The Williams Companies, Inc. (WMB) 10-K 25 Feb 25 2024 FY Annual report Financial data

Audit Information

Audit Information	12 Months Ended
	Dec. 31, 2024
Auditor [Line Items]
Auditor Name	Ernst & Young LLP
Auditor Location	Tulsa, Oklahoma
Auditor Firm ID	42
Transcontinental Gas Pipe Line Company, LLC [Member]
Auditor [Line Items]
Auditor Name	Ernst & Young LLP
Auditor Location	Houston, Texas
Auditor Firm ID	42
Northwest Pipeline LLC [Member]
Auditor [Line Items]
Auditor Name	Ernst & Young LLP
Auditor Location	Houston, Texas
Auditor Firm ID	42

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2024	Feb. 20, 2025	Jun. 30, 2024
Document Information [Line Items]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2024
Document Transition Report	false
Entity Registrant Name	Williams Companies, Inc.
Entity File Number	1-4174
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
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 Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
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
ICFR Auditor Attestation Flag	true
DocumentFinStmtErrorCorrectionFlag	true
Document Financial Statement Restatement Recovery Analysis [Flag]	false
Entity Shell Company	false
Entity Public Float			$ 49,974,668,630
Entity Common Stock, Shares Outstanding		1,219,369,295
Documents Incorporated by Reference [Text Block]	Portions of the Williams’ Definitive Proxy Statement for the Williams’ Annual Meeting of Stockholders to be held on April 29, 2025, are incorporated into Part III, as specifically set forth in Part III.
Entity Central Index Key	0000107263
Amendment Flag	false
Document Fiscal Year Focus	2024
Document Fiscal Period Focus	FY
Current Fiscal Year End Date	--12-31
Transcontinental Gas Pipe Line Company, LLC [Member]
Document Information [Line Items]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2024
Document Transition Report	false
Entity Registrant Name	Transcontinental Gas Pipe Line Company, LLC
Entity File Number	1-7584
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	74-1079400
Entity Address, Address Line One	2800 Post Oak Boulevard
Entity Address, City or Town	Houston
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77056
City Area Code	713
Local Phone Number	215-2000
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	false
DocumentFinStmtErrorCorrectionFlag	false
Entity Shell Company	false
Entity Public Float			0
Entity Common Stock, Shares Outstanding		0
Entity Central Index Key	0000099250
Amendment Flag	false
Document Fiscal Year Focus	2024
Document Fiscal Period Focus	FY
Current Fiscal Year End Date	--12-31
Northwest Pipeline LLC [Member]
Document Information [Line Items]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2024
Document Transition Report	false
Entity Registrant Name	Northwest Pipeline LLC
Entity File Number	1-7414
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	26-1157701
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
City Area Code	800
Local Phone Number	945-5426
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	false
DocumentFinStmtErrorCorrectionFlag	false
Entity Shell Company	false
Entity Public Float			$ 0
Entity Common Stock, Shares Outstanding		0
Entity Central Index Key	0000110019
Amendment Flag	false
Document Fiscal Year Focus	2024
Document Fiscal Period Focus	FY
Current Fiscal Year End Date	--12-31

Consolidated Statement of Incom

Consolidated Statement of Income - Williams - USD ($) shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Revenues:
Revenues	$ 10,503	$ 10,907	$ 10,965
Costs and expenses:
Operating and maintenance expenses	2,179	1,984	1,817
Depreciation and amortization expenses	2,219	2,071	2,009
Selling, general, and administrative expenses	708	665	636
Gain on sale of business (Note 3)	0	(129)	0
Other (income) expense – net	(60)	(30)	28
Total costs and expenses	7,164	6,596	7,947
Operating income (loss)	3,339	4,311	3,018
Equity earnings (losses)	560	589	637
Other investing income (loss) – net	343	108	16
Interest Expense, Nonoperating	(1,364)	(1,236)	(1,147)
Gain (Loss) Related to Litigation Settlement	0	534	0
Other income (expense) – net	108	99	18
Income (loss) before income taxes	2,986	4,405	2,542
Less: Provision (benefit) for income taxes	640	1,005	425
Income (Loss) from Continuing Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	2,346	3,400	2,117
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	0	(97)	0
Net income (loss)	2,346	3,303	2,117
Less: Net income (loss) attributable to noncontrolling interests	121	124	68
Net income (loss) attributable to The Williams Companies, Inc.	2,225	3,179	2,049
Less: Preferred stock dividends	3	3	3
Net income (loss) available to common stockholders	2,222	3,176	2,046
Amounts attributable to The Williams Companies, Inc. available to common stockholders:
Income (loss) from continuing operations	2,222	3,273	2,046
Income (loss) from discontinued operations (Note 1)	$ 0	$ (97)	$ 0
Basic earnings (loss) per common share:
Income (Loss) from Continuing Operations, Per Basic Share	$ 1.82	$ 2.69	$ 1.68
Income (Loss) from Discontinued Operations and Disposal of Discontinued Operations, Net of Tax, Per Basic Share	0	(0.08)	0
Net income (loss) available to common stockholders - Basic	$ 1.82	$ 2.61	$ 1.68
Weighted Average Number of Shares Outstanding, Basic	1,219,184	1,217,784	1,218,362
Diluted earnings (loss) per common share:
Income (Loss) from Continuing Operations, Per Diluted Share	$ 1.82	$ 2.68	$ 1.67
Income (Loss) from Discontinued Operations and Disposal of Discontinued Operations, Net of Tax, Per Diluted Share	0	(0.08)	0
Net income (loss) available to common stockholders - Diluted	$ 1.82	$ 2.60	$ 1.67
Weighted Average Number of Shares Outstanding, Diluted	1,222,954	1,222,715	1,222,672
Service [Member]
Revenues:
Revenues	$ 7,628	$ 7,026	$ 6,536
NonRegulated Service Commodity Consideration [Member]
Revenues:
Revenues	134	146	260
Product [Member]
Revenues:
Revenues	2,991	2,779	4,556
Energy Commodities and Service
Revenues:
Revenues	(250)	956	(387)
Oil and Gas, Purchased [Member]
Costs and expenses:
Cost of Goods and Service, Excluding Depreciation, Depletion, and Amortization	2,075	1,884	3,369
Natural Gas Purchased For Shrink [Member]
Costs and expenses:
Cost of Goods and Service, Excluding Depreciation, Depletion, and Amortization	$ 43	$ 151	$ 88

Consolidated Statement of Compr

Consolidated Statement of Comprehensive Income (Loss) - Williams - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Comprehensive income (loss):
Net income (loss)	$ 2,346	$ 3,303	$ 2,117
Designated interest rate cash flow hedging activities:
Net unrealized gain (loss) from derivative instruments, net of taxes of $(2), $(8), and $1 in 2024, 2023, and 2022, respectively	6	26	(3)
Reclassifications into earnings of net derivative instruments (gain) loss, net of taxes of $1, $1 and $— in 2024, 2023, and 2022, respectively	(2)	(2)	0
Pension and other postretirement benefits:
Net actuarial gain (loss) arising during the year, net of taxes of $(24), $—, and $1 in 2024, 2023, and 2022, respectively	72	(2)	1
Amortization of actuarial (gain) loss and net actuarial loss from settlements included in net periodic benefit cost (credit), net of taxes of $1, $—, and $(4) in 2024, 2023, and 2022, respectively	0	3	11
Other comprehensive income (loss)	76	25	9
Comprehensive income (loss)	2,422	3,328	2,126
Less: Comprehensive income (loss) attributable to noncontrolling interests	121	124	68
Comprehensive income (loss) attributable to The Williams Companies, Inc.	$ 2,301	$ 3,204	$ 2,058

Consolidated Statement of Com_2

Consolidated Statement of Comprehensive Income (Loss) (Parenthetical) - Williams - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Cash flow hedging activities:
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), before Reclassification, Tax	$ (2)	$ (8)	$ 1
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, Tax	1	1	0
Pension and other postretirement benefits:
Other Comprehensive Income (Loss), Defined Benefit Plan, Net Actuarial Gain (Loss) Arising During Period, Tax	(24)	0	1
Other Comprehensive Income Loss, Reclassification Pension And Other Postretirement Benefit Plans Net Gain Loss Included In Net Periodic Benefit Cost (Credit), Tax	$ 1	$ 0	$ (4)

Consolidated Balance Sheet - Wi

Consolidated Balance Sheet - Williams - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Current assets:
Cash and cash equivalents	$ 60	$ 2,150
Receivables, Net, Current	1,863	1,655
Inventories	279	274
Derivative assets	267	239
Other current assets and deferred charges	192	195
Total current assets	2,661	4,513
Investments	4,140	4,637
Property, Plant and Equipment, Net	38,692	34,311
Intangible assets – net of accumulated amortization	7,209	7,593
Regulatory assets, deferred charges, and other	1,830	1,573
Total assets	54,532	52,627
Current liabilities:
Accounts payable	1,613	1,379
Derivative Liability, Current	164	105
Other current liabilities	1,360	1,284
Commercial paper	455	725
Long-term debt due within one year	1,720	2,337
Total current liabilities	5,312	5,830
Long-term debt	24,736	23,376
Deferred income tax liabilities	4,376	3,846
Regulatory liabilities, deferred income, and other	5,268	4,684
Contingent liabilities and commitments (Note 18)
Stockholders’ equity:
Preferred stock ($1 par value; 30 million shares authorized at December 31, 2024 and December 31, 2023; 35 thousand shares issued at December 31, 2024 and December 31, 2023)	35	35
Common stock ($1 par value; 1,470 million shares authorized at December 31, 2024 and December 31, 2023; 1,258 million shares issued at December 31, 2024 and 1,256 million shares issued at December 31, 2023)	1,258	1,256
Capital in excess of par value	24,643	24,578
Retained deficit	(12,396)	(12,287)
Accumulated other comprehensive income (loss)	76	0
Treasury stock, at cost (39 million shares at December 31, 2024 and December 31, 2023 of common stock)	(1,180)	(1,180)
Total stockholders’ equity	12,436	12,402
Noncontrolling interests in consolidated subsidiaries	2,404	2,489
Total equity	14,840	14,891
Total liabilities and equity	$ 54,532	$ 52,627

Consolidated Balance Sheet (Par

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

Consolidated Statement of Chang

Consolidated Statement of Changes in Equity - Williams - USD ($) $ in Millions	Total	Preferred Stock	Common Stock	Capital in Excess of Par Value	Retained Deficit	Accumulated Other Comprehensive Income (Loss)	Treasury Stock	Total Stockholders' Equity	Noncontrolling Interests
Beginning balance at Dec. 31, 2021	$ 14,101	$ 35	$ 1,250	$ 24,449	$ (13,237)	$ (33)	$ (1,041)	$ 11,423	$ 2,678
Net income (loss)	2,117	0	0	0	2,049	0	0	2,049	68
Other comprehensive income (loss)	9	0	0	0	0	9	0	9	0
Dividends, Common Stock, Cash	(2,071)	0	0	0	(2,071)	0	0	(2,071)	0
Stock-based compensation and related common stock issuances, net of tax	96	0	3	93	0	0	0	96	0
Dividends and distributions to noncontrolling interests	(204)	0	0	0	0	0	0	0	(204)
Contributions from noncontrolling interests	18	0	0	0	0	0	0	0	18
Purchases of treasury stock	(9)	0	0	0	0	0	(9)	(9)	0
Other	(12)	0	0	0	(12)	0	0	(12)	0
Net increase (decrease) in equity	(56)	0	3	93	(34)	9	(9)	62	(118)
Ending balance at Dec. 31, 2022	14,045	35	1,253	24,542	(13,271)	(24)	(1,050)	11,485	2,560
Net income (loss)	3,303	0	0	0	3,179	0	0	3,179	124
Other comprehensive income (loss)	25	0	0	0	0	25	0	25	0
Dividends, Common Stock, Cash	(2,179)	0	0	0	(2,179)	0	0	(2,179)	0
Stock-based compensation and related common stock issuances, net of tax	38	0	3	35	0	0	0	38	0
Dividends and distributions to noncontrolling interests	(213)	0	0	0	0	0	0	0	(213)
Contributions from noncontrolling interests	18	0	0	0	0	0	0	0	18
Purchases of treasury stock	(130)	0	0	0	0	0	(130)	(130)	0
Other	(16)	0	0	1	(16)	(1)	0	(16)	0
Net increase (decrease) in equity	846	0	3	36	984	24	(130)	917	(71)
Ending balance at Dec. 31, 2023	14,891	35	1,256	24,578	(12,287)	0	(1,180)	12,402	2,489
Net income (loss)	2,346	0	0	0	2,225	0	0	2,225	121
Other comprehensive income (loss)	76	0	0	0	0	76	0	76	0
Dividends, Common Stock, Cash	(2,316)	0	0	0	(2,316)	0	0	(2,316)	0
Stock-based compensation and related common stock issuances, net of tax	67	0	2	65	0	0	0	67	0
Dividends and distributions to noncontrolling interests	(242)	0	0	0	0	0	0	0	(242)
Contributions from noncontrolling interests	36	0	0	0	0	0	0	0	36
Purchases of treasury stock	0
Other	(18)	0	0	0	(18)	0	0	(18)	0
Net increase (decrease) in equity	(51)	0	2	65	(109)	76	0	34	(85)
Ending balance at Dec. 31, 2024	$ 14,840	$ 35	$ 1,258	$ 24,643	$ (12,396)	$ 76	$ (1,180)	$ 12,436	$ 2,404

Consolidated Statement of Cha_2

Consolidated Statement of Changes in Equity (Parenthetical) - Williams - $ / shares	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Statement of Stockholders' Equity [Abstract]
Common Stock, Dividends, Per Share, Declared	$ 1.90	$ 1.79	$ 1.70

Consolidated Statement of Cash

Consolidated Statement of Cash Flows - Williams - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
OPERATING ACTIVITIES:
Net income (loss)	$ 2,346	$ 3,303	$ 2,117
Adjustments to reconcile to net cash provided (used) by operating activities:
Depreciation and amortization	2,219	2,071	2,009
Provision (benefit) for deferred income taxes	506	951	431
Equity (earnings) losses	(560)	(589)	(637)
Distributions from equity-method investees (Note 8)	789	796	865
Net unrealized (gain) loss from commodity derivative instruments	367	(660)	249
Gain on sale of business (Note 3)	0	(129)	0
Gain on disposition of equity-method investments (Note 8)	(149)	0	0
Gain on remeasurement of equity-method investments (Note 3)	(127)	(30)	0
Inventory write-downs	10	30	161
Amortization of stock-based awards	99	77	73
Cash provided (used) by changes in current assets and liabilities:
Accounts receivable	(169)	1,089	(733)
Inventories	(9)	13	(110)
Other current assets and deferred charges	9	60	(33)
Accounts payable	139	(1,009)	410
Other current liabilities	35	(19)	209
Changes in current and noncurrent commodity derivative assets and liabilities	(286)	200	94
Other, including changes in noncurrent assets and liabilities	(245)	(216)	(216)
Net cash provided (used) by operating activities	4,974	5,938	4,889
FINANCING ACTIVITIES:
Proceeds from (payments of) commercial paper – net	(269)	372	345
Proceeds from long-term debt	3,594	2,755	1,755
Payments of long-term debt	(2,946)	(634)	(2,876)
Payments for debt issuance costs	(32)	(23)	(17)
Proceeds from issuance of common stock	10	6	54
Purchases of treasury stock	0	(130)	(9)
Common dividends paid	(2,316)	(2,179)	(2,071)
Dividends and distributions paid to noncontrolling interests	(242)	(213)	(204)
Contributions from noncontrolling interests	36	18	18
Other – net	(36)	(21)	(37)
Net cash provided (used) by financing activities	(2,201)	(49)	(3,042)
INVESTING ACTIVITIES:
Capital expenditures (1)	(2,573)	(2,516)	(2,253)
Dispositions – net	(105)	(51)	(30)
Proceeds from sale of business (Note 3)	0	346	0
Purchases of businesses, net of cash acquired (Note 3)	(2,244)	(1,568)	(933)
Proceeds from dispositions of equity-method investments (Note 8)	161	0	0
Purchases of and contributions to equity-method investments (Note 8)	(114)	(141)	(166)
Other – net	12	39	7
Net cash provided (used) by investing activities	(4,863)	(3,891)	(3,375)
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total	(2,090)	1,998	(1,528)
Cash and cash equivalents at beginning of year	2,150	152	1,680
Cash and cash equivalents at end of year	60	2,150	152
Additional Cash Flow Elements and Supplemental Cash Flow Information [Abstract]
(1)  Increases to property, plant, and equipment	(2,581)	(2,564)	(2,394)
Changes in related accounts payable and accrued liabilities	8	48	141
Capital expenditures	$ (2,573)	$ (2,516)	$ (2,253)

Statement of Net Income - Trans

Statement of Net Income - Transco - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Revenues [Abstract]
Revenues	$ 10,503	$ 10,907	$ 10,965
Costs and Expenses [Abstract]
Depreciation and amortization	2,219	2,071	2,009
Other Operating Income (Expense), Net	(60)	(30)	28
Total costs and expenses	7,164	6,596	7,947
Operating income (loss)	3,339	4,311	3,018
Interest Expense, Nonoperating	(1,364)	(1,236)	(1,147)
Other Nonoperating Income (Expense)	108	99	18
Net income	2,225	3,179	2,049
Transcontinental Gas Pipe Line Company, LLC [Member]
Revenues [Abstract]
Revenues	2,964	2,866	2,909
Costs and Expenses [Abstract]
Cost of natural gas sales	118	137	179
Utilities Operating Expense, Maintenance and Operations	510	517	531
General and Administrative Expense	216	215	225
Depreciation and amortization	545	519	513
Taxes, Miscellaneous	111	105	98
Other Operating Income (Expense), Net	(35)	(38)	(7)
Total costs and expenses	1,465	1,455	1,539
Operating income (loss)	1,499	1,411	1,370
Interest Expense, Nonoperating	(324)	(324)	(327)
Interest Income, Other	58	87	36
Public Utilities, Allowance for Funds Used During Construction, Additions	88	77	28
Other Nonoperating Income (Expense)	(8)	(4)	(7)
Net income	1,313	1,247	1,100
Natural Gas, US Regulated | Transcontinental Gas Pipe Line Company, LLC [Member]
Revenues [Abstract]
Revenues	2,619	2,506	2,503
Natural Gas, Storage | Transcontinental Gas Pipe Line Company, LLC [Member]
Revenues [Abstract]
Revenues	200	186	193
Natural Gas, Gathering, Transportation, Marketing and Processing | Transcontinental Gas Pipe Line Company, LLC [Member]
Revenues [Abstract]
Revenues	118	137	179
Product and Service, Other | Transcontinental Gas Pipe Line Company, LLC [Member]
Revenues [Abstract]
Revenues	$ 27	$ 37	$ 34

Balance Sheet - Transco

Balance Sheet - Transco - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Assets, Current [Abstract]
Cash and cash equivalents	$ 60	$ 2,150
Inventory, Net	279	274
Other current assets and deferred charges	192	195
Current assets	2,661	4,513
Property, Plant and Equipment, Net	38,692	34,311
Other Assets, Noncurrent	1,830	1,573
Total assets	54,532	52,627
Liabilities, Current [Abstract]
Accounts payable	1,613	1,379
Regulatory Liability, Current	85	77
Other current liabilities	1,360	1,284
Asset Retirement Obligation, Current	91	106
Total current liabilities	5,312	5,830
Contingent liabilities and commitments
Members' Equity [Abstract]
Retained Earnings (Accumulated Deficit)	(12,396)	(12,287)
Total liabilities and equity	54,532	52,627
Transcontinental Gas Pipe Line Company, LLC [Member]
Assets, Current [Abstract]
Cash and cash equivalents	0	0
Accounts and Other Receivables, Net, Current	12	11
Inventory, Net	81	83
Regulatory Assets, Current	74	87
Other current assets and deferred charges	24	14
Current assets	1,103	1,809
Property, Plant and Equipment, Net	14,103	13,330
Regulatory Assets, Noncurrent	320	299
Other Assets, Noncurrent	405	350
Total assets	15,931	15,788
Liabilities, Current [Abstract]
Accounts Payable, Trade, Current	258	278
Regulatory Liability, Current	58	49
Other current liabilities	181	190
Asset Retirement Obligation, Current	22	96
Long-Term Debt, Current Maturities	35	32
Total current liabilities	609	700
Long-Term Debt, Excluding Current Maturities	5,200	5,229
Regulatory Liabilities, Noncurrent	976	956
Asset Retirement Obligations, Noncurrent	593	524
Other Liabilities, Noncurrent	248	242
Contingent liabilities and commitments
Members' Equity [Abstract]
Members' Capital	5,088	5,088
Retained Earnings (Accumulated Deficit)	3,217	3,049
Total Members' Equity	8,305	8,137
Total liabilities and equity	15,931	15,788
Transcontinental Gas Pipe Line Company, LLC [Member] | Related Party
Assets, Current [Abstract]
Accounts and Financing Receivable, after Allowance for Credit Loss, Current	638	1,353
Accounts Receivable, after Allowance for Credit Loss, Current	24	10
Liabilities, Current [Abstract]
Accounts payable	55	55
Transcontinental Gas Pipe Line Company, LLC [Member] | Nonrelated Party
Assets, Current [Abstract]
Accounts Receivable, after Allowance for Credit Loss, Current	$ 250	$ 251

