1.14
Weighted-average shares (thousands)		1,219,367	1,217,673	1,218,761	1,218,564
Diluted earnings (loss) per common share:
Income (Loss) from Continuing Operations, Per Diluted Share		$ 0.33	$ 0.45	$ 0.84	$ 1.20
Income (Loss) from Discontinued Operations and Disposal of Discontinued Operations, Net of Tax, Per Diluted Share		0	(0.07)	0	(0.07)
Net income (loss)		$ 0.33	$ 0.38	$ 0.84	$ 1.13
Weighted-average shares (thousands)		1,222,236	1,219,915	1,222,229	1,223,429
Service [Member]
Revenues:
Revenues		$ 1,837	$ 1,748	$ 3,742	$ 3,442
NonRegulated Service Commodity Consideration [Member]
Revenues:
Revenues		18	27	48	63
Product [Member]
Revenues:
Revenues		610	593	1,455	1,438
Energy Commodities and Service
Revenues:
Revenues	[1]	(129)	115	(138)	621
Oil and Gas, Purchased [Member]
Costs and expenses:
Cost of Goods and Service, Excluding Depreciation, Depletion, and Amortization		424	421	950	974
Natural Gas Purchased For Shrink [Member]
Costs and expenses:
Cost of Goods and Service, Excluding Depreciation, Depletion, and Amortization		$ 17	$ 44	$ 22	$ 98
[1]We record transactions that qualify as commodity derivatives at fair value with changes in fair value recognized in earnings in the period of change and characterized as unrealized gains or losses. Gains and losses from commodity derivatives held for energy trading purposes are presented on a net basis in revenue.

Consolidated Statement of Compr

Consolidated Statement of Comprehensive Income (Loss) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Comprehensive income (loss):
Net income (loss)	$ 426	$ 494	$ 1,088	$ 1,451
Designated interest rate cash flow hedging activities:
Net unrealized gain (loss) from derivative instruments, net of taxes of $(2) and ($5) in 2024 and $(4) and $(11) in 2023	4	16	15	36
Reclassifications into earnings of net derivative instruments (gain) loss, net of taxes of $— and $— in 2024 and $— and $— in 2023	0	(1)	(1)	(1)
Pension and other postretirement benefits:
Amortization of actuarial (gain) loss and net actuarial loss from settlements included in net periodic benefit cost (credit), net of taxes of $— and $— in 2024 and $(1) and ($1) in 2023	(1)	0	(1)	1
Other comprehensive income (loss)	3	15	13	36
Comprehensive income (loss)	429	509	1,101	1,487
Less: Comprehensive income (loss) attributable to noncontrolling interests	25	34	55	64
Comprehensive income (loss) attributable to The Williams Companies, Inc.	$ 404	$ 475	$ 1,046	$ 1,423

Consolidated Statement of Com_2

Consolidated Statement of Comprehensive Income (Loss) (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Cash flow hedging activities:
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), before Reclassification, Tax	$ (2)	$ (4)	$ (5)	$ (11)
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, Tax	0	0	0	0
Pension and other postretirement benefits:
Other Comprehensive Income Loss, Reclassification Pension And Other Postretirement Benefit Plans Net Gain Loss Included In Net Periodic Benefit Cost (Credit), Tax	$ 0	$ (1)	$ 0	$ (1)

Consolidated Balance Sheet

Consolidated Balance Sheet - USD ($) $ in Millions	Jun. 30, 2024	Dec. 31, 2023
Current assets:
Cash and cash equivalents	$ 55	$ 2,150
Receivables, Net, Current	1,398	1,655
Inventories	274	274
Derivative assets	218	239
Other current assets and deferred charges	170	195
Total current assets	2,115	4,513
Investments	4,612	4,637
Property, Plant and Equipment, Gross	54,930	51,842
Accumulated depreciation and amortization	(18,228)	(17,531)
Property, plant, and equipment - net	36,702	34,311
Intangible assets – net of accumulated amortization	7,402	7,593
Regulatory assets, deferred charges, and other	1,578	1,573
Total assets	52,409	52,627
Current liabilities:
Accounts payable	1,192	1,379
Derivative Liability, Current	109	105
Accrued and other current liabilities	1,229	1,284
Commercial Paper	630	725
Long-term debt due within one year	1,536	2,337
Total current liabilities	4,696	5,830
Long-term debt	24,096	23,376
Deferred income tax liabilities	4,107	3,846
Regulatory liabilities, deferred income, and other	4,764	4,684
Contingent liabilities and commitments (Note 9)
Stockholders’ equity:
Preferred stock ($1 par value; 30 million shares authorized at June 30, 2024 and December 31, 2023; 35 thousand shares issued at June 30, 2024 and December 31, 2023)	35	35
Common stock ($1 par value; 1,470 million shares authorized at June 30, 2024 and December 31, 2023; 1,258 million shares issued at June 30, 2024 and 1,256 million shares issued at December 31, 2023)	1,258	1,256
Capital in excess of par value	24,589	24,578
Retained deficit	(12,419)	(12,287)
Accumulated other comprehensive income (loss)	13	0
Treasury stock, at cost (39 million shares at June 30, 2024 and December 31, 2023 of common stock)	(1,180)	(1,180)
Total stockholders’ equity	12,296	12,402
Noncontrolling interests in consolidated subsidiaries	2,450	2,489
Total equity	14,746	14,891
Total liabilities and equity	$ 52,409	$ 52,627

Consolidated Balance Sheet (Par

Consolidated Balance Sheet (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2024	Dec. 31, 2023
Accounts Receivable, Allowance for Credit Loss, Current	$ 4	$ 3
Common Stock, Par or Stated Value Per Share	$ 1	$ 1
Common Stock, Shares Authorized	1,470,000,000	1,470,000,000
Common Stock, Shares, Issued	1,258,000,000	1,256,000,000
Treasury Stock, Common, Shares	39,000,000	39,000,000
Series B Preferred Stock [Member]
Preferred Stock, Par or Stated Value Per Share	$ 1	$ 1
Preferred Stock, Shares Authorized	30,000,000	30,000,000
Preferred Stock, Shares Issued	35,000	35,000

Consolidated Statement of Chang

Consolidated Statement of Changes in Equity - USD ($) $ in Millions	Total	Preferred Stock	Common Stock	Capital in Excess of Par Value	Retained Deficit	Accumulated Other Comprehensive Income (Loss)	Treasury Stock	Total Stockholders' Equity	Noncontrolling Interests
Beginning balance at Dec. 31, 2022	$ 14,045	$ 35	$ 1,253	$ 24,542	$ (13,271)	$ (24)	$ (1,050)	$ 11,485	$ 2,560
Net income (loss)	1,451	0	0	0	1,387	0	0	1,387	64
Other Comprehensive Income (Loss), Net of Tax	36	0	0	0	0	36	0	36	0
Dividends, Common Stock, Cash	(1,091)	0	0	0	(1,091)	0	0	(1,091)	0
Dividends and distributions to noncontrolling interests	(112)	0	0	0	0	0	0	0	(112)
Stock-based compensation and related common stock issuances, net of tax	(1)	0	3	(4)	0	0	0	(1)	0
Contributions from noncontrolling interests	18	0	0	0	0	0	0	0	18
Purchases of treasury stock	(130)	0	0	0	0	0	(130)	(130)	0
Other	(7)	0	0	0	(7)	0	0	(7)	0
Net increase (decrease) in equity	164	0	3	(4)	289	36	(130)	194	(30)
Ending balance at Jun. 30, 2023	14,209	35	1,256	24,538	(12,982)	12	(1,180)	11,679	2,530
Beginning balance at Mar. 31, 2023	14,323	35	1,256	24,516	(12,895)	(3)	(1,124)	11,785	2,538
Net income (loss)	494	0	0	0	460	0	0	460	34
Other Comprehensive Income (Loss), Net of Tax	15	0	0	0	0	15	0	15	0
Dividends, Common Stock, Cash	(545)	0	0	0	(545)	0	0	(545)	0
Dividends and distributions to noncontrolling interests	(58)	0	0	0	0	0	0	0	(58)
Stock-based compensation and related common stock issuances, net of tax	22	0	0	22	0	0	0	22	0
Contributions from noncontrolling interests	15	0	0	0	0	0	0	0	15
Purchases of treasury stock	(56)	0	0	0	0	0	(56)	(56)	0
Other	(1)	0	0	0	(2)	0	0	(2)	1
Net increase (decrease) in equity	(114)	0	0	22	(87)	15	(56)	(106)	(8)
Ending balance at Jun. 30, 2023	14,209	35	1,256	24,538	(12,982)	12	(1,180)	11,679	2,530
Beginning balance at Dec. 31, 2023	14,891	35	1,256	24,578	(12,287)	0	(1,180)	12,402	2,489
Net income (loss)	1,088	0	0	0	1,033	0	0	1,033	55
Other Comprehensive Income (Loss), Net of Tax	13	0	0	0	0	13	0	13	0
Dividends, Common Stock, Cash	(1,158)	0	0	0	(1,158)	0	0	(1,158)	0
Dividends and distributions to noncontrolling interests	(130)	0	0	0	0	0	0	0	(130)
Stock-based compensation and related common stock issuances, net of tax	13	0	2	11	0	0	0	13	0
Contributions from noncontrolling interests	36	0	0	0	0	0	0	0	36
Purchases of treasury stock	0
Other	(7)	0	0	0	(7)	0	0	(7)	0
Net increase (decrease) in equity	(145)	0	2	11	(132)	13	0	(106)	(39)
Ending balance at Jun. 30, 2024	14,746	35	1,258	24,589	(12,419)	13	(1,180)	12,296	2,450
Beginning balance at Mar. 31, 2024	14,930	35	1,258	24,564	(12,238)	10	(1,180)	12,449	2,481
Net income (loss)	426	0	0	0	401	0	0	401	25
Other Comprehensive Income (Loss), Net of Tax	3	0	0	0	0	3	0	3	0
Dividends, Common Stock, Cash	(579)	0	0	0	(579)	0	0	(579)	0
Dividends and distributions to noncontrolling interests	(66)	0	0	0	0	0	0	0	(66)
Stock-based compensation and related common stock issuances, net of tax	25	0	0	25	0	0	0	25	0
Contributions from noncontrolling interests	10	0	0	0	0	0	0	0	10
Other	(3)	0	0	0	(3)	0	0	(3)	0
Net increase (decrease) in equity	(184)	0	0	25	(181)	3	0	(153)	(31)
Ending balance at Jun. 30, 2024	$ 14,746	$ 35	$ 1,258	$ 24,589	$ (12,419)	$ 13	$ (1,180)	$ 12,296	$ 2,450

Consolidated Statement of Cha_2

Consolidated Statement of Changes in Equity (Parenthetical) - $ / shares	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Statement of Stockholders' Equity [Abstract]
Common Stock, Dividends, Per Share, Declared	$ 0.4750	$ 0.4475	$ 0.9500	$ 0.8950

Consolidated Statement of Cash

Consolidated Statement of Cash Flows - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023
OPERATING ACTIVITIES:
Net income (loss)	$ 1,088	$ 1,451
Adjustments to reconcile to net cash provided (used) by operating activities:
Depreciation and amortization	1,088	1,021
Provision (benefit) for deferred income taxes	258	427
Equity (earnings) losses	(284)	(307)
Distributions from equity-method investees	394	418
Net unrealized (gain) loss from commodity derivative instruments	223	(410)
Inventory write-downs	6	23
Amortization of stock-based awards	48	40
Cash provided (used) by changes in current assets and liabilities:
Accounts receivable	270	1,423
Inventories	(3)	41
Other current assets and deferred charges	12	24
Accounts payable	(219)	(1,220)
Accrued and other current liabilities	(76)	(72)
Changes in current and noncurrent commodity derivative assets and liabilities	(141)	119
Other, including changes in noncurrent assets and liabilities	(151)	(87)
Net cash provided (used) by operating activities	2,513	2,891
FINANCING ACTIVITIES:
Proceeds from (payments of) commercial paper – net	(95)	(352)
Proceeds from long-term debt	2,100	1,503
Payments of long-term debt	(2,274)	(14)
Payments for debt issuance costs	(18)	(13)
Proceeds from issuance of common stock	5	4
Purchases of treasury stock	0	(130)
Common dividends paid	(1,158)	(1,091)
Dividends and distributions paid to noncontrolling interests	(130)	(112)
Contributions from noncontrolling interests	36	18
Other – net	(18)	(17)
Net cash provided (used) by financing activities	(1,552)	(204)
INVESTING ACTIVITIES:
Capital expenditures (1)	(1,123)	(1,155)
Dispositions - net	(27)	(21)
Purchases of businesses, net of cash acquired (Note 3)	(1,844)	(1,053)
Purchases of and contributions to equity-method investments	(82)	(69)
Other – net	20	10
Net cash provided (used) by investing activities	(3,056)	(2,288)
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total	(2,095)	399
Cash and cash equivalents at beginning of year	2,150	152
Cash and cash equivalents at end of period	55	551
Additional Cash Flow Elements and Supplemental Cash Flow Information [Abstract]
(1)  Increases to property, plant, and equipment	(1,141)	(1,168)
Changes in related accounts payable and accrued liabilities	18	13
Capital expenditures	$ (1,123)	$ (1,155)

General, Description of Busines

General, Description of Business, and Basis of Presentation	6 Months Ended
	Jun. 30, 2024
Organization, Consolidation and Presentation of Financial Statements [Abstract]
General, Description of Business, and Basis of Presentation [Text Block]	Note 1 – General, Description of Business, and Basis of Presentation General Our accompanying interim consolidated financial statements do not include all the notes in our annual financial statements and, therefore, should be read in conjunction with our consolidated financial statements and notes thereto for the year ended December 31, 2023, in our Annual Report on Form 10-K. The accompanying unaudited financial statements include all normal recurring adjustments and others that, in the opinion of management, are necessary to present fairly our interim financial statements. The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the amounts reported in our consolidated financial statements and accompanying notes. Actual results could differ from those estimates. Unless the context clearly indicates otherwise, references in this report to “Williams,” “we,” “our,” “us,” or like terms refer to The Williams Companies, Inc. and its subsidiaries. Unless the context clearly indicates otherwise, references to “Williams,” “we,” “our,” and “us” include the operations in which we own interests accounted for as equity-method investments that are not consolidated in our financial statements. When we refer to our equity investees by name, we are referring exclusively to their businesses and operations. Share Repurchase Program In September 2021, our Board of Directors authorized a share repurchase program with a maximum dollar limit of $1.5 billion. Repurchases may be made from time to time in the open market, by block purchases, in privately negotiated transactions, or in such other manner as determined by our management. Our management will also determine the timing and amount of any repurchases based on market conditions and other factors. The share repurchase program does not obligate us to acquire any particular amount of common stock, and it may be suspended or discontinued at any time. This share repurchase program does not have an expiration date. During the six months ended June 30, 2024 and 2023, there have been $0 and $130 million in repurchases under the program which are included in our Consolidated Statement of Changes in Equity. Cumulative repurchases to date under the program total $139 million. Description of Business We are a Delaware corporation whose common stock is listed and traded on the New York Stock Exchange. Our operations are located in the United States and are presented within the following reportable segments: Transmission & Gulf of Mexico, Northeast G&P, West, and Gas & NGL Marketing Services, consistent with the manner in which our chief operating decision maker evaluates performance and allocates resources. All remaining business activities, including our upstream operations and corporate activities, are included in Other. Transmission & Gulf of Mexico is comprised of our interstate natural gas pipelines, Transcontinental Gas Pipe Line Company, LLC (Transco), Northwest Pipeline LLC (Northwest Pipeline), and MountainWest Pipelines Holding Company (MountainWest), and their related natural gas storage facilities, as well as natural gas gathering and processing and crude oil production handling and transportation assets in the Gulf Coast region, including a 51 percent interest in Gulfstar One LLC (Gulfstar One) (a consolidated variable interest entity, or VIE), a 50 percent equity-method investment in Gulfstream Natural Gas System, L.L.C. (Gulfstream), and a 60 percent equity-method investment in Discovery Producer Services LLC (Discovery) (see Note 11 - Subsequent Events). Transmission & Gulf of Mexico also includes natural gas storage facilities and pipelines providing services in north Texas, and also in Louisiana and Mississippi related to the January 2024 Gulf Coast Storage Acquisition (see Note 3 – Acquisitions and Divestitures). Northeast G&P is comprised of our midstream gathering, processing, and fractionation businesses in the Marcellus Shale region primarily in Pennsylvania and New York, and the Utica Shale region of eastern Ohio, as well as a 65 percent interest in Ohio Valley Midstream LLC (Northeast JV) (a consolidated VIE) which operates in West Virginia, Ohio, and Pennsylvania, a 66 percent interest in Cardinal Gas Services, L.L.C. (Cardinal) (a consolidated VIE) which operates in Ohio, a 69 percent equity-method investment in Laurel Mountain Midstream, LLC (Laurel Mountain), a 50 percent equity-method investment in Blue Racer Midstream LLC (Blue Racer), and Appalachia Midstream Services, LLC, a wholly owned subsidiary that owns equity-method investments with an approximate average 66 percent interest in multiple gas gathering systems in the Marcellus Shale region (Appalachia Midstream Investments). West is comprised of our gas gathering, processing, and treating operations in the Rocky Mountain region of Colorado and Wyoming, the Barnett Shale region of north-central Texas, the Eagle Ford Shale region of south Texas, the Haynesville Shale region of east Texas and northwest Louisiana, the Mid-Continent region which includes the Anadarko and Permian basins, and the Denver-Julesberg Basin (DJ Basin) of Colorado which includes Rocky Mountain Midstream Holdings LLC (RMM), a former 50 percent equity-method investment in which we acquired the remaining ownership interest in November 2023 (see Note 3 – Acquisitions and Divestitures ) . This segment also includes our NGL storage facilities, an undivided 50 percent interest in an NGL fractionator near Conway, Kansas, and a 50 percent equity-method investment in Overland Pass Pipeline Company LLC (OPPL). Gas & NGL Marketing Services is comprised of our natural gas liquid (NGL) and natural gas marketing and trading operations, which includes risk management and transactions related to the storage and transportation of natural gas and NGLs on strategically positioned assets. Basis of Presentation Significant risks and uncertainties We believe that the carrying value of certain of our property, plant, and equipment and intangible assets, notably certain acquired assets accounted for as business combinations between 2012 and 2014, may be in excess of current fair value. However, the carrying value of these assets, in our judgment, continues to be recoverable. It is reasonably possible that future strategic decisions, including transactions such as monetizing assets or contributing assets to new ventures with third parties, as well as unfavorable changes in expected producer activities, could impact our assumptions and ultimately result in impairments of these assets. Such transactions or developments may also indicate that certain of our equity-method investments have experienced other-than-temporary declines in value, which could result in impairment. Discontinued operations During the second quarter of 2023, we recorded pre-tax charges of $115 million to Income (loss) from discontinued operations in our Consolidated Statement of Income related to litigation associated with our former Alaska refinery, which was settled in January 2024. Except for this item and unless indicated otherwise, the information in the Notes to Consolidated Financial Statements relates to our continuing operations. Accounting Standards Issued But Not Yet Adopted In November 2023, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2023-07, Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures , which requires disclosure of significant segment expenses and expanded interim disclosures. This ASU is effective for fiscal years beginning after December 15, 2023, and interim periods within fiscal years beginning after December 15, 2024, and early adoption is permitted. We do not expect adoption of ASU 2023-07 will have a material impact on our financial statements. In December 2023, the FASB issued ASU 2023-09, Income Taxes: Improvements to Income Tax Disclosures , which requires disclosure of specific categories in the rate reconciliation and additional information for reconciling items that meet a quantitative threshold. This ASU is effective for fiscal years beginning after December 15, 2024, and early adoption is permitted. We do not expect adoption of ASU 2023-09 will have a material impact on our financial statements.

