The Williams Companies, Inc. (WMB) 10-Q 1 Nov 23 2023 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2023	Oct. 30, 2023
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2023
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		1,216,498,672
Entity Central Index Key	0000107263
Amendment Flag	false
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	Q3
Current Fiscal Year End Date	--12-31

Consolidated Statement of Incom

Consolidated Statement of Income (Unaudited) - USD ($) shares in Thousands, $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Revenues:
Revenues		$ 2,559	$ 3,021	$ 8,123	$ 8,035
Costs and expenses:
Operating and maintenance expenses		522	486	1,466	1,345
Depreciation and amortization expenses		521	500	1,542	1,504
Selling, general, and administrative expenses		146	163	483	477
Gain (Loss) on Disposition of Business		(130)	0	(130)	0
Other (income) expense – net		(9)	33	(49)	14
Total costs and expenses		1,565	2,201	4,899	6,089
Operating income (loss)		994	820	3,224	1,946
Equity earnings (losses)		127	193	434	492
Other investing income (loss) – net		24	1	45	4
Interest incurred		(330)	(296)	(953)	(871)
Interest capitalized		16	5	39	13
Other income (expense) – net		30	(6)	69	5
Income (loss) before income taxes		861	717	2,858	1,589
Less: Provision (benefit) for income taxes		176	96	635	169
Income (Loss) from Continuing Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest		685	621	2,223	1,420
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest		(1)	0	(88)	0
Net income (loss)		684	621	2,135	1,420
Less: Net income (loss) attributable to noncontrolling interests		30	21	94	40
Net income (loss) attributable to The Williams Companies, Inc.		654	600	2,041	1,380
Less: Preferred stock dividends		1	1	2	2
Net income (loss) available to common stockholders		653	599	2,039	1,378
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent		654	599	2,127	1,378
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent		$ (1)	$ 0	$ (88)	$ 0
Basic earnings (loss) per common share:
Income (Loss) from Continuing Operations, Per Basic Share		$ 0.54	$ 0.49	$ 1.74	$ 1.13
Income (Loss) from Discontinued Operations and Disposal of Discontinued Operations, Net of Tax, Per Basic Share		0	0	(0.07)	0
Net income (loss) available to common stockholders		$ 0.54	$ 0.49	$ 1.67	$ 1.13
Weighted-average shares (thousands)		1,216,951	1,218,964	1,218,021	1,218,202
Diluted earnings (loss) per common share:
Income (Loss) from Continuing Operations, Per Diluted Share		$ 0.54	$ 0.49	$ 1.74	$ 1.13
Income (Loss) from Discontinued Operations and Disposal of Discontinued Operations, Net of Tax, Per Diluted Share		0	0	(0.07)	0
Net income (loss) available to common stockholders		$ 0.54	$ 0.49	$ 1.67	$ 1.13
Weighted-average shares (thousands)		1,220,073	1,222,472	1,222,650	1,222,153
Service [Member]
Revenues:
Revenues		$ 1,770	$ 1,685	$ 5,212	$ 4,828
NonRegulated Service Commodity Consideration [Member]
Revenues:
Revenues		45	60	108	223
Product [Member]
Revenues:
Revenues		720	1,260	2,158	3,475
Energy Commodities and Service
Revenues:
Revenues	[1]	24	16	645	(491)
Oil and Gas, Purchased [Member]
Costs and expenses:
Product costs		484	990	1,458	2,650
Natural Gas Purchased For Shrink [Member]
Costs and expenses:
Product costs		$ 31	$ 29	$ 129	$ 99
[1]We record transactions that qualify as 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 on derivatives held for energy trading purposes are presented on a net basis in revenue.

Consolidated Statement of Compr

Consolidated Statement of Comprehensive Income (Loss) (Unaudited) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Comprehensive income (loss):
Net income (loss)	$ 684	$ 621	$ 2,135	$ 1,420
Designated interest rate cash flow hedging activities:
Net unrealized gain (loss) from derivative instruments, net of taxes of $(12) and $(23) in 2023 and $3 and $1 in 2022	36	(8)	72	(3)
Reclassifications into earnings of net derivative instruments (gain) loss, net of taxes of $— and $— in 2023 and $— and $— in 2022	(1)	0	(2)	0
Pension and other postretirement benefits:
Net actuarial gain (loss) arising during the year, net of taxes of $— and $— in 2023 and ($1) and ($1) in 2022	0	2	0	2
Amortization of actuarial (gain) loss and net actuarial loss from settlements included in net periodic benefit cost (credit), net of taxes of $— and $(1) in 2023 and $(1) and ($2) in 2022	1	2	2	7
Other comprehensive income (loss)	36	(4)	72	6
Comprehensive income (loss)	720	617	2,207	1,426
Less: Comprehensive income (loss) attributable to noncontrolling interests	30	21	94	40
Comprehensive income (loss) attributable to The Williams Companies, Inc.	$ 690	$ 596	$ 2,113	$ 1,386

Consolidated Statement of Com_2

Consolidated Statement of Comprehensive Income (Loss) (Parenthetical) (Unaudited) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), after Reclassification, Tax [Abstract]
Energy commodity contracts	$ (12)	$ 3	$ (23)	$ 1
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, Tax	0	0	0	0
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss) Arising During Period, Tax	0	(1)	0	(1)
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, Tax [Abstract]
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, Tax	$ 0	$ (1)	$ (1)	$ (2)

Consolidated Balance Sheet (Una

Consolidated Balance Sheet (Unaudited) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Current assets:
Cash and cash equivalents	$ 2,074	$ 152
Trade accounts and other receivables (net of allowance of $3 at September 30, 2023 and $6 at December 31, 2022)	1,419	2,723
Inventories	266	320
Derivative assets	243	323
Other current assets and deferred charges	254	279
Total current assets	4,256	3,797
Investments	4,998	5,065
Property, plant, and equipment	50,805	47,057
Accumulated depreciation and amortization	(18,177)	(16,168)
Property, plant, and equipment – net	32,628	30,889
Intangible assets – net of accumulated amortization	7,459	7,363
Regulatory assets, deferred charges, and other	1,447	1,319
Total assets	50,788	48,433
Current liabilities:
Accounts payable	1,358	2,327
Derivative liabilities	123	316
Accrued and other current liabilities	1,166	1,270
Commercial paper	0	350
Long-term debt due within one year	2,879	627
Total current liabilities	5,526	4,890
Long-term debt	22,772	21,927
Deferred income tax liabilities	3,496	2,887
Regulatory liabilities, deferred income, and other	4,651	4,684
Contingent liabilities and commitments (Note 9)
Stockholders’ equity:
Preferred stock ($1 par value; 30 million shares authorized at September 30, 2023 and December 31, 2022; 35,000 shares issued at September 30, 2023 and December 31, 2022)	35	35
Common stock ($1 par value; 1,470 million shares authorized at September 30, 2023 and December 31, 2022; 1,256 million shares issued at September 30, 2023 and 1,253 million shares issued at December 31, 2022)	1,256	1,253
Capital in excess of par value	24,562	24,542
Retained deficit	(12,876)	(13,271)
Accumulated other comprehensive income (loss)	48	(24)
Treasury stock, at cost (39 million shares at September 30, 2023 and 35 million shares at December 31, 2022 of common stock)	(1,180)	(1,050)
Total stockholders’ equity	11,845	11,485
Noncontrolling interests in consolidated subsidiaries	2,498	2,560
Total equity	14,343	14,045
Total liabilities and equity	$ 50,788	$ 48,433

Consolidated Balance Sheet (Par

Consolidated Balance Sheet (Parenthetical) (Unaudited) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Statement of Financial Position [Abstract]
Accounts Receivable, Allowance for Credit Loss, Current	$ 3	$ 6
Stockholders’ equity:
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
Common stock, par value of shares authorized	$ 1	$ 1
Common stock, shares authorized	1,470,000,000	1,470,000,000
Common stock, shares issued	1,256,000,000	1,253,000,000
Treasury stock, shares of common stock	39,000,000	35,000,000

Consolidated Statement of Chang

Consolidated Statement of Changes in Equity (Unaudited) - USD ($) $ in Millions	Total	Total Stockholders’ Equity	Preferred Stock	Common Stock	Capital in Excess of Par Value	Retained Deficit	AOCI*	Treasury Stock	Noncontrolling Interests
Period Start at Dec. 31, 2021	$ 14,101	$ 11,423	$ 35	$ 1,250	$ 24,449	$ (13,237)	$ (33)	$ (1,041)	$ 2,678
Net income (loss)	1,420	1,380	0	0	0	1,380	0	0	40
Other comprehensive income (loss)	6	6	0	0	0	0	6	0	0
Dividends, Common Stock, Cash	(1,553)	(1,553)	0	0	0	(1,553)	0	0	0
Dividends and distributions to noncontrolling interests	(141)	0	0	0	0	0	0	0	(141)
Stock-based compensation and related common stock issuances, net of tax	82	82	0	3	79	0	0	0	0
Contributions from noncontrolling interests	15	0	0	0	0	0	0	0	15
Purchases of treasury stock	(9)	(9)	0	0	0	0	0	(9)	0
Other	(11)	(10)	0	0	(1)	(9)	0	0	(1)
Net increase (decrease) in equity	(191)	(104)	0	3	78	(182)	6	(9)	(87)
Period End at Sep. 30, 2022	13,910	11,319	35	1,253	24,527	(13,419)	(27)	(1,050)	2,591
Period Start at Jun. 30, 2022	13,836	11,226	35	1,253	24,500	(13,498)	(23)	(1,041)	2,610
Net income (loss)	621	600	0	0	0	600	0	0	21
Other comprehensive income (loss)	(4)	(4)	0	0	0	0	(4)	0	0
Dividends, Common Stock, Cash	(518)	(518)	0	0	0	(518)	0	0	0
Dividends and distributions to noncontrolling interests	(46)	0	0	0	0	0	0	0	(46)
Stock-based compensation and related common stock issuances, net of tax	28	28	0	0	28	0	0	0	0
Contributions from noncontrolling interests	7	0	0	0	0	0	0	0	7
Purchases of treasury stock	(9)	(9)	0	0	0	0	0	(9)	0
Other	(5)	(4)	0	0	(1)	(3)	0	0	(1)
Net increase (decrease) in equity	74	93	0	0	27	79	(4)	(9)	(19)
Period End at Sep. 30, 2022	13,910	11,319	35	1,253	24,527	(13,419)	(27)	(1,050)	2,591
Period Start at Dec. 31, 2022	14,045	11,485	35	1,253	24,542	(13,271)	(24)	(1,050)	2,560
Net income (loss)	2,135	2,041	0	0	0	2,041	0	0	94
Other comprehensive income (loss)	72	72	0	0	0	0	72	0	0
Dividends, Common Stock, Cash	(1,635)	(1,635)	0	0	0	(1,635)	0	0	0
Dividends and distributions to noncontrolling interests	(174)	0	0	0	0	0	0	0	(174)
Stock-based compensation and related common stock issuances, net of tax	22	22	0	3	19	0	0	0	0
Contributions from noncontrolling interests	18	0	0	0	0	0	0	0	18
Purchases of treasury stock	(130)	(130)	0	0	0	0	0	(130)	0
Other	(10)	(10)	0	0	1	(11)	0	0	0
Net increase (decrease) in equity	298	360	0	3	20	395	72	(130)	(62)
Period End at Sep. 30, 2023	14,343	11,845	35	1,256	24,562	(12,876)	48	(1,180)	2,498
Period Start at Jun. 30, 2023	14,209	11,679	35	1,256	24,538	(12,982)	12	(1,180)	2,530
Net income (loss)	684	654	0	0	0	654	0	0	30
Other comprehensive income (loss)	36	36	0	0	0	0	36	0	0
Dividends, Common Stock, Cash	(544)	(544)	0	0	0	(544)	0	0	0
Dividends and distributions to noncontrolling interests	(62)	0	0	0	0	0	0	0	(62)
Stock-based compensation and related common stock issuances, net of tax	23	23	0	0	23	0	0	0	0
Other	(3)	(3)	0	0	1	(4)	0	0	0
Net increase (decrease) in equity	134	166	0	0	24	106	36	0	(32)
Period End at Sep. 30, 2023	$ 14,343	$ 11,845	$ 35	$ 1,256	$ 24,562	$ (12,876)	$ 48	$ (1,180)	$ 2,498

Consolidated Statement of Cha_2

Consolidated Statement of Changes in Equity (Parenthetical) (Unaudited) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Statement of Stockholders' Equity [Abstract]
Common Stock, Dividends, Per Share, Declared	$ 0.4475	$ 0.425	$ 1.3425	$ 1.275

Consolidated Statement of Cash

Consolidated Statement of Cash Flows (Unaudited) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
OPERATING ACTIVITIES:
Net income (loss)	$ 2,135	$ 1,420
Adjustments to reconcile to net cash provided (used) by operating activities:
Depreciation and amortization	1,542	1,504
Provision (benefit) for deferred income taxes	586	182
Equity (earnings) losses	(434)	(492)
Distributions from equity-method investees	607	688
Net unrealized (gain) loss from derivative instruments	(433)	329
Gain on sale of business	(130)	0
Inventory write-downs	28	76
Amortization of stock-based awards	59	58
Cash provided (used) by changes in current assets and liabilities:
Accounts receivable	1,295	(672)
Inventories	29	(152)
Other current assets and deferred charges	(5)	(62)
Accounts payable	(1,072)	743
Accrued and other current liabilities	(114)	167
Changes in current and noncurrent derivative assets and liabilities	172	86
Other, including changes in noncurrent assets and liabilities	(140)	(205)
Net cash provided (used) by operating activities	4,125	3,670
FINANCING ACTIVITIES:
Proceeds from (payments of) commercial paper – net	(352)	0
Proceeds from long-term debt	2,754	1,752
Payments of long-term debt	(21)	(2,019)
Proceeds from issuance of common stock	8	53
Purchases of treasury stock	(130)	(9)
Common dividends paid	(1,635)	(1,553)
Dividends and distributions paid to noncontrolling interests	(174)	(141)
Contributions from noncontrolling interests	18	15
Payments for debt issuance costs	(21)	(14)
Other – net	(19)	(40)
Net cash provided (used) by financing activities	428	(1,956)
INVESTING ACTIVITIES:
Capital expenditures (1)	(1,845)	(1,447)
Dispositions – net	(33)	(19)
Contributions in aid of construction	20	8
Proceeds from sale of business	348	0
Purchases of businesses, net of cash acquired (Note 3)	(1,024)	(933)
Purchases of and contributions to equity-method investments	(80)	(140)
Other – net	(17)	(4)
Net cash provided (used) by investing activities	(2,631)	(2,535)
Increase (decrease) in cash and cash equivalents	1,922	(821)
Cash and cash equivalents at beginning of year	152	1,680
Cash and cash equivalents at end of period	2,074	859
Additional Cash Flow Elements and Supplemental Cash Flow Information [Abstract]
(1) Increases to property, plant, and equipment	(1,960)	(1,549)
Changes in related accounts payable and accrued liabilities	115	102
Capital expenditures	$ (1,845)	$ (1,447)