Statement of Changes in Member'

Statement of Changes in Member's Equity - Transco - USD ($) $ in Millions	Total	Transcontinental Gas Pipe Line Company, LLC [Member]	Member's Capital Transcontinental Gas Pipe Line Company, LLC [Member]	Retained Earnings Transcontinental Gas Pipe Line Company, LLC [Member]
Balance at beginning of year at Dec. 31, 2021			$ 4,960	$ 2,760
Cash contributions from parent		$ (128)	128
Net income	$ 2,049	1,100		1,100
Cash distributions to parent		838		(838)
Balance at end of year at Dec. 31, 2022		8,110	5,088	3,022
Cash contributions from parent		0	0
Net income	3,179	1,247		1,247
Cash distributions to parent		1,220		(1,220)
Balance at end of year at Dec. 31, 2023		8,137	5,088	3,049
Cash contributions from parent		0	0
Net income	$ 2,225	1,313		1,313
Cash distributions to parent		1,145		(1,145)
Balance at end of year at Dec. 31, 2024		$ 8,305	$ 5,088	$ 3,217

Statement of Cash Flows - Trans

Statement of Cash Flows - Transco - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Net Cash Provided by (Used in) Operating Activities [Abstract]
Net income	$ 2,346	$ 3,303	$ 2,117
Adjustments to Reconcile Net Income (Loss) to Cash Provided by (Used in) Operating Activities [Abstract]
Depreciation and amortization	2,219	2,071	2,009
Increase (Decrease) in Operating Capital [Abstract]
Increase (Decrease) in Inventories	(9)	13	(110)
Increase (Decrease) in Other Current Assets	9	60	(33)
Other current liabilities	35	(19)	209
Other Operating Activities, Cash Flow Statement	(245)	(216)	(216)
Net cash provided (used) by operating activities	4,974	5,938	4,889
Net Cash Provided by (Used in) Financing Activities [Abstract]
Net cash provided (used) by financing activities	(2,201)	(49)	(3,042)
Net Cash Provided by (Used in) Investing Activities [Abstract]
Capital expenditures (1)	(2,573)	(2,516)	(2,253)
Net cash provided (used) by investing activities	(4,863)	(3,891)	(3,375)
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total	(2,090)	1,998	(1,528)
Cash and cash equivalents at beginning of year	2,150	152	1,680
Cash and cash equivalents at end of year	60	2,150	152
Additional Cash Flow Elements and Supplemental Cash Flow Information [Abstract]
Property, Plant and Equipment, Additions	(2,581)	(2,564)	(2,394)
Capital expenditures	(2,573)	(2,516)	(2,253)
Transcontinental Gas Pipe Line Company, LLC [Member]
Net Cash Provided by (Used in) Operating Activities [Abstract]
Net income	1,313	1,247	1,100
Adjustments to Reconcile Net Income (Loss) to Cash Provided by (Used in) Operating Activities [Abstract]
Depreciation and amortization	545	519	513
Increase (Decrease) in Allowance for Equity Funds Used During Construction	(71)	(63)	(23)
Increase (Decrease) in Operating Capital [Abstract]
Increase (Decrease) in Accounts Receivable, Related Parties	(14)	(1)	(1)
Increase (Decrease) in Accounts and Other Receivables	0	6	(20)
Increase (Decrease) in Inventories	2	10	(39)
Increase (Decrease) in Other Regulatory Assets	13	37	(10)
Increase (Decrease) in Other Current Assets	(10)	27	(17)
Increase (Decrease) in Accounts Payable, Trade	(4)	(18)	21
Increase (Decrease) in Accounts Payable, Related Parties	0	1	(15)
Other current liabilities	(63)	72	(31)
Other Operating Activities, Cash Flow Statement	(15)	(122)	38
Net cash provided (used) by operating activities	1,696	1,715	1,516
Net Cash Provided by (Used in) Financing Activities [Abstract]
Proceeds from Issuance of Other Long-Term Debt	2	7	9
Repayments of Other Long-Term Debt	(32)	(29)	(26)
Cash distributions to parent	(1,145)	(1,220)	(838)
Cash contributions from parent	0	0	128
Net cash provided (used) by financing activities	(1,175)	(1,242)	(727)
Net Cash Provided by (Used in) Investing Activities [Abstract]
Capital expenditures (1)	(1,140)	(894)	(603)
Contributions in aid of construction	16	21	1
Payments for (Proceeds from) Removal Costs	(110)	(51)	(33)
IncreaseDecreaseInAdvancesToAffiliates	715	460	(143)
Payments to Acquire Investments to be Held in Decommissioning Trust Fund	(23)	(22)	(21)
Proceeds from Decommissioning Trust Fund Assets	21	13	10
Net cash provided (used) by investing activities	(521)	(473)	(789)
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total	0	0	0
Cash and cash equivalents at beginning of year	0	0	0
Cash and cash equivalents at end of year	0	0	0
Additional Cash Flow Elements and Supplemental Cash Flow Information [Abstract]
Property, Plant and Equipment, Additions	(1,112)	(991)	(587)
Increase (Decrease) in Accounts Payable And Accrued Liabilities Related To Capital Expenditures	(28)	97	(16)
Capital expenditures	$ (1,140)	$ (894)	$ (603)

Statement of Net Income - NWP

Statement of Net Income - NWP - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Revenues [Abstract]
Revenues	$ 10,503	$ 10,907	$ 10,965
Costs and Expenses [Abstract]
Depreciation and amortization expenses	1,800	1,700	1,500
Other Operating Income (Expense), Net	(60)	(30)	28
Operating income (loss)	3,339	4,311	3,018
Interest Expense, Nonoperating	(1,364)	(1,236)	(1,147)
Other Nonoperating Income (Expense)	108	99	18
Net income (loss) attributable to The Williams Companies, Inc.	2,225	3,179	2,049
Northwest Pipeline LLC [Member]
Revenues [Abstract]
Revenues	444	440	448
Costs and Expenses [Abstract]
Utilities Operating Expense, Maintenance and Operations	95	88	84
General and Administrative Expense	51	51	52
Depreciation and amortization expenses	111	111	114
Taxes, Miscellaneous	14	12	17
Other Operating Income (Expense), Net	(18)	(16)	22
Operating Expenses	253	246	289
Operating income (loss)	191	194	159
Interest Expense, Nonoperating	(28)	(28)	(31)
Public Utilities, Allowance for Funds Used During Construction, Additions	10	4	3
Other Nonoperating Income (Expense)	7	10	6
Net income (loss) attributable to The Williams Companies, Inc.	180	180	137
Natural Gas, US Regulated | Northwest Pipeline LLC [Member]
Revenues [Abstract]
Revenues	416	415	430
Natural Gas, Storage | Northwest Pipeline LLC [Member]
Revenues [Abstract]
Revenues	15	15	13
Product and Service, Other | Northwest Pipeline LLC [Member]
Revenues [Abstract]
Revenues	$ 13	$ 10	$ 5

Balance Sheet - NWP

Balance Sheet - NWP - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Assets, Current [Abstract]
Cash and cash equivalents	$ 60	$ 2,150
Inventory, Net	279	274
Other current assets and deferred charges	192	195
Current assets	2,661	4,513
Property, Plant and Equipment, Net	38,692	34,311
Other Assets, Noncurrent	1,830	1,573
Total assets	54,532	52,627
Liabilities, Current [Abstract]
Accounts payable	1,613	1,379
Regulatory Liability, Current	85	77
Other current liabilities	1,360	1,284
Total current liabilities	5,312	5,830
Contingent liabilities and commitments
Members' Equity [Abstract]
Retained Earnings (Accumulated Deficit)	(12,396)	(12,287)
Total liabilities and equity	54,532	52,627
Northwest Pipeline LLC [Member]
Assets, Current [Abstract]
Cash and cash equivalents	0	0
Accounts and Other Receivables, Net, Current	2	1
Inventory, Net	9	8
Regulatory Assets, Current	6	2
Other current assets and deferred charges	6	5
Current assets	62	214
Property, Plant and Equipment, Net	2,129	1,949
Regulatory Assets, Noncurrent	49	36
Other Assets, Noncurrent	29	28
Total assets	2,269	2,227
Liabilities, Current [Abstract]
Accounts Payable, Trade, Current	48	48
Regulatory Liability, Current	20	21
Other current liabilities	34	34
Long-Term Debt, Current Maturities	85	0
Total current liabilities	225	116
Long-Term Debt, Excluding Current Maturities	497	581
Regulatory Liabilities, Noncurrent	233	252
Asset Retirement Obligations, Noncurrent	144	136
Other Liabilities, Noncurrent	7	9
Contingent liabilities and commitments
Members' Equity [Abstract]
Members' Capital	1,074	1,074
Retained Earnings (Accumulated Deficit)	89	59
Total Members' Equity	1,163	1,133
Total liabilities and equity	2,269	2,227
Northwest Pipeline LLC [Member] | Related Party
Assets, Current [Abstract]
Accounts and Financing Receivable, after Allowance for Credit Loss, Current	0	158
Accounts Receivable, after Allowance for Credit Loss, Current	0	1
Liabilities, Current [Abstract]
Accounts payable	12	13
Northwest Pipeline LLC [Member] | Nonrelated Party
Assets, Current [Abstract]
Accounts Receivable, after Allowance for Credit Loss, Current	39	39
Northwest Pipeline LLC [Member] | Affiliated Entity
Assets, Current [Abstract]
Accounts and Financing Receivable, after Allowance for Credit Loss, Current		158
Liabilities, Current [Abstract]
Accounts payable	$ 26	$ 0

Statement of Changes in Membe_2

Statement of Changes in Member's Equity - NWP - USD ($) $ in Millions	Total	Northwest Pipeline LLC [Member]	Member's Capital Northwest Pipeline LLC [Member]	Retained Earnings Northwest Pipeline LLC [Member]
Balance at beginning of year at Dec. 31, 2021			$ 1,074	$ 35
Net income	$ 2,049	$ 137		137
Cash distributions to parent		138		(138)
Balance at end of year at Dec. 31, 2022		1,108	1,074	34
Net income	3,179	180		180
Cash distributions to parent		155		(155)
Balance at end of year at Dec. 31, 2023		1,133	1,074	59
Net income	$ 2,225	180		180
Cash distributions to parent		150		(150)
Balance at end of year at Dec. 31, 2024		$ 1,163	$ 1,074	$ 89

Statement of Cash Flows - NWP

Statement of Cash Flows - NWP - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Net Cash Provided by (Used in) Operating Activities [Abstract]
Net income	$ 2,346	$ 3,303	$ 2,117
Adjustments to Reconcile Net Income (Loss) to Cash Provided by (Used in) Operating Activities [Abstract]
Depreciation and amortization	2,219	2,071	2,009
Increase (Decrease) in Operating Capital [Abstract]
Increase (Decrease) in Inventories	(9)	13	(110)
Increase (Decrease) in Other Current Assets	9	60	(33)
Other current liabilities	35	(19)	209
Other Operating Activities, Cash Flow Statement	(245)	(216)	(216)
Net cash provided (used) by operating activities	4,974	5,938	4,889
Net Cash Provided by (Used in) Financing Activities [Abstract]
Net cash provided (used) by financing activities	(2,201)	(49)	(3,042)
Net Cash Provided by (Used in) Investing Activities [Abstract]
Capital expenditures (1)	(2,573)	(2,516)	(2,253)
Net cash provided (used) by investing activities	(4,863)	(3,891)	(3,375)
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total	(2,090)	1,998	(1,528)
Cash and cash equivalents at beginning of year	2,150	152	1,680
Cash and cash equivalents at end of year	60	2,150	152
Additional Cash Flow Elements and Supplemental Cash Flow Information [Abstract]
Property, Plant and Equipment, Additions	(2,581)	(2,564)	(2,394)
Capital expenditures	(2,573)	(2,516)	(2,253)
Northwest Pipeline LLC [Member]
Net Cash Provided by (Used in) Operating Activities [Abstract]
Net income	180	180	137
Adjustments to Reconcile Net Income (Loss) to Cash Provided by (Used in) Operating Activities [Abstract]
Depreciation and amortization	111	111	114
Increase (Decrease) in Allowance for Equity Funds Used During Construction	(8)	(3)	(2)
Increase (Decrease) in Operating Capital [Abstract]
Increase (Decrease) in Accounts Receivable, Related Parties	1	0	(1)
Increase (Decrease) in Accounts and Other Receivables	(1)	0	(1)
Increase (Decrease) in Inventories	(1)	1	0
Increase (Decrease) in Other Current Assets	(2)	1	0
Increase (Decrease) in Accounts Payable, Trade	(3)	4	(1)
Increase (Decrease) in Accounts Payable, Related Parties	(1)	1	(1)
IncreaseDecreaseInOtherRegulatoryLiabilities	1	(126)	145
Other current liabilities	(3)	3	1
Increase (Decrease) in Regulatory Assets Noncurrent	(15)	(29)	0
Increase (Decrease) in Regulatory Liabilities Noncurrent	(27)	(20)	(120)
Other Operating Activities, Cash Flow Statement	7	6	(3)
Net cash provided (used) by operating activities	239	129	268
Net Cash Provided by (Used in) Financing Activities [Abstract]
Cash distributions to parent	(150)	(155)	(138)
Increase Decrease In Advances From Affiliates	26	0	0
Net cash provided (used) by financing activities	(124)	(155)	(138)
Net Cash Provided by (Used in) Investing Activities [Abstract]
Capital expenditures (1)	(266)	(125)	(107)
Contributions in aid of construction	5	6	11
Payments for (Proceeds from) Removal Costs	(12)	(8)	(5)
IncreaseDecreaseInAdvancesToAffiliates	158	153	(29)
Net cash provided (used) by investing activities	(115)	26	(130)
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total	0	0	0
Cash and cash equivalents at beginning of year	0	0	0
Cash and cash equivalents at end of year	0	0	0
Additional Cash Flow Elements and Supplemental Cash Flow Information [Abstract]
Property, Plant and Equipment, Additions	(266)	(140)	(109)
Increase (Decrease) in Accounts Payable And Accrued Liabilities Related To Capital Expenditures	0	15	2
Capital expenditures	$ (266)	$ (125)	$ (107)