Variable Interest Entities

Variable Interest Entities	6 Months Ended
	Jun. 30, 2024
Variable Interest Entity Disclosures [Abstract]
Variable Interest Entities [Text Block]	Note 2 – Variable Interest Entities Consolidated VIEs As of June 30, 2024, we consolidate the following VIEs: Northeast JV We own a 65 percent interest in the Northeast JV, a subsidiary that is a VIE due to certain of our voting rights being disproportionate to our obligation to absorb losses and substantially all of the Northeast JV’s activities being performed on our behalf. We are the primary beneficiary because we have the power to direct the activities that most significantly impact the Northeast JV’s economic performance. The Northeast JV provides midstream services for producers in the Marcellus Shale and Utica Shale regions. Future expansion activity is expected to be funded with capital contributions from us and the other equity partner on a proportional basis. Gulfstar One We own a 51 percent interest in Gulfstar One, a subsidiary that, due to certain risk-sharing provisions in its customer contracts, is a VIE. Gulfstar One includes a proprietary floating-production system, Gulfstar FPS, and associated pipelines that provide production handling and gathering services in the eastern deepwater Gulf of Mexico. We are the primary beneficiary because we have the power to direct the activities that most significantly impact Gulfstar One’s economic performance. Cardinal We own a 66 percent interest in Cardinal, a subsidiary that provides gathering services for the Utica Shale region and is a VIE due to certain risks shared with customers. We are the primary beneficiary because we have the power to direct the activities that most significantly impact Cardinal’s economic performance. In order to meet contractual gas gathering commitments, we may fund more than our proportional share of future expansion activity, which could ultimately impact relative ownership. The following table presents amounts included in our Consolidated Balance Sheet that are only for the use or obligation of our consolidated VIEs: June 30, December 31, 2024 2023 (Millions) Assets (liabilities): Cash and cash equivalents $ 39 $ 33 Trade accounts and other receivables – net 170 215 Inventories 5 5 Other current assets and deferred charges 2 4 Property, plant, and equipment – net 4,980 5,046 Intangible assets – net of accumulated amortization 1,995 2,049 Regulatory assets, deferred charges, and other 28 31 Accounts payable (64) (109) Accrued and other current liabilities (30) (28) Regulatory liabilities, deferred income, and other (269) (268) Nonconsolidated VIEs We own certain equity-method investments that are VIEs due primarily to our limited participating rights as a minority equity holder. Our maximum exposure to loss is limited to the carrying value of these investments, which totaled $73 million at June 30, 2024.

Acquisitions and Divestitures

Acquisitions and Divestitures	6 Months Ended
	Jun. 30, 2024
Business Combinations [Abstract]
Acquisitions and Divestitures [Text Block]	Note 3 – Acquisitions and Divestitures Gulf Coast Storage Acquisition On January 3, 2024, we closed on the acquisition of 100 percent of a strategic portfolio of natural gas storage facilities and pipelines, located in Louisiana and Mississippi, from Hartree Partners LP (Gulf Coast Storage Acquisition) for $1.95 billion. The purpose of this acquisition was to expand our natural gas storage footprint in the Gulf Coast region. Assets acquired, acquisition-related costs incurred, and results of operations realized are included within our Transmission & Gulf of Mexico segment. The Gulf Coast Storage Acquisition was funded with cash on hand and $100 million of deferred consideration that does not accrue interest and is payable one year from the acquisition date. The obligation is presented within Long-term debt due within one year in our Consolidated Balance Sheet owed by our wholly owned subsidiary Williams Field Services Group, LLC. During the period from the acquisition date of January 3, 2024 to June 30, 2024, the operations acquired in the Gulf Coast Storage Acquisition contributed Revenues of $112 million and Modified EBITDA (as defined in Note 10 – Segment Disclosures) of $81 million, which is impacted by acquisition-related costs. Acquisition-related costs for the Gulf Coast Storage Acquisition total $14 million, including $13 million incurred in the six months ended June 30, 2024 included in Selling, general, and administrative expenses in our Consolidated Statement of Income. We accounted for the Gulf Coast Storage Acquisition as a business combination, which requires, among other things, that identifiable assets acquired and liabilities assumed be recognized at their acquisition date fair values. The valuation technique used consisted of the cost approach for property, plant, and equipment. The following table presents the preliminary allocation of the acquisition date fair value of the major classes of the assets acquired and liabilities assumed at January 3, 2024. The allocation is considered preliminary because the valuation work has not been completed due to the ongoing review of the valuation results and validation of significant inputs and assumptions. Preliminary fair value measurements were made for certain acquired assets and liabilities, primarily property, plant, and equipment; however, adjustments to those measurements may be made in subsequent periods, up to one year from the acquisition date, as new information related to facts and circumstances as of the acquisition date may be identified. The fair value of accounts receivable acquired, included in Other current assets in the following table, equals contractual amounts receivable. (Millions) Cash and cash equivalents $ 46 Other current assets 18 Property, plant, and equipment – net 2,035 Other noncurrent assets 2 Total assets acquired $ 2,101 Current liabilities $ (11) Noncurrent liabilities (107) Total liabilities assumed $ (118) Net assets acquired $ 1,983 DJ Basin Acquisitions Cureton Acquisition On November 30, 2023, we closed on the acquisition of 100 percent of Cureton Front Range, LLC (Cureton Acquisition), whose operations are located in the DJ Basin, for $546 million, subject to working capital and post-closing adjustments. The purpose of this acquisition was to expand our gathering and processing footprint and create operational synergies for our operations in the DJ Basin. Assets acquired, acquisition-related costs incurred, and results of operations realized are included within our West segment. The Cureton Acquisition was funded with cash on hand. During the period from the acquisition date of November 30, 2023 to December 31, 2023, the operations acquired in the Cureton Acquisition contributed Revenues of $35 million and Modified EBITDA of $7 million. Acquisition-related costs for the Cureton Acquisition total $7 million, including $1 million incurred in the six months ended June 30, 2024, included in Selling, general, and administrative expenses in our Consolidated Statement of Income. We accounted for the Cureton Acquisition as a business combination. The valuation techniques used consisted of the cost approach for property, plant, and equipment and the income approach for valuation of other intangible assets. The following table presents the preliminary allocation of the acquisition date fair value of the major classes of the assets acquired and liabilities assumed at November 30, 2023. The allocation is considered preliminary because the valuation work has not been completed due to the ongoing review of the valuation results and validation of significant inputs and assumptions. Preliminary fair value measurements were made for certain acquired assets and liabilities, primarily property, plant, and equipment and other intangible assets; however, adjustments to those measurements may be made in subsequent periods, up to one year from the acquisition date, as new information related to facts and circumstances as of the acquisition date may be identified. The fair value of accounts receivable acquired, included in Other current assets in the following table, equals contractual amounts receivable. (Millions) Cash and cash equivalents $ 6 Other current assets 21 Property, plant, and equipment – net 435 Intangible assets – net of accumulated amortization 117 Other noncurrent assets 1 Total identifiable assets acquired $ 580 Current liabilities $ (29) Noncurrent liabilities (14) Total liabilities assumed $ (43) Net identifiable assets acquired $ 537 Goodwill included in Intangible assets – net of accumulated amortization 9 Net assets acquired $ 546 Other intangible assets recognized in the Cureton Acquisition are related to contractual customer relationships from gas gathering and processing agreements with our customers. The basis for determining the value of these intangible assets is estimated future net cash flows to be derived from acquired contractual customer relationships discounted using a risk-adjusted discount rate. These intangible assets are being amortized on a straight-line basis over an initial period of 20 years which represents the term over which the contractual customer relationships are expected to contribute to our cash flows. Approximately 24 percent of the expected future revenues from these contractual customer relationships are impacted by our ability and intent to renew or renegotiate existing customer contracts. We expense costs incurred to renew or extend the terms of our gas gathering contracts with customers. Based on the estimated future revenues during the current contract periods (as estimated at the time of the acquisition), the weighted-average period prior to the next renewal or extension of the existing contractual customer relationships is approximately 10 years. RMM Acquisition As of December 31, 2022, we owned a 50 percent interest in RMM which we accounted for as an equity-method investment. On November 30, 2023, we closed on the acquisition of the remaining 50 percent interest in RMM (RMM Acquisition) for $704 million. As a result of acquiring this additional interest, we obtained control and now consolidate RMM. The purpose of this acquisition was to expand our gathering and processing footprint and create operational synergies for our operations in the DJ Basin. Assets acquired and results of operations realized are included within our West segment. Substantially all of the RMM purchase price is not due to the seller until the first quarter of 2025, does not accrue interest until the fourth quarter of 2024, and may be repaid early without penalty. It was recorded as a deferred consideration obligation at fair value using an income approach, which resulted in a discount to the contractual amount due which will be imputed as interest expense over the term of the obligation. The obligation is presented within Long-term debt due within one year in our Consolidated Balance Sheet owed by our wholly owned subsidiary Williams Rocky Mountain Midstream Holdings LLC. During the period from the acquisition date of November 30, 2023 to December 31, 2023, RMM contributed Revenues of $53 million and Modified EBITDA of $12 million. We accounted for the RMM Acquisition as a business combination. The book value of our existing equity-method investment prior to the acquisition date of November 30, 2023, was $406 million. We recognized a $30 million gain on remeasuring our existing equity-method investment to fair value included in Other investing income (loss) – net in our Consolidated Statement of Income during 2023. The valuation techniques used consisted of the income approach for our previous equity-method investment in RMM and the valuation of other intangible assets, and the cost approach for property, plant, and equipment. The following table presents the preliminary allocation of the acquisition date fair value of the major classes of the assets acquired and liabilities assumed at November 30, 2023. The net assets acquired primarily reflect the noncash consideration transferred, which includes the fair value of both our previous equity-method investment and the deferred consideration obligation. The allocation is considered preliminary because the valuation work has not been completed due to the ongoing review of the valuation results and validation of significant inputs and assumptions. Preliminary fair value measurements were made for certain acquired assets and liabilities, primarily property, plant, and equipment and other intangible assets; however, adjustments to those measurements may be made in subsequent periods, up to one year from the acquisition date, as new information related to facts and circumstances as of the acquisition date may be identified. The fair value of accounts receivable acquired, included in Other current assets in the following table, equals contractual amounts receivable. (Millions) Cash and cash equivalents $ 28 Other current assets 4 Investments 20 Property, plant, and equipment – net 1,041 Intangible assets – net of accumulated amortization 63 Other noncurrent assets 12 Total identifiable assets acquired $ 1,168 Current liabilities $ (44) Noncurrent liabilities (103) Total liabilities assumed $ (147) Net identifiable assets acquired $ 1,021 Goodwill included in Intangible assets – net of accumulated amortization 55 Net assets acquired $ 1,076 Goodwill recognized in the RMM Acquisition relates primarily to enhancing and diversifying our basin positions as well as delivering operational synergies, including increasing volumes on our existing processing facilities and increasing revenues on our NGL transportation, fractionation, and storage assets, and is reported within our West segment. Substantially all of the goodwill is deductible for tax purposes. Goodwill is included within Intangible assets – net of accumulated amortization in our Consolidated Balance Sheet and represents the excess of the consideration, plus the fair value of any noncontrolling interest or any previously held equity interest, over the fair value of the net assets acquired. It is not subject to amortization but is evaluated annually as of October 1 for impairment or more frequently if impairment indicators are present that would indicate it is more likely than not that the fair value of the reporting unit is less than its carrying amount. As part of the evaluation, we compare our estimate of the fair value of the reporting unit with its carrying value, including goodwill. If the carrying value of the reporting unit exceeds its fair value, an impairment charge is recorded for the difference (not to exceed the carrying value of goodwill). Judgments and assumptions are inherent in our management’s estimates of fair value. Other intangible assets recognized in the RMM Acquisition are related to contractual customer relationships from gas gathering and processing agreements with our customers. The basis for determining the value of these intangible assets is estimated future net cash flows to be derived from acquired contractual customer relationships discounted using a risk-adjusted discount rate. These intangible assets are being amortized on a straight-line basis over an initial period of 20 years which represents the term over which the contractual customer relationships are expected to contribute to our cash flows. Approximately 18 percent of the expected future revenues from these contractual customer relationships are impacted by our ability and intent to renew or renegotiate existing customer contracts. We expense costs incurred to renew or extend the terms of our gas gathering contracts with customers. Based on the estimated future revenues during the current contract periods (as estimated at the time of the acquisition), the weighted-average period prior to the next renewal or extension of the existing contractual customer relationships is approximately 10 years. MountainWest Acquisition On February 14, 2023, we closed on the acquisition of 100 percent of MountainWest, which includes Federal Energy Regulatory Commission (FERC)-regulated interstate natural gas pipeline systems and natural gas storage capacity (MountainWest Acquisition), for $1.08 billion of cash, funded with available sources of short-term liquidity, and retaining $430 million outstanding principal amount of MountainWest long-term debt. For 2023, $1.024 billion is presented in Purchases of businesses, net of cash acquired in our Consolidated Statement of Cash Flows reflecting the cash purchase price, reduced for post-closing adjustments and the cash acquired as presented in the purchase price allocation. The purpose of the MountainWest Acquisition was to expand our existing transmission and storage infrastructure footprint into major markets in Utah, Wyoming, and Colorado. Assets acquired, acquisition-related costs incurred, and results of operations realized are included within our Transmission & Gulf of Mexico segment. During the period from the acquisition date of February 14, 2023 to December 31, 2023, the operations acquired in the MountainWest Acquisition contributed Revenues of $225 million and Modified EBITDA of $122 million, which includes $27 million of transition-related costs. Acquisition-related costs for the MountainWest Acquisition total $17 million, including $13 million incurred in the six months ended June 30, 2023, included in Selling, general, and administrative expenses in our Consolidated Statement of Income. We accounted for the MountainWest Acquisition as a business combination. The valuation techniques used consisted of the cost approach for nonregulated property, plant, and equipment, as well as the market approach for the assumed long-term debt consistent with the valuation technique discussed in Note 7 – Fair Value Measurements and Guarantees. MountainWest’s regulated operations are accounted for pursuant to Accounting Standards Codification Topic 980, “Regulated Operations.” The fair value of assets and liabilities subject to rate making and cost recovery provisions were determined utilizing the income approach. MountainWest’s expected return on rate base is consistent with expected returns of similarly situated assets, resulting in carryover basis of these assets and liabilities equaling their fair value. The following table presents the allocation of the acquisition date fair value of the major classes of the assets acquired and liabilities assumed at February 14, 2023. The fair value of accounts receivable acquired equals contractual amounts receivable. (Millions) Cash and cash equivalents $ 23 Trade accounts and other receivables 33 Other current assets 26 Investments 20 Property, plant, and equipment – net 1,019 Other noncurrent assets 33 Total identifiable assets acquired $ 1,154 Current liabilities $ (47) Long-term debt (365) Other noncurrent liabilities (95) Total liabilities assumed $ (507) Net identifiable assets acquired $ 647 Goodwill included in Intangible assets – net of accumulated amortization 400 Net assets acquired $ 1,047 Goodwill recognized in the MountainWest Acquisition relates primarily to enhancing and diversifying our basin positions and the long-term value associated with rate regulated businesses and is reported within our Transmission & Gulf of Mexico segment. Substantially all of the goodwill is deductible for tax purposes. Supplemental Pro Forma The following pro forma Revenues and Net income (loss) attributable to The Williams Companies, Inc. for the three and six months ended June 30, 2023, are presented as if the Gulf Coast Storage Acquisition had been completed on January 1, 2023, and the DJ Basin Acquisitions and MountainWest Acquisition had been completed on January 1, 2022. These pro forma amounts are not necessarily indicative of what the actual results would have been if the acquisitions had in fact occurred on the dates or for the periods indicated, nor do they purport to project Revenues or Net income (loss) attributable to The Williams Companies, Inc. for any future periods or as of any date. These amounts do not give effect to any potential cost savings, operating synergies, or revenue enhancements to result from the transactions or the potential costs to achieve these cost savings, operating synergies, and revenue enhancements. Three Months Ended June 30, 2023 As Reported Pro Forma Gulf Coast Storage Pro Forma DJ Basin Pro Forma Combined (Millions) Revenues $ 2,483 $ 48 $ 77 $ 2,608 Net income (loss) attributable to The Williams Companies, Inc. 460 19 5 484 Six Months Ended June 30, 2023 As Reported Pro Forma Gulf Coast Storage Pro Forma DJ Basin Pro Forma MountainWest (1) Pro Forma Combined (Millions) Revenues $ 5,564 $ 94 $ 141 $ 35 $ 5,834 Net income (loss) attributable to The Williams Companies, Inc. 1,387 35 8 6 1,436 (1) Excludes results from operations acquired in the acquisition for the period beginning on the acquisition date, as these results are included in the amounts as reported. Sale of Certain Gulf Coast Liquids Pipelines On September 29, 2023, we completed the sale of various petrochemical and feedstock pipelines and associated contracts in the Gulf Coast region for $348 million. As a result of this sale, we recorded a gain of $129 million primarily in the third quarter of 2023 in our Transmission & Gulf of Mexico segment. The gain was reflected in Gain on sale of business in our Consolidated Statement of Income. The results of operations for this disposal group, excluding the gain noted, were not significant for the reporting periods.