General, Description of Busines

General, Description of Business, and Basis of Presentation	9 Months Ended
	Sep. 30, 2023
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, 2022, 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 nine months ended September 30, 2023, there have been $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, Transco, Northwest Pipeline, and MountainWest (see Note 3 – Acquisitions and Divestitures ) , 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 (a consolidated variable interest entity, or VIE), a 50 percent equity-method investment in Gulfstream, and a 60 percent equity-method investment in Discovery. Transmission & Gulf of Mexico also includes natural gas storage facilities and pipelines providing services in north Texas. 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 Northeast JV (a consolidated VIE) which operates in West Virginia, Ohio, and Pennsylvania, a 66 percent interest in Cardinal (a consolidated VIE) which operates in Ohio, a 69 percent equity-method investment in Laurel Mountain, a 50 percent equity-method investment in Blue Racer, and 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, and the Mid-Continent region which includes the Anadarko and Permian basins. This segment also includes our NGL storage facilities, an undivided 50 percent interest in an NGL fractionator near Conway, Kansas, a 50 percent equity-method investment in OPPL, a 50 percent equity-method investment in RMM, a 20 percent equity-method investment in Targa Train 7 (a nonconsolidated VIE), and a 15 percent equity-method investment in Brazos Permian II (a nonconsolidated VIE). Gas & NGL Marketing Services is comprised of our 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.

Variable Interest Entities

Variable Interest Entities	9 Months Ended
	Sep. 30, 2023
Variable Interest Entity Disclosures [Abstract]
Variable Interest Entities [Text Block]	Note 2 – Variable Interest Entities Consolidated VIEs As of September 30, 2023, we consolidated 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: September 30, December 31, (Millions) Assets (liabilities): Cash and cash equivalents $ 29 $ 49 Trade accounts and other receivables – net 195 136 Inventories 6 4 Other current assets and deferred charges 6 7 Property, plant, and equipment – net 5,090 5,154 Intangible assets – net of accumulated amortization 2,077 2,158 Regulatory assets, deferred charges, and other 31 29 Accounts payable (97) (76) Accrued and other current liabilities (23) (34) Regulatory liabilities, deferred income, and other (273) (275) Nonconsolidated VIEs Targa Train 7 We own a 20 percent interest in Targa Train 7, which provides fractionation services at Mont Belvieu, Texas, and is a VIE due primarily to our limited participating rights as the minority equity holder. At September 30, 2023, the carrying value of our investment in Targa Train 7 was $44 million. Our maximum exposure to loss is limited to the carrying value of our investment. Brazos Permian II We own a 15 percent interest in Brazos Permian II, which provides gathering and processing services in the Delaware basin and is a VIE due primarily to our limited participating rights as the minority equity holder. At September 30, 2023, the carrying value of our investment in Brazos Permian II was $23 million. Our maximum exposure to loss is limited to the carrying value of our investment.

Acquisitions and Divestitures

Acquisitions and Divestitures	9 Months Ended
	Sep. 30, 2023
Business Combinations [Abstract]
Acquisitions and Divestitures [Text Block]	Note 3 – Acquisitions and Divestitures 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 $130 million in the third quarter of 2023 in our Transmission & Gulf of Mexico segment. The gain is included 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. MountainWest Acquisition On February 14, 2023, we closed on the acquisition of 100 percent of MountainWest, which includes FERC-regulated interstate natural gas pipeline systems and natural gas storage capacity, 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. The $1.024 billion Purchases of businesses, net of cash acquired in our Consolidated Statement of Cash Flows includes the cash purchase price reduced for post-closing adjustments and the cash acquired as presented in the preliminary 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. During the period from the acquisition date of February 14, 2023 to September 30, 2023, the operations acquired in the MountainWest Acquisition contributed Revenues of $156 million and Modified EBITDA (as defined in Note 10 – Segment Disclosures) of $78 million, which includes $20 million of transition-related costs. Acquisition-related costs for the MountainWest Acquisition of $15 million are reported within our Transmission & Gulf of Mexico segment and included in Selling, general, and administrative expenses in our Consolidated Statement of Income during 2023. We accounted for the MountainWest 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 techniques used consisted of depreciated replacement costs for non-regulated 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 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 preliminary allocation of the acquisition date fair value of the major classes of the assets acquired, which are included in our Transmission & Gulf of Mexico segment, and liabilities assumed at February 14, 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 long-term debt; 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 equals contractual amounts receivable. After the March 31, 2023, financial statements were issued, we identified adjustments to the preliminary purchase price allocation, primarily resulting in an increase of $19 million in trade accounts and other receivables and decreases of $72 million in property, plant, and equipment and $60 million in other noncurrent liabilities. (Millions) Cash and cash equivalents $ 23 Trade accounts and other receivables 33 Other current assets 26 Investments 22 Property, plant, and equipment – net 1,020 Other noncurrent assets 32 Total identifiable assets acquired $ 1,156 Current liabilities $ (47) Long-term debt (see Note 6) (365) Other noncurrent liabilities (95) Total liabilities assumed $ (507) Net identifiable assets acquired $ 649 Goodwill included in Intangible assets – net of accumulated amortization 398 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. Goodwill is included within Intangible assets – net of accumulated amortization in our Consolidated Balance Sheet and represents the excess of the consideration 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. Trace Acquisition On April 29, 2022, we closed on the acquisition of 100 percent of Gemini Arklatex, LLC through which we acquired the Haynesville Shale region gas gathering and related assets of Trace for $972 million of cash funded with cash on hand and proceeds from issuance of commercial paper. The purpose of the Trace Acquisition was to expand our footprint into the east Texas area of the Haynesville Shale region, increasing in-basin scale in one of the largest growth basins in the country. During the period from the acquisition date of April 29, 2022 to December 31, 2022, the operations acquired in the Trace Acquisition contributed Revenues of $148 million and Modified EBITDA of $73 million. Acquisition-related costs for the Trace Acquisition of $8 million are reported within our West segment and were included in Selling, general, and administrative expenses in our Consolidated Statement of Income during 2022. We accounted for the Trace Acquisition as a business combination. The following table presents the allocation of the acquisition date fair value of the major classes of the assets acquired, which are included in our West segment, and liabilities assumed at April 29, 2022. The fair value of accounts receivable acquired equals contractual amounts receivable. The valuation techniques used consisted of the income approach (excess earnings method) for valuation of intangible assets and depreciated replacement costs for property, plant, and equipment. (Millions) Cash and cash equivalents $ 39 Trade accounts and other receivables 18 Property, plant, and equipment – net 448 Intangible assets – net of accumulated amortization 472 Other noncurrent assets 20 Total assets acquired $ 997 Accounts payable $ (12) Accrued and other current liabilities (5) Other noncurrent liabilities (8) Total liabilities assumed $ (25) Net assets acquired $ 972 Other intangible assets Other intangible assets recognized in the Trace Acquisition are related to contractual customer relationships from gas gathering 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 2 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 19 years. Supplemental Pro Forma The following pro forma Revenues and Net income (loss) attributable to The Williams Companies, Inc. for the three months ended September 30, 2022, and nine months ended September 30, 2023 and 2022, are presented as if the MountainWest Acquisition had been completed on January 1, 2022, and the Trace Acquisition had been completed on January 1, 2021. These pro forma amounts are not necessarily indicative of what the actual results would have been if the MountainWest Acquisition and Trace Acquisition 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 transaction or the potential costs to achieve these cost savings, operating synergies, and revenue enhancements. Three Months Ended September 30, 2022 As Reported Pro Forma MountainWest Pro Forma Combined (Millions) Revenues $ 3,021 $ 63 $ 3,084 Net income (loss) attributable to The Williams Companies, Inc. 600 12 612 Nine Months Ended September 30, 2023 As Reported Pro Forma MountainWest (1) Pro Forma Combined (Millions) Revenues $ 8,123 $ 35 $ 8,158 Net income (loss) attributable to The Williams Companies, Inc. 2,041 6 2,047 Nine Months Ended September 30, 2022 As Reported Pro Forma MountainWest Pro Forma Trace (2) Pro Forma Combined (Millions) Revenues $ 8,035 $ 192 $ 45 $ 8,272 Net income (loss) attributable to The Williams Companies, Inc. 1,380 43 18 1,441 (1) Excludes results from operations acquired in the MountainWest Acquisition for the period beginning on the acquisition date of February 14, 2023, as these results are included in the amounts as reported. (2) Excludes results from operations acquired in the Trace Acquisition for the period beginning on the acquisition date of April 29, 2022, as these results are included in the amounts as reported. NorTex Asset Purchase On August 31, 2022, we purchased a group of assets in north Texas, primarily natural gas storage facilities and pipelines, from NorTex Midstream Holdings, LLC for approximately $424 million. These assets are included in our Transmission & Gulf of Mexico segment.

Revenue Recognition

Revenue Recognition	9 Months Ended
	Sep. 30, 2023
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 Midstream West Midstream Gas & NGL Marketing Services Other Eliminations Total (Millions) Three Months Ended September 30, 2023 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 841 $ — $ — $ — $ — $ — $ (18) $ 823 Gathering, processing, transportation, fractionation, and storage: Monetary consideration — 121 450 368 — — (41) 898 Commodity consideration — 11 — 34 — — — 45 Other 5 2 22 2 — — (3) 28 Total service revenues 846 134 472 404 — — (62) 1,794 Product sales 35 31 27 112 1,189 117 (244) 1,267 Total revenues from contracts with customers 881 165 499 516 1,189 117 (306) 3,061 Other revenues (1) 5 4 6 17 697 13 (2) 740 Other adjustments (2) — — — — (1,328) — 86 (1,242) Total revenues $ 886 $ 169 $ 505 $ 533 $ 558 $ 130 $ (222) $ 2,559 Three Months Ended September 30, 2022 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 794 $ — $ — $ — $ — $ — $ (18) $ 776 Gathering, processing, transportation, fractionation, and storage: Monetary consideration (3) — 104 391 420 — — (51) 864 Commodity consideration — 11 2 47 — — — 60 Other (3) 3 4 20 2 1 — (4) 26 Total service revenues 797 119 413 469 1 — (73) 1,726 Product sales 81 51 40 245 3,109 238 (523) 3,241 Total revenues from contracts with customers 878 170 453 714 3,110 238 (596) 4,967 Other revenues (1) 3 3 6 (6) 2,607 (23) (1) 2,589 Other adjustments (2) — — — — (4,779) — 244 (4,535) Total revenues $ 881 $ 173 $ 459 $ 708 $ 938 $ 215 $ (353) $ 3,021 Regulated Interstate Transportation & Storage Gulf of Mexico Midstream & Storage Northeast Midstream West Midstream Gas & NGL Marketing Services Other Eliminations Total (Millions) Nine Months Ended September 30, 2023 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 2,480 $ — $ — $ — $ — $ — $ (41) $ 2,439 Gathering, processing, transportation, fractionation, and storage: Monetary consideration — 334 1,334 1,070 — — (130) 2,608 Commodity consideration — 29 3 76 — — — 108 Other 14 10 67 8 1 — (11) 89 Total service revenues 2,494 373 1,404 1,154 1 — (182) 5,244 Product sales 114 91 104 287 3,519 302 (686) 3,731 Total revenues from contracts with customers 2,608 464 1,508 1,441 3,520 302 (868) 8,975 Other revenues (1) 26 11 20 95 3,240 36 (2) 3,426 Other adjustments (2) — — — — (4,566) — 288 (4,278) Total revenues $ 2,634 $ 475 $ 1,528 $ 1,536 $ 2,194 $ 338 $ (582) $ 8,123 Nine Months Ended September 30, 2022 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 2,343 $ — $ — $ — $ — $ — $ (54) $ 2,289 Gathering, processing, transportation, fractionation, and storage: Monetary consideration (3) — 277 1,127 1,122 — — (117) 2,409 Commodity consideration — 54 12 157 — — — 223 Other (3) 8 9 62 8 2 — (13) 76 Total service revenues 2,351 340 1,201 1,287 2 — (184) 4,997 Product sales 140 215 110 684 8,422 522 (1,442) 8,651 Total revenues from contracts with customers 2,491 555 1,311 1,971 8,424 522 (1,626) 13,648 Other revenues (1) 8 7 19 (14) 5,838 (72) (10) 5,776 Other adjustments (2) — — — — (11,911) — 522 (11,389) Total revenues $ 2,499 $ 562 $ 1,330 $ 1,957 $ 2,351 $ 450 $ (1,114) $ 8,035 ______________________________ (1) Revenues not derived from contracts with customers primarily consist of physical product sales related to derivative contracts, realized and unrealized gains and losses associated with our derivative contracts, which are reported in Net gain (loss) on commodity derivatives in the 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. (3) Certain contractual reimbursements of operating and maintenance costs previously included in Other are now presented in Monetary consideration as they were received in exchange for providing gas gathering and processing services. Contract Assets The following table presents a reconciliation of our contract assets: Three Months Ended Nine Months Ended 2023 2022 2023 2022 (Millions) Balance at beginning of period $ 56 $ 48 $ 29 $ 22 Revenue recognized in excess of amounts invoiced 45 54 133 158 Minimum volume commitments invoiced (28) (41) (89) (119) Balance at end of period $ 73 $ 61 $ 73 $ 61 Contract Liabilities The following table presents a reconciliation of our contract liabilities: Three Months Ended Nine Months Ended 2023 2022 2023 2022 (Millions) Balance at beginning of period $ 1,039 $ 1,115 $ 1,043 $ 1,126 Payments received and deferred 40 34 164 144 Significant financing component 3 2 7 7 Contract liability acquired (disposed) – net (2) 2 3 2 Recognized in revenue (68) (71) (205) (197) Balance at end of period $ 1,012 $ 1,082 $ 1,012 $ 1,082 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 September 30, 2023, 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 September 30, 2023, 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 September 30, 2023. Contract Liabilities Remaining Performance Obligations (Millions) 2023 (three months) $ 95 $ 950 2024 (one year) 144 3,746 2025 (one year) 123 3,413 2026 (one year) 119 3,105 2027 (one year) 109 2,579 Thereafter 422 15,300 Total $ 1,012 $ 29,093 Accounts Receivable The following is a summary of our Trade accounts and other receivables – net : September 30, 2023 December 31, 2022 (Millions) Accounts receivable related to revenues from contracts with customers $ 1,145 $ 1,771 Receivables from derivatives 207 889 Other accounts receivable 67 63 Trade accounts and other receivables – net $ 1,419 $ 2,723