General, Description of Busines

General, Description of Business, Basis of Presentation, and Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2024
Organization, Consolidation and Presentation of Financial Statements [Abstract]
General, Description of Business, Basis of Presentation, and Summary of Significant Accounting Policies [Text Block]	Note 1 – General, Description of Business, Basis of Presentation, and Summary of Significant Accounting Policies General This report includes information for multiple registrants, specifically The Williams Companies, Inc. (Williams), as well as Transcontinental Gas Pipe Line Company, LLC (Transco) and Northwest Pipeline LLC (NWP) both of which are wholly owned subsidiaries of Williams (collectively, the Registrants). References to subsidiaries by name, including equity-method investees, Transco, and NWP, refer exclusively to those businesses and operations. Description of Business Williams Williams is a Delaware corporation whose common stock is listed and traded on the New York Stock Exchange. Its operations are located in the United States and are presented within the following reportable segments: Transmission & Gulf of America, Northeast G&P, West, and Gas & NGL Marketing Services, consistent with the manner in which Williams’ Chief Executive Officer, the chief operating decision maker, evaluates performance and allocates resources. All remaining business activities, including upstream operations, certain new energy ventures, and corporate activities, are included in Other. Transmission & Gulf of America is comprised of the Transco, NWP, and MountainWest Pipelines Holding Company (MountainWest) interstate natural gas pipelines and their related natural gas storage facilities, as well as the natural gas gathering and processing and crude oil production handling and transportation assets in the Gulf Coast region, including Discovery Producer Services LLC (Discovery), a former 60 percent equity-method investment in which Williams acquired the remaining ownership interest in August 2024 (see Note 3 – Acquisitions and Divestitures), a 51 percent interest in Gulfstar One LLC (Gulfstar One) (a consolidated variable interest entity, or VIE), and a 50 percent equity-method investment in Gulfstream Natural Gas System, L.L.C. (Gulfstream). Transmission & Gulf of America also includes natural gas storage facilities and pipelines providing services in north Texas, and also in Louisiana and Mississippi related to the January 2024 Gulf Coast Storage Acquisition (see Note 3 – Acquisitions and Divestitures). Northeast G&P is comprised of Williams’ midstream gathering, processing, and fractionation businesses in the Marcellus Shale region primarily in Pennsylvania and New York, and the Utica Shale region of eastern Ohio, as well as a 65 percent interest in Ohio Valley Midstream LLC (Northeast JV) (a consolidated VIE) which operates in West Virginia, Ohio, and Pennsylvania, a 66 percent interest in Cardinal Gas Services, L.L.C. (Cardinal) (a consolidated VIE) which operates in Ohio, a 69 percent equity-method investment in Laurel Mountain Midstream, LLC (Laurel Mountain), a 50 percent equity-method investment in Blue Racer Midstream LLC (Blue Racer), and Appalachia Midstream Services, LLC, a wholly owned subsidiary that owns equity-method investments with an approximate average 66 percent interest in multiple gas gathering systems in the Marcellus Shale region (Appalachia Midstream Investments). West is comprised of Williams’ gas gathering, processing, and treating operations in the Rocky Mountain region of Colorado and Wyoming, the Barnett Shale region of north-central Texas, the Eagle Ford Shale region of south Texas, the Haynesville Shale region of east Texas and northwest Louisiana, the Mid-Continent region which includes the Anadarko and Permian basins, and the Denver-Julesberg Basin (DJ Basin) of Colorado which includes Rocky Mountain Midstream Holdings LLC (RMM), a former 50 percent equity-method investment that Williams acquired the remaining ownership interest in November 2023 (see Note 3 – Acquisitions and Divestitures ) . This segment also includes Williams’ natural gas liquid (NGL) storage facilities, an undivided 50 percent interest in an NGL fractionator near Conway, Kansas, and a 50 percent equity-method investment in Overland Pass Pipeline Company LLC (OPPL). Gas & NGL Marketing Services is comprised of Williams’ 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. Transco Transco is an interstate natural gas transmission company that owns and operates a natural gas pipeline system extending from Texas, Louisiana, Mississippi and the Gulf of America through Alabama, Georgia, South Carolina, North Carolina, Virginia, Maryland, Delaware, Pennsylvania, and New Jersey to the New York City metropolitan area. The system serves customers in Texas and the 12 southeast and Atlantic seaboard states mentioned above, including major metropolitan areas in Georgia, Washington D.C., Maryland, North Carolina, New York, New Jersey, and Pennsylvania. Transco is a single-member limited liability company, and as such, single-member losses are limited to the amount of its investment. NWP NWP owns and operates an interstate pipeline system for the mainline transmission of natural gas. This system extends from the San Juan Basin in northwestern New Mexico and southwestern Colorado through Colorado, Utah, Wyoming, Idaho, Oregon, and Washington to a point on the Canadian border near Sumas, Washington. NWP is a single-member limited liability company, and as such, single-member losses are limited to the amount of its investment. Basis of Presentation Discontinued Operations During 2023, Williams recorded pre-tax charges of $125 million to Income (loss) from discontinued operations in the Consolidated Statement of Income related to litigation associated with its former Alaska refinery. Payments were made in January 2024 and the claims against Williams are now resolved. Except for this item and unless indicated otherwise, the information in the Combined Notes to Financial Statements relates to continuing operations. Net gain from Energy Transfer Litigation Judgment In November 2023, Williams received a $627 million payment from Energy Transfer Equity, L.P. (Energy Transfer) for the final order and judgment in connection to a lawsuit for breach of the Agreement and Plan of Merger with Energy Transfer. On the same day, Williams paid attorney fees which had been incurred on a contingent fee basis. This resulted in a net gain of $534 million reported as Net gain from Energy Transfer litigation judgment in the Consolidated Statement of Income for the year ended December 31, 2023. Reclassifications Certain prior-year amounts for Transco and NWP have been reclassified to conform to the current year’s presentation. These reclassifications had no impact on Transco’s or NWP’s net income (loss), working capital, cash flows or total member’s equity previously reported. Summary of Significant Accounting Policies Principles of Consolidation Williams’ consolidated financial statements include the accounts of all entities that Williams controls and its proportionate interest in the accounts of certain ventures in which it owns an undivided interest. Management’s judgment is required to evaluate whether it controls an entity. Key areas of that evaluation include: • Determining whether an entity is a VIE (see Note 2 – Variable Interest Entities); • Determining whether Williams is the primary beneficiary of a VIE, including evaluating which activities of a VIE most significantly impact its economic performance and the degree of power that Williams and its related parties have over those activities through its variable interests; • Identifying events that require reconsideration of whether an entity is a VIE and continuously evaluating whether Williams is a VIE’s primary beneficiary; • Evaluating whether other owners in entities that are not VIEs are able to effectively participate in significant decisions that would be expected to be made in the ordinary course of business such that Williams does not have the power to control such entities. Williams applies the equity method of accounting to investments over which it exercises significant influence but does not control. Distributions received from equity-method investees are presented in the Consolidated Statement of Cash Flows according to the nature of the distributions approach, which classifies distributions received from equity-method investees as either returns on investment (cash inflows from operating activities) or returns of investment (cash inflows from investing activities) based on the nature of the activities of the equity-method investee that generated the distribution. Use of Estimates 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 the financial statements and accompanying combined notes. Actual results could differ from those estimates. Significant estimates and assumptions may include: • Impairment assessments of investments, property, plant, and equipment, and intangible assets; • Litigation-related contingencies; • Environmental remediation obligations; • Depreciation and amortization of long-lived assets, which are comprised of property, plant, and equipment, and intangible assets; • Depreciation and/or amortization of equity-method investment basis differences; • Asset retirement obligations (AROs); • Measurement of fair value of commodity derivatives; • Pension and postretirement valuation variables; • Measurement of regulatory assets and liabilities; • Measurement of deferred income tax assets and liabilities, including assumptions related to the realization of deferred income tax assets; • Revenue recognition, including estimates utilized in recognition of deferred revenue; • Purchase price accounting. These estimates are discussed further throughout these combined notes. Regulatory Accounting Transco, NWP, and MountainWest are regulated by the Federal Energy Regulatory Commission (FERC), and these regulated entities’ rates may also be negotiated with customers pursuant to the terms of tariffs and FERC policy. Therefore, management has determined that it is appropriate under Accounting Standards Codification (ASC) Topic 980, “Regulated Operations,” (ASC 980) that certain costs that would otherwise be charged to expense should be deferred as regulatory assets, based on the expected recovery from customers in future rates. Likewise, certain actual or anticipated credits that would otherwise reduce expense should be deferred as regulatory liabilities, based on the expected return to customers in future rates. Management’s expected recovery of deferred costs and return of deferred credits generally results from specific decisions by regulators granting such ratemaking treatment. Certain incurred costs and obligations are recorded as regulatory assets or liabilities if, based on regulatory orders or other available evidence, it is probable that the costs or obligations will be included in amounts allowable for recovery or refunded in future rates. Accounting for these operations that are regulated can differ from the accounting requirements for nonregulated operations. For example, for regulated operations, allowance for funds used during construction (AFUDC) represents the estimated cost of debt and equity funds applicable to utility plant in the process of construction and is capitalized as a cost of property, plant, and equipment because it constitutes an actual cost of construction under established regulatory practices; nonregulated operations are only allowed to capitalize the cost of debt funds related to construction activities, while a component for equity is prohibited. Management has determined that for its regulated entities, it is appropriate to apply the accounting prescribed by ASC 980 and, accordingly, the accompanying financial statements include the effects of the types of transactions described above that result from regulatory accounting requirements (see Note 10 – Regulatory Assets and Liabilities). The FERC has prescribed a formula to be used in computing separate allowances for borrowed and equity AFUDC. These allowances are recorded as follows: Transco Year Ended December 31, 2024 2023 2022 (Millions) Allowance for borrowed funds used during construction $ 17 $ 14 $ 5 Allowance for equity funds used during construction 71 63 23 Allowance for equity and borrowed funds used during construction (AFUDC) $ 88 $ 77 $ 28 NWP Year Ended December 31, 2024 2023 2022 (Millions) Allowance for borrowed funds used during construction $ 2 $ 1 $ 1 Allowance for equity funds used during construction 8 3 2 Allowance for equity and borrowed funds used during construction (AFUDC) $ 10 $ 4 $ 3 Revenue Recognition Customers in Williams’ gas pipeline businesses, including Transco and NWP, are comprised of public utilities, municipalities, gas marketers and producers, intrastate pipelines, direct industrial users, and electrical power generators. Customers in Williams’ midstream businesses are comprised of oil and natural gas producer counterparties. Customers for Williams’ product sales are comprised of public utilities, gas marketers, and direct industrial users. Service revenue contracts from Williams’ gas pipeline and midstream businesses, including Transco and NWP, contain a series of distinct services, with the majority of the contracts having a single performance obligation that is satisfied over time as the customer simultaneously receives and consumes the benefits provided. Most of the product sales contracts have a single performance obligation with revenue recognized at a point in time when the products have been sold and delivered to the customer. Certain customers reimburse Williams for costs it incurs associated with construction of property, plant, and equipment utilized in its operations. For Williams’ rate-regulated gas pipeline businesses, including Transco and NWP, that apply ASC 980, Williams follows FERC guidelines with respect to reimbursement of construction costs. FERC tariffs only allow for cost reimbursement and are non-negotiable in nature; thus, in management’s judgment, the construction activities do not represent an ongoing major and central operation of the gas pipeline businesses and are not within the scope of ASC Topic 606, “Revenue from Contracts with Customers”. Accordingly, cost reimbursements are treated as a reduction to the cost of the constructed asset. For the midstream businesses, reimbursement and service contracts with customers are viewed together as providing the same commercial objective, as Williams has the ability to negotiate the mix of consideration between reimbursements and amounts billed over time. Accordingly, Williams generally recognizes reimbursements of construction costs from customers on a gross basis as a contract liability separate from the associated costs included within property, plant, and equipment. The contract liability is recognized into service revenues as the underlying performance obligations are satisfied. Service Revenues Gas pipeline businesses Revenues from the regulated interstate natural gas pipeline businesses, including Transco and NWP, which are subject to regulation by certain state and federal authorities, including the FERC, include both firm and interruptible transportation and storage contracts. Firm transportation and storage agreements provide for a daily or monthly reservation charge based on the pipeline or storage capacity reserved, and a commodity charge based on the volume of natural gas delivered/stored, each at rates specified in the FERC tariffs or based on negotiated contractual rates, with contract terms that are generally long-term in nature. Most of the long-term contracts contain an evergreen provision, which allows the contracts to be extended for periods primarily up to one year in length an indefinite number of times following the specified contract term and until terminated generally by either party. Interruptible transportation and storage agreements provide for a volumetric charge based on actual commodity transportation or storage utilized in the period in which those services are provided, and the contracts are generally limited to one-month periods or less. The related performance obligations include the following: • Firm transportation or storage under firm transportation and storage contracts—an integrated package of services typically constituting a single performance obligation, which includes standing ready to provide such services and receiving, transporting or storing (as applicable), and redelivering commodities; • Interruptible transportation or storage under interruptible transportation and storage contracts—an integrated package of services typically constituting a single performance obligation once scheduled, which includes receiving, transporting or storing (as applicable), and redelivering commodities. In situations where, in management’s judgment, it considers the integrated package of services as a single performance obligation, which represents a majority of its interstate natural gas pipeline contracts with customers, management does not consider there to be multiple performance obligations because the nature of the overall promise in the contract is to stand ready (with regard to firm transportation and storage contracts), receive, transport or store, and redeliver natural gas to the customer; therefore, revenue is recognized over time upon satisfaction of the daily stand ready performance obligation. Revenues are recognized for reservation charges over the performance obligation period, which is the contract term, regardless of the volume of natural gas that is transported or stored. Revenues for commodity charges from both firm and interruptible transportation services and storage services are recognized when natural gas is delivered at the agreed upon delivery point or when natural gas is injected or withdrawn from the storage facility because they specifically relate to efforts to provide these distinct services. Generally, reservation charges and commodity charges in the interstate natural gas pipeline businesses are recognized as revenue in the same period they are invoiced to its customers. As a result of the ratemaking process, certain amounts collected may be subject to refund upon the issuance of final orders by the FERC in pending rate proceedings. Management uses judgment to record estimates of rate refund liabilities considering its and other third-party regulatory proceedings, advice of counsel, and other risks. As of December 31, 2024 and 2023, there were no such rate refund liabilities for Transco and NWP. Midstream businesses Revenues from the nonregulated gathering, processing, transportation, and storage midstream businesses include contracts for natural gas gathering, processing, treating, compression, transportation, and other related services with contract terms that are generally long-term in nature and may extend up to the production life of the associated reservoir. Additionally, the midstream businesses generate revenues from fees charged for storing customers’ natural gas and NGLs, generally under prepaid contracted storage capacity contracts. In situations where, in management’s judgment, it provides an integrated package of services combined into a single performance obligation, which represents a majority of this class of contracts with customers, Williams does not consider there to be multiple performance obligations because the nature of the overall promise in the contract is to provide gathering, processing, transportation, storage, and related services resulting in the delivery, or redelivery in the context of storage services, of pipeline-quality natural gas and NGLs to the customer. As such, revenue is recognized at the daily completion of the integrated package of services as the integrated package represents a single performance obligation. Additionally, certain contracts in the midstream businesses contain fixed or upfront payment terms that result in the deferral of revenues until such services have been performed or such capacity has been made available. Williams also earns revenues from offshore crude oil and natural gas gathering and transportation and offshore production handling. These services represent an integrated package of services and are considered a single distinct performance obligation for which Williams recognizes revenues as the services are provided to the customer. Williams generally earns a contractually stated fee per unit for the volume of product transported, gathered, processed, or stored. The rate is generally fixed; however, certain contracts contain variable rates that are subject to change based on commodity prices, levels of throughput, or an annual adjustment based on a formulaic cost-of-service calculation. In addition, Williams has contracts with contractually stated fees that decline over the contract term, such as declines based on the passage of time periods or achievement of cumulative throughput amounts. The excess of consideration received over revenue recognized results in the deferral of those amounts until future periods based on a units of production or straight-line methodology as these methods appropriately match the consumption of services provided to the customer. The units of production methodology requires the use of production estimates that are uncertain and the use of judgment when developing estimates of future production volumes, thus impacting the rate of revenue recognition. Production estimates are monitored as circumstances and events warrant. Certain of Williams’ gas gathering and processing agreements have minimum volume commitments (MVC). If a customer under such an agreement fails to meet its MVC for a specified period (thus not exercising all the contractual rights to gathering and processing services within the specified period, herein referred to as “breakage”), it is obligated to pay a contractually determined fee based upon the shortfall between the actual gathered or processed volumes and the MVC for the period contained in the contract. When Williams concludes, based on management’s judgment, it is probable that the customer will not exercise all or a portion of its remaining rights, Williams recognizes revenue associated with such breakage amount in proportion to the pattern of exercised rights within the respective MVC period. Under keep-whole and percent-of-liquids processing contracts, Williams receives commodity consideration in the form of NGLs and takes title to the NGLs at the tailgate of the plant. Williams recognizes such commodity consideration as service revenue based on the market value of the NGLs retained at the time the processing is provided. The current market value, as opposed to the market value at the contract inception date, is used due to a combination of factors, including the fact that the volume, mix, and market price of NGL consideration to be received is unknown at the time of contract execution and is not specified in Williams’ contracts with customers. Additionally, product sales revenue (discussed below) is recognized upon the sale of the NGLs to a third party based on the sales price at the time of sale. As a result, revenue is recognized in the Consolidated Statement of Income both at the time the processing service is provided in Service revenues – commodity consideration and at the time the NGLs retained as part of the processing service are sold in Product sales . The recognition of revenue related to commodity consideration has the impact of increasing the book value of NGL inventory, resulting in higher cost of goods sold at the time of sale. Product Sales In the course of providing transportation services to customers of the gas pipeline businesses, including Transco, and gathering and processing services to customers of the midstream businesses, different quantities of natural gas may be received from customers than the quantities delivered on behalf of those customers. The resulting imbalances are primarily settled monthly through the purchase or sale of natural gas with each customer under terms provided for in FERC tariffs or gathering and processing agreements, respectively. Revenue is recognized for Transco from the sale of natural gas upon settlement of imbalances (see Gas Imbalances below). In certain instances, Williams purchases NGLs, crude oil, and natural gas from its oil and natural gas producer customers which Williams remarkets. In addition, Williams retains NGLs as consideration in certain processing arrangements, as discussed above in the Service Revenues - Midstream businesses section. Williams also markets natural gas and NGLs from the production at its upstream properties. Williams recognizes revenue from the sale of these commodities when the products have been sold and delivered. Williams’ product sales contracts are primarily short-term contracts based on prevailing market rates at the time of the transaction. Williams purchases natural gas for storage when the current market price paid to buy and transport natural gas plus the cost to store and finance the natural gas is less than an estimated, forward market price that can be received in the future, resulting in positive net product sales. Commodity-based exchange-traded futures contracts and over-the-counter (OTC) contracts are used to sell natural gas at that future price to substantially protect the natural gas revenues that will ultimately be realized when the stored natural gas is sold. Additionally, Williams enters into transactions to secure transportation capacity between delivery points in order to serve its customers and various markets. The physical purchase, transportation, storage, and sale of natural gas associated with these natural gas purchases are accounted for on a weighted-average cost or accrual basis, as appropriate, unlike the fair value basis utilized for the commodity derivatives used to mitigate the natural gas price risk associated with the storage and transportation portfolio. Monthly demand charges are incurred for contracted storage and transportation capacity and payments associated with asset management agreements and these demand charges and payments are recognized in the Consolidated Statement of Income in the period they are incurred. As Williams is acting as an agent for its natural gas marketing customers and engages in energy trading activities, its natural gas marketing revenues are presented net of the related costs of those activities. Contract Assets Williams Contract assets in the Consolidated Balance Sheet primarily consist of revenue recognized under contracts containing MVC features whereby management has concluded it is probable there will be a short-fall payment at the end of the current MVC period, which typically follows the calendar year, and that a significant reversal of revenue recognized currently for the future MVC payment will not occur. As a result, Williams’ contract assets related to its future MVC payments are generally expected to be collected within the next 12 months and are included within Other current assets and deferred charges in the Consolidated Balance Sheet until such time as the MVC short-fall payments are invoiced to the customer. Transco and NWP Transco’s contract assets primarily result from the modification of an existing contract resulting in increased rates. NWP’s contract assets consist of discounts provided to customers in the beginning of the contract term that are recognized on a straight-line basis over the entire contract term resulting in revenue recognition occurring prior to actual billings. Current and noncurrent contract assets are included within Other current assets and deferred charges and Deferred charges and other, respectively, in the Balance Sheets. Contract Liabilities Williams Contract liabilities in the Consolidated Balance Sheet consist of advance payments primarily from midstream business customers which include construction reimbursements, prepayments, and other billings and transactions for which future services are to be provided under the contract. These amounts are deferred until recognized in revenue when the associated performance obligation has been satisfied, which is primarily based on a units of production methodology over the remaining contractual service periods, and are classified as current or noncurrent according to when such amounts are expected to be recognized. Current and noncurrent contract liabilities are included within Other current liabilities and Regulatory liabilities, deferred income, and other , respectively, in the Consolidated Balance Sheet. Contracts requiring advance payments and the recognition of contract liabilities are evaluated to determine whether the advance payments provide Williams with a significant financing benefit. This determination is based on the combined effect of the expected length of time between when Williams transfers the promised good or service to the customer, when the customer pays for those goods or services, and the prevailing interest rates. Williams has assessed its contracts for significant financing components and determined, in management’s judgment, that one group of contracts entered into in contemplation of one another for certain capital reimbursements contains a significant financing component. As a result, Williams recognizes noncash interest expense based on the effective interest method and revenue (noncash) is recognized when the underlying asset is placed into service utilizing a units of production or straight-line methodology over the life of the corresponding customer contract. Transco and NWP Transco’s contract liabilities consist of advance payments from customers, which include prepayments, and other billings for which future services are to be provided under the contract, and NWP’s contract liabilities consist of a fixed rate facility charge billed to customers with a declining rate structure in its tariffs. Transco assessed its contracts and determined none contain a significant financing component. These liabilities are classified as current or noncurrent according to when such amounts are expected to be recognized. Current and noncurrent contract liabilities are included within Other current liabilities and Deferred charges and other, respectively, in the Balance Sheets. Commodity Derivative Instruments and Hedging Activities Williams is exposed to commodity price risk and utilizes derivatives to manage a portion of its commodity price risk. These instruments consist primarily of swaps, futures, and forward contracts involving short- and long-term purchases and sales of energy commodities. Williams purchases natural gas for storage when the current market price paid to buy and transport natural gas plus the cost to store and finance the natural gas is less than an estimated, forward market price that can be received in the future. Additionally, Williams enters into transactions to secure transportation capacity between delivery points in order to serve its customers and various markets. Commodity-based exchange-traded futures contracts and OTC contracts are used to capture the price differential or spread between the locations served by the capacity in order to substantially protect the natural gas revenues that will ultimately be realized when the physical flow of natural gas between receipt and delivery points occurs. Some commodity derivative contracts require physical delivery as opposed to financial settlement, and this type of derivative is both common and prevalent within the natural gas marketing operations. These contracts generally meet the definition of derivatives and are typically not designated as hedges for accounting purposes. When a commodity derivative contract is settled physically, any cumulative unrealized gain or loss is reversed, and the contract price is recognized in the respective line item in the Consolidated Statement of Income representing the actual price of the underlying goods being delivered. As of December 31, 2024 and 2023, Williams is not applying hedge accounting to any commodity derivative instruments. Unrealized gains and losses from physically settled commodity derivative contracts for commodity sales transactions are recognized in Net gain (loss) from commodity derivatives in the Consolidated Statement of Income. Realized and unrealized gains and losses from non-designated commodity derivative contracts for commodity sales transactions that are financially settled are reported in Net gain (loss) from commodity derivatives

Variable Interest Entities

Variable Interest Entities	12 Months Ended
	Dec. 31, 2024
Variable Interest Entity Disclosures [Abstract]
Variable Interest Entities [Text Block]	Note 2 – Variable Interest Entities Consolidated VIEs As of December 31, 2024, Williams consolidated the following VIEs: Northeast JV Williams owns a 65 percent interest in the Northeast JV, a subsidiary that is a VIE due to certain voting rights being disproportionate to the obligation to absorb losses and substantially all of the Northeast JV’s activities being performed on Williams’ behalf. Williams is the primary beneficiary because it has 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 Williams and the other equity partner on a proportional basis. Gulfstar One Williams owns 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 America. Williams is the primary beneficiary because it has the power to direct the activities that most significantly impact Gulfstar One’s economic performance. Cardinal Williams owns 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. Williams is the primary beneficiary because it has the power to direct the activities that most significantly impact Cardinal’s economic performance. In order to meet contractual gas gathering commitments, Williams may fund more than its proportional share of future expansion activity, which could ultimately impact relative ownership. The following table presents amounts included in the Consolidated Balance Sheet that are only for the use or obligation of the consolidated VIEs: December 31, 2024 2023 (Millions) Assets (liabilities): Cash and cash equivalents $ 15 $ 33 Trade accounts and other receivables – net 178 215 Inventories 5 5 Other current assets and deferred charges 7 4 Property, plant, and equipment – net 4,896 5,046 Intangible assets – net of accumulated amortization 1,940 2,049 Regulatory assets, deferred charges, and other 27 31 Accounts payable (57) (109) Other current liabilities (29) (28) Regulatory liabilities, deferred income, and other (263) (268) Nonconsolidated VIEs Williams owns certain equity-method investments that are VIEs due primarily to its limited participating rights as a minority equity holder. Williams’ maximum exposure to loss is limited to the carrying value of these investments (included within Investments in the Consolidated Balance Sheet), which totaled $72 million at December 31, 2024.