Revenue Recognition

Revenue Recognition	6 Months Ended
	Jun. 30, 2024
Revenue Recognition [Abstract]
Revenue Recognition [Text Block]	Note 4 – Revenue Recognition Revenue by Category The following table presents our revenue disaggregated by major service line: Regulated Interstate Transportation & Storage Gulf of Mexico Midstream & Storage Northeast West Midstream Gas & NGL Marketing Services Other Eliminations Total (Millions) Three Months Ended June 30, 2024 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 846 $ — $ — $ — $ — $ — $ (20) $ 826 Gathering, processing, transportation, fractionation, and storage: Monetary consideration — 158 431 401 — — (37) 953 Commodity consideration — 5 (5) 18 — — — 18 Other 5 6 23 5 — — (4) 35 Total service revenues 851 169 449 424 — — (61) 1,832 Product sales 22 19 23 191 922 86 (248) 1,015 Total revenues from contracts with customers 873 188 472 615 922 86 (309) 2,847 Other revenues (1) 5 3 11 6 337 2 (1) 363 Other adjustments (2) — — — — (968) — 94 (874) Total revenues $ 878 $ 191 $ 483 $ 621 $ 291 $ 88 $ (216) $ 2,336 Three Months Ended June 30, 2023 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 826 $ — $ — $ — $ — $ — $ (12) $ 814 Gathering, processing, transportation, fractionation, and storage: Monetary consideration — 109 462 351 — — (45) 877 Commodity consideration — 6 (3) 24 — — — 27 Other 5 6 20 4 — — (4) 31 Total service revenues 831 121 479 379 — — (61) 1,749 Product sales 57 24 28 85 957 83 (188) 1,046 Total revenues from contracts with customers 888 145 507 464 957 83 (249) 2,795 Other revenues (1) 8 3 7 36 627 8 — 689 Other adjustments (2) — — — — (1,079) — 78 (1,001) Total revenues $ 896 $ 148 $ 514 $ 500 $ 505 $ 91 $ (171) $ 2,483 Regulated Interstate Transportation & Storage Gulf of Mexico Midstream & Storage Northeast West Midstream Gas & NGL Marketing Services Other Eliminations Total (Millions) Six Months Ended June 30, 2024 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 1,726 $ — $ — $ — $ — $ — $ (41) $ 1,685 Gathering, processing, transportation, fractionation, and storage: Monetary consideration — 303 875 831 — — (75) 1,934 Commodity consideration — 14 — 34 — — — 48 Other 9 15 47 11 — — (9) 73 Total service revenues 1,735 332 922 876 — — (125) 3,740 Product sales 47 56 48 439 2,228 194 (566) 2,446 Total revenues from contracts with customers 1,782 388 970 1,315 2,228 194 (691) 6,186 Other revenues (1) 13 6 22 7 1,170 14 (1) 1,231 Other adjustments (2) — — — — (2,537) — 227 (2,310) Total revenues $ 1,795 $ 394 $ 992 $ 1,322 $ 861 $ 208 $ (465) $ 5,107 Six Months Ended June 30, 2023 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 1,639 $ — $ — $ — $ — $ — $ (23) $ 1,616 Gathering, processing, transportation, fractionation, and storage: Monetary consideration — 213 884 702 — — (89) 1,710 Commodity consideration — 18 3 42 — — — 63 Other 9 8 45 6 1 — (8) 61 Total service revenues 1,648 239 932 750 1 — (120) 3,450 Product sales 79 60 77 175 2,330 185 (442) 2,464 Total revenues from contracts with customers 1,727 299 1,009 925 2,331 185 (562) 5,914 Other revenues (1) 21 7 14 78 2,543 23 — 2,686 Other adjustments (2) — — — — (3,238) — 202 (3,036) Total revenues $ 1,748 $ 306 $ 1,023 $ 1,003 $ 1,636 $ 208 $ (360) $ 5,564 ______________________________ (1) Revenues not derived from contracts with customers primarily consist of physical product sales related to commodity derivative contracts, realized and unrealized gains and losses associated with our commodity derivative contracts, which are reported in Net gain (loss) from commodity derivatives in our Consolidated Statement of Income, management fees that we receive for certain services we provide to operated equity-method investments, and leasing revenues associated with our headquarters building. (2) Other adjustments reflect certain costs of Gas & NGL Marketing Services’ risk management activities. As we are acting as agent for natural gas marketing customers or engage in energy trading activities, the resulting revenues are presented net of the related costs of those activities in our Consolidated Statement of Income. Contract Assets The following table presents a reconciliation of our contract assets: Three Months Ended Six Months Ended 2024 2023 2024 2023 (Millions) Balance at beginning of period $ 50 $ 42 $ 36 $ 29 Revenue recognized in excess of amounts invoiced 40 45 81 88 Minimum volume commitments invoiced (23) (31) (50) (61) Balance at end of period $ 67 $ 56 $ 67 $ 56 Contract Liabilities The following table presents a reconciliation of our contract liabilities: Three Months Ended Six Months Ended 2024 2023 2024 2023 (Millions) Balance at beginning of period $ 1,053 $ 1,010 $ 1,081 $ 1,043 Payments received and deferred 75 95 117 124 Significant financing component 2 2 4 4 Contract liability acquired (disposed) – net — — — 5 Recognized in revenue (66) (68) (138) (137) Balance at end of period $ 1,064 $ 1,039 $ 1,064 $ 1,039 Remaining Performance Obligations Remaining performance obligations primarily include reservation charges on contracted capacity for our gas pipeline firm transportation contracts with customers, storage capacity contracts, long-term contracts containing MVC associated with our midstream businesses, and fixed payments associated with offshore production handling. For our interstate natural gas pipeline businesses, remaining performance obligations reflect the rates for such services in our current FERC tariffs for the life of the related contracts; however, these rates may change based on future tariffs approved by the FERC and the amount and timing of these changes are not currently known. Our remaining performance obligations exclude variable consideration, including contracts with variable consideration for which we have elected the practical expedient for consideration recognized in revenue as billed. Certain of our contracts contain evergreen and other renewal provisions for periods beyond the initial term of the contract. The remaining performance obligation amounts as of June 30, 2024, do not consider potential future performance obligations for which the renewal has not been exercised and exclude contracts with customers for which the underlying facilities have not received FERC authorization to be placed into service. Consideration received prior to June 30, 2024, that will be recognized in future periods is also excluded from our remaining performance obligations and is instead reflected in contract liabilities. The following table presents the amount of the contract liabilities balance expected to be recognized as revenue when performance obligations are satisfied and the transaction price allocated to the remaining performance obligations under certain contracts as of June 30, 2024. Contract Liabilities Remaining Performance Obligations (Millions) 2024 (six months) $ 108 $ 2,007 2025 (one year) 165 3,815 2026 (one year) 136 3,562 2027 (one year) 128 3,070 2028 (one year) 114 2,496 Thereafter 413 13,919 Total $ 1,064 $ 28,869 Accounts Receivable The following is a summary of our Trade accounts and other receivables : June 30, 2024 December 31, 2023 (Millions) Accounts receivable related to revenues from contracts with customers $ 1,122 $ 1,292 Receivables from derivatives 205 311 Other accounts receivable 71 52 Trade accounts and other receivables $ 1,398 $ 1,655

Provision (Benefit) for Income

Provision (Benefit) for Income Taxes	6 Months Ended
	Jun. 30, 2024
Income Tax Disclosure [Abstract]
Provision (Benefit) for Income Taxes [Text Block]	Note 5 – Provision (Benefit) for Income Taxes The Provision (benefit) for income taxes from continuing operations includes: Three Months Ended Six Months Ended 2024 2023 2024 2023 (Millions) Current: Federal $ 19 $ (1) $ 54 $ — State 4 4 10 4 23 3 64 4 Deferred: Federal 90 149 217 386 State 16 23 41 69 106 172 258 455 Provision (benefit) for income taxes $ 129 $ 175 $ 322 $ 459 The effective income tax rates for the total provision (benefit) for the three and six months ended June 30, 2024 and 2023 are greater than the federal statutory rate, primarily due to the effect of state income taxes.

Debt and Banking Arrangements

Debt and Banking Arrangements	6 Months Ended
	Jun. 30, 2024
Debt Disclosure [Abstract]
Debt and Banking Arrangements [Text Block]	Note 6 – Debt and Banking Arrangements Issuances Our senior unsecured public debt issuances for 2024 are as follows: Issue Date Maturity Date Amount Rate (Millions) January 5, 2024 March 15, 2029 $ 1,100 4.900% January 5, 2024 March 15, 2034 1,000 5.150% Retirements Our senior unsecured public debt retirements for 2024 are as follows: Date of Retirement Maturity Date Amount Rate (Millions) March 4, 2024 March 4, 2024 $ 1,000 4.300% June 24, 2024 June 24, 2024 1,250 4.550% Credit Facility June 30, 2024 Stated Capacity Outstanding (Millions) Long-term credit facility (1) $ 3,750 $ — Letters of credit under certain bilateral bank agreements 12 ________________ (1) In managing our available liquidity, we do not expect a maximum outstanding amount in excess of the capacity of our credit facility inclusive of any outstanding amounts under our commercial paper program. Commercial Paper Program At June 30, 2024, we had $631 million (at par value) of Commercial paper outstanding at a weighted-average interest rate of 5.60 percent under our $3.5 billion commercial paper program.

Fair Value Measurements and Gua

Fair Value Measurements and Guarantees	6 Months Ended
	Jun. 30, 2024
Fair Value Disclosures [Abstract]
Fair Value Measurements and Guarantees [Text Block]	Note 7 – Fair Value Measurements and Guarantees The following table presents, by level within the fair value hierarchy, certain of our significant financial assets and liabilities. The carrying values of cash and cash equivalents, accounts receivable, accounts payable, and commercial paper approximate fair value because of the short-term nature of these instruments. Therefore, these assets and liabilities are not presented in the following table. Fair Value Measurements Using Carrying Fair Quoted Significant Significant (Millions) Assets (liabilities) at June 30, 2024: Measured on a recurring basis: ARO Trust investments $ 283 $ 283 $ 283 $ — $ — Commodity derivative assets (1) 109 109 — 55 54 Commodity derivative liabilities (1) (310) (310) (2) (304) (4) Interest rate derivatives 2 2 — 2 — Additional disclosures: Long-term debt, including current portion (25,632) (24,884) — (24,884) — Guarantees (36) (29) — (13) (16) Assets (liabilities) at December 31, 2023: Measured on a recurring basis: ARO Trust investments $ 269 $ 269 $ 269 $ — $ — Commodity derivative assets (2) 310 310 141 112 57 Commodity derivative liabilities (2) (285) (285) (3) (278) (4) Interest rate derivatives 6 6 — 6 — Additional disclosures: Long-term debt, including current portion (25,713) (25,553) — (25,553) — Guarantees (37) (28) — (12) (16) (1) Commodity derivative assets and liabilities exclude $143 million of net cash collateral in Level 1. (2) Commodity derivative assets and liabilities exclude $2 million of net cash collateral in Level 1. Fair Value Methods We use the following methods and assumptions in estimating the fair value of our financial instruments: Assets measured at fair value on a recurring basis ARO Trust investments : Transco deposits a portion of its collected rates, pursuant to its rate case settlement, into an external trust (ARO Trust) that is specifically designated to fund future asset retirement obligations (ARO). The ARO Trust invests in a portfolio of actively traded mutual funds that are measured at fair value on a recurring basis based on quoted prices in an active market and is reported in Regulatory assets, deferred charges, and other in our Consolidated Balance Sheet. Both realized and unrealized gains and losses are ultimately recorded as regulatory assets or liabilities. Commodity derivatives : Commodity derivatives include exchange-traded contracts and over-the-counter (OTC) contracts, which consist of physical forwards, futures, and swaps that are measured at fair value on a recurring basis. We also have other derivatives related to asset management agreements and other contracts that require physical delivery. Derivatives classified as Level 1 are valued using New York Mercantile Exchange (NYMEX) futures prices. Derivatives classified as Level 2 are valued using basis transactions that represent the cost to transport natural gas from a NYMEX delivery point to the contract delivery point. These transactions are based on quotes obtained either through electronic trading platforms or directly from brokers. Derivatives classified as Level 3 are valued using a combination of observable and unobservable inputs. The fair value amounts are presented on a net basis and reflect the netting of asset and liability positions permitted under the terms of our master netting arrangements and cash held on deposit in margin accounts that we have received or remitted to collateralize certain derivative positions. Commodity derivative assets are reported in Derivative assets and Regulatory assets, deferred charges, and other in our Consolidated Balance Sheet . Commodity derivative liabilities are reported in Derivative liabilities and Regulatory liabilities, deferred income, and other in our Consolidated Balance Sheet. Changes in the fair value of our derivative assets and liabilities are recorded in Net gain (loss) from commodity derivatives and Net processing commodity expenses in our Consolidated Statement of Income. See Note 8 – Commodity Derivatives for additional information on our derivatives. Interest rate derivatives: At December 31, 2023, we held forward starting interest rate swap agreements with notional amounts totaling $1.15 billion. During January 2024 we terminated certain of these agreements totaling $750 million of notional value coinciding with the issuance of long-term debt (see Note 6 – Debt and Banking Arrangements). During the six months ended June 30, 2024, we entered into new agreements totaling $200 million of notional value. The fair value of these derivatives is determined using discounted cash flows considering forward interest rates and the terms of the agreements, corroborated by counterparty valuations, and is classified as a Level 2 measurement. We designated these derivatives as cash flow hedges to reduce interest rate exposure on future debt issuances. Gains and losses on these derivative instruments are reflected as a component of AOCI and, after the termination of the swap agreement, are amortized to earnings over the term of the related debt as a component of Interest expense in our Consolidated Statement of Income. These forward starting interest rate swaps are reported in Derivative assets and Derivative liabilities in our Consolidated Balance Sheet. Additional fair value disclosures Long-term debt, including current portion : The disclosed fair value of our long-term debt is determined primarily by a market approach using broker quoted indicative period-end bond prices. The quoted prices are based on observable transactions in less active markets for our debt or similar instruments. The fair values of the financing obligations associated with our Dalton, Leidy South, and Atlantic Sunrise projects, as well as the deferred consideration obligations associated with the RMM Acquisition and the Gulf Coast Storage Acquisition (see Note 3 – Acquisitions and Divestitures), all included within long-term debt, were determined using an income approach. Guarantees : Guarantees primarily consist of a guarantee we have provided in the event of nonpayment by our previously owned communications subsidiary, Williams Communications Group, Inc., (WilTel), on a lease performance obligation that extends through 2042. Guarantees also include an indemnification related to a disposed operation. To estimate the fair value of the WilTel guarantee, an estimated default rate is applied to the sum of the future contractual lease payments using an income approach. The estimated default rate is determined by obtaining the average cumulative issuer-weighted default rate based on the credit rating of WilTel’s current owner and the term of the underlying obligation. The default rate is published by Moody’s Investors Service. The carrying value of the WilTel guarantee is reported in Accrued and other current liabilities in our Consolidated Balance Sheet. The maximum potential undiscounted liquidity exposure is approximately $22 million at June 30, 2024. Our exposure declines systematically through the remaining term of WilTel’s obligation. The fair value of the guarantee associated with the indemnification related to a disposed operation was estimated using an income approach that considered probability-weighted scenarios of potential levels of future performance. The terms of the indemnification do not limit the maximum potential future payments associated with the guarantee. The carrying value of this guarantee is reported in Regulatory liabilities, deferred income, and other in our Consolidated Balance Sheet. We are required by our revolving credit agreement to indemnify lenders for certain taxes required to be withheld from payments due to the lenders and for certain tax payments made by the lenders. The maximum potential amount of future payments under these indemnifications is based on the related borrowings and such future payments cannot currently be determined. These indemnifications generally continue indefinitely unless limited by the underlying tax regulations and have no carrying value. We have never been called upon to perform under these indemnifications and have no current expectation of a future claim.