Provision (Benefit) for Income

Provision (Benefit) for Income Taxes	9 Months Ended
	Sep. 30, 2023
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 Nine Months Ended 2023 2022 2023 2022 (Millions) Current: Federal $ 10 $ — $ 10 $ (27) State 7 4 11 14 17 4 21 (13) Deferred: Federal 169 163 555 247 State (10) (71) 59 (65) 159 92 614 182 Provision (benefit) for income taxes $ 176 $ 96 $ 635 $ 169 The effective income tax rate for the total provision (benefit) for the three months ended September 30, 2023, is less than the federal statutory rate primarily due to a decrease in our estimate of the deferred state income tax rate. The effective income tax rate for the total provision (benefit) for the nine months ended September 30, 2023, is greater than the federal statutory rate primarily due to the effect of state income taxes. The effective income tax rate for the total provision (benefit) for the three months ended September 30, 2022, is less than the federal statutory rate primarily due to the effect of state income taxes, including a $92 million state income tax benefit related to a decrease in our estimate of the deferred state income tax rate (net of federal effect) driven primarily by the enacted decline in the Pennsylvania state income tax rate over the next several years, partially offset by a $23 million unfavorable revision to a state net operating loss carryforward (net of federal benefit). The effective income tax rate for the total provision (benefit) for the nine months ended September 30, 2022, is less than the federal statutory rate primarily due to the release of a valuation allowance on foreign tax credits, the effect of state income taxes, including a $92 million state income tax benefit related to a decrease in our estimate of the deferred state income tax rate (net of federal effect), and federal settlements. We have a valuation allowance on certain deferred income tax assets that serves to reduce those assets to amounts that will, more likely than not, be realized. We must evaluate whether we will ultimately realize these tax benefits considering all available positive and negative evidence, which incorporates management’s assessment of available tax planning strategies, future reversals of existing taxable temporary differences, and the availability and character of future taxable income. In the second quarter of 2022, we released $88 million of valuation allowance upon determining we expect to utilize an additional $70 million of foreign tax credits and $18 million related to various state net operating loss carryforwards and state credits. During the second quarter of 2022, we finalized settlements for 2011 through 2014 on certain contested matters with the IRS. This settlement resulted in decreasing our uncertain tax positions of approximately $46 million, which favorably impacted the Provision (benefit) for income taxes .

Debt and Banking Arrangements

Debt and Banking Arrangements	9 Months Ended
	Sep. 30, 2023
Debt Disclosure [Abstract]
Debt and Banking Arrangements [Text Block]	Note 6 – Debt and Banking Arrangements Long-Term Debt Our senior unsecured public debt issuances for 2023 are as follows: Issue Date Maturity Date Amount Rate (Millions) March 2, 2023 March 2, 2026 $ 750 5.40% March 2, 2023 March 15, 2033 $ 750 5.65% August 10, 2023* March 2, 2026 $ 350 5.40% August 10, 2023 August 15, 2028 $ 900 5.30% *Additional issuance of the 5.40 percent senior notes due 2026 issued on March 2, 2023, and will trade interchangeably with such notes. As a result of the MountainWest Acquisition on February 14, 2023, our Consolidated Balance Sheet now includes $100 million of 3.53 percent senior unsecured notes due January 31, 2028, $150 million of 3.91 percent senior unsecured notes due January 31, 2038, and $180 million of 4.875 percent senior unsecured notes due December 1, 2041. The acquisition date fair value reflects a $65 million reduction to the aggregate principal amount. (See Note 3 – Acquisitions and Divestitures.) Commercial Paper Program At September 30, 2023, no commercial paper was outstanding under our $3.5 billion commercial paper program. Credit Facility In the second quarter of 2023, the maturity date of our October 2021 amended and restated credit agreement (Credit Agreement) was extended one year and now expires October 8, 2027. One participating lender, Credit Suisse AG, New York Branch, with a commitment of approximately $194 million did not extend their commitment beyond October 8, 2026. The amended Credit Agreement allows the co-borrowers to request up to two extensions of the maturity date each for an additional one-year period to allow a maturity date as late as October 8, 2029, under certain circumstances. Additionally, the amended Credit Agreement replaces the London Interbank Offered Rate with the Term Secured Overnight Financing Rate as the benchmark interest rate index. September 30, 2023 Stated Capacity Outstanding (Millions) Long-term credit facility (1) $ 3,750 $ — Letters of credit under certain bilateral bank agreements 10 (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 Gua

Fair Value Measurements and Guarantees	9 Months Ended
	Sep. 30, 2023
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 September 30, 2023: Measured on a recurring basis: ARO Trust investments $ 247 $ 247 $ 247 $ — $ — Commodity derivative assets (1) 170 170 90 75 5 Commodity derivative liabilities (1) (373) (373) — (347) (26) Interest rate derivatives 66 66 — 66 — Other financial assets (liabilities) – net 4 4 — 4 — Additional disclosures: Long-term debt, including current portion (25,651) (23,895) — (23,895) — Guarantees (37) (29) — (13) (16) Assets (liabilities) at December 31, 2022: Measured on a recurring basis: ARO Trust investments $ 230 $ 230 $ 230 $ — $ — Commodity derivative assets (2) 166 166 20 132 14 Commodity derivative liabilities (2) (810) (810) (22) (718) (70) Other financial assets (liabilities) – net (5) (5) — (5) — Additional disclosures: Long-term debt, including current portion (22,554) (21,569) — (21,569) — Guarantees (38) (25) — (9) (16) (1) Commodity derivative assets and liabilities exclude $30 million of net cash collateral in Level 1. (2) Commodity derivative assets and liabilities exclude $202 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) on 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: During 2023, we entered into forward starting interest rate swap agreements with notional amounts totaling $750 million. 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 will be amortized to earnings as a component of Interest incurred in our Consolidated Statement of Income . These forward starting interest rate swaps are reported in Derivative assets 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, which are 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 $23 million at September 30, 2023. 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	9 Months Ended
	Sep. 30, 2023
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 September 30, 2023, 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 848,556,144 Central Hub Risk - Henry Hub Natural Gas MMBtu (68,125,793) Basis Risk Natural Gas MMBtu (29,104,256) Central Hub Risk - Mont Belvieu Natural Gas Liquids Barrels (669,952) Basis Risk Natural Gas Liquids Barrels (605,000) Central Hub Risk - WTI Crude Oil Barrels (234,600) Derivative Financial Statement Presentation The fair value of commodity derivatives, which are not designated as hedging instruments for accounting purposes, was reflected as follows: September 30, December 31, Derivative Category Assets (Liabilities) Assets (Liabilities) (Millions) Current $ 457 $ (434) $ 1,099 $ (1,278) Noncurrent 172 (398) 269 (734) Total derivatives $ 629 $ (832) $ 1,368 $ (2,012) Counterparty and collateral netting offset (428) 458 (1,034) 1,236 Amounts recognized in our Consolidated Balance Sheet $ 201 $ (374) $ 334 $ (776) The pre-tax effects of commodity derivative instruments in our Consolidated Statement of Income were as follows: Gain (Loss) Three Months Ended Nine Months Ended 2023 2022 2023 2022 (Millions) Net gain (loss) on commodity derivatives within Total revenues : Realized commodity derivatives not designated as hedging instruments $ (8) $ (13) $ 169 $ (145) Unrealized commodity derivatives not designated as hedging instruments 32 29 476 (346) $ 24 $ 16 $ 645 $ (491) Net gain (loss) on commodity derivatives within Net processing commodity expenses : Realized commodity derivatives not designated as hedging instruments $ — $ 6 $ (3) $ 12 Unrealized commodity derivatives not designated as hedging instruments (9) 6 (43) 17 $ (9) $ 12 $ (46) $ 29 Total net gain (loss) on commodity derivatives $ 15 $ 28 $ 599 $ (462) 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 September 30, 2023, the contractually required collateral in the event of a credit rating downgrade to non-investment grade status was $9 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

Contingencies

Contingencies	9 Months Ended
	Sep. 30, 2023
Commitments and Contingencies Disclosure [Abstract]
Contingencies [Text Block]	Note 9 – Contingencies Alaska Refinery Contamination Litigation We are involved in litigation arising from our ownership and operation of the North Pole Refinery in North Pole, Alaska, from 1980 until 2004, through our wholly owned subsidiaries Williams Alaska Petroleum Inc. (WAPI) and MAPCO Inc. We sold the refinery to Flint Hills Resources Alaska, LLC (FHRA), a subsidiary of Koch Industries, Inc., in 2004. The litigation involves three cases, with filing dates ranging from 2010 to 2014. The actions primarily arise from sulfolane contamination allegedly emanating from the refinery. A putative class action lawsuit was filed by James West in 2010 naming us, WAPI, and FHRA as defendants. We and FHRA filed claims against each other seeking, among other things, contractual indemnification alleging that the other party caused the sulfolane contamination. In 2011, we and FHRA settled the claim with James West. Certain claims by FHRA against us were resolved by the Alaska Supreme Court in our favor. FHRA’s claims against us for contractual indemnification and statutory claims for damages related to off-site sulfolane were remanded to the Alaska Superior Court. The State of Alaska filed its action in March 2014, seeking damages. The City of North Pole (North Pole) filed its lawsuit in November 2014, seeking past and future damages, as well as punitive damages. Both we and WAPI asserted counterclaims against the State of Alaska and North Pole, and cross-claims against FHRA. FHRA has also filed cross-claims against us. The underlying factual basis and claims in the cases are similar and may duplicate exposure. As such, in February 2017, the three cases were consolidated into one action in state court containing the remaining claims from the James West case and those of the State of Alaska and North Pole. The State of Alaska later announced the discovery of additional contaminants per- and polyfluoralkyl (PFOS and PFOA) offsite of the refinery, and the court permitted the State of Alaska to amend its complaint to add a claim for offsite PFOS/PFOA contamination. The court subsequently remanded the offsite PFOS/PFOA claims to the Alaska Department of Environmental Conservation for investigation and stayed the claims pending their potential resolution at the administrative agency. Several trial dates encompassing all three cases have been scheduled and stricken. In the summer of 2019, the court deconsolidated the cases for purposes of trial. A bench trial on all claims except North Pole’s claims began in October 2019. In January 2020, the Alaska Superior Court issued its Memorandum of Decision finding in favor of the State of Alaska and FHRA, with the total incurred and potential future damages estimated to be $86 million, plus fees and interest. The court found that FHRA is not entitled to contractual indemnification from us because FHRA contributed to the sulfolane contamination. On March 23, 2020, the court entered final judgment in the case. Filing deadlines were stayed until May 1, 2020. However, on April 21, 2020, we filed a Notice of Appeal. We also filed post-judgment motions including a Motion for New Trial and a Motion to Alter or Amend the Judgment. These post-trial motions were resolved with the court’s denial of the last motion on June 11, 2020. Our Statement of Points on Appeal was filed on July 13, 2020. On June 22, 2020, the court stayed the North Pole’s case pending resolution of the appeal in the State of Alaska and FHRA case. On December 23, 2020, we filed our opening brief on appeal. Oral argument was held on December 15, 2021. On May 26, 2023, the Alaska Supreme Court issued its Opinion substantially affirming the Superior Court’s decision. On July 18, 2023, the Superior Court granted our stay of execution of the monetary judgment portions of the judgment while we seek review before the United States Supreme Court. On September 25, 2023, we filed a Petition for a Writ of Certiorari with the United States Supreme Court. During the second quarter of 2023, as a result of the Alaska Supreme Court’s Opinion, we recorded a pre-tax charge of $115 million to Income (loss) from discontinued operations to fully accrue for the judgment, plus the related fees and interest. An additional $1 million of pre-tax interest expense was recorded in the third quarter of 2023. 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. Litigation Against Energy Transfer and Related Parties On April 6, 2016, we filed suit in Delaware Chancery Court against Energy Transfer Equity, L.P. (Energy Transfer) and LE GP, LLC (the general partner for Energy Transfer) alleging willful and material breaches of the Agreement and Plan of Merger (ETE Merger Agreement) with Energy Transfer resulting from the private offering by Energy Transfer on March 8, 2016, of Series A Convertible Preferred Units (Special Offering) to certain Energy Transfer insiders and other accredited investors. The suit seeks, among other things, an injunction ordering the defendants to unwind the Special Offering and to specifically perform their obligations under the ETE Merger Agreement. On April 19, 2016, we filed an amended complaint seeking the same relief. On May 3, 2016, Energy Transfer and LE GP, LLC filed an answer and counterclaims. On May 13, 2016, we filed a separate complaint in Delaware Chancery Court against Energy Transfer, LE GP, LLC and the other Energy Transfer affiliates that are parties to the ETE Merger Agreement, alleging material breaches of the ETE Merger Agreement for failing to cooperate and use necessary efforts to obtain a tax opinion required under the ETE Merger Agreement (Tax Opinion) and for otherwise failing to use necessary efforts to consummate the merger under the ETE Merger Agreement wherein we would be merged with and into the newly formed Energy Transfer Corp LP (ETC) (ETC Merger). The suit sought, among other things, a declaratory judgment and injunction preventing Energy Transfer from terminating or otherwise avoiding its obligations under the ETE Merger Agreement due to any failure to obtain the Tax Opinion. The Court of Chancery coordinated the Special Offering and Tax Opinion suits. On May 20, 2016, the Energy Transfer defendants filed amended affirmative defenses and verified counterclaims in the Special Offering and Tax Opinion suits, alleging certain breaches of the ETE Merger Agreement by us and seeking, among other things, a declaration that we were not entitled to specific performance, that Energy Transfer could terminate the ETC Merger, and that Energy Transfer is entitled to a $1.48 billion termination fee. On June 24, 2016, following a two-day trial, the court issued a Memorandum Opinion and Order denying our requested relief in the Tax Opinion suit. The court did not rule on the substance of our claims related to the Special Offering or on the substance of Energy Transfer’s counterclaims. On June 27, 2016, we filed an appeal of the court’s decision with the Supreme Court of Delaware, seeking reversal and remand to pursue damages. On March 23, 2017, the Supreme Court of Delaware affirmed the Court of Chancery’s ruling. On March 30, 2017, we filed a motion for reargument with the Supreme Court of Delaware, which was denied on April 5, 2017. On September 16, 2016, we filed an amended complaint with the Court of Chancery seeking damages for breaches of the ETE Merger Agreement by defendants. On September 23, 2016, Energy Transfer filed a second amended and supplemental affirmative defenses and verified counterclaim with the Court of Chancery seeking, among other things, payment of the $1.48 billion termination fee due to our alleged breaches of the ETE Merger Agreement. On December 1, 2017, the court granted our motion to dismiss certain of Energy Transfer’s counterclaims, including its claim seeking payment of the $1.48 billion termination fee. On December 8, 2017, Energy Transfer filed a motion for reargument, which the Court of Chancery denied on April 16, 2018. Trial was held May 10 through May 17, 2021. On December 29, 2021, the court entered judgment in our favor in the amount of $410 million, plus interest at the contractual rate, and our reasonable attorneys’ fees and expenses. On September 21, 2022, the court entered a final order and judgment awarding us the termination fee, attorney’s fees, expenses, and interest in the amount of $602 million plus additional interest starting September 17, 2022. Attorney fees of approximately $90 million will be payable upon receipt of the judgment amount. Energy Transfer appealed to the Delaware Supreme Court. The Delaware Supreme Court held oral argument en banc on July 12, 2023. On October 10, 2023, the Delaware Supreme Court issued an opinion affirming the Court of Chancery’s ruling. On October 25, 2023, Energy Transfer filed a motion for reargument with the Delaware Supreme Court. 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 September 30, 2023, we have accrued liabilities totaling $51 million for these matters, as discussed below. Estimates of the most likely costs of cleanup are generally based on completed assessment studies, preliminary results of studies, or our experience with other similar cleanup operations. At September 30, 2023, certain assessment studies were still in process for which the ultimate outcome may yield different estimates of most likely costs. Therefore, the actual costs incurred will depend on the final amount, type, and extent of contamination discovered at these sites, the final cleanup standards mandated by the EPA or other governmental authorities, and other factors. 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 September 30, 2023, we have accrued liabilities of $13 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 September 30, 2023, we have accrued liabilities totaling $10 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. Our responsibilities relate to the operations of the assets and businesses described below. • Former agricultural fertilizer and chemical operations and former retail petroleum and refining operations; • Former petroleum products and natural gas pipelines; • Former petroleum refining facilities; • Former exploration and production and mining operations; • Former electricity and natural gas marketing and trading operations. At September 30, 2023, we have accrued environmental liabilities of $28 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. The indemnities generally relate to breach of warranties, tax, historic litigation, personal injury, property damage, environmental matters, right of way, and other representations that we have provided. At September 30, 2023, other than as previously disclosed, we are not aware of any material claims against us involving the above-described indemnities; thus, we do not expect any of the indemnities provided pursuant to the sales agreements to have a material impact on our future financial position. 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