Acquisitions and Divestitures

Acquisitions and Divestitures	12 Months Ended
	Dec. 31, 2024
Business Combinations [Abstract]
Acquisitions and Divestitures [Text Block]	Note 3 – Acquisitions and Divestitures Crowheart Acquisition As of December 31, 2023, Williams had an agreement regarding certain crude oil and natural gas properties in the Wamsutter basin in Wyoming under which it owned a 75 percent undivided interest in each well’s working interest and proportionally consolidated its undivided interest. On November 1, 2024, Williams closed on the acquisition of a third-party operator, Crowheart Energy, LLC, for $307 million cash, subject to working capital and post-closing adjustments (Crowheart Acquisition). After closing on the acquisition, Williams owns more than a 90 percent working interest in each well. The purpose of this acquisition was to consolidate Williams’ interests in the Wamsutter basin and further optimize development in the area to continue to supply its gathering and processing assets. Assets acquired, acquisition-related costs incurred, and results of operations realized are included at Other. During the period from the acquisition date of November 1, 2024 to December 31, 2024, the additional interest acquired in the Crowheart Acquisition contributed Revenues of $20 million and Modified EBITDA (as defined in Note 19 – Segment Disclosures) of $7 million. Williams accounted for the Crowheart 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 following table presents the preliminary allocation of the acquisition date fair value of the major classes of the assets acquired and liabilities assumed at November 1, 2024. The allocation is considered preliminary because the valuation work has not been completed due to the ongoing review of the valuation results and validation of significant inputs and assumptions. Preliminary fair value measurements were made for certain acquired assets and liabilities, primarily property, plant, and equipment, which utilized the income approach for proved developed producing reserves and the market approach for undeveloped reserves; 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. (Millions) Cash and cash equivalents $ 94 Other current assets 15 Property, plant, and equipment – net 400 Other noncurrent assets 2 Total assets acquired 511 Current liabilities (45) Noncurrent liabilities (115) Total liabilities assumed (160) Net assets acquired $ 351 Discovery Acquisition As of December 31, 2023, Williams owned a 60 percent interest in Discovery, which it accounted for as an equity-method investment. On August 1, 2024, Williams closed on the acquisition of the remaining 40 percent interest in Discovery, along with certain other assets, for $170 million cash, subject to working capital and post-closing adjustments (Discovery Acquisition). As a result of acquiring this additional interest, Williams obtained control and subsequently consolidates Discovery. The purpose of this acquisition was to expand Williams’ gathering, processing, and transportation presence in the Gulf of America region. Assets acquired, acquisition-related costs incurred, and results of operations realized are included within Williams’ Transmission & Gulf of America segment. During the period from the acquisition date of August 1, 2024 to December 31, 2024, the operations acquired in the Discovery Acquisition contributed Revenues of $144 million and Modified EBITDA of $42 million. Acquisition-related costs for the Discovery Acquisition total $1 million and are included in Selling, general, and administrative expenses in the Williams Consolidated Statement of Income. Williams accounted for the Discovery Acquisition as a business combination. The book value of its existing equity-method investment prior to the acquisition date of August 1, 2024, was $381 million. Williams recognized a $127 million gain on remeasuring its existing equity-method investment to fair value included in Other investing income (loss) – net in the Williams Consolidated Statement of Income during 2024, which is not included in the pro forma Discovery adjustments below. Williams utilized the income approach to fair value its previous equity-method investment in Discovery. The following table presents the preliminary allocation of the acquisition date fair value of the major classes of the assets acquired and liabilities assumed at August 1, 2024. The allocation is considered preliminary because the valuation work has not been completed due to the ongoing review of the valuation results and validation of significant inputs and assumptions. Preliminary fair value measurements were made for certain acquired assets and liabilities, primarily property, plant, and equipment, which utilized the cost approach; 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. (Millions) Cash and cash equivalents $ 22 Other current assets 19 Property, plant, and equipment – net 941 Other noncurrent assets 39 Total assets acquired 1,021 Current liabilities (40) Noncurrent liabilities (296) Total liabilities assumed (336) Net assets acquired $ 685 Gulf Coast Storage Acquisition On January 3, 2024, Williams closed on the acquisition from Hartree Partners LP for $1.95 billion of 100 percent of a strategic portfolio of natural gas storage facilities and pipelines, located in Louisiana and Mississippi (Gulf Coast Storage Acquisition). The purpose of this acquisition was to expand Williams’ natural gas storage footprint in the Gulf Coast region. Assets acquired, acquisition-related costs incurred, and results of operations realized are included within Williams’ Transmission & Gulf of America segment. The Gulf Coast Storage Acquisition was funded with cash on hand and $100 million of deferred consideration that did not accrue interest and was payable one year from the acquisition date. The obligation is presented within Long-term debt due within one year in the Williams Consolidated Balance Sheet as of December 31, 2024, owed by Williams’ wholly owned subsidiary Williams Field Services Group, LLC. On January 3, 2025, Williams paid the remaining $100 million of the Gulf Coast Storage Acquisition purchase price obligation. During the period from the acquisition date of January 3, 2024 to December 31, 2024, the operations acquired in the Gulf Coast Storage Acquisition contributed Revenues of $228 million and Modified EBITDA of $160 million, which is impacted by acquisition-related costs. Acquisition-related costs for the Gulf Coast Storage Acquisition total $15 million, including $14 million incurred in 2024, and are included in Selling, general, and administrative expenses in the Williams Consolidated Statement of Income. Williams accounted for the Gulf Coast Storage Acquisition as a business combination. The valuation technique used consisted of the cost approach for property, plant, and equipment. The following table presents the allocation of the acquisition date fair value of the major classes of the assets acquired and liabilities assumed at January 3, 2024. (Millions) Cash and cash equivalents $ 46 Other current assets 18 Property, plant, and equipment – net 2,035 Other noncurrent assets 2 Total assets acquired 2,101 Current liabilities (11) Noncurrent liabilities (107) Total liabilities assumed (118) Net assets acquired $ 1,983 DJ Basin Acquisitions Cureton Acquisition On November 30, 2023, Williams closed on the acquisition of 100 percent of Cureton Front Range, LLC (Cureton Acquisition), whose operations are located in the DJ Basin, for $546 million. The purpose of this acquisition was to expand Williams’ gathering and processing footprint and create operational synergies for its operations in the DJ Basin. Assets acquired, acquisition-related costs incurred, and results of operations realized are included within Williams’ West segment. The Cureton Acquisition was funded with cash on hand. During the period from the acquisition date of November 30, 2023 to December 31, 2023, the operations acquired in the Cureton Acquisition contributed Revenues of $35 million and Modified EBITDA of $7 million. Acquisition-related costs for the Cureton Acquisition total $8 million, including $6 million incurred in 2023, and are included in Selling, general, and administrative expenses in the Williams Consolidated Statement of Income. Williams accounted for the Cureton Acquisition as a business combination. The valuation techniques used consisted of the cost approach for property, plant, and equipment and the income approach for valuation of other intangible assets. The following table presents the allocation of the acquisition date fair value of the major classes of the assets acquired and liabilities assumed at November 30, 2023. (Millions) Cash and cash equivalents $ 6 Other current assets 21 Property, plant, and equipment – net 433 Intangible assets – net of accumulated amortization 117 Other noncurrent assets 1 Total identifiable assets acquired 578 Current liabilities (29) Noncurrent liabilities (14) Total liabilities assumed (43) Net identifiable assets acquired 535 Goodwill included in Intangible assets – net of accumulated amortization 11 Net assets acquired $ 546 Other intangible assets recognized in the Cureton Acquisition are related to contractual customer relationships from gas gathering and processing agreements with 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 Williams’ cash flows. Approximately 24 percent of the expected future revenues from these contractual customer relationships are impacted by Williams’ ability and intent to renew or renegotiate existing customer contracts. Williams expenses costs incurred to renew or extend the terms of its gas gathering contracts with customers. Based on the estimated future revenues during the current contract periods (as estimated at the time of the acquisition), the weighted-average period prior to the next renewal or extension of the existing contractual customer relationships is approximately 10 years. See Note 11 – Goodwill and Other Intangible Assets. RMM Acquisition As of December 31, 2022, Williams owned a 50 percent interest in RMM which it accounted for as an equity-method investment. On November 30, 2023, Williams closed on the acquisition of the remaining 50 percent interest in RMM (RMM Acquisition) for $704 million. As a result of acquiring this additional interest, Williams obtained control and subsequently consolidates RMM. The purpose of this acquisition was to expand Williams’ gathering and processing footprint and create operational synergies for its operations in the DJ Basin. Assets acquired and results of operations realized are included within Williams’ West segment. Substantially all of the RMM purchase price was not due to the seller until the first quarter of 2025, would not accrue interest until November 2, 2024, and could be repaid early without penalty. It was recorded as a deferred consideration obligation at fair value using an income approach, which resulted in a discount to the contractual amount due which was imputed as interest expense over the term of the obligation. On November 1, 2024, Williams paid the remaining $651 million of the RMM purchase price obligation. During the period from the acquisition date of November 30, 2023 to December 31, 2023, RMM contributed Revenues of $53 million and Modified EBITDA of $12 million. Williams accounted for the RMM Acquisition as a business combination. The book value of Williams’ existing equity-method investment prior to the acquisition date of November 30, 2023, was $406 million. Williams recognized a $30 million gain on remeasuring its existing equity-method investment to fair value included in Other investing income (loss) – net in the Williams Consolidated Statement of Income during the fourth quarter of 2023, which is not included in the pro forma DJ Basin adjustments below. The valuation techniques used consisted of the income approach for Williams’ previous equity-method investment in RMM and the valuation of other intangible assets, and the cost approach for property, plant, and equipment. The following table presents the allocation of the acquisition date fair value of the major classes of the assets acquired and liabilities assumed at November 30, 2023. The net assets acquired primarily reflect the noncash consideration transferred, which includes the fair value of both Williams’ previous equity-method investment and the deferred consideration obligation. (Millions) Cash and cash equivalents $ 28 Other current assets 4 Investments 20 Property, plant, and equipment – net 1,041 Intangible assets – net of accumulated amortization 63 Other noncurrent assets 12 Total identifiable assets acquired 1,168 Current liabilities (44) Noncurrent liabilities (103) Total liabilities assumed (147) Net identifiable assets acquired 1,021 Goodwill included in Intangible assets – net of accumulated amortization 55 Net assets acquired $ 1,076 Goodwill recognized in the RMM Acquisition relates primarily to enhancing and diversifying Williams’ basin positions as well as delivering operational synergies, including increasing volumes on its existing processing facilities and increasing revenues on its NGL transportation, fractionation, and storage assets, and is reported within Williams’ West segment. Substantially all of the goodwill is deductible for tax purposes. Other intangible assets recognized in the RMM Acquisition are related to contractual customer relationships from gas gathering and processing agreements with 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 Williams’ cash flows. Approximately 18 percent of the expected future revenues from these contractual customer relationships are impacted by Williams’ ability and intent to renew or renegotiate existing customer contracts. Williams expenses costs incurred to renew or extend the terms of its gas gathering contracts with customers. Based on the estimated future revenues during the current contract periods (as estimated at the time of the acquisition), the weighted-average period prior to the next renewal or extension of the existing contractual customer relationships is approximately 10 years. See Note 11 – Goodwill and Other Intangible Assets. MountainWest Acquisition On February 14, 2023, Williams closed on the acquisition of 100 percent of MountainWest, which includes FERC-regulated interstate natural gas pipeline systems and natural gas storage capacity (MountainWest Acquisition), for $1.08 billion of cash, funded with available sources of short-term liquidity, and retaining $430 million outstanding principal amount of MountainWest long-term debt. For 2023, $1.024 billion is presented in Purchases of businesses, net of cash acquired in the Williams Consolidated Statement of Cash Flows reflecting the cash purchase price, reduced for post-closing adjustments and the cash acquired as presented in the purchase price allocation. The purpose of the MountainWest Acquisition was to expand Williams’ existing transmission and storage infrastructure footprint into major markets in Utah, Wyoming, and Colorado. Assets acquired, acquisition-related costs incurred, and results of operations realized are included within Williams’ Transmission & Gulf of America segment. During the period from the acquisition date of February 14, 2023 to December 31, 2023, the operations acquired in the MountainWest Acquisition contributed Revenues of $225 million and Modified EBITDA of $122 million, which includes $27 million of transition-related costs. Acquisition-related costs for the MountainWest Acquisition total $18 million, including $16 million incurred in 2023, and are included in Selling, general, and administrative expenses in the Williams Consolidated Statement of Income. Williams accounted for the MountainWest Acquisition as a business combination. The valuation techniques used consisted of the cost approach for nonregulated property, plant, and equipment, as well as the market approach for the assumed long-term debt consistent with the valuation technique discussed in Note 16 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk. MountainWest’s regulated operations are accounted for pursuant to ASC 980. The fair value of assets and liabilities subject to rate making and cost recovery provisions were determined utilizing the income approach. MountainWest’s expected return on rate base is consistent with expected returns of similarly situated assets, resulting in carryover basis of these assets and liabilities equaling their fair value. The following table presents the allocation of the acquisition date fair value of the major classes of the assets acquired and liabilities assumed at February 14, 2023. The fair value of accounts receivable acquired equals contractual amounts receivable. (Millions) Cash and cash equivalents $ 23 Trade accounts and other receivables 33 Other current assets 26 Investments 20 Property, plant, and equipment – net 1,019 Other noncurrent assets 33 Total identifiable assets acquired 1,154 Current liabilities (47) Long-term debt (365) Other noncurrent liabilities (95) Total liabilities assumed (507) Net identifiable assets acquired 647 Goodwill included in Intangible assets – net of accumulated amortization 400 Net assets acquired $ 1,047 Goodwill recognized in the MountainWest Acquisition relates primarily to enhancing and diversifying Williams’ basin positions and the long-term value associated with rate regulated businesses and is reported within its Transmission & Gulf of America segment. Substantially all of the goodwill is deductible for tax purposes. Trace Acquisition On April 29, 2022, Williams closed on the acquisition of 100 percent of Gemini Arklatex, LLC through which it acquired the Haynesville Shale region gas gathering and related assets of Trace Midstream for $972 million of cash funded with cash on hand and proceeds from issuance of commercial paper (Trace Acquisition). The purpose of the Trace Acquisition was to expand Williams’ 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. Assets acquired, acquisition-related costs incurred, and results of operations realized are included within Williams’ West segment. 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 were included in Selling, general, and administrative expenses in the Williams Consolidated Statement of Income during 2022. Williams 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 and liabilities assumed at April 29, 2022. The valuation techniques used consisted of the income approach for valuation of intangible assets and the cost approach 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) Other current liabilities (5) Other noncurrent liabilities (8) Total liabilities assumed (25) Net assets acquired $ 972 Other intangible assets recognized in the Trace Acquisition are related to contractual customer relationships from gas gathering agreements with 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 Williams’ cash flows. Approximately 2 percent of the expected future revenues from these contractual customer relationships are impacted by Williams’ ability and intent to renew or renegotiate existing customer contracts. Williams expenses costs incurred to renew or extend the terms of its 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. See Note 11 – Goodwill and Other Intangible Assets. Supplemental Pro Forma The following pro forma Revenues and Net income (loss) attributable to The Williams Companies, Inc. for 2024, 2023, and 2022, are presented as if the Crowheart Acquisition, Discovery Acquisition, and Gulf Coast Storage Acquisition had been completed on January 1, 2023, the DJ Basin Acquisitions and 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 acquisitions had in fact occurred on the dates or for the periods indicated, nor do they purport to project Revenues or Net income (loss) attributable to The Williams Companies, Inc. for any future periods or as of any date. These amounts do not give effect to any potential cost savings, operating synergies, or revenue enhancements to result from the transactions or the potential costs to achieve these cost savings, operating synergies, and revenue enhancements. Year Ended December 31, 2024 As Reported Pro Forma Crowheart (1) Pro Forma Discovery (1) Pro Forma Combined (Millions) Revenues $ 10,503 $ 60 $ 58 $ 10,621 Net income (loss) attributable to The Williams Companies, Inc. 2,225 8 (5) 2,228 Year Ended December 31, 2023 As Reported Pro Forma Crowheart Pro Forma Discovery Pro Forma Gulf Coast Storage Pro Forma DJ Basin (1) Pro Forma MountainWest (1) Pro Forma Combined (Millions) Revenues $ 10,907 $ 74 $ 129 $ 202 $ 270 $ 35 $ 11,617 Net income (loss) attributable to The Williams Companies, Inc. 3,179 19 (1) 53 17 6 3,273 Year Ended December 31, 2022 As Reported Pro Forma DJ Basin Pro Forma MountainWest Pro Forma Trace (1) Pro Forma Combined (Millions) Revenues $ 10,965 $ 218 $ 265 $ 45 $ 11,493 Net income (loss) attributable to The Williams Companies, Inc. 2,049 13 170 18 2,250 (1) Excludes results from operations acquired in the acquisition for the period beginning on the acquisition date, as these results are included in the amounts as reported. NorTex Asset Purchase On August 31, 2022, Williams purchased a group of assets in north Texas, primarily natural gas storage facilities and pipelines, from NorTex Midstream Holdings, LLC (NorTex Asset Purchase) for approximately $424 million. These assets are included in Williams’ Transmission & Gulf of America segment. Sale of Certain Gulf Coast Liquids Pipelines On September 29, 2023, Williams 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, Williams recorded a gain of $129 million in 2023 in its Transmission & Gulf of America segment. The gain is reflected in Gain on sale of business in the Williams Consolidated Statement of Income. The results of operations for this disposal group, excluding the gain noted, were not significant for the reporting periods.