Commodity Derivatives

Commodity Derivatives	6 Months Ended
	Jun. 30, 2024
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Commodity Derivatives [Text Block]	Note 8 – Commodity Derivatives We are exposed to commodity price risk. To manage this volatility, we use various contracts in our marketing and trading activities that generally meet the definition of derivatives. Derivative positions are monitored using techniques including, but not limited to, value at risk. Derivative instruments are recognized at fair value in our Consolidated Balance Sheet as either assets or liabilities and are presented on a net basis by counterparty, net of margin deposits. See Note 7 – Fair Value Measurements and Guarantees for additional fair value information. In our Consolidated Statement of Cash Flows, any cash impacts of settled commodity derivatives are recorded as operating activities. We enter into commodity derivatives to economically hedge exposures to natural gas, NGLs, and crude oil and retain exposure to price changes that can, in a volatile energy market, be material and can adversely affect our results of operations. At June 30, 2024, the notional volume of the net long (short) positions for our commodity derivative contracts were as follows: Commodity Unit of Measure Net Long (Short) Position Index Risk Natural Gas MMBtu 886,109,134 Central Hub Risk - Henry Hub Natural Gas MMBtu (81,136,597) Basis Risk Natural Gas MMBtu (28,533,844) Central Hub Risk - Mont Belvieu Natural Gas Liquids Barrels (1,929,000) Basis Risk Natural Gas Liquids Barrels (300,000) Central Hub Risk - WTI Crude Oil Barrels (240,000) Commodity Derivatives Financial Statement Presentation The fair value of commodity derivatives, which are not designated as hedging instruments for accounting purposes, is reflected as follows: June 30, December 31, Commodity Derivatives Categories Assets (Liabilities) Assets (Liabilities) (Millions) Current $ 464 $ (500) $ 623 $ (496) Noncurrent 223 (388) 243 (345) Total commodity derivatives $ 687 $ (888) $ 866 $ (841) Counterparty and collateral netting offset (420) 563 (552) 554 Amounts recognized in our Consolidated Balance Sheet $ 267 $ (325) $ 314 $ (287) The pre-tax impacts of commodity derivatives, which are not designated as hedging instruments for accounting purposes, are reflected in our Consolidated Statement of Income as follows: Gain (Loss) Three Months Ended Six Months Ended 2024 2023 2024 2023 (Millions) Net gain (loss) from commodity derivatives within Total revenues : Realized $ (5) $ 3 $ 81 $ 177 Unrealized (124) 112 (219) 444 $ (129) $ 115 $ (138) $ 621 Net gain (loss) from commodity derivatives within Net processing commodity expenses : Realized $ (1) $ 1 $ (5) $ (3) Unrealized (7) (29) (4) (34) $ (8) $ (28) $ (9) $ (37) Total net gain (loss) from commodity derivatives $ (137) $ 87 $ (147) $ 584 Contingent Features Generally, collateral may be provided in the form of a parent guaranty, letter of credit, or cash. If collateral is required, fair value amounts recognized for the right to reclaim cash collateral or the obligation to return cash collateral are offset against fair value amounts recognized for derivatives executed with the same counterparty. We have specific trade and credit contracts that contain minimum credit rating requirements. These credit rating requirements typically give counterparties the right to suspend or terminate credit if our credit ratings are downgraded to non-investment grade status. Under such circumstances, we would need to post collateral to continue transacting business with these counterparties. At June 30, 2024, the contractually required collateral in the event of a credit rating downgrade to non-investment grade status was $15 million. We maintain accounts with brokers or the clearing houses of certain exchanges to facilitate financial derivative transactions. Based on the value of the positions in these accounts and the associated margin requirements, we may be required to deposit cash into these accounts. At June 30, 2024, net cash collateral held on deposit in broker margin accounts was $143 million.

Contingencies

Contingencies	6 Months Ended
	Jun. 30, 2024
Commitments and Contingencies Disclosure [Abstract]
Contingencies [Text Block]	Note 9 – Contingencies Royalty Matters Certain of our customers, including Chesapeake Energy Corporation (Chesapeake), have been named in various lawsuits alleging underpayment of royalties and claiming, among other things, violations of anti-trust laws and the Racketeer Influenced and Corrupt Organizations Act. We have also been named as a defendant in certain of these cases filed in Pennsylvania based on allegations that we improperly participated with Chesapeake in causing the alleged royalty underpayments. We believe that the claims asserted are subject to indemnity obligations owed to us by Chesapeake, which obligations survived Chesapeake’s bankruptcy proceedings. Prior to its bankruptcy, Chesapeake reached a settlement to resolve substantially all Pennsylvania royalty cases pending. During the pendency of the bankruptcy, that settlement was renegotiated. The settlement applies to both Chesapeake and us and does not require any contribution from us. On August 23, 2021, after referral to the United States District Court for the Southern District of Texas by the bankruptcy court, the court approved the settlement. Two objectors filed an appeal with the United States Court of Appeals for the Fifth Circuit. On June 8, 2023, the Court of Appeals vacated the settlement approval and remanded to the United States District Court for the Southern District of Texas with instructions to dismiss the settlement proceedings for lack of jurisdiction. On August 31, 2023, the bankruptcy court entered an order finding the settlement agreements to be null and void. Certain plaintiffs have filed a notice of dismissal of their claims against Chesapeake that arose prior to February 8, 2021, in the United States District Court for the Middle District of Pennsylvania lawsuits. The notice states that plaintiffs are not releasing their claims against the other defendants, including us, or claims against Chesapeake that arose after February 9, 2021. We continue to believe the claims against us are subject to indemnity obligations owed to us by Chesapeake. Environmental Matters We are a participant in certain environmental activities in various stages including assessment studies, cleanup operations, and/or remedial processes at certain sites, some of which we currently do not own. We are monitoring these sites in a coordinated effort with other potentially responsible parties, the U.S. Environmental Protection Agency (EPA), or other governmental authorities. We are jointly and severally liable along with unrelated third parties in some of these activities and solely responsible in others. Certain of our subsidiaries have been identified as potentially responsible parties at various Superfund and state waste disposal sites. In addition, these subsidiaries have incurred, or are alleged to have incurred, various other hazardous materials removal or remediation obligations under environmental laws. As of June 30, 2024, we have accrued liabilities totaling $ 43 million The EPA and various state regulatory agencies routinely propose and promulgate new rules and issue updated guidance to existing rules. These rulemakings include, but are not limited to, rules for reciprocating internal combustion engine and combustion turbine maximum achievable control technology, reviews and updates to the National Ambient Air Quality Standards, and rules for new and existing source performance standards for volatile organic compound and methane. We continuously monitor these regulatory changes and how they may impact our operations. Implementation of new or modified regulations may result in impacts to our operations and increase the cost of additions to Property, plant, and equipment – net in our Consolidated Balance Sheet for both new and existing facilities in affected areas; however, due to regulatory uncertainty on final rule content and applicability timeframes, we are unable to reasonably estimate the cost of these regulatory impacts at this time. Continuing operations Our interstate gas pipelines are involved in remediation and monitoring activities related to certain facilities and locations for polychlorinated biphenyls, mercury, and other hazardous substances. These activities have involved the EPA and various state environmental authorities, resulting in our identification as a potentially responsible party at various Superfund waste sites. At June 30, 2024, we have accrued liabilities of $12 million for these costs and expect to recover approximately $4 million through rates. We also accrue environmental remediation costs for natural gas underground storage facilities, primarily related to soil and groundwater contamination. At June 30, 2024, we have accrued liabilities totaling $6 million for these costs. Former operations We have potential obligations in connection with assets and businesses we no longer operate. These potential obligations include remediation activities at the direction of federal and state environmental authorities and the indemnification of the purchasers of certain of these assets and businesses for environmental and other liabilities existing at the time the sale was consummated. At June 30, 2024, we have accrued environmental liabilities of $25 million related to these matters. Other Divestiture Indemnifications Pursuant to various purchase and sale agreements relating to divested businesses and assets, we have indemnified certain purchasers against liabilities that they may incur with respect to the businesses and assets acquired from us. The indemnities provided to the purchasers are customary in sale transactions and are contingent upon the purchasers incurring liabilities that are not otherwise recoverable from third parties. At June 30, 2024, other than as previously disclosed, we are not aware of any material claims against us involving the above-described indemnities. Any claim for indemnity brought against us in the future may have a material adverse effect on our results of operations in the period in which the claim is made. In addition to the foregoing, various other proceedings are pending against us that are incidental to our operations, none of which are expected to be material to our expected future annual results of operations, liquidity, and financial position. Summary We have disclosed our estimated range of reasonably possible losses for certain matters above, as well as all significant matters for which we are unable to reasonably estimate a range of possible loss. We estimate that for all other matters for which we are able to reasonably estimate a range of loss, our aggregate reasonably possible losses beyond amounts accrued are immaterial to our expected future annual results of operations, liquidity, and financial position. These calculations have been made without consideration of any potential recovery from third parties.

Segment Disclosures

Segment Disclosures	6 Months Ended
	Jun. 30, 2024
Segment Reporting [Abstract]
Segment Disclosures [Text Block]	Note 10 – Segment Disclosures Our reportable segments are Transmission & Gulf of Mexico, Northeast G&P, West, and Gas & NGL Marketing Services. All remaining business activities are included in Other. (See Note 1 – General, Description of Business, and Basis of Presentation.) Performance Measurement We evaluate segment operating performance based upon Modified EBITDA . This measure represents the basis of our internal financial reporting and is the primary performance measure used by our chief operating decision maker in measuring performance and allocating resources among our reportable segments. Intersegment Service revenues primarily represent transportation services provided to our marketing business and gathering services provided to our oil and gas properties. Intersegment Product sales primarily represent the sale of natural gas and NGLs from our natural gas processing plants and our oil and gas properties to our marketing business. We define Modified EBITDA as follows: • Net income (loss) before: ◦ Income (loss) from discontinued operations; ◦ Provision (benefit) for income taxes; ◦ Interest expense; ◦ Equity earnings (losses); ◦ Other investing income (loss) – net; ◦ Depreciation and amortization expenses; ◦ Accretion expense associated with asset retirement obligations for nonregulated operations; • This measure is further adjusted to include our proportionate share (based on ownership interest) of Modified EBITDA from our equity-method investments calculated consistently with the definition described above. Significant noncash items which are components of Modified EBITDA may include unrealized net gain (loss) from commodity derivatives within Total revenues, unrealized net gain (loss) from commodity derivatives within Net processing commodity expenses for our Gas & NGL Marketing segment, charges associated with lower of cost or net realizable value adjustments to our inventory within Product sales and Product costs , and impairments of certain assets within Other (income) expense – net within Operating income (loss) . The following table reflects the reconciliation of Modified EBITDA to Net income (loss) as reported in our Consolidated Statement of Income: Three Months Ended Six Months Ended 2024 2023 2024 2023 (Millions) Modified EBITDA by segment: Transmission & Gulf of Mexico $ 808 $ 731 $ 1,637 $ 1,446 Northeast G&P 481 515 985 985 West 318 312 645 616 Gas & NGL Marketing Services (126) 68 (25) 635 Total reportable segments 1,481 1,626 3,242 3,682 Modified EBITDA of other business activities 47 41 123 115 1,528 1,667 3,365 3,797 Accretion expense associated with asset retirement obligations for nonregulated operations (21) (14) (39) (29) Depreciation and amortization expenses (540) (515) (1,088) (1,021) Equity earnings (losses) 147 160 284 307 Other investing income (loss) – net 18 13 42 21 Proportional Modified EBITDA of equity-method investments (238) (249) (466) (478) Interest expense (339) (306) (688) (600) (Provision) benefit for income taxes (129) (175) (322) (459) Income (loss) from discontinued operations — (87) — (87) Net income (loss) $ 426 $ 494 $ 1,088 $ 1,451 The following table reflects the reconciliation of Segment revenues to Total revenues as reported in our Consolidated Statement of Income: Transmission & Gulf of Mexico Northeast G&P West Gas & NGL Marketing Services (1) Other Eliminations Total (Millions) Three Months Ended June 30, 2024 Segment revenues: Service revenues External $ 999 $ 462 $ 372 $ — $ 4 $ — $ 1,837 Internal 24 3 35 — — (62) — Total service revenues 1,023 465 407 — 4 (62) 1,837 Total service revenues – commodity consideration 5 (5) 18 — — — 18 Product sales External 25 5 34 508 38 — 610 Internal 15 18 157 (85) 48 (153) — Total product sales 40 23 191 423 86 (153) 610 Net gain (loss) from commodity derivatives Realized — — 5 (33) 23 — (5) Unrealized — — — (99) (25) — (124) Total net gain (loss) from commodity derivatives (2) — — 5 (132) (2) — (129) Total revenues $ 1,068 $ 483 $ 621 $ 291 $ 88 $ (215) $ 2,336 Three Months Ended June 30, 2023 Segment revenues: Service revenues External $ 933 $ 480 $ 330 $ — $ 5 $ — $ 1,748 Internal 23 9 28 — — (60) — Total service revenues 956 489 358 — 5 (60) 1,748 Total service revenues – commodity consideration 6 (3) 24 — — — 27 Product sales External 57 11 10 487 28 — 593 Internal 22 17 75 (60) 55 (109) — Total product sales 79 28 85 427 83 (109) 593 Net gain (loss) from commodity derivatives Realized 1 — 33 (45) 14 — 3 Unrealized — — — 123 (11) — 112 Total net gain (loss) from commodity derivatives (2) 1 — 33 78 3 — 115 Total revenues $ 1,042 $ 514 $ 500 $ 505 $ 91 $ (169) $ 2,483 Transmission & Gulf of Mexico Northeast G&P West Gas & NGL Marketing Services (1) Other Eliminations Total (Millions) Six Months Ended June 30, 2024 Segment revenues: Service revenues External $ 2,028 $ 937 $ 769 $ — $ 8 $ — $ 3,742 Internal 44 7 75 — — (126) — Total service revenues 2,072 944 844 — 8 (126) 3,742 Total service revenues – commodity consideration 14 — 34 — — — 48 Product sales External 55 7 106 1,215 72 — 1,455 Internal 46 41 333 (205) 122 (337) — Total product sales 101 48 439 1,010 194 (337) 1,455 Net gain (loss) from commodity derivatives Realized — — 5 48 28 — 81 Unrealized — — — (197) (22) — (219) Total net gain (loss) from commodity derivatives (2) — — 5 (149) 6 — (138) Total revenues $ 2,187 $ 992 $ 1,322 $ 861 $ 208 $ (463) $ 5,107 Six Months Ended June 30, 2023 Segment revenues: Service revenues External $ 1,848 $ 923 $ 662 $ 1 $ 8 $ — $ 3,442 Internal 48 20 52 — — (120) — Total service revenues 1,896 943 714 1 8 (120) 3,442 Total service revenues – commodity consideration 18 3 42 — — — 63 Product sales External 81 19 29 1,263 46 — 1,438 Internal 53 58 146 (161) 139 (235) — Total product sales 134 77 175 1,102 185 (235) 1,438 Net gain (loss) from commodity derivatives Realized 1 — 72 72 32 — 177 Unrealized — — — 461 (17) — 444 Total net gain (loss) from commodity derivatives (2) 1 — 72 533 15 — 621 Total revenues $ 2,049 $ 1,023 $ 1,003 $ 1,636 $ 208 $ (355) $ 5,564 ______________ (1) As we are acting as agent for natural gas marketing customers or engage in energy trading activities, the resulting revenues are presented net of the related costs of those activities. (2) We record transactions that qualify as commodity derivatives at fair value with changes in fair value recognized in earnings in the period of change and characterized as unrealized gains or losses. Gains and losses from commodity derivatives held for energy trading purposes are presented on a net basis in revenue.