Segment Disclosures

Segment Disclosures	9 Months Ended
	Sep. 30, 2023
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 incurred, net of interest capitalized; ◦ 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) on commodity derivatives within Total revenues, unrealized net gain (loss) on commodity derivatives within Net processing commodity expenses for our Gas & NGL Marketing segment, and charges associated with lower of cost or net realizable value adjustments to our Gas & NGL Marketing segment inventory. These charges are reflected in Product sales and Product costs in our Consolidated Statement of Income. The following table reflects the reconciliation of Modified EBITDA to Net income (loss) as reported in our Consolidated Statement of Income. Three Months Ended Nine Months Ended 2023 2022 2023 2022 (Millions) Modified EBITDA by segment: Transmission & Gulf of Mexico $ 881 $ 638 $ 2,327 $ 1,987 Northeast G&P 454 464 1,439 1,332 West 315 337 931 885 Gas & NGL Marketing Services 43 20 678 (249) Other 81 140 196 284 1,774 1,599 5,571 4,239 Accretion expense associated with asset retirement obligations for nonregulated operations (14) (12) (43) (36) Depreciation and amortization expenses (521) (500) (1,542) (1,504) Equity earnings (losses) 127 193 434 492 Other investing income (loss) – net 24 1 45 4 Proportional Modified EBITDA of equity-method investments (215) (273) (693) (748) Interest expense (314) (291) (914) (858) (Provision) benefit for income taxes (176) (96) (635) (169) Income (loss) from discontinued operations (1) — (88) — Net income (loss) $ 684 $ 621 $ 2,135 $ 1,420 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 September 30, 2023 Segment revenues: Service revenues External $ 953 $ 473 $ 340 $ — $ 4 $ — $ 1,770 Internal 25 5 34 — — (64) — Total service revenues 978 478 374 — 4 (64) 1,770 Total service revenues – commodity consideration 11 — 34 — — — 45 Product sales External 35 13 14 619 39 — 720 Internal 28 14 98 (63) 79 (156) — Total product sales 63 27 112 556 118 (156) 720 Net gain (loss) on commodity derivatives Realized 1 — 13 (31) 9 — (8) Unrealized — — — 33 (1) — 32 Total net gain (loss) on commodity derivatives (2) 1 — 13 2 8 — 24 Total revenues $ 1,053 $ 505 $ 533 $ 558 $ 130 $ (220) $ 2,559 Three Months Ended September 30, 2022 Segment revenues: Service revenues External $ 880 $ 408 $ 393 $ 1 $ 3 $ — $ 1,685 Internal 30 9 32 — 3 (74) — Total service revenues 910 417 425 1 6 (74) 1,685 Total service revenues – commodity consideration 11 2 47 — — — 60 Product sales External 78 11 61 1,079 31 — 1,260 Internal 43 29 184 (195) 207 (268) — Total product sales 121 40 245 884 238 (268) 1,260 Net gain (loss) on commodity derivatives Realized — — (9) 54 (58) — (13) Unrealized 1 — — (1) 29 — 29 Total net gain (loss) on commodity derivatives (2) 1 — (9) 53 (29) — 16 Total revenues $ 1,043 $ 459 $ 708 $ 938 $ 215 $ (342) $ 3,021 Transmission &Gulf of Mexico Northeast G&P West Gas & NGL Marketing Services (1) Other Eliminations Total (Millions) Nine Months Ended September 30, 2023 Segment revenues: Service revenues External $ 2,801 $ 1,396 $ 1,002 $ 1 $ 12 $ — $ 5,212 Internal 73 25 86 — — (184) — Total service revenues 2,874 1,421 1,088 1 12 (184) 5,212 Total service revenues – commodity consideration 29 3 76 — — — 108 Product sales External 116 32 43 1,882 85 — 2,158 Internal 81 72 244 (224) 218 (391) — Total product sales 197 104 287 1,658 303 (391) 2,158 Net gain (loss) on commodity derivatives Realized 2 — 85 41 41 — 169 Unrealized — — — 494 (18) — 476 Total net gain (loss) on commodity derivatives (2) 2 — 85 535 23 — 645 Total revenues $ 3,102 $ 1,528 $ 1,536 $ 2,194 $ 338 $ (575) $ 8,123 Nine Months Ended September 30, 2022 Segment revenues: Service revenues External $ 2,563 $ 1,178 $ 1,073 $ 2 $ 12 $ — $ 4,828 Internal 88 30 66 — 10 (194) — Total service revenues 2,651 1,208 1,139 2 22 (194) 4,828 Total service revenues – commodity consideration 54 12 157 — — — 223 Product sales External 187 24 111 3,073 80 — 3,475 Internal 147 86 573 (349) 442 (899) — Total product sales 334 110 684 2,724 522 (899) 3,475 Net gain (loss) on commodity derivatives Realized — — (23) (18) (104) — (145) Unrealized 1 — — (357) 10 — (346) Total net gain (loss) on commodity derivatives (2) 1 — (23) (375) (94) — (491) Total revenues $ 3,040 $ 1,330 $ 1,957 $ 2,351 $ 450 $ (1,093) $ 8,035 _____________ (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 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 on derivatives held for energy trading purposes are presented on a net basis in revenue.

Subsequent Events

Subsequent Events	9 Months Ended
	Sep. 30, 2023
Subsequent Events [Abstract]
Subsequent Events [Text Block]	Note 11 – Subsequent Events DJ Basin Acquisitions In October 2023, we agreed to acquire Cureton Front Range, LLC, whose operations are located in the Denver-Julesberg Basin (DJ Basin), for $560 million, subject to working capital and post-closing adjustments. Concurrently, we entered into an agreement to purchase an additional 50 percent interest in our equity-method investment RMM for $714 million. Upon closing, we will own 100 percent of and will consolidate RMM. These acquisitions are expected to close in the fourth quarter of 2023 and will expand our gathering and processing footprint in the DJ Basin. The Cureton Front Range, LLC acquisition is expected to be funded with available sources of short-term liquidity. Substantially all of the RMM purchase price is not due to the seller and does not accrue interest until the fourth quarter of 2024. These businesses will be reported within the West segment.

Pay vs Performance Disclosure

Pay vs Performance Disclosure - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Pay vs Performance Disclosure
Net Income (Loss) Attributable to Parent	$ 654	$ 600	$ 2,041	$ 1,380

Insider Trading Arrangements

Insider Trading Arrangements	3 Months Ended
	Sep. 30, 2023
Trading Arrangements, by Individual
Rule 10b5-1 Arrangement Adopted	false
Non-Rule 10b5-1 Arrangement Adopted	false
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false

Variable Interest Entities (Tab

Variable Interest Entities (Tables)	9 Months Ended
	Sep. 30, 2023
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: September 30, December 31, (Millions) Assets (liabilities): Cash and cash equivalents $ 29 $ 49 Trade accounts and other receivables – net 195 136 Inventories 6 4 Other current assets and deferred charges 6 7 Property, plant, and equipment – net 5,090 5,154 Intangible assets – net of accumulated amortization 2,077 2,158 Regulatory assets, deferred charges, and other 31 29 Accounts payable (97) (76) Accrued and other current liabilities (23) (34) Regulatory liabilities, deferred income, and other (273) (275)

Acquisitions and Divestitures (

Acquisitions and Divestitures (Tables)	9 Months Ended
	Sep. 30, 2023
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Information	The following pro forma Revenues and Net income (loss) attributable to The Williams Companies, Inc. for the three months ended September 30, 2022, and nine months ended September 30, 2023 and 2022, are presented as if the MountainWest Acquisition had been completed on January 1, 2022, and the Trace Acquisition had been completed on January 1, 2021. These pro forma amounts are not necessarily indicative of what the actual results would have been if the MountainWest Acquisition and Trace Acquisition 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 transaction or the potential costs to achieve these cost savings, operating synergies, and revenue enhancements. Three Months Ended September 30, 2022 As Reported Pro Forma MountainWest Pro Forma Combined (Millions) Revenues $ 3,021 $ 63 $ 3,084 Net income (loss) attributable to The Williams Companies, Inc. 600 12 612 Nine Months Ended September 30, 2023 As Reported Pro Forma MountainWest (1) Pro Forma Combined (Millions) Revenues $ 8,123 $ 35 $ 8,158 Net income (loss) attributable to The Williams Companies, Inc. 2,041 6 2,047 Nine Months Ended September 30, 2022 As Reported Pro Forma MountainWest Pro Forma Trace (2) Pro Forma Combined (Millions) Revenues $ 8,035 $ 192 $ 45 $ 8,272 Net income (loss) attributable to The Williams Companies, Inc. 1,380 43 18 1,441 (1) Excludes results from operations acquired in the MountainWest Acquisition for the period beginning on the acquisition date of February 14, 2023, as these results are included in the amounts as reported. (2) Excludes results from operations acquired in the Trace Acquisition for the period beginning on the acquisition date of April 29, 2022, as these results are included in the amounts as reported.
MountainWest 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, which are included in our Transmission & Gulf of Mexico segment, and liabilities assumed at February 14, 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 long-term debt; 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 equals contractual amounts receivable. After the March 31, 2023, financial statements were issued, we identified adjustments to the preliminary purchase price allocation, primarily resulting in an increase of $19 million in trade accounts and other receivables and decreases of $72 million in property, plant, and equipment and $60 million in other noncurrent liabilities. (Millions) Cash and cash equivalents $ 23 Trade accounts and other receivables 33 Other current assets 26 Investments 22 Property, plant, and equipment – net 1,020 Other noncurrent assets 32 Total identifiable assets acquired $ 1,156 Current liabilities $ (47) Long-term debt (see Note 6) (365) Other noncurrent liabilities (95) Total liabilities assumed $ (507) Net identifiable assets acquired $ 649 Goodwill included in Intangible assets – net of accumulated amortization 398 Net assets acquired $ 1,047
Trace Midstream Acquisition
Business Acquisition [Line Items]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	We accounted for the Trace Acquisition as a business combination. The following table presents the allocation of the acquisition date fair value of the major classes of the assets acquired, which are included in our West segment, and liabilities assumed at April 29, 2022. The fair value of accounts receivable acquired equals contractual amounts receivable. The valuation techniques used consisted of the income approach (excess earnings method) for valuation of intangible assets and depreciated replacement costs for property, plant, and equipment. (Millions) Cash and cash equivalents $ 39 Trade accounts and other receivables 18 Property, plant, and equipment – net 448 Intangible assets – net of accumulated amortization 472 Other noncurrent assets 20 Total assets acquired $ 997 Accounts payable $ (12) Accrued and other current liabilities (5) Other noncurrent liabilities (8) Total liabilities assumed $ (25) Net assets acquired $ 972