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2024
Related Party Transactions [Abstract]
Related Party Transactions [Text Block]	Note 4 – Related Party Transactions Williams Transactions with Equity-Method Investees Williams has costs and expenses associated with its equity-method investees of $266 million, $776 million, and $1.3 billion for 2024, 2023, and 2022, respectively in its Consolidated Statement of Income. Substantially all of these expenses are included in Product costs . Williams also has revenue from its equity-method investees of $2 million, $5 million, and $76 million for 2024, 2023, and 2022, respectively. In addition, Williams has $1 million and $2 million included in Trade accounts and other receivables and $19 million and $33 million included in Accounts payable in its Consolidated Balance Sheet with its equity-method investees at December 31, 2024 and 2023, respectively. Williams has operating agreements with certain equity-method investees. These operating agreements typically provide for reimbursement or payment to Williams for certain direct operational payroll and employee benefit costs, materials, supplies, and other charges and also for management services. The total charges to equity-method investees for these fees are $52 million, $64 million, and $65 million for 2024, 2023, and 2022, respectively. Board of Directors Two members of Williams’ Board of Directors are also executive officers at certain of its counterparties. Williams recorded $59 million, $90 million, and $180 million in Product sales and $40 million, $25 million, and $86 million in Product costs in its Consolidated Statement of Income from these companies for the purchase and sale of natural gas for 2024, 2023, and 2022, respectively. Transco and NWP Affiliate Transactions Benefit Plans Transco and NWP do not have employees. Certain of the costs charged to them by Williams associated with employees who directly support them are described below. Additionally, allocated corporate expenses from Williams also include amounts related to these same employee benefits, which are not included in the amounts presented immediately below. Pension and Other Postretirement Benefit Plans Williams’ pension and other postretirement benefit plans are single-employer plans. However, Transco and NWP follow multiemployer plan accounting whereby the amount charged to them and thus paid by them, is based on their share of net periodic benefit cost (see Note 7 – Employee Benefit Plans). Pension costs charged to Transco by Williams were $1 million, $2 million, and $4 million for 2024, 2023, and 2022, respectively. NWP received pension credits from Williams of $1 million in 2024, $0 million in 2023, and pension charges of $1 million in 2022. Williams makes annual cash contributions to the pension plans, based on annual actuarial estimates, which Transco recovers through rates that are set through periodic general rate filings. Effective with Transco’s Docket No. RP18-1126 rate case settlement, any amounts of annual contributions that fall below a threshold are recorded as adjustments to income and refunded through future rate adjustments. The amounts of deferred pension collections recorded as regulatory liabilities at December 31, 2024 and 2023 were $30 million and $26 million, respectively. Also effective with Transco’s Docket No. RP18-1126 rate case settlement, the pension regulatory liability as of March 1, 2019 was amortized over a five Transco recognized other postretirement benefit income of $8 million, $6 million, and $5 million for 2024, 2023, and 2022, respectively, while NWP recognized other postretirement benefit income of $1 million, $0 million, and $1 million, respectively for the same periods. These credits were recorded as regulatory liabilities. Transco and NWP have been allowed by rate case settlements to collect or refund in future rates any differences between the actuarially determined costs and amounts currently being recovered in rates related to other postretirement benefits. Any differences between the annual actuarially determined cost and amounts currently being recovered in rates are recorded as regulatory assets or liabilities and collected or refunded through future rate adjustments. The amounts of other postretirement benefits costs deferred as regulatory liabilities at December 31, 2024 and 2023 are $31 million and $31 million, for Transco respectively, and $43 million and $42 million, for NWP respectively. Effective with the Docket No. RP18-1126 rate case settlement, Transco’s other postretirement benefits regulatory liability as of March 1, 2019 was amortized over a period of approximately five Defined Contribution Plan Williams maintains a defined contribution plan for substantially all of its employees. Williams charged Transco compensation expense of $13 million, $12 million, and $11 million in 2024, 2023, and 2022, respectively, and charged NWP compensation expense of $3 million, $3 million, and $3 million in 2024, 2023, and 2022, respectively, for Williams’ company contributions to this plan. Employee Stock-Based Compensation Plan Information (see Note 15 – Equity-Based Compensation) Williams currently bills Transco and NWP directly for compensation expense related to stock-based compensation awards based on the fair value of the awards. Transco and NWP are also billed for their proportionate share of Williams’ and other affiliates’ stock-based compensation expense through various allocation processes. Total stock-based compensation expense for the years ended December 31, 2024, 2023, and 2022 was $6 million, $6 million, and $6 million, for Transco respectively, and $2 million, $2 million, and $1 million, for NWP respectively. Cash Management Program Transco and NWP are participants in Williams’ cash management program, and thus make advances to and receive advances from Williams. At December 31, 2024 and 2023, Transco’s advances to Williams totaled approximately $638 million and $1.4 billion, respectively. These advances are represented by demand notes and are classified as Trade accounts and other receivables - Advances to affiliate in the Balance Sheet. NWP’s advances from Williams totaled approximately $26 million at December 31, 2024. These advances from Williams are classified as Payables - Advances from affiliate . Advances to Williams from NWP totaled approximately $158 million at December 31, 2023. These advances are represented by demand notes and are classified as Trade accounts and other receivables - Advances to affiliate in the Balance Sheet. Advances are stated at the historical carrying amounts. Interest expense and income are recognized when earned and the collectability is reasonably assured. The interest rate on these intercompany demand notes is based upon the daily overnight investment rate paid on Williams’ excess cash at the end of each month, which was approximately 4 percent at December 31, 2024. The net interest income from these advances was $51 million, $81 million, and $31 million during years ended December 31, 2024, 2023, and 2022, for Transco respectively, and $5 million, $8 million, and $5 million for the years ended December 31, 2024, 2023, and 2022 for NWP respectively. Such interest income is included in Interest income in the Statement of Net Income for Transco and Other income (expense) – net in the Statement of Net Income for NWP. Other Affiliate Transactions Included in Transco’s Total revenues in the Statement of Net Income for 2024, 2023, and 2022 are revenues received from affiliates of $76 million, $56 million, and $89 million, respectively. Included in Transco’s Natural gas product costs in the Statement of Net Income for 2024, 2023, and 2022 are costs of gas purchased from affiliates of $5 million, $7 million, and $18 million, respectively. All gas purchases are made at market or contract prices. Services necessary to operate Transco and NWP are provided by Williams and certain affiliates of Williams. Transco and NWP reimburse Williams and its affiliates for all direct and indirect expenses incurred or payments made (including salary, bonus, incentive compensation, and benefits) in connection with these services. Employees of Williams also provide general, administrative, and management services, and Transco and NWP are charged for certain administrative expenses incurred by Williams. These charges are either directly assigned or allocated. Allocated charges are specific or general. Specific allocations are based on a relationship with the delivery of services and general allocations are based on a three-factor formula, which considers revenues; property, plant, and equipment; and payroll. In management’s estimation, the allocation methodologies used are reasonable and result in a reasonable allocation of costs of doing business incurred by Williams. For the years ended December 31, 2024, 2023, and 2022, Transco has recorded $344 million, $324 million, and $345 million, respectively, and NWP has recorded $91 million, $86 million, and $88 million, respectively, for these service expenses, which are primarily included in Operating and maintenance expenses and Selling, general, and administrative expenses in the Statement of Net Income. Transco provides services to certain of its affiliates. Transco recorded reductions in operating expenses for services provided to and reimbursed by affiliates of $6 million, $14 million, and $10 million for the years ended December 31, 2024, 2023, and 2022, respectively. During January 2025, Transco and NWP declared and paid cash distributions of $246 million and $24 million, respectively, to Williams, and Williams made a cash contribution to NWP of $85 million.

Revenue Recognition

Revenue Recognition	12 Months Ended
	Dec. 31, 2024
Revenue Recognition [Abstract]
Revenue Recognition [Text Block]	Note 5 – Revenue Recognition Revenue by Category The following table presents Williams’ revenue disaggregated by major service line: Transmission & Gulf of America Northeast G&P West Gas & NGL Marketing Services Other Eliminations Total (Millions) 2024 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 3,500 $ — $ — $ — $ — $ (81) $ 3,419 Gathering, processing, transportation, fractionation, and storage: Monetary consideration 661 1,778 1,693 — — (162) 3,970 Commodity consideration 54 2 78 — — — 134 Other 46 92 21 — — (19) 140 Total service revenues 4,261 1,872 1,792 — — (262) 7,663 Product sales 328 110 869 4,530 420 (1,288) 4,969 Total revenues from contracts with customers 4,589 1,982 2,661 4,530 420 (1,550) 12,632 Other revenues (1) 39 43 8 2,236 24 (2) 2,348 Other adjustments (2) — — — (4,977) — 500 (4,477) Total revenues $ 4,628 $ 2,025 $ 2,669 $ 1,789 $ 444 $ (1,052) $ 10,503 2023 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 3,334 $ — $ — $ — $ — $ (60) $ 3,274 Gathering, processing, transportation, fractionation, and storage: Monetary consideration 443 1,782 1,478 — — (170) 3,533 Commodity consideration 38 5 103 — — — 146 Other 30 87 12 1 — (15) 115 Total service revenues 3,845 1,874 1,593 1 — (245) 7,068 Product sales 252 132 441 4,615 442 (954) 4,928 Total revenues from contracts with customers 4,097 2,006 2,034 4,616 442 (1,199) 11,996 Other revenues (1) 53 27 101 4,294 64 (2) 4,537 Other adjustments (2) — — — (6,032) — 406 (5,626) Total revenues $ 4,150 $ 2,033 $ 2,135 $ 2,878 $ 506 $ (795) $ 10,907 Transmission & Gulf of America Northeast G&P West Gas & NGL Marketing Services Other Eliminations Total (Millions) 2022 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 3,139 $ — $ — $ — $ — $ (72) $ 3,067 Gathering, processing, transportation, fractionation, and storage: Monetary consideration 381 1,526 1,518 — — (167) 3,258 Commodity consideration 64 14 182 — — — 260 Other 21 102 12 3 — (16) 122 Total service revenues 3,605 1,642 1,712 3 — (255) 6,707 Product sales 404 134 841 10,768 706 (1,787) 11,066 Total revenues from contracts with customers 4,009 1,776 2,553 10,771 706 (2,042) 17,773 Other revenues (1) 38 26 8 7,929 (55) (11) 7,935 Other adjustments (2) — — — (15,467) — 724 (14,743) Total revenues $ 4,047 $ 1,802 $ 2,561 $ 3,233 $ 651 $ (1,329) $ 10,965 ______________________________ (1) Revenues not derived from contracts with customers primarily consist of physical product sales related to commodity derivative contracts, realized and unrealized gains and losses associated with Williams’ commodity derivative contracts, which are reported in Net gain (loss) from commodity derivatives in the Consolidated Statement of Income, management fees received for certain services provided to operated equity-method investments, and leasing revenues associated with the Williams headquarters building. (2) Other adjustments reflect certain costs of Gas & NGL Marketing Services’ risk management activities. As Williams is acting as agent for natural gas marketing customers or engages in energy trading activities, the resulting revenues are presented net of the related costs of those activities in the Consolidated Statement of Income. For Transco and NWP, revenue disaggregation by major service line includes Natural gas transportation , Natural gas storage , Natural gas product sales , and Other , which are separately presented on their Statements of Net Income. Contract Assets The following tables present a reconciliation of contract assets: Williams Year Ended December 31, 2024 2023 (Millions) Balance at beginning of year $ 36 $ 29 Revenue recognized in excess of amounts invoiced 170 183 Minimum volume commitments invoiced (144) (176) Contract assets acquired 36 — Balance at end of year $ 98 $ 36 Transco Year Ended December 31, 2024 2023 (Millions) Balance at beginning of year $ — $ — Revenue recognized in excess of amounts invoiced 10 — Balance at end of year $ 10 $ — NWP Year Ended December 31, 2024 2023 (Millions) Balance at beginning of year $ 17 $ 13 Revenue recognized in excess of amounts invoiced 6 6 Amortization of contract assets (2) (2) Balance at end of year $ 21 $ 17 Contract Liabilities The following tables present a reconciliation of contract liabilities: Williams Year Ended December 31, 2024 2023 (Millions) Balance at beginning of year $ 1,081 $ 1,043 Payments received and deferred 183 190 Significant financing component 8 9 Contract liability acquired (disposed) – net 53 115 Recognized in revenue (279) (276) Balance at end of year $ 1,046 $ 1,081 Transco Year Ended December 31, 2024 2023 (Millions) Balance at beginning of year $ 184 $ 194 Recognized in revenue (11) (10) Balance at end of year $ 173 $ 184 NWP Year Ended December 31, 2024 2023 (Millions) Balance at beginning of year $ 2 $ 3 Recognized in revenue (2) (1) Balance at end of year $ — $ 2 Remaining Performance Obligations Remaining performance obligations primarily include reservation charges on contracted capacity for Williams’ gas pipeline firm transportation contracts with customers, storage capacity contracts, long-term contracts containing MVC associated with midstream businesses, and fixed payments associated with offshore production handling. For Williams’ interstate natural gas pipeline businesses, including Transco and NWP, remaining performance obligations reflect the rates for such services in its current effective 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. Remaining performance obligations exclude variable consideration, including contracts with variable consideration for which it has elected the practical expedient for consideration recognized in revenue as billed. Certain of its contracts contain evergreen and other renewal provisions for periods beyond the initial term of the contract. The remaining performance obligation amounts as of December 31, 2024, do not consider potential future performance obligations for which the renewal has not been exercised and exclude contracts with customers for which the underlying facilities have not received FERC authorization to be placed into service. Consideration received prior to December 31, 2024, that will be recognized in future periods is also excluded from its remaining performance obligations and is instead reflected in contract liabilities. The following tables present 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 December 31, 2024. Williams Contract Liabilities Remaining Performance Obligations (Millions) 2025 (one year) $ 173 $ 4,132 2026 (one year) 146 3,860 2027 (one year) 141 3,623 2028 (one year) 118 2,778 2029 (one year) 100 2,564 Thereafter 368 14,102 Total $ 1,046 $ 31,059 Transco Contract Liabilities Remaining Performance Obligations (Millions) 2025 (one year) $ 10 $ 2,726 2026 (one year) 10 2,536 2027 (one year) 11 2,438 2028 (one year) 11 1,784 2029 (one year) 11 1,693 Thereafter 120 10,421 Total $ 173 $ 21,598 NWP Contract Liabilities Remaining Performance Obligations (Millions) 2025 (one year) $ — $ 391 2026 (one year) — 386 2027 (one year) — 373 2028 (one year) — 368 2029 (one year) — 349 Thereafter — 2,234 Total $ — $ 4,101

Provision (Benefit) for Income

Provision (Benefit) for Income Taxes	12 Months Ended
	Dec. 31, 2024
Income Tax Disclosure [Abstract]
Provision (Benefit) for Income Taxes [Text Block]	Note 6 – Provision (Benefit) for Income Taxes The Provision (benefit) for income taxes from continuing operations includes: Year Ended December 31, 2024 2023 2022 (Millions) Current: Federal $ 125 $ 3 $ (25) State 9 21 19 134 24 (6) Deferred: Federal 472 872 424 State 34 109 7 506 981 431 Provision (benefit) for income taxes $ 640 $ 1,005 $ 425 Reconciliations from the Provision (benefit) at statutory rate from continuing operations to recorded Provision (benefit) for income taxes are as follows: Year Ended December 31, 2024 2023 2022 (Millions) Provision (benefit) at statutory rate $ 627 $ 925 $ 534 Increases (decreases) in taxes resulting from: State income taxes (net of federal benefit) 79 129 113 State deferred income tax rate change (44) (25) (92) Federal valuation allowance — — (70) Federal settlements — — (45) Impact of nontaxable noncontrolling interests (25) (26) (14) Other – net 3 2 (1) Provision (benefit) for income taxes $ 640 $ 1,005 $ 425 The State deferred income tax rate change benefit of $44 million, $25 million and $92 million in 2024, 2023 and 2022, respectively, is related to a decrease in Williams’ estimate of the deferred state income tax rate (net of federal effect). The 2024 benefit is driven primarily by a decrease in the Louisiana state income tax rate and the enacted decline in the Pennsylvania state income tax rate over the next several years. During the course of audits of its business by domestic and foreign tax authorities, Williams frequently faces challenges regarding the amount of taxes due. These challenges include questions regarding the timing and amount of deductions and the allocation of income among various tax jurisdictions. In evaluating the liability associated with its various filing positions, Williams applies the two-step process of recognition and measurement. In association with this liability, Williams records an estimate of related interest and tax exposure as a component of its tax provision. The impact of this accrual is included within Other – net in its reconciliation of the Provision (benefit) at statutory rate to recorded Provision (benefit) for income taxes . Significant components of Deferred income tax liabilities are as follows: December 31, 2024 2023 (Millions) Gross deferred income tax liabilities: Property, plant and equipment $ 4,501 $ 3,541 Investments 1,733 1,740 Other 193 146 Total gross deferred income tax liabilities 6,427 5,427 Gross deferred income tax assets: Accrued liabilities 1,146 868 Corporate alternative minimum tax credits 108 — Foreign tax credits — 35 Federal loss carryovers 325 398 Disallowed business interest expense carryforward 247 67 State losses and credits 224 293 Other 92 103 Total gross deferred income tax assets 2,142 1,764 Less valuation allowance 91 183 Net deferred income tax assets 2,051 1,581 Deferred income tax liabilities $ 4,376 $ 3,846 The valuation allowance at December 31, 2024 and 2023 serves to reduce the available deferred income tax assets to an amount that will, more likely than not, be realized. Williams considered all available positive and negative evidence, which incorporates available tax planning strategies, and management’s estimate of future reversals of existing taxable temporary differences and has determined that a portion of its deferred income tax assets related to State losses and credits may not be realized. The change from prior year for the Foreign tax credits reflects a decrease of $35 million due to its expiration in 2024. The amounts presented in the table above are, with respect to state items, before any federal benefit. The change from prior year for the State losses and credits reflects increases in losses and credits generated in the current and prior years less losses and/or credits utilized in the current year. Williams has loss and credit carryovers in multiple state taxing jurisdictions. These attributes generally expire between 2025 and 2043 with some carryovers having indefinite carryforward periods. Federal loss carryovers at December 31, 2024 reflect deferred tax assets on net operating loss carryovers with no expiration date. Disallowed business interest expense carryforward reflects Williams’ federal interest expense carryforward which has no expiration date. Cash payments for income taxes (net of refunds) were $68 million, $31 million and $13 million in 2024, 2023 and 2022 respectively. During the second quarter of 2022, Williams finalized settlements for 2011 through 2014 on certain contested matters with the Internal Revenue Service (IRS) that resulted in a 2022 year-to-date tax benefit of approximately $45 million and Williams received cash refunds totaling $7 million. During the fourth quarter of 2023, Williams closed the audit for 2018 and made a $5 million payment. Williams recognizes related interest and penalties as a component of Provision (benefit) for income taxes . There were no significant interest and penalties recognized for any period presented. There were no interest or penalties relating to uncertain tax positions accrued as of December 31, 2024 and December 31, 2023. Consolidated U.S. Federal income tax returns are open to IRS examination for tax years after 2020. The statute of limitations for most states expires one year after expiration of the IRS statute.