Subsequent Events

Subsequent Events	6 Months Ended
	Jun. 30, 2024
Subsequent Events [Abstract]
Subsequent Events [Text Block]	Note 11 – Subsequent Events Discovery Acquisition As of December 31, 2023, we owned a 60 percent interest in Discovery which we accounted for as an equity-method investment. On August 1, 2024, we closed on the acquisition of the remaining 40 percent interest in Discovery, along with certain other assets, for $170 million, subject to working capital and post-closing adjustments. As a result of acquiring this additional interest, we obtained control and will consolidate Discovery. The purpose of this acquisition was to expand our gathering, processing, and transportation footprint in the Gulf of Mexico region. Assets acquired, acquisition-related costs incurred, and results of operations realized will be included within our Transmission & Gulf of Mexico segment. Due to the recent timing, the initial purchase price accounting for the transaction was not available at the time of filing. Sale of Aux Sable Interest Also on August 1, 2024, we completed the sale of our equity-method investments in Aux Sable Liquid Products Inc., Aux Sable Liquid Products LP, and Aux Sable Midstream LLC (collectively, “Aux Sable”) for total consideration of $160 million. As a result of this sale, we expect to record a gain in the third quarter of 2024 in our Northeast G&P segment.

Pay vs Performance Disclosure

Pay vs Performance Disclosure - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Pay vs Performance Disclosure
Net income (loss) attributable to The Williams Companies, Inc.	$ 401	$ 460	$ 1,033	$ 1,387

Insider Trading Arrangements

Insider Trading Arrangements shares in Thousands	3 Months Ended
	Jun. 30, 2024 shares
Trading Arrangements, by Individual
Material Terms of Trading Arrangement	On June 14, 2024, T. Lane Wilson, Senior Vice President and General Counsel of the Company, adopted a Rule 10b5-1 trading arrangement that is intended to satisfy the affirmative defense conditions of Exchange Act Rule 10b5-1(c)(a “Rule 10b5-1 Trading Plan”) for the sale of up to 24,000 shares of the Company’s common stock. The Rule 10b5-1 Trading Plan will terminate on August 29, 2025.
Non-Rule 10b5-1 Arrangement Adopted	false
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false
T Lane Wilson Rule 10b51 Trading Arrangement Common Stock [Member] | T Lane Wilson [Member]
Trading Arrangements, by Individual
Name	T. Lane Wilson
Title	Senior Vice President and General Counsel
Rule 10b5-1 Arrangement Adopted	true
Adoption Date	June 14, 2024
Arrangement Duration	441 days
Aggregate Available	24

Variable Interest Entities (Tab

Variable Interest Entities (Tables)	6 Months Ended
	Jun. 30, 2024
Variable Interest Entity Disclosures [Abstract]
Schedule of Variable Interest Entities [Table Text Block]	The following table presents amounts included in our Consolidated Balance Sheet that are only for the use or obligation of our consolidated VIEs: June 30, December 31, 2024 2023 (Millions) Assets (liabilities): Cash and cash equivalents $ 39 $ 33 Trade accounts and other receivables – net 170 215 Inventories 5 5 Other current assets and deferred charges 2 4 Property, plant, and equipment – net 4,980 5,046 Intangible assets – net of accumulated amortization 1,995 2,049 Regulatory assets, deferred charges, and other 28 31 Accounts payable (64) (109) Accrued and other current liabilities (30) (28) Regulatory liabilities, deferred income, and other (269) (268)

Acquisitions and Divestitures (

Acquisitions and Divestitures (Tables)	6 Months Ended
	Jun. 30, 2024
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Information [Table Text Block]	The following pro forma Revenues and Net income (loss) attributable to The Williams Companies, Inc. for the three and six months ended June 30, 2023, are presented as if the Gulf Coast Storage Acquisition had been completed on January 1, 2023, and the DJ Basin Acquisitions and MountainWest Acquisition had been completed on January 1, 2022. These pro forma amounts are not necessarily indicative of what the actual results would have been if the acquisitions had in fact occurred on the dates or for the periods indicated, nor do they purport to project Revenues or Net income (loss) attributable to The Williams Companies, Inc. for any future periods or as of any date. These amounts do not give effect to any potential cost savings, operating synergies, or revenue enhancements to result from the transactions or the potential costs to achieve these cost savings, operating synergies, and revenue enhancements. Three Months Ended June 30, 2023 As Reported Pro Forma Gulf Coast Storage Pro Forma DJ Basin Pro Forma Combined (Millions) Revenues $ 2,483 $ 48 $ 77 $ 2,608 Net income (loss) attributable to The Williams Companies, Inc. 460 19 5 484 Six Months Ended June 30, 2023 As Reported Pro Forma Gulf Coast Storage Pro Forma DJ Basin Pro Forma MountainWest (1) Pro Forma Combined (Millions) Revenues $ 5,564 $ 94 $ 141 $ 35 $ 5,834 Net income (loss) attributable to The Williams Companies, Inc. 1,387 35 8 6 1,436 (1) Excludes results from operations acquired in the acquisition for the period beginning on the acquisition date, as these results are included in the amounts as reported.
Gulf Coast Storage Acquisition
Business Acquisition [Line Items]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	The following table presents the preliminary allocation of the acquisition date fair value of the major classes of the assets acquired and liabilities assumed at January 3, 2024. The allocation is considered preliminary because the valuation work has not been completed due to the ongoing review of the valuation results and validation of significant inputs and assumptions. Preliminary fair value measurements were made for certain acquired assets and liabilities, primarily property, plant, and equipment; however, adjustments to those measurements may be made in subsequent periods, up to one year from the acquisition date, as new information related to facts and circumstances as of the acquisition date may be identified. The fair value of accounts receivable acquired, included in Other current assets in the following table, equals contractual amounts receivable. (Millions) Cash and cash equivalents $ 46 Other current assets 18 Property, plant, and equipment – net 2,035 Other noncurrent assets 2 Total assets acquired $ 2,101 Current liabilities $ (11) Noncurrent liabilities (107) Total liabilities assumed $ (118) Net assets acquired $ 1,983
Cureton Acquisition
Business Acquisition [Line Items]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	The following table presents the preliminary allocation of the acquisition date fair value of the major classes of the assets acquired and liabilities assumed at November 30, 2023. The allocation is considered preliminary because the valuation work has not been completed due to the ongoing review of the valuation results and validation of significant inputs and assumptions. Preliminary fair value measurements were made for certain acquired assets and liabilities, primarily property, plant, and equipment and other intangible assets; however, adjustments to those measurements may be made in subsequent periods, up to one year from the acquisition date, as new information related to facts and circumstances as of the acquisition date may be identified. The fair value of accounts receivable acquired, included in Other current assets in the following table, equals contractual amounts receivable. (Millions) Cash and cash equivalents $ 6 Other current assets 21 Property, plant, and equipment – net 435 Intangible assets – net of accumulated amortization 117 Other noncurrent assets 1 Total identifiable assets acquired $ 580 Current liabilities $ (29) Noncurrent liabilities (14) Total liabilities assumed $ (43) Net identifiable assets acquired $ 537 Goodwill included in Intangible assets – net of accumulated amortization 9 Net assets acquired $ 546
RMM Acquisition
Business Acquisition [Line Items]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	The following table presents the preliminary allocation of the acquisition date fair value of the major classes of the assets acquired and liabilities assumed at November 30, 2023. The net assets acquired primarily reflect the noncash consideration transferred, which includes the fair value of both our previous equity-method investment and the deferred consideration obligation. The allocation is considered preliminary because the valuation work has not been completed due to the ongoing review of the valuation results and validation of significant inputs and assumptions. Preliminary fair value measurements were made for certain acquired assets and liabilities, primarily property, plant, and equipment and other intangible assets; however, adjustments to those measurements may be made in subsequent periods, up to one year from the acquisition date, as new information related to facts and circumstances as of the acquisition date may be identified. The fair value of accounts receivable acquired, included in Other current assets in the following table, equals contractual amounts receivable. (Millions) Cash and cash equivalents $ 28 Other current assets 4 Investments 20 Property, plant, and equipment – net 1,041 Intangible assets – net of accumulated amortization 63 Other noncurrent assets 12 Total identifiable assets acquired $ 1,168 Current liabilities $ (44) Noncurrent liabilities (103) Total liabilities assumed $ (147) Net identifiable assets acquired $ 1,021 Goodwill included in Intangible assets – net of accumulated amortization 55 Net assets acquired $ 1,076
MountainWest Acquisition
Business Acquisition [Line Items]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	The following table presents the allocation of the acquisition date fair value of the major classes of the assets acquired and liabilities assumed at February 14, 2023. The fair value of accounts receivable acquired equals contractual amounts receivable. (Millions) Cash and cash equivalents $ 23 Trade accounts and other receivables 33 Other current assets 26 Investments 20 Property, plant, and equipment – net 1,019 Other noncurrent assets 33 Total identifiable assets acquired $ 1,154 Current liabilities $ (47) Long-term debt (365) Other noncurrent liabilities (95) Total liabilities assumed $ (507) Net identifiable assets acquired $ 647 Goodwill included in Intangible assets – net of accumulated amortization 400 Net assets acquired $ 1,047

Revenue Recognition (Tables)

Revenue Recognition (Tables)	6 Months Ended
	Jun. 30, 2024
Revenue Recognition [Abstract]
Disaggregation of Revenue [Table Text Block]	The following table presents our revenue disaggregated by major service line: Regulated Interstate Transportation & Storage Gulf of Mexico Midstream & Storage Northeast West Midstream Gas & NGL Marketing Services Other Eliminations Total (Millions) Three Months Ended June 30, 2024 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 846 $ — $ — $ — $ — $ — $ (20) $ 826 Gathering, processing, transportation, fractionation, and storage: Monetary consideration — 158 431 401 — — (37) 953 Commodity consideration — 5 (5) 18 — — — 18 Other 5 6 23 5 — — (4) 35 Total service revenues 851 169 449 424 — — (61) 1,832 Product sales 22 19 23 191 922 86 (248) 1,015 Total revenues from contracts with customers 873 188 472 615 922 86 (309) 2,847 Other revenues (1) 5 3 11 6 337 2 (1) 363 Other adjustments (2) — — — — (968) — 94 (874) Total revenues $ 878 $ 191 $ 483 $ 621 $ 291 $ 88 $ (216) $ 2,336 Three Months Ended June 30, 2023 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 826 $ — $ — $ — $ — $ — $ (12) $ 814 Gathering, processing, transportation, fractionation, and storage: Monetary consideration — 109 462 351 — — (45) 877 Commodity consideration — 6 (3) 24 — — — 27 Other 5 6 20 4 — — (4) 31 Total service revenues 831 121 479 379 — — (61) 1,749 Product sales 57 24 28 85 957 83 (188) 1,046 Total revenues from contracts with customers 888 145 507 464 957 83 (249) 2,795 Other revenues (1) 8 3 7 36 627 8 — 689 Other adjustments (2) — — — — (1,079) — 78 (1,001) Total revenues $ 896 $ 148 $ 514 $ 500 $ 505 $ 91 $ (171) $ 2,483 Regulated Interstate Transportation & Storage Gulf of Mexico Midstream & Storage Northeast West Midstream Gas & NGL Marketing Services Other Eliminations Total (Millions) Six Months Ended June 30, 2024 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 1,726 $ — $ — $ — $ — $ — $ (41) $ 1,685 Gathering, processing, transportation, fractionation, and storage: Monetary consideration — 303 875 831 — — (75) 1,934 Commodity consideration — 14 — 34 — — — 48 Other 9 15 47 11 — — (9) 73 Total service revenues 1,735 332 922 876 — — (125) 3,740 Product sales 47 56 48 439 2,228 194 (566) 2,446 Total revenues from contracts with customers 1,782 388 970 1,315 2,228 194 (691) 6,186 Other revenues (1) 13 6 22 7 1,170 14 (1) 1,231 Other adjustments (2) — — — — (2,537) — 227 (2,310) Total revenues $ 1,795 $ 394 $ 992 $ 1,322 $ 861 $ 208 $ (465) $ 5,107 Six Months Ended June 30, 2023 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 1,639 $ — $ — $ — $ — $ — $ (23) $ 1,616 Gathering, processing, transportation, fractionation, and storage: Monetary consideration — 213 884 702 — — (89) 1,710 Commodity consideration — 18 3 42 — — — 63 Other 9 8 45 6 1 — (8) 61 Total service revenues 1,648 239 932 750 1 — (120) 3,450 Product sales 79 60 77 175 2,330 185 (442) 2,464 Total revenues from contracts with customers 1,727 299 1,009 925 2,331 185 (562) 5,914 Other revenues (1) 21 7 14 78 2,543 23 — 2,686 Other adjustments (2) — — — — (3,238) — 202 (3,036) Total revenues $ 1,748 $ 306 $ 1,023 $ 1,003 $ 1,636 $ 208 $ (360) $ 5,564 ______________________________ (1) Revenues not derived from contracts with customers primarily consist of physical product sales related to commodity derivative contracts, realized and unrealized gains and losses associated with our commodity derivative contracts, which are reported in Net gain (loss) from commodity derivatives in our Consolidated Statement of Income, management fees that we receive for certain services we provide to operated equity-method investments, and leasing revenues associated with our headquarters building. (2) Other adjustments reflect certain costs of Gas & NGL Marketing Services’ risk management activities. As we are acting as agent for natural gas marketing customers or engage in energy trading activities, the resulting revenues are presented net of the related costs of those activities in our Consolidated Statement of Income.
Contract with Customer, Asset and Liability [Table Text Block]	Contract Assets The following table presents a reconciliation of our contract assets: Three Months Ended Six Months Ended 2024 2023 2024 2023 (Millions) Balance at beginning of period $ 50 $ 42 $ 36 $ 29 Revenue recognized in excess of amounts invoiced 40 45 81 88 Minimum volume commitments invoiced (23) (31) (50) (61) Balance at end of period $ 67 $ 56 $ 67 $ 56 Contract Liabilities The following table presents a reconciliation of our contract liabilities: Three Months Ended Six Months Ended 2024 2023 2024 2023 (Millions) Balance at beginning of period $ 1,053 $ 1,010 $ 1,081 $ 1,043 Payments received and deferred 75 95 117 124 Significant financing component 2 2 4 4 Contract liability acquired (disposed) – net — — — 5 Recognized in revenue (66) (68) (138) (137) Balance at end of period $ 1,064 $ 1,039 $ 1,064 $ 1,039
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Table Text Block]	The following table presents the amount of the contract liabilities balance expected to be recognized as revenue when performance obligations are satisfied and the transaction price allocated to the remaining performance obligations under certain contracts as of June 30, 2024. Contract Liabilities Remaining Performance Obligations (Millions) 2024 (six months) $ 108 $ 2,007 2025 (one year) 165 3,815 2026 (one year) 136 3,562 2027 (one year) 128 3,070 2028 (one year) 114 2,496 Thereafter 413 13,919 Total $ 1,064 $ 28,869
Contract With Customer Accounts Receivable	The following is a summary of our Trade accounts and other receivables : June 30, 2024 December 31, 2023 (Millions) Accounts receivable related to revenues from contracts with customers $ 1,122 $ 1,292 Receivables from derivatives 205 311 Other accounts receivable 71 52 Trade accounts and other receivables $ 1,398 $ 1,655

Provision (Benefit) for Incom_2

Provision (Benefit) for Income Taxes (Tables)	6 Months Ended
	Jun. 30, 2024
Income Tax Expense (Benefit), Continuing Operations [Abstract]
Schedule of Components of Provision (benefit) for income taxes [Table Text Block]	The Provision (benefit) for income taxes from continuing operations includes: Three Months Ended Six Months Ended 2024 2023 2024 2023 (Millions) Current: Federal $ 19 $ (1) $ 54 $ — State 4 4 10 4 23 3 64 4 Deferred: Federal 90 149 217 386 State 16 23 41 69 106 172 258 455 Provision (benefit) for income taxes $ 129 $ 175 $ 322 $ 459

Debt and Banking Arrangements (

Debt and Banking Arrangements (Tables)	6 Months Ended
	Jun. 30, 2024
Debt Disclosure [Abstract]
Schedule of Debt Issuances	Our senior unsecured public debt issuances for 2024 are as follows: Issue Date Maturity Date Amount Rate (Millions) January 5, 2024 March 15, 2029 $ 1,100 4.900% January 5, 2024 March 15, 2034 1,000 5.150%
Schedule of Extinguishment of Debt	Our senior unsecured public debt retirements for 2024 are as follows: Date of Retirement Maturity Date Amount Rate (Millions) March 4, 2024 March 4, 2024 $ 1,000 4.300% June 24, 2024 June 24, 2024 1,250 4.550%
Schedule of Line of Credit Facilities [Table Text Block]	Credit Facility June 30, 2024 Stated Capacity Outstanding (Millions) Long-term credit facility (1) $ 3,750 $ — Letters of credit under certain bilateral bank agreements 12 ________________ (1) In managing our available liquidity, we do not expect a maximum outstanding amount in excess of the capacity of our credit facility inclusive of any outstanding amounts under our commercial paper program.