Revenue Recognition (Tables)

Revenue Recognition (Tables)	9 Months Ended
	Sep. 30, 2023
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 Midstream West Midstream Gas & NGL Marketing Services Other Eliminations Total (Millions) Three Months Ended September 30, 2023 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 841 $ — $ — $ — $ — $ — $ (18) $ 823 Gathering, processing, transportation, fractionation, and storage: Monetary consideration — 121 450 368 — — (41) 898 Commodity consideration — 11 — 34 — — — 45 Other 5 2 22 2 — — (3) 28 Total service revenues 846 134 472 404 — — (62) 1,794 Product sales 35 31 27 112 1,189 117 (244) 1,267 Total revenues from contracts with customers 881 165 499 516 1,189 117 (306) 3,061 Other revenues (1) 5 4 6 17 697 13 (2) 740 Other adjustments (2) — — — — (1,328) — 86 (1,242) Total revenues $ 886 $ 169 $ 505 $ 533 $ 558 $ 130 $ (222) $ 2,559 Three Months Ended September 30, 2022 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 794 $ — $ — $ — $ — $ — $ (18) $ 776 Gathering, processing, transportation, fractionation, and storage: Monetary consideration (3) — 104 391 420 — — (51) 864 Commodity consideration — 11 2 47 — — — 60 Other (3) 3 4 20 2 1 — (4) 26 Total service revenues 797 119 413 469 1 — (73) 1,726 Product sales 81 51 40 245 3,109 238 (523) 3,241 Total revenues from contracts with customers 878 170 453 714 3,110 238 (596) 4,967 Other revenues (1) 3 3 6 (6) 2,607 (23) (1) 2,589 Other adjustments (2) — — — — (4,779) — 244 (4,535) Total revenues $ 881 $ 173 $ 459 $ 708 $ 938 $ 215 $ (353) $ 3,021 Regulated Interstate Transportation & Storage Gulf of Mexico Midstream & Storage Northeast Midstream West Midstream Gas & NGL Marketing Services Other Eliminations Total (Millions) Nine Months Ended September 30, 2023 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 2,480 $ — $ — $ — $ — $ — $ (41) $ 2,439 Gathering, processing, transportation, fractionation, and storage: Monetary consideration — 334 1,334 1,070 — — (130) 2,608 Commodity consideration — 29 3 76 — — — 108 Other 14 10 67 8 1 — (11) 89 Total service revenues 2,494 373 1,404 1,154 1 — (182) 5,244 Product sales 114 91 104 287 3,519 302 (686) 3,731 Total revenues from contracts with customers 2,608 464 1,508 1,441 3,520 302 (868) 8,975 Other revenues (1) 26 11 20 95 3,240 36 (2) 3,426 Other adjustments (2) — — — — (4,566) — 288 (4,278) Total revenues $ 2,634 $ 475 $ 1,528 $ 1,536 $ 2,194 $ 338 $ (582) $ 8,123 Nine Months Ended September 30, 2022 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 2,343 $ — $ — $ — $ — $ — $ (54) $ 2,289 Gathering, processing, transportation, fractionation, and storage: Monetary consideration (3) — 277 1,127 1,122 — — (117) 2,409 Commodity consideration — 54 12 157 — — — 223 Other (3) 8 9 62 8 2 — (13) 76 Total service revenues 2,351 340 1,201 1,287 2 — (184) 4,997 Product sales 140 215 110 684 8,422 522 (1,442) 8,651 Total revenues from contracts with customers 2,491 555 1,311 1,971 8,424 522 (1,626) 13,648 Other revenues (1) 8 7 19 (14) 5,838 (72) (10) 5,776 Other adjustments (2) — — — — (11,911) — 522 (11,389) Total revenues $ 2,499 $ 562 $ 1,330 $ 1,957 $ 2,351 $ 450 $ (1,114) $ 8,035 ______________________________ (1) Revenues not derived from contracts with customers primarily consist of physical product sales related to derivative contracts, realized and unrealized gains and losses associated with our derivative contracts, which are reported in Net gain (loss) on commodity derivatives in the 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. (3) Certain contractual reimbursements of operating and maintenance costs previously included in Other are now presented in Monetary consideration as they were received in exchange for providing gas gathering and processing services.
Contract with Customer, Asset and Liability [Table Text Block]	The following table presents a reconciliation of our contract assets: Three Months Ended Nine Months Ended 2023 2022 2023 2022 (Millions) Balance at beginning of period $ 56 $ 48 $ 29 $ 22 Revenue recognized in excess of amounts invoiced 45 54 133 158 Minimum volume commitments invoiced (28) (41) (89) (119) Balance at end of period $ 73 $ 61 $ 73 $ 61 Contract Liabilities The following table presents a reconciliation of our contract liabilities: Three Months Ended Nine Months Ended 2023 2022 2023 2022 (Millions) Balance at beginning of period $ 1,039 $ 1,115 $ 1,043 $ 1,126 Payments received and deferred 40 34 164 144 Significant financing component 3 2 7 7 Contract liability acquired (disposed) – net (2) 2 3 2 Recognized in revenue (68) (71) (205) (197) Balance at end of period $ 1,012 $ 1,082 $ 1,012 $ 1,082
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 September 30, 2023. Contract Liabilities Remaining Performance Obligations (Millions) 2023 (three months) $ 95 $ 950 2024 (one year) 144 3,746 2025 (one year) 123 3,413 2026 (one year) 119 3,105 2027 (one year) 109 2,579 Thereafter 422 15,300 Total $ 1,012 $ 29,093
Contract With Customer Accounts Receivable [Table Text Block]	The following is a summary of our Trade accounts and other receivables – net : September 30, 2023 December 31, 2022 (Millions) Accounts receivable related to revenues from contracts with customers $ 1,145 $ 1,771 Receivables from derivatives 207 889 Other accounts receivable 67 63 Trade accounts and other receivables – net $ 1,419 $ 2,723

Provision (Benefit) for Incom_2

Provision (Benefit) for Income Taxes (Tables)	9 Months Ended
	Sep. 30, 2023
Income Tax Disclosure [Abstract]
Schedule of Components of Income Tax Expense (Benefit) [Table Text Block]	The Provision (benefit) for income taxes from continuing operations includes: Three Months Ended Nine Months Ended 2023 2022 2023 2022 (Millions) Current: Federal $ 10 $ — $ 10 $ (27) State 7 4 11 14 17 4 21 (13) Deferred: Federal 169 163 555 247 State (10) (71) 59 (65) 159 92 614 182 Provision (benefit) for income taxes $ 176 $ 96 $ 635 $ 169

Debt and Banking Arrangements (

Debt and Banking Arrangements (Tables)	9 Months Ended
	Sep. 30, 2023
Debt Disclosure [Abstract]
Schedule of Long-Term Debt Instruments	Our senior unsecured public debt issuances for 2023 are as follows: Issue Date Maturity Date Amount Rate (Millions) March 2, 2023 March 2, 2026 $ 750 5.40% March 2, 2023 March 15, 2033 $ 750 5.65% August 10, 2023* March 2, 2026 $ 350 5.40% August 10, 2023 August 15, 2028 $ 900 5.30% *Additional issuance of the 5.40 percent senior notes due 2026 issued on March 2, 2023, and will trade interchangeably with such notes.
Schedule of Line of Credit Facilities [Table Text Block]	Credit Facility In the second quarter of 2023, the maturity date of our October 2021 amended and restated credit agreement (Credit Agreement) was extended one year and now expires October 8, 2027. One participating lender, Credit Suisse AG, New York Branch, with a commitment of approximately $194 million did not extend their commitment beyond October 8, 2026. The amended Credit Agreement allows the co-borrowers to request up to two extensions of the maturity date each for an additional one-year period to allow a maturity date as late as October 8, 2029, under certain circumstances. Additionally, the amended Credit Agreement replaces the London Interbank Offered Rate with the Term Secured Overnight Financing Rate as the benchmark interest rate index. September 30, 2023 Stated Capacity Outstanding (Millions) Long-term credit facility (1) $ 3,750 $ — Letters of credit under certain bilateral bank agreements 10 (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)	9 Months Ended
	Sep. 30, 2023
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 September 30, 2023: Measured on a recurring basis: ARO Trust investments $ 247 $ 247 $ 247 $ — $ — Commodity derivative assets (1) 170 170 90 75 5 Commodity derivative liabilities (1) (373) (373) — (347) (26) Interest rate derivatives 66 66 — 66 — Other financial assets (liabilities) – net 4 4 — 4 — Additional disclosures: Long-term debt, including current portion (25,651) (23,895) — (23,895) — Guarantees (37) (29) — (13) (16) Assets (liabilities) at December 31, 2022: Measured on a recurring basis: ARO Trust investments $ 230 $ 230 $ 230 $ — $ — Commodity derivative assets (2) 166 166 20 132 14 Commodity derivative liabilities (2) (810) (810) (22) (718) (70) Other financial assets (liabilities) – net (5) (5) — (5) — Additional disclosures: Long-term debt, including current portion (22,554) (21,569) — (21,569) — Guarantees (38) (25) — (9) (16) (1) Commodity derivative assets and liabilities exclude $30 million of net cash collateral in Level 1. (2) Commodity derivative assets and liabilities exclude $202 million of net cash collateral in Level 1.

Commodity Derivatives (Tables)

Commodity Derivatives (Tables)	9 Months Ended
	Sep. 30, 2023
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Commodity Derivative Instruments	At September 30, 2023, 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 848,556,144 Central Hub Risk - Henry Hub Natural Gas MMBtu (68,125,793) Basis Risk Natural Gas MMBtu (29,104,256) Central Hub Risk - Mont Belvieu Natural Gas Liquids Barrels (669,952) Basis Risk Natural Gas Liquids Barrels (605,000) Central Hub Risk - WTI Crude Oil Barrels (234,600)
Schedule of Commodity Derivative 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, was reflected as follows: September 30, December 31, Derivative Category Assets (Liabilities) Assets (Liabilities) (Millions) Current $ 457 $ (434) $ 1,099 $ (1,278) Noncurrent 172 (398) 269 (734) Total derivatives $ 629 $ (832) $ 1,368 $ (2,012) Counterparty and collateral netting offset (428) 458 (1,034) 1,236 Amounts recognized in our Consolidated Balance Sheet $ 201 $ (374) $ 334 $ (776)
Pretax Effect Of Commodity Derivatives	The pre-tax effects of commodity derivative instruments in our Consolidated Statement of Income were as follows: Gain (Loss) Three Months Ended Nine Months Ended 2023 2022 2023 2022 (Millions) Net gain (loss) on commodity derivatives within Total revenues : Realized commodity derivatives not designated as hedging instruments $ (8) $ (13) $ 169 $ (145) Unrealized commodity derivatives not designated as hedging instruments 32 29 476 (346) $ 24 $ 16 $ 645 $ (491) Net gain (loss) on commodity derivatives within Net processing commodity expenses : Realized commodity derivatives not designated as hedging instruments $ — $ 6 $ (3) $ 12 Unrealized commodity derivatives not designated as hedging instruments (9) 6 (43) 17 $ (9) $ 12 $ (46) $ 29 Total net gain (loss) on commodity derivatives $ 15 $ 28 $ 599 $ (462)

Segment Disclosures (Tables)