Employee Benefit Plans

Employee Benefit Plans	12 Months Ended
	Dec. 31, 2024
Retirement Benefits [Abstract]
Employee Benefit Plans [Text Block]	Note 7 – Employee Benefit Plans Pension Plans Williams has noncontributory defined benefit pension plans for eligible employees hired prior to January 1, 2019. Eligible employees earn compensation credits based on a cash balance formula. As of January 1, 2020, certain active employees are no longer eligible to receive compensation credits. Other Postretirement Benefits Williams provides subsidized retiree medical benefits to a closed group of participants as well as retiree life insurance benefits to eligible participants. Medical benefits for Medicare eligible participants are paid through contributions to health reimbursement accounts. Benefits for all other participants are provided through a self-insured medical plan, which includes participant contributions and contains other cost-sharing features such as deductibles, co-payments, and co-insurance. Defined Contribution Plan Williams has a defined contribution plan for the benefit of substantially all employees. Plan participants may contribute a portion of their compensation on a pre-tax or after-tax basis. Generally, Williams matches employee contributions up to 6 percent of eligible compensation. Additionally, eligible active employees that do not receive compensation credits under the defined benefit pension plan are eligible for an additional annual fixed-percentage contribution made by Williams to the defined contribution plan. Williams’ contributions charged to expense were $69 million in 2024, $60 million in 2023, and $53 million in 2022. Funded Status The following table presents the changes in benefit obligations and plan assets for pension benefits and other postretirement benefits for the years indicated: Pension Benefits Other 2024 2023 2024 2023 (Millions) Change in benefit obligation: Benefit obligation at beginning of year $ 1,006 $ 940 $ 145 $ 152 Service cost 25 23 1 1 Interest cost 47 46 7 7 Plan participants’ contributions — — 2 2 Benefits paid (73) (71) (11) (13) Net actuarial loss (gain) (1) (65) 68 (12) (4) Settlements (3) — — — Net increase (decrease) in benefit obligation (69) 66 (13) (7) Benefit obligation at end of year 937 1,006 132 145 Change in plan assets: Fair value of plan assets at beginning of year 1,167 1,117 262 253 Actual return on plan assets 88 120 16 17 Employer contributions 4 1 3 3 Plan participants’ contributions — — 2 2 Benefits paid (73) (71) (11) (13) Settlements (3) — — — Net increase (decrease) in fair value of plan assets 16 50 10 9 Fair value of plan assets at end of year 1,183 1,167 272 262 Funded status — overfunded (underfunded) $ 246 $ 161 $ 140 $ 117 Amounts recognized in the Consolidated Balance Sheet: Noncurrent assets $ 270 $ 187 $ 143 $ 120 Current liabilities (4) (4) (3) (3) Noncurrent liabilities (20) (22) — — Funded status — overfunded (underfunded) $ 246 $ 161 $ 140 $ 117 Accumulated benefit obligation $ 929 $ 998 ____________ (1) 2024 amounts are due primarily to changes in the following factors: Pension Benefits - discount rate assumptions and interest crediting rate assumption; Other Postretirement Benefits - discount rate assumption. 2023 amounts are due primarily to changes in the following factors: Pension Benefits - interest crediting rate assumption and discount rate assumptions. The following table summarizes information for pension plans with obligations in excess of plan assets at December 31. 2024 2023 (Millions) Projected benefit obligation $ 23 $ 26 Accumulated benefit obligation 22 24 Fair value of plan assets — — Pre-tax amounts recognized in Accumulated other comprehensive income (loss) at December 31 are as follows: Pension Benefits Other 2024 2023 2024 2023 (Millions) Net actuarial gain (loss) $ 49 $ (45) $ 20 $ 19 Additionally, as of December 31, 2024 and 2023, Williams has $139 million and $123 million, respectively, of pension and other postretirement plan amounts included in regulatory liabilities associated with its gas pipeline companies. Net Periodic Benefit Cost (Credit) Net periodic benefit cost (credit) for the years ended December 31 consist of the following: Pension Benefits Other 2024 2023 2022 2024 2023 2022 (Millions) Components of net periodic benefit cost (credit): Service cost $ 25 $ 23 $ 28 $ 1 $ 1 $ 1 Interest cost 47 46 31 7 7 6 Expected return on plan assets (60) (57) (44) (11) (10) (10) Amortization of net actuarial loss (gain) — 5 12 (5) (3) — Net actuarial loss from settlements 1 — 3 — — — Reclassification to regulatory liability — — — — — 1 Net periodic benefit cost (credit) (1) $ 13 $ 17 $ 30 $ (8) $ (5) $ (2) ____________ (1) Components other than Service cost are included in Other income (expense) – net below Operating income (loss) in Williams’ Consolidated Statement of Income . Items Recognized in Other Comprehensive Income (Loss) Other changes in plan assets and benefit obligations recognized in Other comprehensive income (loss) before taxes for the years ended December 31 consist of the following: Pension Benefits Other 2024 2023 2022 2024 2023 2022 (Millions) Net actuarial gain (loss) arising during the year $ 93 $ (5) $ (14) $ 3 $ 3 $ 14 Amortization of net actuarial loss (gain) — 5 12 (2) (2) — Net actuarial loss from settlements 1 — 3 — — — Total recognized in Other comprehensive income (loss) $ 94 $ — $ 1 $ 1 $ 1 $ 14 Key Assumptions The weighted-average assumptions utilized to determine benefit obligations and Net periodic benefit cost (credit) as of December 31 are as follows: Pension Benefits Other 2024 2023 2022 2024 2023 2022 Benefit obligations: Discount rate 5.60 % 4.98 % 5.16 % 5.67 % 5.01 % 5.20 % Rate of compensation increase 3.48 3.52 3.58 N/A N/A N/A Cash balance interest crediting rate 4.00 4.50 3.50 N/A N/A N/A Net periodic benefit cost (credit): Discount rate 4.98 % 5.16 % 2.84 % 5.01 % 5.20 % 2.93 % Expected long-term rate of return on plan assets 5.31 5.17 3.81 4.16 4.04 3.67 Rate of compensation increase 3.52 3.58 3.67 N/A N/A N/A Cash balance interest crediting rate 4.50 3.50 3.00 N/A N/A N/A Williams uses mortality tables issued by the Society of Actuaries to measure the benefit obligations. The assumed health care cost trend rate for 2025 is 9.2 percent. This rate decreases to 4.5 percent by 2034. Plan Assets The plans’ investment objectives include a framework to manage the volatility of the plans’ funded status and minimize future cash contributions. The plans follow a policy of diversifying the investments across various asset classes, strategies, and investment managers. In order to mitigate risks associated with investing, the investment policy for the pension plans defines target asset allocation percentages and outlines types of investments that are authorized and not authorized under the policy. The December 31, 2024, target asset allocation was 25 percent equity securities and 75 percent fixed income securities, including investments in equity and fixed income commingled investment funds and separate accounts. The fair values of Williams’ pension and other postretirement benefits plan assets by asset class at December 31 are as follows: 2024 Pension Benefits Other Postretirement Benefits Level 1 (1) Level 2 (2) Total Level 1 (1) Level 2 (2) Total (Millions) Cash management funds $ 29 $ — $ 29 $ 103 $ — $ 103 Government debt securities 74 19 93 11 3 14 Corporate debt securities — 295 295 — 43 43 Other 1 4 5 — — — $ 104 $ 318 422 $ 114 $ 46 160 Commingled investment funds (3): Equities 292 43 Fixed income 469 69 Total assets at fair value $ 1,183 $ 272 2023 Pension Benefits Other Postretirement Benefits Level 1 (1) Level 2 (2) Total Level 1 (1) Level 2 (2) Total (Millions) Cash management funds $ 17 $ — $ 17 $ 99 $ — $ 99 Government debt securities 61 17 78 9 2 11 Corporate debt securities — 311 311 — 44 44 Other 2 5 7 1 — 1 $ 80 $ 333 413 $ 109 $ 46 155 Commingled investment funds (3): Equities 287 41 Fixed income 467 66 Total assets at fair value $ 1,167 $ 262 ____________ (1) Level 1 includes assets with fair values based on quoted prices in active markets for identical assets. Cash management funds and U.S. Treasury securities are included in this level. (2) Level 2 includes assets with fair values determined by using significant other observable inputs. This level includes fixed income securities, other than U.S. Treasury securities, that are valued primarily using pricing models which incorporate observable inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. (3) The commingled investment funds are measured at fair value using net asset value per share. Certain standard withdrawal restrictions generally apply, which may include redemption notification periods ranging from 1 day to 15 days. Plan Benefit Payments and Employer Contributions Following are the expected benefit payments, which reflect the same assumptions previously discussed and future service as appropriate. Pension Other (Millions) 2025 $ 101 $ 11 2026 95 11 2027 91 11 2028 87 11 2029 83 10 2030-2034 389 48 In 2025, Williams expects to contribute approximately $1 million to the pension plans and approximately $3 million to the other postretirement benefit plan.

Investing Activities

Investing Activities	12 Months Ended
	Dec. 31, 2024
Investments [Abstract]
Investing Activities [Text Block]	Note 8 – Investing Activities Equity-Method Investments Ownership Interest at December 31, 2024 December 31, 2024 2023 (Millions) Appalachia Midstream Investments (1) $ 2,810 $ 2,886 OPPL 50% 385 387 Blue Racer 50% 366 398 Gulfstream 50% 196 210 Laurel Mountain 69% 171 184 Discovery (2) 100% — 361 Other Various 179 188 $ 4,107 $ 4,614 ___________ (1) Includes equity-method investments in multiple gathering systems in the Marcellus Shale region with an approximate average 66 percent interest. (2) Discovery is a wholly owned subsidiary of Williams as of August 1, 2024. See Note 3 – Acquisitions and Divestitures. Basis differential The carrying value of Appalachia Midstream Investments exceeds Williams’ portion of the underlying net assets by approximately $1 billion and $1.1 billion at December 31, 2024 and 2023, respectively. These differences were assigned at the acquisition date to property, plant, and equipment and customer relationship intangible assets. Certain other equity-method investments have a carrying value less than Williams’ portion of the underlying equity in the net assets primarily due to other than temporary impairments that Williams recognized but were not required to be recognized in the investees’ financial statements. These differences total approximately $634 million and $773 million at December 31, 2024 and 2023, respectively, and were assigned to property, plant, and equipment and customer relationship intangible assets. Differences in the carrying value of Williams’ equity-method investments and its portion of the equity in the underlying net assets are generally amortized over the remaining useful lives of the associated underlying assets and included in Equity earnings (losses) within Williams’ Consolidated Statement of Income. Purchases of and contributions to equity-method investments Williams generally funds its portion of significant expansion or development projects of these investees through additional capital contributions. These transactions increased the carrying value of Williams’ investments and included: Year Ended December 31, 2024 2023 2022 (Millions) Appalachia Midstream Investments $ 74 $ 59 $ 83 Discovery 37 40 41 OPPL 2 1 — Aux Sable Liquid Products LP 1 38 — Cardinal Pipeline Company, LLC — — 16 Gulfstream — — 14 Other — 3 12 $ 114 $ 141 $ 166 Dividends and distributions The organizational documents of entities in which Williams has an equity-method investment generally require distribution of available cash to members on at least a quarterly basis. These transactions reduced the carrying value of its investments and included: Year Ended December 31, 2024 2023 2022 (Millions) Appalachia Midstream Investments $ 407 $ 405 $ 415 Gulfstream 103 98 89 Blue Racer 95 62 49 OPPL 90 56 34 Laurel Mountain 29 42 112 Discovery 22 49 49 RMM — 49 52 Other 43 35 65 $ 789 $ 796 $ 865 Summarized Financial Position and Results of Operations of All Equity-Method Investments December 31, 2024 2023 (Millions) Assets (liabilities): Current assets $ 564 $ 669 Noncurrent assets 9,439 11,058 Current liabilities (1,146) (358) Noncurrent liabilities (2,383) (3,619) Year Ended December 31, 2024 2023 2022 (Millions) Gross revenue $ 2,880 $ 3,714 $ 5,520 Operating income 1,190 966 1,268 Net income 987 748 1,102 Sale of Aux Sable Interest On August 1, 2024, Williams completed the sale of its equity-method investments in Aux Sable Liquid Products Inc., Aux Sable Liquid Products LP, and Aux Sable Midstream LLC (collectively, “Aux Sable”) in Williams’ Northeast G&P segment for total consideration of $161 million. As a result of this sale, Williams recorded a gain of $149 million in the third quarter of 2024. The gain is reflected in Other investing income (loss) – net in Williams’ Consolidated Statement of Income. Other investing income (loss) – net The following table presents certain items reflected in Other investing income (loss) – net in Williams’ Consolidated Statement of Income: Year Ended December 31, 2024 2023 2022 (Millions) Gain on sale of Aux Sable investments $ 149 $ — $ — Gain on remeasurement of Discovery investment (Note 3) 127 — — Interest income 67 79 15 Gain on remeasurement of RMM investment (Note 3) — 30 — Other — (1) 1 $ 343 $ 108 $ 16

Property, Plant, and Equipment

Property, Plant, and Equipment	12 Months Ended
	Dec. 31, 2024
Property, Plant and Equipment [Abstract]
Property, Plant, and Equipment [Text Block]	Note 9 – Property, Plant, and Equipment The following tables present Property, plant, and equipment – net for the years ended: Williams Estimated Depreciation December 31, 2024 2023 (Millions) Nonregulated: Natural gas gathering and processing facilities 5 - 40 $ 23,134 $ 21,357 Construction in progress Not applicable 1,543 1,138 Oil and gas properties Units of production 1,685 1,111 Other 0 - 45 4,798 3,268 Regulated: Natural gas transmission facilities 0 - 25 1.25 - 10.2 22,763 21,083 Construction in progress Not applicable Not applicable 542 1,124 Other 5 - 45 0.00 - 33.33 2,930 2,761 Total property, plant, and equipment, at cost 57,395 51,842 Accumulated depreciation and amortization (18,703) (17,531) Property, plant, and equipment — net $ 38,692 $ 34,311 Depreciation and amortization expense for Property, plant, and equipment – net was $1.8 billion, $1.7 billion, and $1.5 billion in 2024, 2023, and 2022, respectively. Interest capitalized was $68 million, $54 million, and $20 million in 2024, 2023, and 2022, respectively. Regulated Property, plant, and equipment – net includes approximately $354 million and $389 million at December 31, 2024 and 2023, respectively, related to the purchase price allocation of $1.5 billion to property, plant and equipment and adjustments to deferred taxes in excess of original cost from Williams’ purchase of Transco in 1995. This amount is being amortized over 40 years using the straight-line amortization method. Current FERC policy does not permit recovery through rates for amounts in excess of original cost of construction. Transco Depreciation December 31, 2024 2023 (Millions) Onshore transmission facilities 2.50 - 7.13 $ 17,242 $ 16,031 Offshore transmission facilities 1.25 659 681 Storage facilities 1.86 - 2.05 948 830 Gathering facilities 0.00 - 1.00 136 158 Construction in progress Not applicable 420 1,008 Other 1.77 - 20.00 639 585 Total property, plant, and equipment, at cost 20,044 19,293 Accumulated depreciation and amortization (5,941) (5,963) Property, plant, and equipment — net $ 14,103 $ 13,330 NWP Depreciation December 31, 2024 2023 (Millions) Transmission facilities 2.70 - 10.20 $ 3,821 $ 3,570 Storage facilities 1.60 - 2.76 160 155 Construction in progress Not applicable 66 85 Other 0.00 - 33.33 171 165 Total property, plant, and equipment, at cost 4,218 3,975 Accumulated depreciation and amortization (2,089) (2,026) Property, plant, and equipment — net $ 2,129 $ 1,949 __________ (1) Estimated useful life and depreciation rates are presented as of December 31, 2024. Depreciation rates and estimated useful lives for regulated assets are prescribed by the FERC. Asset Retirement Obligations Williams’ accrued obligations primarily relate to offshore platforms and pipelines, oil and gas properties, gas transmission pipelines and facilities, underground storage caverns, gas processing, fractionation, and compression facilities, and gas gathering well connections and pipelines. At the end of the useful life of each respective asset, Williams is legally obligated to dismantle offshore platforms and appropriately abandon offshore pipelines, to remove certain components of gas transmission facilities from the ground, to restore land and remove surface equipment at gas processing, fractionation, and compression facilities, to cap certain gathering pipelines at the wellhead connection and remove any related surface equipment, to plug storage caverns and remove any related surface equipment, and to plug producing wells and remove any related surface equipment. The following tables present the significant changes to AROs, of which $2.548 billion and $1.978 billion are included in Regulatory liabilities, deferred income, and other with the remaining current portion in Other current liabilities at December 31, 2024 and 2023, respectively. Williams Year Ended December 31, 2024 2023 (Millions) Balance at beginning of year $ 2,084 $ 1,914 Liabilities incurred (1) 474 42 Liabilities settled (68) (43) Accretion 118 97 Revisions (2) 31 74 Balance at end of year $ 2,639 $ 2,084 ___________ (1) Includes $250 million, $106 million, and $114 million of ARO in 2024 related to the Discovery, Gulf Coast Storage, and Crowheart Acquisitions, respectively. (2) Several factors are considered in the annual review process, including inflation rates, current estimates for removal cost, market risk premiums, discount rates, and the estimated remaining useful life of the assets. Transco Year Ended December 31, 2024 2023 (Millions) Balance at beginning of year $ 619 $ 563 Liabilities incurred — 8 Liabilities settled (32) (23) Accretion 29 31 Revisions (1) (1) 40 Balance at end of year $ 615 $ 619 ___________ (1) Changes in estimates of existing obligations are primarily due to the annual review process, which considers various factors including inflation rate, current estimates for removal costs, discount rates, and the estimated remaining life of assets. The funds Transco collects through a portion of its rates to fund its AROs are deposited into an external trust account dedicated to funding its AROs (ARO Trust). (See Note 16 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk.) NWP Year Ended December 31, 2024 2023 (Millions) Balance at beginning of year $ 136 $ 129 Accretion 8 7 Balance at end of year $ 144 $ 136 NWP’s gross regulatory asset balances associated with ARO as of December 31, 2024 and 2023 were $124 million and $116 million, respectively. NWP’s regulatory asset is expected to be fully recovered through the negative salvage component of depreciation included in NWP’s rates; as such, the negative salvage component of accumulated depreciation collected through rates and reflected as a regulatory liability has been netted with the ARO regulatory asset to result in a regulatory liability of $30 million and $31 million at December 31, 2024 and 2023, respectively (See Note 10 – Regulatory Assets and Liabilities).

Regulatory Assets and Liabiliti

Regulatory Assets and Liabilities	12 Months Ended
	Dec. 31, 2024
Regulated Operations [Abstract]
Regulatory Assets and Liabilities [Table Text Block]	Note 10 – Regulatory Assets and Liabilities The components of regulatory assets and liabilities include the effects of deferred taxes on equity funds used during construction, AROs, shipper imbalance activity, fuel and power cost differentials, depreciation, negative salvage, pension and other postretirement benefits, trackers, customer tax refunds, and rate allowances for deferred income taxes at a historically higher federal income tax rate. Williams December 31, 2024 2023 (Millions) Current assets reported within Other current assets and deferred charges $ 84 $ 95 Noncurrent assets reported within Regulatory assets, deferred charges, and other 582 527 Total regulatory assets $ 666 $ 622 Current liabilities reported within Other current liabilities $ 85 $ 77 Noncurrent liabilities reported within Regulatory liabilities, deferred income, and other 1,300 1,288 Total regulatory liabilities $ 1,385 $ 1,365 Transco December 31, 2024 2023 (Millions) Current regulatory assets: Fuel recovery $ 47 $ 60 ARO 16 16 Deferred cash out 6 6 ARO - Eminence 5 5 Total current regulatory assets 74 87 Long-term regulatory assets: ARO 243 209 Grossed-up deferred taxes on equity AFUDC 29 31 ARO - Eminence 15 20 Slug catcher 6 6 Deferred cash out — 11 Other 27 22 Total long-term regulatory assets 320 299 Total regulatory assets $ 394 $ 386 Current regulatory liabilities: Deferred taxes - liability $ 31 $ 31 Postretirement benefits other than pension — 8 Electric power cost 26 7 Pension — 2 Other 1 1 Total current regulatory liabilities 58 49 Long-term regulatory liabilities: Negative salvage 632 605 Deferred taxes - liability 252 283 Postretirement benefits other than pension 31 23 Pension 30 24 Sentinel meter station depreciation 7 7 Other 24 14 Total long-term regulatory liabilities 976 956 Total regulatory liabilities $ 1,034 $ 1,005 The significant regulatory assets and liabilities include: Fuel recovery : This amount represents the value of the cumulative volumetric difference between the gas retained from customers and the gas consumed in operations. These amounts are not included in the rate base, but assets and liabilities are expected to be recovered or refunded, respectively, in subsequent annual fuel tracker filings. Electric power cost : This amount represents the value of the difference between the electric power costs recovered from our customers and the electric power costs incurred in operations. These amounts are expected to be recovered by changing the electric power reimbursement rate in subsequent annual electric power tracker filings. ARO : This regulatory asset balance includes the uncollected ARO depreciation expense and accretion expense. The regulatory asset is being recovered through rates, and is being amortized to expense consistent with the amounts collected in rates (see AROs in Note 9 – Property, Plant, and Equipment). Deferred cash out : This amount represents the deferral of gains or losses on the purchases and sales of gas imbalances with shippers. These assets and liabilities amounts will be recovered or refunded, respectively, under terms provided for in Transco’s FERC tariff. Asset retirement costs - Eminence : This regulatory asset balance is associated with the Eminence Storage Field retirement costs. The regulatory asset is being recovered through rates and is being amortized to expense consistent with the amounts collected in rates. Grossed-up deferred taxes on equity AFUDC : This regulatory asset balance is established to offset the deferred tax for the equity component of the allowance for funds used during the construction of long-lived assets. All amounts were generated during the period that Transco was a taxable entity. Taxes on capitalized funds used during construction and the offsetting deferred income taxes are included in the rate base and are recovered over the depreciable lives of the long-lived assets to which they relate. Slug catcher: This amount represents certain costs associated with the replacement of a component of a slug catcher which was included in the Docket No. RP18-1126 rate case settlement. A regulatory asset has been established to recognize the recovery of Transco’s investment in the slug catcher as it is collected through Transco’s depreciation rates and is being amortized at the prescribed depreciation rate for onshore transmission facilities (see Note 1 – General, Description of Business, Basis of Presentation, and Summary of Significant Accounting Policies). Negative salvage: Transco’s rates include a component designed to recover certain future retirement costs for which it is not required to record an ARO. Transco records a regulatory liability representing the cumulative residual amount of recoveries through rates, net of expenditures associated with these retirement costs. Deferred taxes - liability : This regulatory liability balance was established as a result of a decrease to rate base deferred taxes due to a decrease to the effective federal income tax rate. The timing of the refund of the regulatory liability to rate payers is stated in the Docket No. RP18-1126 rate case settlement. Additionally, as of December 31, 2024, Transco has $13 million of rate base deferred taxes established as a result of a decrease to the effective state income tax rate. This amount and timing of the refund is being addressed in Transco’s ongoing rate case. Postretirement benefits other than pension: Transco recovers the actuarially determined cost of postretirement benefits through rates that are set through periodic general rate filings. Any differences between the annual actuarially determined cost and the amounts recovered in rates are recorded as regulatory assets or liabilities to be collected or refunded through future rate adjustments. These amounts are not included in the rate base. Effective with the Docket No. RP18-1126 rate case settlement, the other postretirement benefits regulatory liability balance as of March 1, 2019, was fully amortized in 2024 (see Note 7 – Employee Benefit Plans). Pension: Transco recovers the actuarially determined pension cash contributions through rates that are set through periodic general rate filings. Effective with the Docket No. RP18-1126 rate case settlement, any amounts of annual contributions that fall below the threshold are recorded as adjustments to income and refunded through future rate adjustments. Also effective with the Docket No. RP18-1126 rate case settlement, the pension regulatory liability balance as of March 1, 2019, was fully amortized in 2024 (see Note 7 – Employee Benefit Plans). Sentinel meter station depreciation: This amount reflects the incremental depreciation being recorded related to the meter station modifications made for three of the Sentinel shippers. These modifications will be recovered through a surcharge over a defined period of time as stated in the Sentinel FERC order. The incremental depreciation represents the difference between the FERC granted depreciation rate for such facilities in the last rate case as compared to the depreciation rates in the Sentinel order which are based on the contractual terms in the surcharge agreements. The incremental depreciation will be recorded through the end of the contractual term and then will be amortized. NWP December 31, 2024 2023 (Millions) Current regulatory assets: Fuel recovery $ 4 $ — Levelized depreciation 2 2 Total current regulatory assets 6 2 Long-term regulatory assets: Levelized depreciation 7 10 Grossed-up deferred taxes on equity AFUDC 4 4 Washington State Carbon and Greenhouse Gas Tax 38 22 Total long-term regulatory assets 49 36 Total regulatory assets $ 55 $ 38 Current regulatory liabilities: Deferred taxes - liability $ 20 $ 20 Fuel recovery — 1 Total current regulatory liabilities 20 21 Long-term regulatory liabilities: Deferred taxes - liability 160 179 Postretirement benefits other than pension 43 42 Negative salvage - net 30 31 Total long-term regulatory liabilities 233 252 Total regulatory liabilities $ 253 $ 273 The significant regulatory assets and liabilities include: Fuel recovery : This amount represents the value of the cumulative volumetric difference between the gas retained from customers and the gas consumed in operations. These amounts are not included in the rate base, but assets and liabilities are expected to be recovered or refunded, respectively, in subsequent annual fuel tracker filings. Levelized depreciation : Levelized depreciation allows contract revenue streams to remain constant over the primary contract terms by recognizing lower than book depreciation in the early years and higher than book depreciation in later years. The depreciation component of the levelized incremental rates will equal the accumulated book depreciation by the end of the primary contract terms. The difference between levelized depreciation and straight-line book depreciation is recorded as a FERC approved regulatory asset or liability and is eliminated over the levelization period. Grossed-up deferred taxes on equity AFUDC : This regulatory asset balance is established to offset the deferred tax for the equity component of the allowance for funds used during the construction of long-lived assets. All amounts were generated during the period that NWP was a taxable entity. Taxes on capitalized funds used during construction and the offsetting deferred income taxes are included in the rate base and are recovered over the depreciable lives of the long-lived assets to which they relate. Washington State Carbon and Greenhouse Tax : This amount represents the cost of emission allowances and the associated accumulated interest as a result of the passage of the state of Washington Climate Commitment Act that took effect January 1, 2023. NWP’s Settlement allows it to recover the costs of purchasing allowances under the program in NWP’s next rate case. Deferred taxes - liability : This regulatory liability balance was established as a result of a decrease to rate base deferred taxes due to a decrease to the effective federal and state income tax rates. The timing of the refund of the regulatory liability to rate payers is stated in the Docket No. RP22-1155 rate case settlement. Postretirement benefits other than pension: NWP seeks to recover the actuarially determined cost of postretirement benefits through rates that are set through periodic general rate filings. Any differences between the annual actuarially determined cost and amounts currently being recovered in rates are recorded as regulatory assets or liabilities and collected or refunded through future rate adjustments. These amounts are not included in the rate base, and NWP is not currently recovering postretirement benefit costs in its rates (see Note 7 – Employee Benefit Plans). Negative salvage, net of ARO asset : This regulatory liability balance reflects the amount that NWP has recovered in rates related to future retirement costs offset by depreciation of the ARO asset and accretion expense of the ARO liability due to the passage of time. AROs are expected to be fully recovered through the net negative salvage component of depreciation included in rates (see AROs in Note 9 – Property, Plant, and Equipment).