Fair Value Measurements and G_2

Fair Value Measurements and Guarantees (Tables)	6 Months Ended
	Jun. 30, 2024
Fair Value Disclosures [Abstract]
Fair Value Assets and Liabilities Measured On Recurring Basis [Table Text Block]	The following table presents, by level within the fair value hierarchy, certain of our significant financial assets and liabilities. The carrying values of cash and cash equivalents, accounts receivable, accounts payable, and commercial paper approximate fair value because of the short-term nature of these instruments. Therefore, these assets and liabilities are not presented in the following table. Fair Value Measurements Using Carrying Fair Quoted Significant Significant (Millions) Assets (liabilities) at June 30, 2024: Measured on a recurring basis: ARO Trust investments $ 283 $ 283 $ 283 $ — $ — Commodity derivative assets (1) 109 109 — 55 54 Commodity derivative liabilities (1) (310) (310) (2) (304) (4) Interest rate derivatives 2 2 — 2 — Additional disclosures: Long-term debt, including current portion (25,632) (24,884) — (24,884) — Guarantees (36) (29) — (13) (16) Assets (liabilities) at December 31, 2023: Measured on a recurring basis: ARO Trust investments $ 269 $ 269 $ 269 $ — $ — Commodity derivative assets (2) 310 310 141 112 57 Commodity derivative liabilities (2) (285) (285) (3) (278) (4) Interest rate derivatives 6 6 — 6 — Additional disclosures: Long-term debt, including current portion (25,713) (25,553) — (25,553) — Guarantees (37) (28) — (12) (16) (1) Commodity derivative assets and liabilities exclude $143 million of net cash collateral in Level 1. (2) Commodity derivative assets and liabilities exclude $2 million of net cash collateral in Level 1.

Commodity Derivatives (Tables)

Commodity Derivatives (Tables)	6 Months Ended
	Jun. 30, 2024
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Derivative Instruments	At June 30, 2024, the notional volume of the net long (short) positions for our commodity derivative contracts were as follows: Commodity Unit of Measure Net Long (Short) Position Index Risk Natural Gas MMBtu 886,109,134 Central Hub Risk - Henry Hub Natural Gas MMBtu (81,136,597) Basis Risk Natural Gas MMBtu (28,533,844) Central Hub Risk - Mont Belvieu Natural Gas Liquids Barrels (1,929,000) Basis Risk Natural Gas Liquids Barrels (300,000) Central Hub Risk - WTI Crude Oil Barrels (240,000)
Schedule of Derivatives Instruments Statements of Financial Performance and Financial Position, Location	The fair value of commodity derivatives, which are not designated as hedging instruments for accounting purposes, is reflected as follows: June 30, December 31, Commodity Derivatives Categories Assets (Liabilities) Assets (Liabilities) (Millions) Current $ 464 $ (500) $ 623 $ (496) Noncurrent 223 (388) 243 (345) Total commodity derivatives $ 687 $ (888) $ 866 $ (841) Counterparty and collateral netting offset (420) 563 (552) 554 Amounts recognized in our Consolidated Balance Sheet $ 267 $ (325) $ 314 $ (287)
Pretax Effect Of Interest Rate And Energy Related Derivatives	The pre-tax impacts of commodity derivatives, which are not designated as hedging instruments for accounting purposes, are reflected in our Consolidated Statement of Income as follows: Gain (Loss) Three Months Ended Six Months Ended 2024 2023 2024 2023 (Millions) Net gain (loss) from commodity derivatives within Total revenues : Realized $ (5) $ 3 $ 81 $ 177 Unrealized (124) 112 (219) 444 $ (129) $ 115 $ (138) $ 621 Net gain (loss) from commodity derivatives within Net processing commodity expenses : Realized $ (1) $ 1 $ (5) $ (3) Unrealized (7) (29) (4) (34) $ (8) $ (28) $ (9) $ (37) Total net gain (loss) from commodity derivatives $ (137) $ 87 $ (147) $ 584

Segment Disclosures (Tables)

Segment Disclosures (Tables)	6 Months Ended
	Jun. 30, 2024
Segment Reporting [Abstract]
Reconciliation of Modified EBITDA to Net income (loss) [Table Text Block]	The following table reflects the reconciliation of Modified EBITDA to Net income (loss) as reported in our Consolidated Statement of Income: Three Months Ended Six Months Ended 2024 2023 2024 2023 (Millions) Modified EBITDA by segment: Transmission & Gulf of Mexico $ 808 $ 731 $ 1,637 $ 1,446 Northeast G&P 481 515 985 985 West 318 312 645 616 Gas & NGL Marketing Services (126) 68 (25) 635 Total reportable segments 1,481 1,626 3,242 3,682 Modified EBITDA of other business activities 47 41 123 115 1,528 1,667 3,365 3,797 Accretion expense associated with asset retirement obligations for nonregulated operations (21) (14) (39) (29) Depreciation and amortization expenses (540) (515) (1,088) (1,021) Equity earnings (losses) 147 160 284 307 Other investing income (loss) – net 18 13 42 21 Proportional Modified EBITDA of equity-method investments (238) (249) (466) (478) Interest expense (339) (306) (688) (600) (Provision) benefit for income taxes (129) (175) (322) (459) Income (loss) from discontinued operations — (87) — (87) Net income (loss) $ 426 $ 494 $ 1,088 $ 1,451
Reconciliation of revenue from segment to consolidated [Table Text Block]	The following table reflects the reconciliation of Segment revenues to Total revenues as reported in our Consolidated Statement of Income: Transmission & Gulf of Mexico Northeast G&P West Gas & NGL Marketing Services (1) Other Eliminations Total (Millions) Three Months Ended June 30, 2024 Segment revenues: Service revenues External $ 999 $ 462 $ 372 $ — $ 4 $ — $ 1,837 Internal 24 3 35 — — (62) — Total service revenues 1,023 465 407 — 4 (62) 1,837 Total service revenues – commodity consideration 5 (5) 18 — — — 18 Product sales External 25 5 34 508 38 — 610 Internal 15 18 157 (85) 48 (153) — Total product sales 40 23 191 423 86 (153) 610 Net gain (loss) from commodity derivatives Realized — — 5 (33) 23 — (5) Unrealized — — — (99) (25) — (124) Total net gain (loss) from commodity derivatives (2) — — 5 (132) (2) — (129) Total revenues $ 1,068 $ 483 $ 621 $ 291 $ 88 $ (215) $ 2,336 Three Months Ended June 30, 2023 Segment revenues: Service revenues External $ 933 $ 480 $ 330 $ — $ 5 $ — $ 1,748 Internal 23 9 28 — — (60) — Total service revenues 956 489 358 — 5 (60) 1,748 Total service revenues – commodity consideration 6 (3) 24 — — — 27 Product sales External 57 11 10 487 28 — 593 Internal 22 17 75 (60) 55 (109) — Total product sales 79 28 85 427 83 (109) 593 Net gain (loss) from commodity derivatives Realized 1 — 33 (45) 14 — 3 Unrealized — — — 123 (11) — 112 Total net gain (loss) from commodity derivatives (2) 1 — 33 78 3 — 115 Total revenues $ 1,042 $ 514 $ 500 $ 505 $ 91 $ (169) $ 2,483 Transmission & Gulf of Mexico Northeast G&P West Gas & NGL Marketing Services (1) Other Eliminations Total (Millions) Six Months Ended June 30, 2024 Segment revenues: Service revenues External $ 2,028 $ 937 $ 769 $ — $ 8 $ — $ 3,742 Internal 44 7 75 — — (126) — Total service revenues 2,072 944 844 — 8 (126) 3,742 Total service revenues – commodity consideration 14 — 34 — — — 48 Product sales External 55 7 106 1,215 72 — 1,455 Internal 46 41 333 (205) 122 (337) — Total product sales 101 48 439 1,010 194 (337) 1,455 Net gain (loss) from commodity derivatives Realized — — 5 48 28 — 81 Unrealized — — — (197) (22) — (219) Total net gain (loss) from commodity derivatives (2) — — 5 (149) 6 — (138) Total revenues $ 2,187 $ 992 $ 1,322 $ 861 $ 208 $ (463) $ 5,107 Six Months Ended June 30, 2023 Segment revenues: Service revenues External $ 1,848 $ 923 $ 662 $ 1 $ 8 $ — $ 3,442 Internal 48 20 52 — — (120) — Total service revenues 1,896 943 714 1 8 (120) 3,442 Total service revenues – commodity consideration 18 3 42 — — — 63 Product sales External 81 19 29 1,263 46 — 1,438 Internal 53 58 146 (161) 139 (235) — Total product sales 134 77 175 1,102 185 (235) 1,438 Net gain (loss) from commodity derivatives Realized 1 — 72 72 32 — 177 Unrealized — — — 461 (17) — 444 Total net gain (loss) from commodity derivatives (2) 1 — 72 533 15 — 621 Total revenues $ 2,049 $ 1,023 $ 1,003 $ 1,636 $ 208 $ (355) $ 5,564 ______________ (1) As we are acting as agent for natural gas marketing customers or engage in energy trading activities, the resulting revenues are presented net of the related costs of those activities. (2) We record transactions that qualify as commodity derivatives at fair value with changes in fair value recognized in earnings in the period of change and characterized as unrealized gains or losses. Gains and losses from commodity derivatives held for energy trading purposes are presented on a net basis in revenue.

General, Description of Busin_2

General, Description of Business, and Basis of Presentation (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023	Sep. 01, 2021
Accelerated Share Repurchases [Line Items]
Stock Repurchase Program, Authorized Amount				$ 1,500
Purchases of treasury stock	$ 56	$ 0	$ 130
StockRepurchaseProgramCumulativeAmountPurchased		$ 139
Transmission And Gulf Of Mexico [Member] | Gulfstream Natural Gas System, LLC [Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage		50%
Transmission And Gulf Of Mexico [Member] | Discovery Producer Services LLC [Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage		60%
Transmission And Gulf Of Mexico [Member] | Williams Companies Inc [Member] | Gulfstar One [Member]
General and Description Of Business [Abstract]
Variable Interest Entity Ownership Percentage		51%
Northeast G And P [Member] | Laurel Mountain Midstream, LLC [Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage		69%
Northeast G And P [Member] | Blue Racer Midstream LLC [Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage		50%
Northeast G And P [Member] | Williams Companies Inc [Member] | Northeast JV [Member]
General and Description Of Business [Abstract]
Variable Interest Entity Ownership Percentage		65%
Northeast G And P [Member] | Williams Companies Inc [Member] | Cardinal Gas Services LLC [Member]
General and Description Of Business [Abstract]
Variable Interest Entity Ownership Percentage		66%
Northeast G And P [Member] | Williams Companies Inc [Member] | Appalachia Midstream Services, LLC [Member]
General and Description Of Business [Abstract]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest		66%
West [Member] | Overland Pass Pipeline Company LLC [Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage		50%
West [Member] | Rocky Mountain Midstream Holdings LLC [Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage	50%		50%
West [Member] | Williams Companies Inc [Member] | Conway Fractionator [Member]
General and Description Of Business [Abstract]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest		50%
Former Alaska Refinery [Member]
Loss Contingencies [Line Items]
Loss Contingency Accrual, Period Increase (Decrease)	$ 115

Variable Interest Entities (Det

Variable Interest Entities (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2024	Dec. 31, 2023	Jun. 30, 2023	Dec. 31, 2022
Variable Interest Entity [Line Items]
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents	$ 55	$ 2,150	$ 551	$ 152
Receivables, Net, Current	1,398	1,655
Inventory, Net	274	274
Other current assets and deferred charges	170	195
Property, Plant and Equipment, Net	36,702	34,311
Intangible assets – net of accumulated amortization	7,402	7,593
Other Assets, Noncurrent	1,578	1,573
Accounts payable	(1,192)	(1,379)
Accrued Liabilities, Current	(1,229)	(1,284)
Other Liabilities and Deferred Revenue, Noncurrent	(4,764)	(4,684)
Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents	39	33
Receivables, Net, Current	170	215
Inventory, Net	5	5
Other current assets and deferred charges	2	4
Property, Plant and Equipment, Net	4,980	5,046
Intangible assets – net of accumulated amortization	1,995	2,049
Other Assets, Noncurrent	28	31
Accounts payable	(64)	(109)
Accrued Liabilities, Current	(30)	(28)
Other Liabilities and Deferred Revenue, Noncurrent	$ (269)	$ (268)
Variable Interest Entity, Primary Beneficiary [Member] | Williams Companies Inc [Member] | Northeast JV [Member]
Variable Interest Entity [Line Items]
Variable Interest Entity Ownership Percentage	65%
Variable Interest Entity, Primary Beneficiary [Member] | Williams Companies Inc [Member] | Gulfstar One [Member]
Variable Interest Entity [Line Items]
Variable Interest Entity Ownership Percentage	51%
Variable Interest Entity, Primary Beneficiary [Member] | Williams Companies Inc [Member] | Cardinal Gas Services LLC [Member]
Variable Interest Entity [Line Items]
Variable Interest Entity Ownership Percentage	66%
Variable Interest Entity, Not Primary Beneficiary [Member] | Williams Companies Inc [Member]
Variable Interest Entity [Line Items]
Equity-method investments	$ 73

Acquisitions (Details)

Acquisitions (Details) - USD ($) $ in Millions					1 Months Ended	3 Months Ended		6 Months Ended			11 Months Ended	12 Months Ended
		Jan. 03, 2024	Nov. 30, 2023	Feb. 14, 2023	Dec. 31, 2023	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2024	Jun. 30, 2023	Dec. 31, 2023	Dec. 31, 2023	Dec. 31, 2022
Business Acquisition [Line Items]
Payments to Acquire Businesses, Net of Cash Acquired								$ 1,844		$ 1,053
Revenues						$ 2,336	$ 2,483	5,107		5,564
Modified EBITDA Earnings Loss						1,528	1,667	3,365		3,797
Net income (loss) attributable to The Williams Companies, Inc.						401	460	1,033		1,387
Pro Forma [Member]
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Revenue							2,608			5,834
Business Acquisition, Pro Forma Net Income (Loss)							484			1,436
Operating Segments [Member]
Business Acquisition [Line Items]
Modified EBITDA Earnings Loss						1,481	1,626	3,242		3,682
Transmission And Gulf Of Mexico [Member] | Operating Segments [Member]
Business Acquisition [Line Items]
Revenues						1,068	1,042	2,187		2,049
Modified EBITDA Earnings Loss						808	731	1,637		1,446
West [Member] | Operating Segments [Member]
Business Acquisition [Line Items]
Revenues						621	500	1,322		1,003
Modified EBITDA Earnings Loss						$ 318	312	645		616
Gulf Coast Storage Acquisition
Business Acquisition [Line Items]
Business Acquisition, Percentage of Voting Interests Acquired		100%
Business Combination, Consideration Transferred		$ 1,950
Business Combination, Consideration Transferred, Liabilities Incurred		100
Gulf Coast Storage Acquisition | Pro Forma [Member]
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Revenue							48			94
Business Acquisition, Pro Forma Net Income (Loss)							19			35
Gulf Coast Storage Acquisition | Transmission And Gulf Of Mexico [Member]
Business Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Cash and Equivalents		46
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Other		18
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment		2,035
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets		2
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets		2,101
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Other		(11)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Other		(107)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities		(118)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net		$ 1,983
Gulf Coast Storage Acquisition | Transmission And Gulf Of Mexico [Member] | Selling, general and administrative expenses [Member]
Business Acquisition [Line Items]
Business Combination Acquisition Related Costs Cumulative								14
Business Combination, Acquisition Related Costs								13
Gulf Coast Storage Acquisition | Transmission And Gulf Of Mexico [Member] | Operating Segments [Member]
Business Acquisition [Line Items]
Revenues									$ 112
Modified EBITDA Earnings Loss									$ 81
Cureton Acquisition
Business Acquisition [Line Items]
Business Acquisition, Percentage of Voting Interests Acquired			100%
Business Combination, Consideration Transferred			$ 546
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life			20 years
Percentage Of Finite Lived Intangible Assets Impacted By Our Intent Or Ability To Renew Or Extend Arrangement			24%
Acquired Finite-lived Intangible Asset, Weighted-Average Period before Renewal or Extension			10 years
Cureton Acquisition | West [Member]
Business Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Cash and Equivalents			$ 6
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Other			21
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment			435
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Finite-Lived Intangibles			117
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets			1
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets			580
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Other			(29)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Other			(14)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities			(43)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net			537
Goodwill			9
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Net			546
Cureton Acquisition | West [Member] | Selling, general and administrative expenses [Member]
Business Acquisition [Line Items]
Business Combination Acquisition Related Costs Cumulative								7
Business Combination, Acquisition Related Costs								1
Cureton Acquisition | West [Member] | Operating Segments [Member]
Business Acquisition [Line Items]
Revenues					$ 35
Modified EBITDA Earnings Loss					7
RMM Acquisition
Business Acquisition [Line Items]
Business Combination, Consideration Transferred			704
Business Combination, Step Acquisition, Equity Interest in Acquiree, Fair Value			406
Gain on remeasurement of equity-method investment (Note 2)			$ 30
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life			20 years
Percentage Of Finite Lived Intangible Assets Impacted By Our Intent Or Ability To Renew Or Extend Arrangement			18%
Acquired Finite-lived Intangible Asset, Weighted-Average Period before Renewal or Extension			10 years
RMM Acquisition | West [Member]
Business Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Cash and Equivalents			$ 28
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Other			4
Business Combination Recognized Identifiable Assets Acquired And Liabilities Assumed Investments			20
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment			1,041
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Finite-Lived Intangibles			63
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets			12
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets			1,168
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Other			(44)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Other			(103)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities			(147)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net			1,021
Goodwill			55
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Net			1,076
Business Acquisition, Goodwill, Expected Tax Deductible Amount			$ 55
RMM Acquisition | West [Member] | Rocky Mountain Midstream Holdings LLC [Member]
Business Acquisition [Line Items]
Business Combination, Step Acquisition, Equity Interest in Acquiree, Percentage													50%
Business Acquisition, Percentage of Voting Interests Acquired			50%
RMM Acquisition | West [Member] | Operating Segments [Member]
Business Acquisition [Line Items]
Revenues					53
Modified EBITDA Earnings Loss					$ 12
DJ Basin Acquisitions | Pro Forma [Member]
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Revenue							77			141
Business Acquisition, Pro Forma Net Income (Loss)							$ 5			8
MountainWest Acquisition
Business Acquisition [Line Items]
Business Acquisition, Percentage of Voting Interests Acquired				100%
Business Combination, Consideration Transferred				$ 1,080
Business Combination, Consideration Transferred, Liabilities Incurred				430
Payments to Acquire Businesses, Net of Cash Acquired												$ 1,024
MountainWest Acquisition | Pro Forma [Member]
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Revenue	[1]									35
Business Acquisition, Pro Forma Net Income (Loss)	[1]									6
MountainWest Acquisition | Transmission And Gulf Of Mexico [Member]
Business Acquisition [Line Items]
Business Combination, Transition Related Costs											$ 27
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Cash and Equivalents				23
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Receivables				33
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Other				26
Business Combination Recognized Identifiable Assets Acquired And Liabilities Assumed Investments				20
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment				1,019
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets				33
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets				1,154
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Other				(47)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-Term Debt				(365)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Other				(95)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities				(507)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net				647
Goodwill				400
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Net				1,047
Business Acquisition, Goodwill, Expected Tax Deductible Amount				$ 400
MountainWest Acquisition | Transmission And Gulf Of Mexico [Member] | Selling, general and administrative expenses [Member]
Business Acquisition [Line Items]
Business Combination Acquisition Related Costs Cumulative								$ 17
Business Combination, Acquisition Related Costs										$ 13
MountainWest Acquisition | Transmission And Gulf Of Mexico [Member] | Operating Segments [Member]
Business Acquisition [Line Items]
Revenues											225
Modified EBITDA Earnings Loss											$ 122
[1] Excludes results from operations acquired in the acquisition for the period beginning on the acquisition date, as these results are included in the amounts as reported.