Segment Disclosures (Tables)	9 Months Ended
	Sep. 30, 2023
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 Nine Months Ended 2023 2022 2023 2022 (Millions) Modified EBITDA by segment: Transmission & Gulf of Mexico $ 881 $ 638 $ 2,327 $ 1,987 Northeast G&P 454 464 1,439 1,332 West 315 337 931 885 Gas & NGL Marketing Services 43 20 678 (249) Other 81 140 196 284 1,774 1,599 5,571 4,239 Accretion expense associated with asset retirement obligations for nonregulated operations (14) (12) (43) (36) Depreciation and amortization expenses (521) (500) (1,542) (1,504) Equity earnings (losses) 127 193 434 492 Other investing income (loss) – net 24 1 45 4 Proportional Modified EBITDA of equity-method investments (215) (273) (693) (748) Interest expense (314) (291) (914) (858) (Provision) benefit for income taxes (176) (96) (635) (169) Income (loss) from discontinued operations (1) — (88) — Net income (loss) $ 684 $ 621 $ 2,135 $ 1,420
Reconciliation of Revenue from Segments 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 September 30, 2023 Segment revenues: Service revenues External $ 953 $ 473 $ 340 $ — $ 4 $ — $ 1,770 Internal 25 5 34 — — (64) — Total service revenues 978 478 374 — 4 (64) 1,770 Total service revenues – commodity consideration 11 — 34 — — — 45 Product sales External 35 13 14 619 39 — 720 Internal 28 14 98 (63) 79 (156) — Total product sales 63 27 112 556 118 (156) 720 Net gain (loss) on commodity derivatives Realized 1 — 13 (31) 9 — (8) Unrealized — — — 33 (1) — 32 Total net gain (loss) on commodity derivatives (2) 1 — 13 2 8 — 24 Total revenues $ 1,053 $ 505 $ 533 $ 558 $ 130 $ (220) $ 2,559 Three Months Ended September 30, 2022 Segment revenues: Service revenues External $ 880 $ 408 $ 393 $ 1 $ 3 $ — $ 1,685 Internal 30 9 32 — 3 (74) — Total service revenues 910 417 425 1 6 (74) 1,685 Total service revenues – commodity consideration 11 2 47 — — — 60 Product sales External 78 11 61 1,079 31 — 1,260 Internal 43 29 184 (195) 207 (268) — Total product sales 121 40 245 884 238 (268) 1,260 Net gain (loss) on commodity derivatives Realized — — (9) 54 (58) — (13) Unrealized 1 — — (1) 29 — 29 Total net gain (loss) on commodity derivatives (2) 1 — (9) 53 (29) — 16 Total revenues $ 1,043 $ 459 $ 708 $ 938 $ 215 $ (342) $ 3,021 Transmission &Gulf of Mexico Northeast G&P West Gas & NGL Marketing Services (1) Other Eliminations Total (Millions) Nine Months Ended September 30, 2023 Segment revenues: Service revenues External $ 2,801 $ 1,396 $ 1,002 $ 1 $ 12 $ — $ 5,212 Internal 73 25 86 — — (184) — Total service revenues 2,874 1,421 1,088 1 12 (184) 5,212 Total service revenues – commodity consideration 29 3 76 — — — 108 Product sales External 116 32 43 1,882 85 — 2,158 Internal 81 72 244 (224) 218 (391) — Total product sales 197 104 287 1,658 303 (391) 2,158 Net gain (loss) on commodity derivatives Realized 2 — 85 41 41 — 169 Unrealized — — — 494 (18) — 476 Total net gain (loss) on commodity derivatives (2) 2 — 85 535 23 — 645 Total revenues $ 3,102 $ 1,528 $ 1,536 $ 2,194 $ 338 $ (575) $ 8,123 Nine Months Ended September 30, 2022 Segment revenues: Service revenues External $ 2,563 $ 1,178 $ 1,073 $ 2 $ 12 $ — $ 4,828 Internal 88 30 66 — 10 (194) — Total service revenues 2,651 1,208 1,139 2 22 (194) 4,828 Total service revenues – commodity consideration 54 12 157 — — — 223 Product sales External 187 24 111 3,073 80 — 3,475 Internal 147 86 573 (349) 442 (899) — Total product sales 334 110 684 2,724 522 (899) 3,475 Net gain (loss) on commodity derivatives Realized — — (23) (18) (104) — (145) Unrealized 1 — — (357) 10 — (346) Total net gain (loss) on commodity derivatives (2) 1 — (23) (375) (94) — (491) Total revenues $ 3,040 $ 1,330 $ 1,957 $ 2,351 $ 450 $ (1,093) $ 8,035 _____________ (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 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 on 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	9 Months Ended
	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022	Sep. 03, 2021
Subsidiary of Limited Liability Company or Limited Partnership [Line Items]
Stock Repurchase Program, Authorized Amount				$ 1,500
Treasury Stock, Value, Acquired, Cost Method	$ 9	$ 130	$ 9
Stock Repurchase Program, Cumulative Amount Purchased		$ 139
Transmission And Gulf Of Mexico [Member] | Williams Companies Inc [Member] | Gulfstar One [Member]
Subsidiary of Limited Liability Company or Limited Partnership [Line Items]
Variable Interest Entity Ownership Percentage		51%
Transmission And Gulf Of Mexico [Member] | Gulfstream Natural Gas System, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		50%
Transmission And Gulf Of Mexico [Member] | Discovery Producer Services LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		60%
Northeast G And P [Member] | Williams Companies Inc [Member] | Northeast JV [Member]
Subsidiary of Limited Liability Company or Limited Partnership [Line Items]
Variable Interest Entity Ownership Percentage		65%
Northeast G And P [Member] | Williams Companies Inc [Member] | Cardinal Gas Services LLC [Member]
Subsidiary of Limited Liability Company or Limited Partnership [Line Items]
Variable Interest Entity Ownership Percentage		66%
Northeast G And P [Member] | Laurel Mountain Midstream, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		69%
Northeast G And P [Member] | Blue Racer Midstream LLC
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		50%
West [Member] | Williams Companies Inc [Member] | Conway Fractionator [Member]
Subsidiary of Limited Liability Company or Limited Partnership [Line Items]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest		50%
West [Member] | Overland Pass Pipeline Company LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		50%
West [Member] | Rocky Mountain Midstream Holdings LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		50%
West [Member] | Targa Train 7 LLC
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		20%
West [Member] | Brazos Permian II LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		15%

Variable Interest Entities (Det

Variable Interest Entities (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2023	Dec. 31, 2022
Variable Interest Entity [Line Items]
Assets	$ 50,788	$ 48,433
Variable Interest Entity, Primary Beneficiary [Member] | Cash and cash equivalents [Member]
Variable Interest Entity [Line Items]
Assets	29	49
Variable Interest Entity, Primary Beneficiary [Member] | Trade accounts and other receivables - net [Member]
Variable Interest Entity [Line Items]
Assets	195	136
Variable Interest Entity, Primary Beneficiary [Member] | Inventories [Member]
Variable Interest Entity [Line Items]
Assets	6	4
Variable Interest Entity, Primary Beneficiary [Member] | Other current assets and deferred charges [Member]
Variable Interest Entity [Line Items]
Assets	6	7
Variable Interest Entity, Primary Beneficiary [Member] | Property, plant, and equipment - net [Member]
Variable Interest Entity [Line Items]
Assets	5,090	5,154
Variable Interest Entity, Primary Beneficiary [Member] | Intangible assets - net of accumulated amortization [Member]
Variable Interest Entity [Line Items]
Assets	2,077	2,158
Variable Interest Entity, Primary Beneficiary [Member] | Regulatory assets, deferred charges, and other [Member]
Variable Interest Entity [Line Items]
Assets	31	29
Variable Interest Entity, Primary Beneficiary [Member] | Accounts payable [Member]
Variable Interest Entity [Line Items]
Liabilities	(97)	(76)
Variable Interest Entity, Primary Beneficiary [Member] | Accrued and other current liabilities [Member]
Variable Interest Entity [Line Items]
Liabilities	(23)	(34)
Variable Interest Entity, Primary Beneficiary [Member] | Regulatory liabilities, deferred income, and other [Member]
Variable Interest Entity [Line Items]
Liabilities	$ (273)	$ (275)
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] | Targa Train 7 LLC
Variable Interest Entity [Line Items]
Variable Interest Entity Ownership Percentage	20%
Equity Method Investments	$ 44
Variable Interest Entity, Not Primary Beneficiary [Member] | Williams Companies Inc [Member] | Brazos Permian II LLC [Member]
Variable Interest Entity [Line Items]
Variable Interest Entity Ownership Percentage	15%
Equity Method Investments	$ 23

Divestitures (Details)

Divestitures (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
	Sep. 29, 2023	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Gain on sale of business		$ 130	$ 0	$ 130	$ 0
Certain Gulf Coast Liquids Pipelines
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Disposal Group, Including Discontinued Operation, Consideration	$ 348
Certain Gulf Coast Liquids Pipelines | Transmission And Gulf Of Mexico [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Gain on sale of business	$ 130

Acquisitions (Details)

Acquisitions (Details) - USD ($) $ in Millions					3 Months Ended		6 Months Ended	8 Months Ended		9 Months Ended
		Feb. 14, 2023	Aug. 31, 2022	Apr. 29, 2022	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2023	Dec. 31, 2022	Sep. 30, 2023		Sep. 30, 2022
Business Acquisition [Line Items]
Purchases of businesses, net of cash acquired (Note 3)										$ 1,024		$ 933
Revenues					$ 2,559	$ 3,021				8,123		8,035
Modified EBITDA Earnings Loss					1,774	1,599				5,571		4,239
Net Income (Loss) Attributable to Parent					654	600				2,041		1,380
Pro Forma
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Revenue						3,084				8,158		8,272
Business Acquisition, Pro Forma Net Income (Loss)						612				2,047		1,441
Transmission And Gulf Of Mexico [Member] | NorTex Acquisition [Member]
Business Acquisition [Line Items]
Payments to Acquire Productive Assets			$ 424
Transmission And Gulf Of Mexico [Member] | Operating Segments [Member]
Business Acquisition [Line Items]
Revenues					1,053	1,043				3,102		3,040
Modified EBITDA Earnings Loss					881	638				2,327		1,987
West [Member] | Operating Segments [Member]
Business Acquisition [Line Items]
Revenues					533	708				1,536		1,957
Modified EBITDA Earnings Loss					$ 315	337				931		885
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
Business Combination, Provisional Information, Initial Accounting Incomplete, Adjustment, Receivables							$ 19
Business Combination, Provisional Information, Initial Accounting Incomplete, Adjustment, Property, Plant, and Equipment							(72)
Business Combination, Provisional Information, Initial Accounting Incomplete, Adjustment, Financial Liabilities							$ (60)
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		22
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment		1,020
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets		32
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets		1,156
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		649
Goodwill		398
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Net		1,047
Business Acquisition, Goodwill, Expected Tax Deductible Amount		$ 398
MountainWest Acquisition | Pro Forma
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Revenue						63				35	[1]	192
Business Acquisition, Pro Forma Net Income (Loss)						$ 12				6	[1]	43
MountainWest Acquisition | Transmission And Gulf Of Mexico [Member]
Business Acquisition [Line Items]
Business Combination, Transition Related Costs								$ 20
MountainWest Acquisition | Transmission And Gulf Of Mexico [Member] | Selling, general, and administrative expenses [Member]
Business Acquisition [Line Items]
Business Combination, Acquisition Related Costs										$ 15
MountainWest Acquisition | Transmission And Gulf Of Mexico [Member] | Operating Segments [Member]
Business Acquisition [Line Items]
Revenues								156
Modified EBITDA Earnings Loss								$ 78
Trace Midstream Acquisition
Business Acquisition [Line Items]
Business Acquisition, Percentage of Voting Interests Acquired				100%
Business Combination, Consideration Transferred				$ 972
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Cash and Equivalents				39
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Receivables				18
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment				448
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Finite-Lived Intangibles				472
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets				20
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets				997
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Accounts Payable				(12)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Other				(5)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Other				(8)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities				(25)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net				$ 972
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				2%
Acquired Finite-lived Intangible Asset, Weighted-Average Period before Renewal or Extension				19 years
Trace Midstream Acquisition | Pro Forma
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Revenue	[2]											45
Business Acquisition, Pro Forma Net Income (Loss)	[2]											$ 18
Trace Midstream Acquisition | West [Member] | Selling, general, and administrative expenses [Member]
Business Acquisition [Line Items]
Business Combination, Acquisition Related Costs									$ 8
Trace Midstream Acquisition | West [Member] | Operating Segments [Member]
Business Acquisition [Line Items]
Revenues									148
Modified EBITDA Earnings Loss									$ 73
[1]Excludes results from operations acquired in the MountainWest Acquisition for the period beginning on the acquisition date of February 14, 2023, as these results are included in the amounts as reported.[2]Excludes results from operations acquired in the Trace Acquisition for the period beginning on the acquisition date of April 29, 2022, as these results are included in the amounts as reported.