Goodwill and Other Intangible A

Goodwill and Other Intangible Assets	12 Months Ended
	Dec. 31, 2024
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill and Other Intangible Assets [Text Block]	Note 11 – Goodwill and Other Intangible Assets Goodwill Changes in the carrying amount of goodwill, included in Intangible assets – net of accumulated amortization in Williams’ Consolidated Balance Sheet, by reportable segment for the years indicated are as follows: Transmission & Gulf of America West Total (Millions) December 31, 2022 $ — $ — $ — MountainWest Acquisition (Note 3) 400 — 400 Cureton Acquisition (Note 3) — 6 6 RMM Acquisition (Note 3) — 57 57 December 31, 2023 400 63 463 Cureton Acquisition (Note 3) — 5 5 RMM Acquisition (Note 3) — (2) (2) December 31, 2024 $ 400 $ 66 $ 466 Goodwill is not subject to amortization, but is evaluated at least annually for impairment or more frequently if impairment indicators are present. Williams did not identify or recognize any impairments to goodwill in connection with the evaluation of goodwill for impairment during the year ended December 31, 2024. Other Intangible Assets The gross carrying amount and accumulated amortization of other intangible assets, included in Intangible assets – net of accumulated amortization in Williams’ Consolidated Balance Sheet, at December 31 are as follows: 2024 2023 Gross Carrying Amount Accumulated Amortization Gross Carrying Amount Accumulated Amortization (Millions) Customer relationships $ 10,239 $ (3,523) $ 10,237 $ (3,155) Transportation and storage capacity contracts 267 (244) 267 (223) Other 6 (2) 6 (2) Other intangible assets $ 10,512 $ (3,769) $ 10,510 $ (3,380) Customer Relationships Customer relationships primarily relate to gas gathering, processing, and fractionation contractual customer relationships recognized in acquisitions. Contractual customer relationships are being amortized on a straight-line basis over periods of up to 30 years, which represents the term over which the contractual customer relationships are expected to contribute to cash flows. Williams expenses costs incurred to renew or extend the terms of its gas gathering, processing, and fractionation contracts with customers. Although a significant portion of the expected future cash flows associated with these contractual customer relationships are dependent on the ability to renew or extend the arrangements beyond the initial contract periods, these expected future cash flows are significantly influenced by the scope and pace of Williams’ producer customers’ drilling programs. Once producer customers’ wells are connected to Williams’ gathering infrastructure, their likelihood of switching to another provider before the wells are abandoned is reduced due to the significant capital investment required. The amortization expense related to customer relationships was $368 million, $360 million, and $353 million in 2024, 2023, and 2022, respectively. The estimated amortization expense for each of the next five succeeding fiscal years is $368 million, $364 million, $360 million, $360 million, and $360 million. Transportation and Storage Capacity Contracts Certain transportation and storage capacity contracts were recognized as intangible assets as part of the acquisition of Sequent in 2021. The amortization expense related to transportation and storage capacity contracts was $21 million, $51 million, and $158 million in 2024, 2023, and 2022, respectively. The estimated amortization expense for each of the next five succeeding fiscal years is $10 million, $7 million, $4 million, $2 million, and $0 million.

Other Current Liabilities

Other Current Liabilities	12 Months Ended
	Dec. 31, 2024
Accrued Liabilities, Current [Abstract]
Other Current Liabilities [Text Block]	Note 12 – Other Current Liabilities Williams December 31, 2024 2023 (Millions) Interest on debt $ 350 $ 322 Employee costs 285 197 Contract liabilities (Note 5) 170 159 Alaska refinery contamination litigation (Note 1) — 134 Asset retirement obligations (Note 9) 91 106 Regulatory liabilities (Note 10) 85 77 Operating lease liabilities (Note 14) 26 24 Other, including accrued loss contingencies 353 265 $ 1,360 $ 1,284 Transco December 31, 2024 2023 (Millions) Interest on debt $ 76 $ 76 Contract liabilities 10 10 Customer deposits 38 35 Other 57 69 $ 181 $ 190 NWP December 31, 2024 2023 (Millions) Interest on debt $ 6 $ 6 Taxes, other than income taxes 8 7 Contract liabilities — 1 Transportation and gas exchange payables 10 5 Other 10 15 $ 34 $ 34

Debt and Banking Arrangements

Debt and Banking Arrangements	12 Months Ended
	Dec. 31, 2024
Debt Disclosure [Abstract]
Debt and Banking Arrangements [Text Block]	Note 13 – Debt and Banking Arrangements Long-Term Debt by Issuing Entity December 31, 2024 2023 (Millions) Transco: 7.08% Debentures due 2026 $ 8 $ 8 7.25% Debentures due 2026 200 200 7.85% Notes due 2026 1,000 1,000 4% Notes due 2028 400 400 3.25% Notes due 2030 700 700 5.4% Notes due 2041 375 375 4.45% Notes due 2042 400 400 4.6% Notes due 2048 600 600 3.95% Notes due 2050 500 500 Other financing obligation — Atlantic Sunrise 764 790 Other financing obligation — Leidy South 75 76 Other financing obligation — Dalton 247 250 Unamortized debt issuance costs (23) (26) Net unamortized debt premium (discount) (11) (12) Total debt — Transco $ 5,235 $ 5,261 MountainWest: 3.53% Notes due 2028 (Note 3) $ 100 $ 100 3.91% Notes due 2038 (Note 3) 150 150 4.875% Notes due 2041 (Note 3) 180 180 Net unamortized debt premium (discount) (58) (61) Total debt — MountainWest $ 372 $ 369 NWP: 7.125% Debentures due 2025 $ 85 $ 85 4% Notes due 2027 500 500 Unamortized debt issuance costs (1) (2) Net unamortized debt premium (discount) (2) (2) Total debt — NWP $ 582 $ 581 Williams: 4.3% Notes due 2024 $ — $ 1,000 4.55% Notes due 2024 — 1,250 3.9% Notes due 2025 750 750 4% Notes due 2025 750 750 5.4% Notes due 2026 1,100 1,100 7.7% Notes due 2027 2 2 3.75% Notes due 2027 1,450 1,450 5.3% Notes due 2028 900 900 4.9% Notes due 2029 1,100 — 4.8% Notes due 2029 450 — 3.5% Notes due 2030 1,000 1,000 2.6% Notes due 2031 1,500 1,500 7.5% Debentures due 2031 339 339 7.75% Notes due 2031 252 252 8.75% Notes due 2032 445 445 4.65% Notes due 2032 1,000 1,000 5.65% Notes due 2033 750 750 5.15% Notes due 2034 1,300 — 6.3% Notes due 2040 1,250 1,250 5.8% Notes due 2043 400 400 December 31, 2024 2023 (Millions) 5.4% Notes due 2044 500 500 5.75% Notes due 2044 650 650 4.9% Notes due 2045 500 500 5.1% Notes due 2045 1,000 1,000 4.85% Notes due 2048 800 800 3.5% Notes due 2051 650 650 5.3% Notes due 2052 750 750 5.8% Notes due 2054 750 — Unamortized debt issuance costs (130) (112) Net unamortized debt premium (discount) (41) (39) Total debt — Williams $ 20,167 $ 18,837 RMM deferred consideration obligation (Note 3) — 665 Gulf Coast Storage deferred consideration obligation (Note 3) 100 — Total debt $ 26,456 $ 25,713 Long-term debt due within one year — Williams (1,600) (2,305) Long-term debt due within one year — Transco (35) (32) Long-term debt due within one year — NWP (85) — Long-term debt $ 24,736 $ 23,376 Certain of Williams’ debt agreements contain covenants that restrict or limit, among other things, its ability to create liens supporting indebtedness, sell assets, and incur additional debt. Default of these agreements could also restrict Williams’ ability to make certain distributions or repurchase equity. The following table presents aggregate minimum maturities of long-term debt, other financing obligations, and the Gulf Coast Storage deferred consideration obligation, excluding net unamortized debt premium (discount) and debt issuance costs, for each of the next five years: December 31, 2024 (Millions) Williams: 2025 $ 1,720 2026 2,345 2027 1,994 2028 1,445 2029 1,600 Transco: 2025 $ 35 2026 1,245 2027 41 2028 445 2029 50 NWP: 2025 $ 85 2027 500 Issuances Williams senior unsecured public debt issuances for the past three years and subsequent to the balance sheet date are as follows: Issue Date Maturity Date Amount Rate (Millions) January 9, 2025 March 15, 2035 $ 1,000 5.600% January 9, 2025 March 15, 2055 500 6.000% August 13, 2024 November 15, 2029 450 4.800% August 13, 2024 (1) March 15, 2034 300 5.150% August 13, 2024 November 15, 2054 750 5.800% January 5, 2024 March 15, 2029 1,100 4.900% January 5, 2024 March 15, 2034 1,000 5.150% August 10, 2023 (2) March 2, 2026 350 5.400% August 10, 2023 August 15, 2028 900 5.300% March 2, 2023 March 2, 2026 750 5.400% March 2, 2023 March 15, 2033 750 5.650% August 8, 2022 August 15, 2032 1,000 4.650% August 8, 2022 August 15, 2052 750 5.300% ________________ (1) Additional issuance of the 5.15 percent senior notes due 2034 issued on January 5, 2024, and trade interchangeably with such notes. (2) Additional issuance of the 5.40 percent senior notes due 2026 issued on March 2, 2023, and trade interchangeably with such notes. Retirements Williams’ senior unsecured public debt retirements for the past three years and subsequent to the balance sheet date are as follows: Date of Retirement Maturity Date Amount Rate (Millions) January 15, 2025 January 15, 2025 $ 750 3.900% June 24, 2024 June 24, 2024 1,250 4.550% March 4, 2024 March 4, 2024 1,000 4.300% November 15, 2023 November 15, 2023 600 4.500% October 17, 2022 January 15, 2023 850 3.700% May 16, 2022 August 15, 2022 750 3.350% January 18, 2022 March 15, 2022 1,250 3.600% Other financing obligations During the construction of the Atlantic Sunrise, Leidy South, and Dalton projects, Transco received funding from co-owners for their proportionate share of construction costs. Amounts received were recorded within noncurrent liabilities and the costs associated with construction were capitalized. Upon placing these projects into service Transco began utilizing the co-owners’ undivided interest in the assets, including the associated pipeline capacity, and reclassified the funding previously received from its co-owners from noncurrent liabilities to debt. The obligations, which mature in 2038, 2041, and 2052, respectively, require monthly interest and principal payments and bear interest rates of approximately 9 percent, 13 percent, and 9 percent, respectively. Credit Facility December 31, 2024 Stated Capacity Outstanding (Millions) Long-term credit facility (1) $ 3,750 $ — Letters of credit under certain bilateral bank agreements 15 ________________ (1) In managing its available liquidity, Williams does not expect a maximum outstanding amount in excess of the capacity of its credit facility inclusive of any outstanding amounts under the commercial paper program. Revolving credit facility In October 2021, Williams along with Transco and NWP, the lenders named therein, and an administrative agent entered into an amended and restated credit agreement (Credit Agreement) that reduced aggregate commitments available from $4.5 billion to $3.75 billion, with up to an additional $500 million increase in aggregate commitments available under certain circumstances. The Credit Agreement was effective on October 8, 2021. In the second quarter of 2023, the maturity date of the Credit Agreement was extended one year and now expires October 8, 2027. 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. The Credit Agreement allows for swing line loans up to an aggregate of $200 million, subject to available capacity under the credit facility, and letters of credit commitments of $500 million. Transco and NWP are each able to borrow up to $500 million under this credit facility to the extent not otherwise utilized by the other co-borrowers. The Credit Agreement contains the following terms and conditions: • Various covenants may limit, among other things, a borrower’s and its material subsidiaries’ ability to grant certain liens supporting indebtedness, merge or consolidate, sell all or substantially all of its assets in certain circumstances, make certain distributions during an event of default, and each borrower and each borrower’s respective material subsidiaries’ ability to enter into certain restrictive agreements. • If an event of default with respect to a borrower occurs under the credit facility, the lenders will be able to terminate the commitments for the respective borrowers and accelerate the maturity of the loans of the defaulting borrower under the credit facility and exercise other rights and remedies. • Other than swing line loans, each time funds are borrowed, the applicable borrower may choose from two methods of calculating interest: a fluctuating base rate equal to an alternative base rate as defined in the Credit Agreement plus an applicable margin or a periodic fixed rate equal to the Term Secured Overnight Financing Rate plus an applicable margin. Williams is required to pay a commitment fee based on the unused portion of the credit facility. The applicable margin is determined by reference to a pricing schedule based on the applicable borrower’s senior unsecured long-term debt ratings and the commitment fee is determined by reference to a pricing schedule based on Williams’ senior unsecured long-term debt ratings. Significant financial covenants under the Credit Agreement require Williams’ ratio of debt to EBITDA (earnings before interest, taxes, depreciation, and amortization), each as defined in the Credit Agreement, to be no greater than 5.0 to 1.0, except that for any fiscal quarter in which the funding of the purchase price for an acquisition (whether effectuated as one or a series of related transactions) with an aggregate purchase price of $25 million or more has been effected, and the following two fiscal quarters (in each case subject to certain limitations), the ratio of debt to EBITDA is to be no greater than 5.5 to 1. The ratio of debt to capitalization (defined as net worth plus debt), each as defined in the Credit Agreement, must be no greater than 65 percent for each of Transco and NWP. Williams expects to be in compliance with these covenants for the December 31, 2024 reporting period. Commercial Paper Program Williams has a $3.5 billion commercial paper program. The maturities of the commercial paper notes vary but may not exceed 397 days from the date of issuance. The commercial paper notes are sold under customary terms in the commercial paper market and are issued at a discount from par, or, alternatively, are sold at par and bear varying interest rates on a fixed or floating basis. The net proceeds of issuances of the commercial paper notes are expected to be used to fund planned capital expenditures and for other general corporate purposes. At December 31, 2024, $455 million commercial paper was outstanding at a weighted-average interest rate of 4.6 percent. At December 31, 2023, $725 million of commercial paper was outstanding at a weighted-average interest rate of 5.6 percent. Restrictive Debt Covenants At December 31, 2024, none of Transco’s nor NWP’s debt instruments restrict the amount of distributions to Williams, provided, however, that under the credit facility described above, Transco or NWP are restricted from making distributions to Williams during an event of default if Transco or NWP have directly incurred indebtedness under the credit facility. The debt agreements of Transco and NWP contain restrictions on their ability to incur secured debt beyond certain levels and to guarantee certain indebtedness. The indenture governing Transco’s $1 billion of 7.85 percent Senior Notes due 2026 further restricts its ability to guarantee certain indebtedness. Transco and NWP expect to be in compliance with these covenants, for the December 31, 2024 reporting period. Cash Payments for Interest by Registrant (Net of Amounts Capitalized) Year Ended December 31, 2024 2023 2022 (Millions) Williams $ 1,293 $ 1,152 $ 1,117 Transco 302 307 326 NWP 24 26 26