Divestitures (Details)

Divestitures (Details) - Certain Gulf Coast Liquids Pipelines $ in Millions	Sep. 29, 2023 USD ($)
Business Acquisition [Line Items]
Disposal Group, Consideration	$ 348
Transmission And Gulf Of Mexico [Member]
Business Acquisition [Line Items]
Gain (Loss) on Disposition of Business	$ 129

Revenue by Category (Details)

Revenue by Category (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		$ 2,847	$ 2,795	$ 6,186	$ 5,914
Revenue Not from Contract with Customer	[1]	363	689	1,231	2,686
Revenue Not from Contract with Customer, Other	[2]	(874)	(1,001)	(2,310)	(3,036)
Total revenues		2,336	2,483	5,107	5,564
Regulated Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		826	814	1,685	1,616
NonRegulated Service Monetary Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		953	877	1,934	1,710
NonRegulated Service Commodity Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		18	27	48	63
Total revenues		18	27	48	63
Other Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		35	31	73	61
Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		1,832	1,749	3,740	3,450
Total revenues		1,837	1,748	3,742	3,442
Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		1,015	1,046	2,446	2,464
Total revenues		610	593	1,455	1,438
Regulated Interstate Transportation & Storage
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		873	888	1,782	1,727
Revenue Not from Contract with Customer	[1]	5	8	13	21
Revenue Not from Contract with Customer, Other	[2]	0	0	0	0
Total revenues		878	896	1,795	1,748
Regulated Interstate Transportation & Storage | Regulated Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		846	826	1,726	1,639
Regulated Interstate Transportation & Storage | NonRegulated Service Monetary Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Regulated Interstate Transportation & Storage | NonRegulated Service Commodity Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Regulated Interstate Transportation & Storage | Other Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		5	5	9	9
Regulated Interstate Transportation & Storage | Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		851	831	1,735	1,648
Regulated Interstate Transportation & Storage | Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		22	57	47	79
Gulf of Mexico Midstream and Storage [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		188	145	388	299
Revenue Not from Contract with Customer	[1]	3	3	6	7
Revenue Not from Contract with Customer, Other	[2]	0	0	0	0
Total revenues		191	148	394	306
Gulf of Mexico Midstream and Storage [Member] | Regulated Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Gulf of Mexico Midstream and Storage [Member] | NonRegulated Service Monetary Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		158	109	303	213
Gulf of Mexico Midstream and Storage [Member] | NonRegulated Service Commodity Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		5	6	14	18
Gulf of Mexico Midstream and Storage [Member] | Other Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		6	6	15	8
Gulf of Mexico Midstream and Storage [Member] | Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		169	121	332	239
Gulf of Mexico Midstream and Storage [Member] | Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		19	24	56	60
Northeast Midstream [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		472	507	970	1,009
Revenue Not from Contract with Customer	[1]	11	7	22	14
Revenue Not from Contract with Customer, Other	[2]	0	0	0	0
Total revenues		483	514	992	1,023
Northeast Midstream [Member] | Regulated Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Northeast Midstream [Member] | NonRegulated Service Monetary Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		431	462	875	884
Northeast Midstream [Member] | NonRegulated Service Commodity Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		(5)	(3)	0	3
Northeast Midstream [Member] | Other Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		23	20	47	45
Northeast Midstream [Member] | Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		449	479	922	932
Northeast Midstream [Member] | Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		23	28	48	77
West Midstream [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		615	464	1,315	925
Revenue Not from Contract with Customer	[1]	6	36	7	78
Revenue Not from Contract with Customer, Other	[2]	0	0	0	0
Total revenues		621	500	1,322	1,003
West Midstream [Member] | Regulated Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
West Midstream [Member] | NonRegulated Service Monetary Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		401	351	831	702
West Midstream [Member] | NonRegulated Service Commodity Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		18	24	34	42
West Midstream [Member] | Other Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		5	4	11	6
West Midstream [Member] | Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		424	379	876	750
West Midstream [Member] | Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		191	85	439	175
Gas & NGL Marketing Services
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		922	957	2,228	2,331
Revenue Not from Contract with Customer	[1]	337	627	1,170	2,543
Revenue Not from Contract with Customer, Other	[2]	(968)	(1,079)	(2,537)	(3,238)
Total revenues		291	505	861	1,636
Gas & NGL Marketing Services | Regulated Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Gas & NGL Marketing Services | NonRegulated Service Monetary Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Gas & NGL Marketing Services | NonRegulated Service Commodity Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Gas & NGL Marketing Services | Other Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	1
Gas & NGL Marketing Services | Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	1
Gas & NGL Marketing Services | Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		922	957	2,228	2,330
Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		86	83	194	185
Revenue Not from Contract with Customer	[1]	2	8	14	23
Revenue Not from Contract with Customer, Other	[2]	0	0	0	0
Total revenues		88	91	208	208
Other [Member] | Regulated Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Other [Member] | NonRegulated Service Monetary Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Other [Member] | NonRegulated Service Commodity Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Other [Member] | Other Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Other [Member] | Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Other [Member] | Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		86	83	194	185
Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		(309)	(249)	(691)	(562)
Revenue Not from Contract with Customer	[1]	(1)	0	(1)	0
Revenue Not from Contract with Customer, Other	[2]	94	78	227	202
Total revenues		(216)	(171)	(465)	(360)
Intersegment Eliminations [Member] | Regulated Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		(20)	(12)	(41)	(23)
Intersegment Eliminations [Member] | NonRegulated Service Monetary Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		(37)	(45)	(75)	(89)
Intersegment Eliminations [Member] | NonRegulated Service Commodity Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Intersegment Eliminations [Member] | Other Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		(4)	(4)	(9)	(8)
Intersegment Eliminations [Member] | Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		(61)	(61)	(125)	(120)
Intersegment Eliminations [Member] | Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		$ (248)	$ (188)	$ (566)	$ (442)
[1] Revenues not derived from contracts with customers primarily consist of physical product sales related to commodity derivative contracts, realized and unrealized gains and losses associated with our commodity derivative contracts, which are reported in Net gain (loss) from commodity derivatives in our Consolidated Statement of Income, management fees that we receive for certain services we provide to operated equity-method investments, and leasing revenues associated with our headquarters building. Other adjustments reflect certain costs of Gas & NGL Marketing Services’ risk management activities. As we are acting as agent for natural gas marketing customers or engage in energy trading activities, the resulting revenues are presented net of the related costs of those activities in our Consolidated Statement of Income.

Revenue Recognition Contract As

Revenue Recognition Contract Assets (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Contract With Customer, Asset [Line Items]
Contract with Customer, Asset, Net - Beginning of Period	$ 50	$ 42	$ 36	$ 29
Contract with Customer, Asset, Cumulative Catch-up Adjustment to Revenue, Change in Measure of Progress	40	45	81	88
Contract with Customer, Asset, Reclassified to Receivable	(23)	(31)	(50)	(61)
Contract with Customer, Asset, Net - End of Period	$ 67	$ 56	$ 67	$ 56

Revenue Recognition Contract Li

Revenue Recognition Contract Liabilities (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Contract With Customer, Liability [Line Items]
Contract with Customer, Liability - Beginning of Period	$ 1,053	$ 1,010	$ 1,081	$ 1,043
Contract with Customer, Liability, Cumulative Catch-up Adjustment to Revenue, Change in Measure of Progress	75	95	117	124
Other Significant Noncash Transaction, Value of Consideration Received	2	2	4	4
Contract with Customer, Liability, Increase (Decrease) for Contract Acquired in Business Combination	0	0	0	5
Contract with Customer, Liability, Revenue Recognized	(66)	(68)	(138)	(137)
Contract with Customer, Liability - End of Period	$ 1,064	$ 1,039	$ 1,064	$ 1,039

Revenue Recognition Contract _2

Revenue Recognition Contract Liabilities Performance Obligations (Details) - USD ($) $ in Millions	Jun. 30, 2024	Mar. 31, 2024	Dec. 31, 2023	Jun. 30, 2023	Mar. 31, 2023	Dec. 31, 2022
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	$ 1,064	$ 1,053	$ 1,081	$ 1,039	$ 1,010	$ 1,043
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	108
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	165
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	136
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	128
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	114
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	$ 413
Performance Obligations Related To Contract Liabilities [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	6 months
Performance Obligations Related To Contract Liabilities [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Performance Obligations Related To Contract Liabilities [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Performance Obligations Related To Contract Liabilities [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Performance Obligations Related To Contract Liabilities [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Performance Obligations Related To Contract Liabilities [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period

Revenue Recognition Remaining P

Revenue Recognition Remaining Performance Obligations (Details) $ in Millions	Jun. 30, 2024 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 28,869
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	2,007
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	3,815
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	3,562
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	3,070
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	2,496
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 13,919
Remaining Performance Obligations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	6 months
Remaining Performance Obligations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Remaining Performance Obligations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Remaining Performance Obligations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Remaining Performance Obligations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Remaining Performance Obligations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period

Revenue Recognition Accounts Re

Revenue Recognition Accounts Receivable (Details) - USD ($) $ in Millions	Jun. 30, 2024	Dec. 31, 2023
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, Net, Current	$ 1,398	$ 1,655
Derivative Receivables
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, Net, Current	205	311
Accounts Receivable Related To Contracts With Customers [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, Net, Current	1,122	1,292
Other Accounts Receivable
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, Net, Current	$ 71	$ 52

Provision (Benefit) for Incom_3

Provision (Benefit) for Income Taxes Tax Provison (Benefit) Table (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Current :
Federal	$ 19	$ (1)	$ 54	$ 0
State	4	4	10	4
Total	23	3	64	4
Deferred:
Federal	90	149	217	386
State	16	23	41	69
Total	106	172	258	455
Less: Provision (benefit) for income taxes	$ 129	$ 175	$ 322	$ 459

Long-Term Debt Issuances and Re

Long-Term Debt Issuances and Retirements (Details) - The Williams Companies, Inc. [Member] - USD ($) $ in Millions	Jun. 24, 2024	Mar. 04, 2024	Jan. 05, 2024
4.9 Percent Senior Unsecured Notes Due 2029
Debt Instrument [Line Items]
Long-term debt face amount			$ 1,100
Long-term debt interest rate			4.90%
5.15 Percent Senior Unsecured Notes Due 2034
Debt Instrument [Line Items]
Long-term debt face amount			$ 1,000
Long-term debt interest rate			5.15%
4.3% Senior Unsecured Notes Due 2024 [Member]
Debt Instrument [Line Items]
Long-term debt interest rate		4.30%
Extinguishment of Debt, Amount		$ 1,000
4.55% Senior Unsecured Notes Due 2024 [Member]
Debt Instrument [Line Items]
Long-term debt interest rate	4.55%
Extinguishment of Debt, Amount	$ 1,250

Credit Facility and Commercial

Credit Facility and Commercial Paper (Details) - USD ($) $ in Millions		Jun. 30, 2024	Dec. 31, 2023
Credit Facility and Commercial Paper [Line Items]
Commercial paper, outstanding		$ 630	$ 725
Williams Companies Inc [Member]
Credit Facility and Commercial Paper [Line Items]
Credit facility, capacity	[1]	3,750
Credit facility, loans outstanding	[1]	0
Williams Companies Inc [Member] | Commercial paper [Member]
Credit Facility and Commercial Paper [Line Items]
Credit facility, capacity		3,500
Commercial paper, outstanding		$ 631
Short-Term Debt, Weighted Average Interest Rate, at Point in Time		5.60%
Williams Companies Inc [Member] | Letters Of Credit Under Certain Bilateral Bank Agreements [Member]
Credit Facility and Commercial Paper [Line Items]
Credit facility, letters of credit outstanding		$ 12
[1]In managing our available liquidity, we do not expect a maximum outstanding amount in excess of the capacity of our credit facility inclusive of any outstanding amounts under our commercial paper program.

Fair Value Measurements and G_3

Fair Value Measurements and Guarantees Recurring Measurements and Additional (Details) - USD ($) $ in Millions	1 Months Ended	6 Months Ended
	Jan. 31, 2024	Jun. 30, 2024		Dec. 31, 2023
Additional disclosures:
Derivative Asset, Noncurrent, Statement of Financial Position [Extensible Enumeration]		Other Assets, Noncurrent
Derivative Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]		Other Liabilities and Deferred Revenue, Noncurrent
Derivative, Notional Amount				$ 1,150
Derivative Notional Amount Terminated	$ 750
Derivative, Additional Notional Amount		$ 200
Carrying Amount [Member]
Additional disclosures:
Long-term debt, including current portion		(25,632)		(25,713)
Guarantees		(36)		(37)
Fair Value [Member]
Additional disclosures:
Long-term debt, including current portion		(24,884)		(25,553)
Guarantees		(29)		(28)
Level 1 [Member]
Additional disclosures:
Long-term debt, including current portion		0		0
Guarantees		0		0
Collateral Already Posted, Aggregate Fair Value		143		2
Level 2 [Member]
Additional disclosures:
Long-term debt, including current portion		(24,884)		(25,553)
Guarantees		(13)		(12)
Level 3 [Member]
Additional disclosures:
Long-term debt, including current portion		0		0
Guarantees		(16)		(16)
Fair Value, Recurring [Member] | Carrying Amount [Member]
Measured on a recurring basis
ARO Trust investments		283		269
Derivative Asset, Fair Value, Gross Asset		109		310
Derivative Liability, Fair Value, Gross Liability		(310)		(285)
Interest Rate Derivatives, at Fair Value, Net		2		6
Fair Value, Recurring [Member] | Fair Value [Member]
Measured on a recurring basis
ARO Trust investments		283		269
Derivative Asset, Fair Value, Gross Asset		109		310
Derivative Liability, Fair Value, Gross Liability		(310)		(285)
Interest Rate Derivatives, at Fair Value, Net		2		6
Fair Value, Recurring [Member] | Level 1 [Member]
Measured on a recurring basis
ARO Trust investments		283		269
Derivative Asset, Fair Value, Gross Asset		0	[1]	141	[2]
Derivative Liability, Fair Value, Gross Liability		(2)	[1]	(3)	[2]
Interest Rate Derivatives, at Fair Value, Net		0		0
Fair Value, Recurring [Member] | Level 2 [Member]
Measured on a recurring basis
ARO Trust investments		0		0
Derivative Asset, Fair Value, Gross Asset		55		112
Derivative Liability, Fair Value, Gross Liability		(304)		(278)
Interest Rate Derivatives, at Fair Value, Net		2		6
Fair Value, Recurring [Member] | Level 3 [Member]
Measured on a recurring basis
ARO Trust investments		0		0
Derivative Asset, Fair Value, Gross Asset		54		57
Derivative Liability, Fair Value, Gross Liability		(4)		(4)
Interest Rate Derivatives, at Fair Value, Net		0		$ 0
Wiltel Guarantee [Member]
Additional disclosures:
Guarantor Obligations, Maximum Exposure, Undiscounted		22
Indemnification Agreement [Member] | Carrying Amount [Member]
Additional disclosures:
Guarantees		$ 0
[1] Commodity derivative assets and liabilities exclude $143 million of net cash collateral in Level 1. Commodity derivative assets and liabilities exclude $2 million of net cash collateral in Level 1.