Revenue Recognition Revenue by

Revenue Recognition Revenue by Category (Details) - USD ($) $ in Millions		3 Months Ended			9 Months Ended
		Sep. 30, 2023	Sep. 30, 2022		Sep. 30, 2023	Sep. 30, 2022
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		$ 3,061	$ 4,967		$ 8,975	$ 13,648
Revenue Not from Contract with Customer	[1]	740	2,589		3,426	5,776
Revenue Not from Contract with Customer, Other	[2]	(1,242)	(4,535)		(4,278)	(11,389)
Total revenues		2,559	3,021		8,123	8,035
Regulated Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		823	776		2,439	2,289
NonRegulated Service Monetary Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		898	864	[3]	2,608	2,409	[3]
NonRegulated Service Commodity Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		45	60		108	223
Total revenues		45	60		108	223
Other Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		28	26	[3]	89	76	[3]
Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		1,794	1,726		5,244	4,997
Total revenues		1,770	1,685		5,212	4,828
Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		1,267	3,241		3,731	8,651
Total revenues		720	1,260		2,158	3,475
Regulated Interstate Transportation & Storage
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		881	878		2,608	2,491
Revenue Not from Contract with Customer	[1]	5	3		26	8
Revenue Not from Contract with Customer, Other	[2]	0	0		0	0
Total revenues		886	881		2,634	2,499
Regulated Interstate Transportation & Storage | Regulated Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		841	794		2,480	2,343
Regulated Interstate Transportation & Storage | NonRegulated Service Monetary Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	[3]	0	0	[3]
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	3	[3]	14	8	[3]
Regulated Interstate Transportation & Storage | Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		846	797		2,494	2,351
Regulated Interstate Transportation & Storage | Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		35	81		114	140
Transmission And Gulf Of Mexico Midstream [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		165	170		464	555
Revenue Not from Contract with Customer	[1]	4	3		11	7
Revenue Not from Contract with Customer, Other	[2]	0	0		0	0
Total revenues		169	173		475	562
Transmission And Gulf Of Mexico Midstream [Member] | Regulated Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0		0	0
Transmission And Gulf Of Mexico Midstream [Member] | NonRegulated Service Monetary Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		121	104	[3]	334	277	[3]
Transmission And Gulf Of Mexico Midstream [Member] | NonRegulated Service Commodity Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		11	11		29	54
Transmission And Gulf Of Mexico Midstream [Member] | Other Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		2	4	[3]	10	9	[3]
Transmission And Gulf Of Mexico Midstream [Member] | Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		134	119		373	340
Transmission And Gulf Of Mexico Midstream [Member] | Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		31	51		91	215
Northeast Midstream [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		499	453		1,508	1,311
Revenue Not from Contract with Customer	[1]	6	6		20	19
Revenue Not from Contract with Customer, Other	[2]	0	0		0	0
Total revenues		505	459		1,528	1,330
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		450	391	[3]	1,334	1,127	[3]
Northeast Midstream [Member] | NonRegulated Service Commodity Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	2		3	12
Northeast Midstream [Member] | Other Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		22	20	[3]	67	62	[3]
Northeast Midstream [Member] | Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		472	413		1,404	1,201
Northeast Midstream [Member] | Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		27	40		104	110
West Midstream [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		516	714		1,441	1,971
Revenue Not from Contract with Customer	[1]	17	(6)		95	(14)
Revenue Not from Contract with Customer, Other	[2]	0	0		0	0
Total revenues		533	708		1,536	1,957
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		368	420	[3]	1,070	1,122	[3]
West Midstream [Member] | NonRegulated Service Commodity Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		34	47		76	157
West Midstream [Member] | Other Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		2	2	[3]	8	8	[3]
West Midstream [Member] | Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		404	469		1,154	1,287
West Midstream [Member] | Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		112	245		287	684
Gas & NGL Marketing Services
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		1,189	3,110		3,520	8,424
Revenue Not from Contract with Customer	[1]	697	2,607		3,240	5,838
Revenue Not from Contract with Customer, Other	[2]	(1,328)	(4,779)		(4,566)	(11,911)
Total revenues		558	938		2,194	2,351
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	[3]	0	0	[3]
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	1	[3]	1	2	[3]
Gas & NGL Marketing Services | Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	1		1	2
Gas & NGL Marketing Services | Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		1,189	3,109		3,519	8,422
Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		117	238		302	522
Revenue Not from Contract with Customer	[1]	13	(23)		36	(72)
Revenue Not from Contract with Customer, Other	[2]	0	0		0	0
Total revenues		130	215		338	450
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	[3]	0	0	[3]
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	[3]	0	0	[3]
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		117	238		302	522
Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		(306)	(596)		(868)	(1,626)
Revenue Not from Contract with Customer	[1]	(2)	(1)		(2)	(10)
Revenue Not from Contract with Customer, Other	[2]	86	244		288	522
Total revenues		(222)	(353)		(582)	(1,114)
Intersegment Eliminations [Member] | Regulated Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		(18)	(18)		(41)	(54)
Intersegment Eliminations [Member] | NonRegulated Service Monetary Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		(41)	(51)	[3]	(130)	(117)	[3]
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		(3)	(4)	[3]	(11)	(13)	[3]
Intersegment Eliminations [Member] | Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		(62)	(73)		(182)	(184)
Intersegment Eliminations [Member] | Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		$ (244)	$ (523)		$ (686)	$ (1,442)
[1] Revenues not derived from contracts with customers primarily consist of physical product sales related to derivative contracts, realized and unrealized gains and losses associated with our derivative contracts, which are reported in Net gain (loss) on commodity derivatives in the 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. Certain contractual reimbursements of operating and maintenance costs previously included in Other are now presented in Monetary consideration as they were received in exchange for providing gas gathering and processing services.

Revenue Recognition Contract As

Revenue Recognition Contract Assets (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Revenue Recognition [Abstract]
Contract with Customer, Asset, Net - Beginning of Period	$ 56	$ 48	$ 29	$ 22
Contract with Customer, Asset, Cumulative Catch-up Adjustment to Revenue, Change in Measure of Progress	45	54	133	158
Contract with Customer, Asset, Reclassified to Receivable	(28)	(41)	(89)	(119)
Contract with Customer, Asset, Net - End of Period	$ 73	$ 61	$ 73	$ 61

Revenue Recognition Contract Li

Revenue Recognition Contract Liabilities (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Contract With Customer, Liability [Line Items]
Contract with Customer, Liability - Beginning of Period	$ 1,039	$ 1,115	$ 1,043	$ 1,126
Contract with Customer, Liability, Cumulative Catch-up Adjustment to Revenue, Change in Measure of Progress	40	34	164	144
Other Significant Noncash Transaction, Value of Consideration Received	3	2	7	7
Contract with Customer, Liability, Increase (Decrease) for Contract Acquired in Business Combination	(2)	2	3	2
Contract with Customer, Liability, Revenue Recognized	(68)	(71)	(205)	(197)
Contract with Customer, Liability - End of Period	$ 1,012	$ 1,082	$ 1,012	$ 1,082

Revenue Recognition Contract _2

Revenue Recognition Contract Liabilities Performance Obligations (Details) - USD ($) $ in Millions	Sep. 30, 2023	Jun. 30, 2023	Dec. 31, 2022	Sep. 30, 2022	Jun. 30, 2022	Dec. 31, 2021
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	$ 1,012	$ 1,039	$ 1,043	$ 1,082	$ 1,115	$ 1,126
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	95
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	144
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	123
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	119
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	109
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	$ 422
Performance Obligations Related To Contract Liabilities [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	3 months
Performance Obligations Related To Contract Liabilities [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
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]: 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

Revenue Recognition Remaining P

Revenue Recognition Remaining Performance Obligations (Details) $ in Millions	Sep. 30, 2023 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 29,093
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	950
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	3,746
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	3,413
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	3,105
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	2,579
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	$ 15,300
Remaining Performance Obligations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	3 months
Remaining Performance Obligations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
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]: 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

Revenue Recognition Accounts Re

Revenue Recognition Accounts Receivable (Details) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, Net, Current	$ 1,419	$ 2,723
Derivative Receivables
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, Net, Current	207	889
Accounts Receivable Related To Contracts With Customers [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, Net, Current	1,145	1,771
Other Accounts Receivable [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, Net, Current	$ 67	$ 63

Provision (Benefit) for Incom_3

Provision (Benefit) for Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended			9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Jun. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Current:
Federal	$ 10	$ 0		$ 10	$ (27)
State	7	4		11	14
Total	17	4		21	(13)
Deferred:
Federal	169	163		555	247
State	(10)	(71)		59	(65)
Total	159	92		614	182
Provision (benefit) for income taxes	$ 176	96		$ 635	169
Valuation Allowance [Line Items]
Valuation Allowance, Deferred Tax Asset, Increase (Decrease), Amount			$ 88
Operating Loss Carryforwards [Line Items]
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Amount		92			92
Deferred Tax Assets, Operating Loss Carryforwards, State and Local		$ 23	18		$ 23
Deferred Tax Assets, Tax Credit Carryforwards, Foreign			70
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items]
Unrecognized Tax Benefits, Decrease Resulting from Prior Period Tax Positions			$ 46

Debt and Banking Arrangements L

Debt and Banking Arrangements Long-Term Debt Issuances and Retirements (Details 1) - USD ($) $ in Millions	Feb. 14, 2023	Aug. 10, 2023		Mar. 02, 2023
MountainWest
Debt Instrument [Line Items]
Liabilities, Fair Value Adjustment	$ (65)
5.40 Percent Senior Unsecured Notes Due 2026 | Williams Companies Inc [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 350	[1]	$ 750
Long-term debt interest rate		5.40%	[1]	5.40%
5.65 Percent Senior Unsecured Notes Due 2033 [Member] | Williams Companies Inc [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount				$ 750
Long-term debt interest rate				5.65%
5.30 Percent Senior Unsecured Notes Due 2028 | Williams Companies Inc [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 900
Long-term debt interest rate		5.30%
3.53 Percent Senior Unsecured Notes due 2028 | MountainWest
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 100
Long-term debt interest rate	3.53%
3.91 Percent Senior Unsecured Notes due 2038 | MountainWest
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 150
Long-term debt interest rate	3.91%
4.875 Percent Senior Unsecured Notes due 2041 | MountainWest
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 180
Long-term debt interest rate	4.875%
[1]*Additional issuance of the 5.40 percent senior notes due 2026 issued on March 2, 2023, and will trade interchangeably with such notes.

Debt and Banking Arrangements C

Debt and Banking Arrangements Credit Facility and Commercial Paper (Details 2) - USD ($) $ in Millions		Oct. 08, 2026	Sep. 30, 2023	Dec. 31, 2022
Credit Facility and Commercial Paper [Line Items]
Commercial paper, outstanding			$ 0	$ 350
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] | Forecast
Credit Facility and Commercial Paper [Line Items]
Line Of Credit Facility, Maximum Borrowing Capacity Commitment Increase (Decrease)		$ (194)
Commercial Paper [Member] | Williams Companies Inc [Member]
Credit Facility and Commercial Paper [Line Items]
Commercial paper, outstanding			0
Credit facility, capacity			3,500
Letters Of Credit Under Certain Bilateral Bank Agreements [Member] | Williams Companies Inc [Member]
Credit Facility and Commercial Paper [Line Items]
Credit facility, letters of credit outstanding			$ 10
[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	Sep. 30, 2023		Dec. 31, 2022
Additional disclosures:
Collateral Already Posted, Aggregate Fair Value	$ 30
Derivative, Notional Amount	750
Carrying Amount [Member]
Additional disclosures:
Long-term debt, including current portion	(25,651)		$ (22,554)
Guarantees	(37)		(38)
Fair Value [Member]
Additional disclosures:
Long-term debt, including current portion	(23,895)		(21,569)
Guarantees	(29)		(25)
Level 1 [Member]
Additional disclosures:
Long-term debt, including current portion	0		0
Guarantees	0		0
Collateral Already Posted, Aggregate Fair Value	30		202
Level 2 [Member]
Additional disclosures:
Long-term debt, including current portion	(23,895)		(21,569)
Guarantees	(13)		(9)
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	247		230
Derivative Asset, Fair Value, Gross Asset	170	[1]	166	[2]
Derivative Liability, Fair Value, Gross Liability	(373)	[1]	(810)	[2]
Interest Rate Derivatives, at Fair Value, Net	66
Other financial assets (liabilities) – net	4		(5)
Fair Value, Recurring [Member] | Fair Value [Member]
Measured on a recurring basis:
ARO Trust investments	247		230
Derivative Asset, Fair Value, Gross Asset	170	[1]	166	[2]
Derivative Liability, Fair Value, Gross Liability	(373)	[1]	(810)	[2]
Interest Rate Derivatives, at Fair Value, Net	66
Other financial assets (liabilities) – net	4		(5)
Fair Value, Recurring [Member] | Level 1 [Member]
Measured on a recurring basis:
ARO Trust investments	247		230
Derivative Asset, Fair Value, Gross Asset	90	[1]	20	[2]
Derivative Liability, Fair Value, Gross Liability	0	[1]	(22)	[2]
Interest Rate Derivatives, at Fair Value, Net	0
Other financial assets (liabilities) – 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	75	[1]	132	[2]
Derivative Liability, Fair Value, Gross Liability	(347)	[1]	(718)	[2]
Interest Rate Derivatives, at Fair Value, Net	66
Other financial assets (liabilities) – net	4		(5)
Fair Value, Recurring [Member] | Level 3 [Member]
Measured on a recurring basis:
ARO Trust investments	0		0
Derivative Asset, Fair Value, Gross Asset	5	[1]	14	[2]
Derivative Liability, Fair Value, Gross Liability	(26)	[1]	(70)	[2]
Interest Rate Derivatives, at Fair Value, Net	0
Other financial assets (liabilities) – net	0		$ 0
WilTel Guarantee [Member]
Additional disclosures:
Guarantor Obligations, Maximum Exposure, Undiscounted	23
Indemnification Agreement [Member] | Carrying Amount [Member]
Additional disclosures:
Guarantees	$ 0
[1]Commodity derivative assets and liabilities exclude $30 million of net cash collateral in Level 1.[2]Commodity derivative assets and liabilities exclude $202 million of net cash collateral in Level 1.

Commodity Derivatives (Details)

Commodity Derivatives (Details) - Not Designated as Hedging Instrument [Member]	Sep. 30, 2023 MMBTU Boe
Public Utilities, Inventory, Natural Gas | Index Risk
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Nonmonetary Notional Amount Net Long Short Position Volume | MMBTU	848,556,144
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	(68,125,793)
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	(29,104,256)
Natural Gas Liquids | Central Hub Risk
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Nonmonetary Notional Amount Net Long Short Position Volume | Boe	(669,952)
Natural Gas Liquids | Basis Risk
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Nonmonetary Notional Amount Net Long Short Position Volume | Boe	(605,000)
Crude Oil | Central Hub Risk
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Nonmonetary Notional Amount Net Long Short Position Volume | Boe	(234,600)

Commodity Derivatives - Financi

Commodity Derivatives - Financial Statement Presentation (Details) - Energy Related Derivative - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022	Dec. 31, 2022
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Asset, Fair Value, Gross Liability	$ (428)		$ (428)		$ (1,034)
Derivative Liability, Fair Value, Gross Asset	458		458		1,236
Derivative Asset	201		201		334
Derivative Liability	(374)		(374)		(776)
Gain (Loss) on Derivative Instruments, Net, Pretax	15	$ 28	599	$ (462)
Gain (Loss) on Derivative Instruments
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Gain (Loss) on Derivative Instruments, Net, Pretax	24	16	645	(491)
Cost of Sales
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Gain (Loss) on Derivative Instruments, Net, Pretax	(9)	12	(46)	29
Not Designated as Hedging Instrument [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Asset, Fair Value, Gross Asset	629		629		1,368
Derivative Liability, Fair Value, Gross Liability	(832)		(832)		(2,012)
Not Designated as Hedging Instrument [Member] | Gain (Loss) on Derivative Instruments
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Gain (Loss) on Derivative, Net	(8)	(13)	169	(145)
Unrealized Gain (Loss) on Derivatives	32	29	476	(346)
Not Designated as Hedging Instrument [Member] | Cost of Sales
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Gain (Loss) on Derivative, Net	0	6	(3)	12
Unrealized Gain (Loss) on Derivatives	(9)	$ 6	(43)	$ 17
Derivative assets [Member] | Not Designated as Hedging Instrument [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Asset, Fair Value, Gross Asset	457		457		1,099
Other Current Liabilities | Not Designated as Hedging Instrument [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Liability, Fair Value, Gross Liability	(434)		(434)		(1,278)
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	172		172		269
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	$ (398)		$ (398)		$ (734)