Commodity Derivatives - Notiona

Commodity Derivatives - Notional Volumes (Details) - Not Designated as Hedging Instrument [Member]	Jun. 30, 2024 MMBTU Boe
Public Utilities, Inventory, Natural Gas | IndexRisk
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Nonmonetary Notional Amount Net Long Short Position Volume | MMBTU	886,109,134
Public Utilities, Inventory, Natural Gas | Central Hub Risk
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Nonmonetary Notional Amount Net Long Short Position Volume | MMBTU	(81,136,597)
Public Utilities, Inventory, Natural Gas | Basis Risk
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Nonmonetary Notional Amount Net Long Short Position Volume | MMBTU	(28,533,844)
Natural Gas Liquids | Central Hub Risk
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Nonmonetary Notional Amount Net Long Short Position Volume | Boe	(1,929,000)
Natural Gas Liquids | Basis Risk
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Nonmonetary Notional Amount Net Long Short Position Volume | Boe	(300,000)
Crude Oil | Central Hub Risk
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Nonmonetary Notional Amount Net Long Short Position Volume | Boe	(240,000)

Commodity Derivatives - Financi

Commodity Derivatives - Financial Statement Presentation (Details) - Energy Related Derivative - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023	Dec. 31, 2023
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Asset, Fair Value, Gross Liability	$ (420)		$ (420)		$ (552)
Derivative Liability, Fair Value, Gross Asset	563		563		554
Derivative Asset	267		267		314
Derivative Liability	(325)		(325)		(287)
Gain (Loss) on Derivative Instruments, Net, Pretax	(137)	$ 87	(147)	$ 584
Gain (Loss) on Derivative Instruments
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Gain (Loss) on Derivative Instruments, Net, Pretax	(129)	115	(138)	621
Cost of Sales
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Gain (Loss) on Derivative Instruments, Net, Pretax	(8)	(28)	(9)	(37)
Not Designated as Hedging Instrument [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Asset, Fair Value, Gross Asset	687		687		866
Derivative Liability, Fair Value, Gross Liability	(888)		(888)		(841)
Not Designated as Hedging Instrument [Member] | Gain (Loss) on Derivative Instruments
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Realized	(5)	3	81	177
Unrealized	(124)	112	(219)	444
Not Designated as Hedging Instrument [Member] | Cost of Sales
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Realized	(1)	1	(5)	(3)
Unrealized	(7)	$ (29)	(4)	$ (34)
Derivative assets [Member] | Not Designated as Hedging Instrument [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Asset, Fair Value, Gross Asset	464		464		623
Regulatory assets, deferred charges, and other [Member] | Not Designated as Hedging Instrument [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Asset, Fair Value, Gross Asset	223		223		243
Derivative Liabilities [Member] | Not Designated as Hedging Instrument [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Liability, Fair Value, Gross Liability	(500)		(500)		(496)
Regulatory liabilities, deferred income, and other [Member] | Not Designated as Hedging Instrument [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Liability, Fair Value, Gross Liability	$ (388)		$ (388)		$ (345)

Commodity Derivatives - Conting

Commodity Derivatives - Contingent Features (Details) - USD ($) $ in Millions	Jun. 30, 2024	Dec. 31, 2023
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Additional Collateral, Aggregate Fair Value	$ 15
Level 1 [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Collateral Already Posted, Aggregate Fair Value	$ 143	$ 2

Contingencies (Details)

Contingencies (Details) $ in Millions	Jun. 30, 2024 USD ($)
Loss Contingencies [Line Items]
Accrued environmental loss liabilities	$ 43
Environmental Loss Contingency, Statement of Financial Position [Extensible Enumeration]	Accrued Liabilities, Current
Gas Pipeline [Member]
Loss Contingencies [Line Items]
Accrued environmental loss liabilities	$ 12
Recoverable through rates [Member]
Loss Contingencies [Line Items]
Accrued environmental loss liabilities	4
Natural Gas Underground Storage Facilities [Member]
Loss Contingencies [Line Items]
Accrued environmental loss liabilities	6
Former Operations [Member]
Loss Contingencies [Line Items]
Accrued environmental loss liabilities	$ 25

Segment Disclosures Recon from

Segment Disclosures Recon from Modified EBITDA to Net Income (Loss) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Reconciliation of Modified EBITDA to Net Income (Loss)
Modified EBITDA	$ 1,528	$ 1,667	$ 3,365	$ 3,797
Accretion expense associated with asset retirement obligations for nonregulated operations	(21)	(14)	(39)	(29)
Depreciation and amortization expenses	(540)	(515)	(1,088)	(1,021)
Equity earnings (losses)	147	160	284	307
Other investing income (loss) – net	18	13	42	21
Proportional Modified EBITDA Equity Method Investments	(238)	(249)	(466)	(478)
Interest Expense	(339)	(306)	(688)	(600)
(Provision) benefit for income taxes	(129)	(175)	(322)	(459)
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	0	(87)	0	(87)
Net income (loss)	426	494	1,088	1,451
Operating Segments [Member]
Reconciliation of Modified EBITDA to Net Income (Loss)
Modified EBITDA	1,481	1,626	3,242	3,682
Operating Segments [Member] | Transmission And Gulf Of Mexico [Member]
Reconciliation of Modified EBITDA to Net Income (Loss)
Modified EBITDA	808	731	1,637	1,446
Operating Segments [Member] | Northeast G And P [Member]
Reconciliation of Modified EBITDA to Net Income (Loss)
Modified EBITDA	481	515	985	985
Operating Segments [Member] | West [Member]
Reconciliation of Modified EBITDA to Net Income (Loss)
Modified EBITDA	318	312	645	616
Operating Segments [Member] | Gas & NGL Marketing Services
Reconciliation of Modified EBITDA to Net Income (Loss)
Modified EBITDA	(126)	68	(25)	635
Corporate, Non-Segment
Reconciliation of Modified EBITDA to Net Income (Loss)
Modified EBITDA	$ 47	$ 41	$ 123	$ 115

Segment Disclosures Recon fro_2

Segment Disclosures Recon from Segment to Consolidated - Revenues (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Segment revenues [Line Items]
Revenues		$ 2,336	$ 2,483	$ 5,107	$ 5,564
Other financial information:
Proportional Modified EBITDA Equity Method Investments		238	249	466	478
Intersegment Eliminations [Member]
Segment revenues [Line Items]
Revenues		(215)	(169)	(463)	(355)
Operating Segments [Member] | Transmission And Gulf Of Mexico [Member]
Segment revenues [Line Items]
Revenues		1,068	1,042	2,187	2,049
Operating Segments [Member] | Northeast G And P [Member]
Segment revenues [Line Items]
Revenues		483	514	992	1,023
Operating Segments [Member] | West [Member]
Segment revenues [Line Items]
Revenues		621	500	1,322	1,003
Operating Segments [Member] | Gas & NGL Marketing Services
Segment revenues [Line Items]
Revenues	[1]	291	505	861	1,636
Operating Segments [Member] | Other [Member]
Segment revenues [Line Items]
Revenues		88	91	208	208
Service [Member]
Segment revenues [Line Items]
Revenues		1,837	1,748	3,742	3,442
Service [Member] | Transmission And Gulf Of Mexico [Member]
Segment revenues [Line Items]
Revenues		999	933	2,028	1,848
Service [Member] | Northeast G And P [Member]
Segment revenues [Line Items]
Revenues		462	480	937	923
Service [Member] | West [Member]
Segment revenues [Line Items]
Revenues		372	330	769	662
Service [Member] | Gas & NGL Marketing Services
Segment revenues [Line Items]
Revenues	[1]	0	0	0	1
Service [Member] | Other [Member]
Segment revenues [Line Items]
Revenues		4	5	8	8
Service [Member] | Intersegment Eliminations [Member]
Segment revenues [Line Items]
Revenues		(62)	(60)	(126)	(120)
Service [Member] | Intersegment Eliminations [Member] | Transmission And Gulf Of Mexico [Member]
Segment revenues [Line Items]
Revenues		(24)	(23)	(44)	(48)
Service [Member] | Intersegment Eliminations [Member] | Northeast G And P [Member]
Segment revenues [Line Items]
Revenues		(3)	(9)	(7)	(20)
Service [Member] | Intersegment Eliminations [Member] | West [Member]
Segment revenues [Line Items]
Revenues		(35)	(28)	(75)	(52)
Service [Member] | Intersegment Eliminations [Member] | Gas & NGL Marketing Services
Segment revenues [Line Items]
Revenues	[1]	0	0	0	0
Service [Member] | Intersegment Eliminations [Member] | Other [Member]
Segment revenues [Line Items]
Revenues		0	0	0	0
Service [Member] | Operating Segments [Member] | Transmission And Gulf Of Mexico [Member]
Segment revenues [Line Items]
Revenues		1,023	956	2,072	1,896
Service [Member] | Operating Segments [Member] | Northeast G And P [Member]
Segment revenues [Line Items]
Revenues		465	489	944	943
Service [Member] | Operating Segments [Member] | West [Member]
Segment revenues [Line Items]
Revenues		407	358	844	714
Service [Member] | Operating Segments [Member] | Gas & NGL Marketing Services
Segment revenues [Line Items]
Revenues	[1]	0	0	0	1
Service [Member] | Operating Segments [Member] | Other [Member]
Segment revenues [Line Items]
Revenues		4	5	8	8
NonRegulated Service Commodity Consideration [Member]
Segment revenues [Line Items]
Revenues		18	27	48	63
NonRegulated Service Commodity Consideration [Member] | Intersegment Eliminations [Member]
Segment revenues [Line Items]
Revenues		0	0	0	0
NonRegulated Service Commodity Consideration [Member] | Operating Segments [Member] | Transmission And Gulf Of Mexico [Member]
Segment revenues [Line Items]
Revenues		5	6	14	18
NonRegulated Service Commodity Consideration [Member] | Operating Segments [Member] | Northeast G And P [Member]
Segment revenues [Line Items]
Revenues		(5)	(3)	0	3
NonRegulated Service Commodity Consideration [Member] | Operating Segments [Member] | West [Member]
Segment revenues [Line Items]
Revenues		18	24	34	42
NonRegulated Service Commodity Consideration [Member] | Operating Segments [Member] | Gas & NGL Marketing Services
Segment revenues [Line Items]
Revenues	[1]	0	0	0	0
NonRegulated Service Commodity Consideration [Member] | Operating Segments [Member] | Other [Member]
Segment revenues [Line Items]
Revenues		0	0	0	0
Product [Member]
Segment revenues [Line Items]
Revenues		610	593	1,455	1,438
Product [Member] | Transmission And Gulf Of Mexico [Member]
Segment revenues [Line Items]
Revenues		25	57	55	81
Product [Member] | Northeast G And P [Member]
Segment revenues [Line Items]
Revenues		5	11	7	19
Product [Member] | West [Member]
Segment revenues [Line Items]
Revenues		34	10	106	29
Product [Member] | Gas & NGL Marketing Services
Segment revenues [Line Items]
Revenues	[1]	508	487	1,215	1,263
Product [Member] | Other [Member]
Segment revenues [Line Items]
Revenues		38	28	72	46
Product [Member] | Intersegment Eliminations [Member]
Segment revenues [Line Items]
Revenues		(153)	(109)	(337)	(235)
Product [Member] | Intersegment Eliminations [Member] | Transmission And Gulf Of Mexico [Member]
Segment revenues [Line Items]
Revenues		(15)	(22)	(46)	(53)
Product [Member] | Intersegment Eliminations [Member] | Northeast G And P [Member]
Segment revenues [Line Items]
Revenues		(18)	(17)	(41)	(58)
Product [Member] | Intersegment Eliminations [Member] | West [Member]
Segment revenues [Line Items]
Revenues		(157)	(75)	(333)	(146)
Product [Member] | Intersegment Eliminations [Member] | Gas & NGL Marketing Services
Segment revenues [Line Items]
Revenues	[1]	85	60	205	161
Product [Member] | Intersegment Eliminations [Member] | Other [Member]
Segment revenues [Line Items]
Revenues		(48)	(55)	(122)	(139)
Product [Member] | Operating Segments [Member] | Transmission And Gulf Of Mexico [Member]
Segment revenues [Line Items]
Revenues		40	79	101	134
Product [Member] | Operating Segments [Member] | Northeast G And P [Member]
Segment revenues [Line Items]
Revenues		23	28	48	77
Product [Member] | Operating Segments [Member] | West [Member]
Segment revenues [Line Items]
Revenues		191	85	439	175
Product [Member] | Operating Segments [Member] | Gas & NGL Marketing Services
Segment revenues [Line Items]
Revenues	[1]	423	427	1,010	1,102
Product [Member] | Operating Segments [Member] | Other [Member]
Segment revenues [Line Items]
Revenues		86	83	194	185
Energy Commodities and Service
Segment revenues [Line Items]
Revenues	[2]	(129)	115	(138)	621
Energy Commodities and Service | Realized Gain (Loss)
Segment revenues [Line Items]
Revenues		(5)	3	81	177
Energy Commodities and Service | Unrealized Gain (Loss)
Segment revenues [Line Items]
Revenues		(124)	112	(219)	444
Energy Commodities and Service | Intersegment Eliminations [Member]
Segment revenues [Line Items]
Revenues	[2]	0	0	0	0
Energy Commodities and Service | Intersegment Eliminations [Member] | Realized Gain (Loss)
Segment revenues [Line Items]
Revenues		0	0	0	0
Energy Commodities and Service | Intersegment Eliminations [Member] | Unrealized Gain (Loss)
Segment revenues [Line Items]
Revenues		0	0	0	0
Energy Commodities and Service | Operating Segments [Member] | Transmission And Gulf Of Mexico [Member]
Segment revenues [Line Items]
Revenues	[2]	0	1	0	1
Energy Commodities and Service | Operating Segments [Member] | Transmission And Gulf Of Mexico [Member] | Realized Gain (Loss)
Segment revenues [Line Items]
Revenues		0	1	0	1
Energy Commodities and Service | Operating Segments [Member] | Transmission And Gulf Of Mexico [Member] | Unrealized Gain (Loss)
Segment revenues [Line Items]
Revenues		0	0	0	0
Energy Commodities and Service | Operating Segments [Member] | Northeast G And P [Member]
Segment revenues [Line Items]
Revenues	[2]	0	0	0	0
Energy Commodities and Service | Operating Segments [Member] | Northeast G And P [Member] | Realized Gain (Loss)
Segment revenues [Line Items]
Revenues		0	0	0	0
Energy Commodities and Service | Operating Segments [Member] | Northeast G And P [Member] | Unrealized Gain (Loss)
Segment revenues [Line Items]
Revenues		0	0	0	0
Energy Commodities and Service | Operating Segments [Member] | West [Member]
Segment revenues [Line Items]
Revenues	[2]	5	33	5	72
Energy Commodities and Service | Operating Segments [Member] | West [Member] | Realized Gain (Loss)
Segment revenues [Line Items]
Revenues		5	33	5	72
Energy Commodities and Service | Operating Segments [Member] | West [Member] | Unrealized Gain (Loss)
Segment revenues [Line Items]
Revenues		0	0	0	0
Energy Commodities and Service | Operating Segments [Member] | Gas & NGL Marketing Services
Segment revenues [Line Items]
Revenues	[1],[2]	(132)	78	(149)	533
Energy Commodities and Service | Operating Segments [Member] | Gas & NGL Marketing Services | Realized Gain (Loss)
Segment revenues [Line Items]
Revenues	[1]	(33)	(45)	48	72
Energy Commodities and Service | Operating Segments [Member] | Gas & NGL Marketing Services | Unrealized Gain (Loss)
Segment revenues [Line Items]
Revenues	[1]	(99)	123	(197)	461
Energy Commodities and Service | Operating Segments [Member] | Other [Member]
Segment revenues [Line Items]
Revenues	[2]	(2)	3	6	15
Energy Commodities and Service | Operating Segments [Member] | Other [Member] | Realized Gain (Loss)
Segment revenues [Line Items]
Revenues		23	14	28	32
Energy Commodities and Service | Operating Segments [Member] | Other [Member] | Unrealized Gain (Loss)
Segment revenues [Line Items]
Revenues		$ (25)	$ (11)	$ (22)	$ (17)
[1]As we are acting as agent for natural gas marketing customers or engage in energy trading activities, the resulting revenues are presented net of the related costs of those activities.[2]We record transactions that qualify as commodity derivatives at fair value with changes in fair value recognized in earnings in the period of change and characterized as unrealized gains or losses. Gains and losses from commodity derivatives held for energy trading purposes are presented on a net basis in revenue.

Subsequent Events (Details)

Subsequent Events (Details) - USD ($) $ in Millions	Aug. 01, 2024	Dec. 31, 2023
Discovery Producer Services LLC [Member] | Discovery Acquisition | Transmission And Gulf Of Mexico [Member]
Subsequent Event [Line Items]
Business Combination, Step Acquisition, Equity Interest in Acquiree, Percentage		60%
Subsequent Event [Member] | Discovery Producer Services LLC [Member] | Discovery Acquisition | Transmission And Gulf Of Mexico [Member]
Subsequent Event [Line Items]
Business Acquisition, Percentage of Voting Interests Acquired	40%
Business Combination, Consideration Transferred	$ 170
Subsequent Event [Member] | Aux Sable Liquid Products Inc And Aux Sable Liquid Products LP And Aux Sable Midstream LLC | Northeast G And P [Member]
Subsequent Event [Line Items]
Proceeds from Sale of Equity Method Investments	$ 160