Commodity Derivatives - Conting

Commodity Derivatives - Contingent Features (Details) $ in Millions	Sep. 30, 2023 USD ($)
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Additional Collateral, Aggregate Fair Value	$ 9
Collateral Already Posted, Aggregate Fair Value	$ 30

Contingencies (Details)

Contingencies (Details) - USD ($) $ in Millions				1 Months Ended	3 Months Ended
	Sep. 21, 2022	Dec. 29, 2021	May 20, 2016	Jan. 31, 2020	Sep. 30, 2023	Jun. 30, 2023
Loss Contingencies [Line Items]
Accrued environmental loss liabilities					$ 51
Former Alaska Refinery [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Awarded, Value				$ 86
Loss Contingency Accrual, Period Increase (Decrease)					1	$ 115
Energy Transfer Merger [Member]
Loss Contingencies [Line Items]
Loss contingency, damages sought, value			$ 1,480
Litigation Settlement, Amount Awarded from Other Party	$ 602	$ 410
Litigation Settlement, Expense	$ 90
Gas Pipeline [Member]
Loss Contingencies [Line Items]
Accrued environmental loss liabilities					13
Recoverable through rates
Loss Contingencies [Line Items]
Accrued environmental loss liabilities					4
Natural Gas Under Ground Storage Facilities [Member]
Loss Contingencies [Line Items]
Accrued environmental loss liabilities					10
Former Operations [Member]
Loss Contingencies [Line Items]
Accrued environmental loss liabilities					$ 28

Segment Disclosures Reconciliat

Segment Disclosures Reconciliation of Segment Modified EBITDA to Consolidated Net Income (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Reconciliation of Modified EBITDA to Net Income (Loss):
Modified EBITDA Earnings (Loss)	$ 1,774	$ 1,599	$ 5,571	$ 4,239
Accretion expense associated with asset retirement obligations for nonregulated operations	(14)	(12)	(43)	(36)
Depreciation and amortization expenses	(521)	(500)	(1,542)	(1,504)
Equity earnings (losses)	127	193	434	492
Other investing income (loss) - net	24	1	45	4
Proportional Modified EBITDA of equity-method investments	(215)	(273)	(693)	(748)
Interest expense	(314)	(291)	(914)	(858)
(Provision) benefit for income taxes	(176)	(96)	(635)	(169)
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	(1)	0	(88)	0
Net income (loss)	684	621	2,135	1,420
Inventory write-downs			28	76
Energy Related Derivative | Not Designated as Hedging Instrument [Member] | Cost of Sales
Reconciliation of Modified EBITDA to Net Income (Loss):
Unrealized Gain (Loss) on Derivatives	(9)	6	(43)	17
Operating Segments [Member] | Transmission And Gulf Of Mexico [Member]
Reconciliation of Modified EBITDA to Net Income (Loss):
Modified EBITDA Earnings (Loss)	881	638	2,327	1,987
Operating Segments [Member] | Northeast G And P [Member]
Reconciliation of Modified EBITDA to Net Income (Loss):
Modified EBITDA Earnings (Loss)	454	464	1,439	1,332
Operating Segments [Member] | West [Member]
Reconciliation of Modified EBITDA to Net Income (Loss):
Modified EBITDA Earnings (Loss)	315	337	931	885
Operating Segments [Member] | Gas & NGL Marketing Services
Reconciliation of Modified EBITDA to Net Income (Loss):
Modified EBITDA Earnings (Loss)	43	20	678	(249)
Operating Segments [Member] | Other [Member]
Reconciliation of Modified EBITDA to Net Income (Loss):
Modified EBITDA Earnings (Loss)	$ 81	$ 140	$ 196	$ 284

Segment Disclosures Reconcili_2

Segment Disclosures Reconciliation of Segment Revenues to Consolidated (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Segment revenues
Revenues		$ 2,559	$ 3,021	$ 8,123	$ 8,035
Intersegment Elimination [Member]
Segment revenues
Revenues		(220)	(342)	(575)	(1,093)
Operating Segments [Member] | Transmission And Gulf Of Mexico [Member]
Segment revenues
Revenues		1,053	1,043	3,102	3,040
Operating Segments [Member] | Northeast G And P [Member]
Segment revenues
Revenues		505	459	1,528	1,330
Operating Segments [Member] | West [Member]
Segment revenues
Revenues		533	708	1,536	1,957
Operating Segments [Member] | Gas & NGL Marketing Services
Segment revenues
Revenues	[1]	558	938	2,194	2,351
Operating Segments [Member] | Other [Member]
Segment revenues
Revenues		130	215	338	450
Service [Member]
Segment revenues
Revenues		1,770	1,685	5,212	4,828
Service [Member] | Transmission And Gulf Of Mexico [Member]
Segment revenues
Revenues		953	880	2,801	2,563
Service [Member] | Northeast G And P [Member]
Segment revenues
Revenues		473	408	1,396	1,178
Service [Member] | West [Member]
Segment revenues
Revenues		340	393	1,002	1,073
Service [Member] | Gas & NGL Marketing Services
Segment revenues
Revenues	[1]	0	1	1	2
Service [Member] | Other [Member]
Segment revenues
Revenues		4	3	12	12
Service [Member] | Intersegment Elimination [Member]
Segment revenues
Revenues		(64)	(74)	(184)	(194)
Service [Member] | Intersegment Elimination [Member] | Transmission And Gulf Of Mexico [Member]
Segment revenues
Revenues		(25)	(30)	(73)	(88)
Service [Member] | Intersegment Elimination [Member] | Northeast G And P [Member]
Segment revenues
Revenues		(5)	(9)	(25)	(30)
Service [Member] | Intersegment Elimination [Member] | West [Member]
Segment revenues
Revenues		(34)	(32)	(86)	(66)
Service [Member] | Intersegment Elimination [Member] | Gas & NGL Marketing Services
Segment revenues
Revenues	[1]	0	0	0	0
Service [Member] | Intersegment Elimination [Member] | Other [Member]
Segment revenues
Revenues		0	(3)	0	(10)
Service [Member] | Operating Segments [Member] | Transmission And Gulf Of Mexico [Member]
Segment revenues
Revenues		978	910	2,874	2,651
Service [Member] | Operating Segments [Member] | Northeast G And P [Member]
Segment revenues
Revenues		478	417	1,421	1,208
Service [Member] | Operating Segments [Member] | West [Member]
Segment revenues
Revenues		374	425	1,088	1,139
Service [Member] | Operating Segments [Member] | Gas & NGL Marketing Services
Segment revenues
Revenues	[1]	0	1	1	2
Service [Member] | Operating Segments [Member] | Other [Member]
Segment revenues
Revenues		4	6	12	22
NonRegulated Service Commodity Consideration [Member]
Segment revenues
Revenues		45	60	108	223
NonRegulated Service Commodity Consideration [Member] | Intersegment Elimination [Member]
Segment revenues
Revenues		0	0	0	0
NonRegulated Service Commodity Consideration [Member] | Operating Segments [Member] | Transmission And Gulf Of Mexico [Member]
Segment revenues
Revenues		11	11	29	54
NonRegulated Service Commodity Consideration [Member] | Operating Segments [Member] | Northeast G And P [Member]
Segment revenues
Revenues		0	2	3	12
NonRegulated Service Commodity Consideration [Member] | Operating Segments [Member] | West [Member]
Segment revenues
Revenues		34	47	76	157
NonRegulated Service Commodity Consideration [Member] | Operating Segments [Member] | Gas & NGL Marketing Services
Segment revenues
Revenues	[1]	0	0	0	0
NonRegulated Service Commodity Consideration [Member] | Operating Segments [Member] | Other [Member]
Segment revenues
Revenues		0	0	0	0
Product [Member]
Segment revenues
Revenues		720	1,260	2,158	3,475
Product [Member] | Transmission And Gulf Of Mexico [Member]
Segment revenues
Revenues		35	78	116	187
Product [Member] | Northeast G And P [Member]
Segment revenues
Revenues		13	11	32	24
Product [Member] | West [Member]
Segment revenues
Revenues		14	61	43	111
Product [Member] | Gas & NGL Marketing Services
Segment revenues
Revenues	[1]	619	1,079	1,882	3,073
Product [Member] | Other [Member]
Segment revenues
Revenues		39	31	85	80
Product [Member] | Intersegment Elimination [Member]
Segment revenues
Revenues		(156)	(268)	(391)	(899)
Product [Member] | Intersegment Elimination [Member] | Transmission And Gulf Of Mexico [Member]
Segment revenues
Revenues		(28)	(43)	(81)	(147)
Product [Member] | Intersegment Elimination [Member] | Northeast G And P [Member]
Segment revenues
Revenues		(14)	(29)	(72)	(86)
Product [Member] | Intersegment Elimination [Member] | West [Member]
Segment revenues
Revenues		(98)	(184)	(244)	(573)
Product [Member] | Intersegment Elimination [Member] | Gas & NGL Marketing Services
Segment revenues
Revenues	[1]	63	195	224	349
Product [Member] | Intersegment Elimination [Member] | Other [Member]
Segment revenues
Revenues		(79)	(207)	(218)	(442)
Product [Member] | Operating Segments [Member] | Transmission And Gulf Of Mexico [Member]
Segment revenues
Revenues		63	121	197	334
Product [Member] | Operating Segments [Member] | Northeast G And P [Member]
Segment revenues
Revenues		27	40	104	110
Product [Member] | Operating Segments [Member] | West [Member]
Segment revenues
Revenues		112	245	287	684
Product [Member] | Operating Segments [Member] | Gas & NGL Marketing Services
Segment revenues
Revenues	[1]	556	884	1,658	2,724
Product [Member] | Operating Segments [Member] | Other [Member]
Segment revenues
Revenues		118	238	303	522
Energy Commodities and Service
Segment revenues
Revenues	[2]	24	16	645	(491)
Energy Commodities and Service | Realized Gain (Loss)
Segment revenues
Revenues		(8)	(13)	169	(145)
Energy Commodities and Service | Unrealized Gain (Loss)
Segment revenues
Revenues		32	29	476	(346)
Energy Commodities and Service | Intersegment Elimination [Member]
Segment revenues
Revenues	[2]	0	0	0	0
Energy Commodities and Service | Intersegment Elimination [Member] | Realized Gain (Loss)
Segment revenues
Revenues		0	0	0	0
Energy Commodities and Service | Intersegment Elimination [Member] | Unrealized Gain (Loss)
Segment revenues
Revenues		0	0	0	0
Energy Commodities and Service | Operating Segments [Member] | Transmission And Gulf Of Mexico [Member]
Segment revenues
Revenues	[2]	1	1	2	1
Energy Commodities and Service | Operating Segments [Member] | Transmission And Gulf Of Mexico [Member] | Realized Gain (Loss)
Segment revenues
Revenues		1	0	2	0
Energy Commodities and Service | Operating Segments [Member] | Transmission And Gulf Of Mexico [Member] | Unrealized Gain (Loss)
Segment revenues
Revenues		0	1	0	1
Energy Commodities and Service | Operating Segments [Member] | Northeast G And P [Member]
Segment revenues
Revenues	[2]	0	0	0	0
Energy Commodities and Service | Operating Segments [Member] | Northeast G And P [Member] | Realized Gain (Loss)
Segment revenues
Revenues		0	0	0	0
Energy Commodities and Service | Operating Segments [Member] | Northeast G And P [Member] | Unrealized Gain (Loss)
Segment revenues
Revenues		0	0	0	0
Energy Commodities and Service | Operating Segments [Member] | West [Member]
Segment revenues
Revenues	[2]	13	(9)	85	(23)
Energy Commodities and Service | Operating Segments [Member] | West [Member] | Realized Gain (Loss)
Segment revenues
Revenues		13	(9)	85	(23)
Energy Commodities and Service | Operating Segments [Member] | West [Member] | Unrealized Gain (Loss)
Segment revenues
Revenues		0	0	0	0
Energy Commodities and Service | Operating Segments [Member] | Gas & NGL Marketing Services
Segment revenues
Revenues	[1],[2]	2	53	535	(375)
Energy Commodities and Service | Operating Segments [Member] | Gas & NGL Marketing Services | Realized Gain (Loss)
Segment revenues
Revenues	[1]	(31)	54	41	(18)
Energy Commodities and Service | Operating Segments [Member] | Gas & NGL Marketing Services | Unrealized Gain (Loss)
Segment revenues
Revenues	[1]	33	(1)	494	(357)
Energy Commodities and Service | Operating Segments [Member] | Other [Member]
Segment revenues
Revenues	[2]	8	(29)	23	(94)
Energy Commodities and Service | Operating Segments [Member] | Other [Member] | Realized Gain (Loss)
Segment revenues
Revenues		9	(58)	41	(104)
Energy Commodities and Service | Operating Segments [Member] | Other [Member] | Unrealized Gain (Loss)
Segment revenues
Revenues		$ (1)	$ 29	$ (18)	$ 10
[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 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 on derivatives held for energy trading purposes are presented on a net basis in revenue.

Subsequent Events (Details)

Subsequent Events (Details) - West [Member] - USD ($) $ in Millions	1 Months Ended
	Oct. 31, 2023	Sep. 30, 2023
Rocky Mountain Midstream Holdings LLC [Member]
Subsequent Event [Line Items]
Equity Method Investment, Ownership Percentage		50%
Subsequent Event [Member] | Scenario, Plan | Rocky Mountain Midstream Holdings LLC [Member]
Subsequent Event [Line Items]
Equity Method Investment, Ownership Percentage	100%
Subsequent Event [Member] | Scenario, Plan | DJ Basin Acquisition
Subsequent Event [Line Items]
Business Combination, Consideration Transferred	$ 560
Subsequent Event [Member] | Scenario, Plan | RMM Acquisition
Subsequent Event [Line Items]
Business Combination, Consideration Transferred	$ 714
Subsequent Event [Member] | Scenario, Plan | RMM Acquisition | Rocky Mountain Midstream Holdings LLC [Member]
Subsequent Event [Line Items]
Business Acquisition, Percentage of Voting Interests Acquired	50%