Leases

Leases	12 Months Ended
	Dec. 31, 2024
Leases [Abstract]
Leases [Text Block]	Note 14 – Leases Williams, Transco, and NWP are lessees through noncancellable lease agreements for property and equipment consisting primarily of buildings, land, vehicles, and equipment used in both its operations and administrative functions. Williams Year Ended December 31, 2024 2023 2022 (Millions) Lease Cost: Operating lease cost $ 39 $ 38 $ 34 Variable lease cost 31 31 26 Sublease income — (1) — Total lease cost $ 70 $ 68 $ 60 Cash paid for operating lease liabilities $ 37 $ 37 $ 33 December 31, 2024 2023 (Dollars in Millions) Other Information: Right-of-use assets (included in Regulatory assets, deferred charges, and other ) $ 154 $ 159 Operating lease liabilities: Current (included in Other current liabilities ) $ 26 $ 24 Noncurrent (included in Regulatory liabilities, deferred income, and other ) $ 142 $ 148 Weighted-average remaining lease term – operating leases (years) 11 11 Weighted-average discount rate – operating leases 4.90% 4.78% At December 31, 2024, the following table represents operating lease maturities, including renewal provisions Williams has assessed as being reasonably certain of exercise, for each of the years ended December 31: (Millions) 2025 $ 34 2026 33 2027 30 2028 22 2029 19 Thereafter 86 Total future lease payments 224 Less: Amount representing interest 56 Total obligations under operating leases $ 168 Williams is the lessor to certain lease agreements for office space in its headquarters building, which are insignificant to its financial statements. Transco Year Ended December 31, 2024 2023 2022 (Millions) Lease Cost: Operating lease cost $ 9 $ 9 $ 9 Variable lease cost 7 7 7 Total lease cost $ 16 $ 16 $ 16 Cash paid for operating lease liabilities $ 9 $ 10 $ 10 December 31, 2024 2023 (Dollars in Millions) Other Information: Right-of-use assets (included in Deferred charges and other in Transco’s Balance Sheet) $ 48 $ 53 Operating lease liabilities: Current (included in Other current liabilities in Transco’s Balance Sheet) $ 6 $ 6 Noncurrent (included in Deferred income and other in Transco’s Balance Sheet) $ 51 $ 56 Weighted-average remaining lease term – operating leases (years) 13 13 Weighted-average discount rate – operating leases 4.77% 4.73% As of December 31, 2024, the following table represents operating lease maturities, including renewal provisions that Transco has assessed as being reasonably certain of exercise, for each of the years ended December 31: (Millions) 2025 $ 9 2026 9 2027 10 2028 10 2029 10 Thereafter 32 Total future lease payments 80 Less: Amount representing interest 23 Total obligations under operating leases $ 57 NWP Year Ended December 31, 2024 2023 2022 (Millions) Lease Cost: Operating lease cost $ 3 $ 1 $ 1 Variable lease cost 1 1 1 Total lease cost $ 4 $ 2 $ 2 Cash paid for operating lease liabilities $ 2 $ 1 $ 1 December 31, 2024 2023 (Dollars in Millions) Other Information: Right-of-use assets (included in Deferred charges and other in NWP’s Balance Sheet) $ 5 $ 9 Operating lease liabilities: Current (included in Other current liabilities in NWP’s Balance Sheet) $ 1 $ 1 Noncurrent (included in Deferred income and other in NWP’s Balance Sheet) $ 5 $ 7 Weighted-average remaining lease term – operating leases (years) 19 15 Weighted-average discount rate – operating leases 4.90% 4.18% As of December 31, 2024, the following table represents operating lease maturities, including renewal provisions that NWP has assessed as being reasonably certain of exercise, for each of the years ended December 31: (Millions) 2025 $ 1 2026 — 2027 1 2028 — 2029 1 Thereafter 6 Total future lease payments 9 Less: Amount representing interest 3 Total obligations under operating leases $ 6

Equity-Based Compensation

Equity-Based Compensation	12 Months Ended
	Dec. 31, 2024
Share-Based Payment Arrangement, Noncash Expense [Abstract]
Equity-Based Compensation [Text Block]	Note 15 – Equity-Based Compensation Williams’ Plan Information The Williams Companies, Inc. 2007 Incentive Plan (the Plan) provides common-stock-based awards to both employees and nonmanagement directors. To date, 50 million new shares have been authorized for making awards under the Plan. The Plan permits the granting of various types of awards including, but not limited to, restricted stock units and stock options. At December 31, 2024, 17 million shares of common stock were reserved for issuance pursuant to existing and future stock awards, of which 9 million shares were available for future grants. Additionally, up to 5.2 million new shares of Williams’ common stock have been authorized to date to be available for sale under Williams’ Employee Stock Purchase Plan (ESPP). Employees purchased 240 thousand shares at a weighted-average price of $33.00 per share during 2024. Approximately 0.7 million shares were available for purchase under the ESPP at December 31, 2024. Williams recognizes compensation expense on employee stock-based awards on a straight-line basis; forfeitures are recognized when they occur. Operating and maintenance expenses and Selling, general, and administrative expenses in Williams’ Consolidated Statement of Income include equity-based compensation expense in 2024, 2023, and 2022 of $99 million, $77 million, and $73 million, respectively. Income tax benefit recognized related to the stock-based compensation expense in 2024, 2023, and 2022 was $24 million, $19 million, and $18 million, respectively. Measured but unrecognized stock-based compensation expense at December 31, 2024, was $70 million, all of which related to restricted stock units. These amounts are expected to be recognized over a weighted-average period of 1.7 years. Nonvested Restricted Stock Units At December 31, 2024 and 2023, Williams had restricted stock units outstanding, including performance-based shares, of 6.4 million shares and 6.6 million shares, respectively, with a weighted-average fair value of $32.48 and $28.34, respectively. During 2024 and 2023, Williams granted 3.1 million and 3.8 million shares of restricted stock units with a weighted-average fair value of $31.77 and $27.43, respectively. Restricted stock units generally vest after three years. Performance-based grants may vest at a range from zero percent to 200 percent of the original shares granted based on performance against a target. At December 31, 2024, there were 1.8 million performance-based shares outstanding. Stock Options There were no stock options granted in 2024, 2023, or 2022. At December 31, 2024, Williams had 0.4 million stock options that were both outstanding and exercisable, with a weighted-average exercise price of $29.99. The weighted-average remaining contractual life for stock options that were both outstanding and exercisable at December 31, 2024, was 2.4 years. Cash received for the exercise of stock options in 2024 and 2023 was $5 million and $2 million, respectively, and the related income tax benefit recognized in both 2024 and 2023 was $2 million.

Fair Value Measurements, Guaran

Fair Value Measurements, Guarantees, and Concentration of Credit Risk	12 Months Ended
	Dec. 31, 2024
Fair Value Disclosures [Abstract]
Fair Value Measurements, Guarantees, and Concentration of Credit Risk [Text Block]	Note 16 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk The following table presents, by level within the fair value hierarchy, certain of Williams’, Transco’s, and NWP’s 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 December 31, 2024: Measured on a recurring basis: ARO Trust investments - Transco $ 297 $ 297 $ 297 $ — $ — Commodity derivative assets (1) 344 726 427 188 111 Commodity derivative liabilities (1) (400) (1,070) (532) (475) (63) Additional disclosures: Debt by issuer, including current portion: Williams (20,167) (19,517) — (19,517) — Transco (5,235) (5,276) — (5,276) — NWP (582) (573) — (573) — MountainWest (372) (364) — (364) — Gulf Coast Storage deferred consideration obligation (Note 3) (100) (100) — (100) — Total debt (26,456) (25,830) — (25,830) — Guarantees (36) (28) — (12) (16) Assets (liabilities) at December 31, 2023: Measured on a recurring basis: ARO Trust investments - Transco $ 269 $ 269 $ 269 $ — $ — Commodity derivative assets (1)(2) 314 866 514 196 156 Commodity derivative liabilities (1)(2) (287) (841) (376) (362) (103) Interest rate derivatives 6 6 — 6 — Additional disclosures: Debt by issuer, including current portion: Williams (18,837) (18,494) — (18,494) — Transco (5,261) (5,438) — (5,438) — NWP (581) (581) — (581) — MountainWest (369) (375) — (375) — RMM deferred consideration obligation (Note 3) (665) (665) — (665) — Total debt (25,713) (25,553) — (25,553) — Guarantees (37) (28) — (12) (16) (1) The carrying amount is presented net of counterparty offsetting arrangements and collateral (see Note 17 – Commodity Derivatives). (2) Previously, the fair value of Williams’ commodity derivative assets and liabilities were disclosed by level within the fair value hierarchy net of counterparty offsetting arrangements. The December 31, 2023, amounts have been corrected to disclose the fair values by level on a gross basis, as presented above. Fair Value Methods The following methods and assumptions are used in estimating the fair value of financial instruments: Assets Measured at Fair Value on a Recurring Basis ARO Trust investments Transco is entitled to collect rates in the amounts necessary to fund its future AROs and deposits a portion of the collected rates, pursuant to the terms of its Docket Number RP18-1126 rate case settlement, into an ARO Trust. The ARO Trust invests in a moderate risk 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 Williams’ Consolidated Balance Sheet and in Deferred charges and other in the Transco Balance Sheet. The Money Market Funds held in the ARO Trust are considered investments. Both realized and unrealized gains and losses are ultimately recorded to the ARO regulatory asset. Pursuant to the approved stipulation and agreement in Docket Number RP18-1126 the annual funding obligation effective March 1, 2020, is approximately $16 million, with deposits made monthly. Transco investments within the ARO Trust were as follows: December 31, 2024 December 31, 2023 Amortized Cost Basis Fair Value Amortized Cost Basis Fair Value (Millions) Money Market Funds $ 27 $ 27 $ 26 $ 26 U.S. Equity Funds 53 146 53 120 International Equity Funds 32 40 32 39 Municipal Bond Funds 88 84 87 84 Total $ 200 $ 297 $ 198 $ 269 Commodity derivatives Williams’ commodity derivatives include exchange-traded contracts and OTC contracts, which consist of physical forwards, futures, and swaps that are measured at fair value on a recurring basis. Williams also has 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. See Note 17 – Commodity Derivatives for additional information. The following table presents a reconciliation of changes in fair value of the net commodity derivatives classified as Level 3 in the fair value hierarchy. Year Ended December 31, 2024 2023 (Millions) Balance at beginning of period $ 53 $ (56) Gains (losses) included in Williams’ Consolidated Statement of Income (5) 91 Purchases, issuances, and settlements (1) 20 Transfers into Level 3 1 — Transfers out of Level 3 — (2) Balance at end of period $ 48 $ 53 A substantial portion of the December 31, 2024, and December 31, 2023, Level 3 derivatives relate to a long-term physical natural gas purchase contract associated with an ongoing pipeline expansion project. The valuation of this contract reflects the extrapolation of forward natural gas prices for periods beyond observable price curves, which is considered a significant unobservable input. Interest rate derivatives At December 31, 2023, Williams held interest rate derivative agreements with notional amounts totaling $1.15 billion. During 2024, Williams entered into additional agreements totaling $950 million of notional value and terminated agreements totaling $1.75 billion of notional value coinciding with issuances of long-term debt (see Note 13 – Debt and Banking Arrangements). At December 31, 2024, Williams holds interest rate derivative agreements with notional amounts totaling $350 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. These derivatives are designated as cash flow hedges to reduce interest rate exposure on future corporate debt issuances. Gains and losses on these derivative agreements are reflected as a component of AOCI and, after the termination of the agreements, are amortized to earnings over the term of the related debt as a component of Interest expense . These interest rate derivative agreements are reported in Derivative assets and Derivative liabilities . Additional Fair Value Disclosures Long-term debt, including current portion The disclosed fair value of 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 the debt or similar instruments. The fair values of the financing obligations associated with Transco’s Dalton, Leidy South, and Atlantic Sunrise projects, as well as the deferred consideration obligations associated with the RMM Acquisition and the Gulf Coast Storage Acquisition (see Note 3 – Acquisitions and Divestitures), all included within long-term debt including current portion, were determined using an income approach (see Note 13 – Debt and Banking Arrangements). Guarantees Guarantees primarily consist of a guarantee Williams has provided in the event of nonpayment by a 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 Other current liabilities . The maximum potential undiscounted liquidity exposure is approximately $22 million at December 31, 2024. The 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 . Williams is required by its 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. Williams has never been called upon to perform under these indemnifications and there is no current expectation of a future claim. Concentration of Credit Risk Accounts receivable The following table summarizes Williams’ concentration of receivables, net of allowances: December 31, 2024 2023 (Millions) NGLs, natural gas, and related products and services $ 594 $ 589 Regulated interstate natural gas transportation and storage 339 310 Marketing of natural gas and NGLs 516 321 Upstream activities 45 72 Accounts receivable related to revenues from contracts with customers 1,494 1,292 Receivables from derivatives 294 311 Other accounts receivable 75 52 Trade accounts and other receivables - net $ 1,863 $ 1,655 Williams’ customers include producers, distribution companies, industrial users, gas marketers, and pipelines primarily located in the continental United States. As a general policy, collateral is not required for receivables with the exception of the marketing receivables discussed below. Customers’ financial condition and credit worthiness are evaluated regularly and, based upon this evaluation, Williams may obtain collateral to support receivables. Williams uses established credit policies to determine and monitor the creditworthiness of gas marketing and trading counterparties, including requirements to post collateral or other credit security, as well as the quality of pledged collateral. Collateral or credit security is most often in the form of cash or letters of credit from an investment-grade financial institution, but may also include U.S. government securities. Williams also utilizes netting agreements whenever possible to mitigate exposure to gas marketing and trading counterparty credit risk. When more than one derivative transaction with the same counterparty is outstanding and a legally enforceable netting agreement exists with that counterparty, the “net” mark-to-market exposure represents a reasonable measure of the credit risk with that counterparty. Transco and NWP receivables from contracts with customers are included within Receivables - Trade and Receivables - Affiliates. Receivables that are not related to contracts with customers are included within the balance of Receivables - Advances to affiliate and Receivables - Other . Revenues Customers representing 10 percent or more of Transco’s and NWP’s revenues include: Year Ended December 31, 2024 2023 2022 (Millions) Transco: Dominion Energy, Inc (1) $ 217 $ 287 $ 293 NWP: Puget Sound Energy, Inc. $ 136 $ 126 $ 131 Cascade Natural Gas Corporation 46 47 49 Northwest Natural Gas Company 47 47 49 _______________ (1) The 2024 amount is less than 10 percent of Transco’s revenue.

Commodity Derivatives

Commodity Derivatives	12 Months Ended
	Dec. 31, 2024
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Commodity Derivatives [Text Block]	Note 17 – Commodity Derivatives Williams is exposed to commodity price risk and utilizes derivatives to manage a portion of that risk. Williams reports the fair value of commodity derivatives in Derivative assets ; Regulatory assets, deferred charges, and other ; Derivative liabilities ; or Regulatory liabilities, deferred income, and other . These amounts are presented on a net basis by counterparty and reflect the netting of asset and liability positions permitted under the terms of master netting arrangements and cash held on deposit in margin accounts that Williams has received or remitted to collateralize certain derivative positions. See Note 16 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk for additional fair value information. In Williams’ Consolidated Statement of Cash Flows, any cash impacts of settled commodity derivatives are recorded as operating activities. Williams enters into commodity derivatives to economically hedge exposures to natural gas, NGLs, and crude oil and retains exposure to price changes that can, in a volatile energy market, be material and can adversely affect its results of operations. Volumes At December 31, 2024, the notional volume of the net long (short) positions for Williams’ commodity derivative contracts were as follows: Commodity Unit of Measure Net Long (Short) Position Index Risk Natural Gas MMBtu 592,842,257 Central Hub Risk - Henry Hub Natural Gas MMBtu (50,513,793) Basis Risk Natural Gas MMBtu 13,306,615 Central Hub Risk - Mont Belvieu Natural Gas Liquids Barrels (2,561,000) Basis Risk Natural Gas Liquids Barrels (205,000) Central Hub Risk - WTI Crude Oil Barrels (480,000) Financial Statement Presentation The fair value of commodity derivatives, which are not designated as hedging instruments for accounting purposes, is reflected as follows: December 31, December 31, Commodity Derivatives Categories Assets (Liabilities) Assets (Liabilities) (Millions) Current $ 508 $ (635) $ 623 $ (496) Noncurrent 218 (435) 243 (345) Total commodity derivatives $ 726 $ (1,070) $ 866 $ (841) Counterparty and collateral netting offset (382) 670 (552) 554 Amounts recognized in Williams’ Consolidated Balance Sheet $ 344 $ (400) $ 314 $ (287) The pre-tax impacts of Williams’ commodity derivatives, which are not designated as hedging instruments for accounting purposes, are reflected as follows: Year Ended December 31, 2024 2023 2022 (Millions) Net gain (loss) from commodity derivatives within Total revenues : Realized $ 111 $ 253 $ (91) Unrealized (361) 703 (296) $ (250) $ 956 $ (387) Net gain (loss) from commodity derivatives within Net processing commodity expenses : Realized $ (8) $ (4) $ 16 Unrealized (6) (43) 47 $ (14) $ (47) $ 63 Total net gain (loss) from commodity derivatives $ (264) $ 909 $ (324) 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. Williams has 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 Williams’ credit ratings are downgraded to non-investment grade status. Under such circumstances, Williams would need to post collateral to continue transacting business with these counterparties. At December 31, 2024, the contractually required collateral in the event of a credit rating downgrade to non-investment grade status was $6 million. Williams maintains 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, Williams may be required to deposit cash into these accounts. At December 31, 2024, and 2023, net cash collateral held on deposit in broker margin accounts was $288 million, and $2 million, respectively.

Contingencies and Commitments

Contingencies and Commitments	12 Months Ended
	Dec. 31, 2024
Commitments and Contingencies Disclosure [Abstract]
Contingencies and Commitments [Text Block]	Note 18 – Contingencies and Commitments Royalty Matters Certain customers, including Expand Energy Corporation (formerly Chesapeake Energy Corporation or 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. Williams has also been named as a defendant in certain of these cases filed in Pennsylvania based on allegations that Williams improperly participated with Chesapeake in causing the alleged royalty underpayments. Williams believes that the claims asserted are subject to indemnity obligations owed to Williams 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 Williams and does not require any contribution from Williams. 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 Williams, or claims against Chesapeake that arose after February 9, 2021. Williams continues to believe the claims against Williams are subject to indemnity obligations owed to Williams by Chesapeake. Rate Matters On August 30, 2024, Transco filed a general rate case (Docket No. RP24-1035) with the FERC for an overall increase in rates and to comply with the terms of the settlement of its prior rate case to file a rate case no later than August 30, 2024. On September 30, 2024, the FERC issued an order accepting and suspending Transco’s general rate filing to be effective March 1, 2025, subject to refund and the outcome of hearing procedures established by the FERC except that rates for certain services that were proposed as overall rate decreases were accepted, without suspension, to be effective October 1, 2024. The decreased rates will not be subject to refund but may be subject to decrease prospectively under Section 5 of the Natural Gas Act of 1938 as amended. Construction Litigation In February 2025, Transco received an adverse judgment related to litigation in the United States Bankruptcy Court for the District of Delaware involving the contractor for the construction of Transco’s Atlantic Sunrise project completed in 2018. The total award to the contractor, estimated at $110 million, included amounts for unpaid invoices, interest, and attorney fees. Management estimates the probable loss from the judgment to be substantially less and Transco has filed a notice of appeal. Transco has capitalized the amount considered probable within noncurrent assets and expects any additional probable loss would also be capitalized. Transco also expects to recover approximately 29 percent of any amount paid from the counterparty on the project. Environmental Matters Williams Williams is a participant in certain environmental activities in various stages including assessment studies, cleanup operations, and/or remedial processes at certain sites, some of which Williams currently does not own. Williams is monitoring these sites in a coordinated effort with other potentially responsible parties, the U.S. Environmental Protection Agency (EPA), or other governmental authorities. Williams is jointly and severally liable along with unrelated third parties in some of these activities and solely responsible in others. Certain of Williams’ 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 December 31, 2024, Williams has accrued liabilities totaling $ 42 million The EPA, other federal agencies, and various state regulatory agencies routinely propose and promulgate new rules, issue updated guidance to rules, or revise existing rules. These rulemakings include, but are not limited to, reviews and updates to the National Ambient Air Quality Standards, and promulgation of rules for new and existing source performance standards for certain equipment emitting volatile organic compound and methane as well as limitations on emissions of greenhouse gas compounds. Williams continuously monitors these regulatory changes and how they may impact its operations. Implementation of new or revised regulations may result in impacts to Williams’ operations and increase the cost of additions to Property, plant, and equipment – net in the balance sheet for both new and existing facilities in affected areas; however, due to regulatory uncertainty on final rule content or guidance and applicability timeframes, Williams is unable to reasonably estimate the cost of these regulatory impacts at this time. Continuing operations Williams’ 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 Williams’ identification as a potentially responsible party at various Superfund waste sites. At December 31, 2024, Williams has accrued liabilities of $12 million (see Transco and NWP below) for these costs and expect to recover approximately $4 million through rates. Williams also accrues environmental remediation costs for natural gas underground storage facilities, primarily related to soil and groundwater contamination. At December 31, 2024, Williams has accrued liabilities totaling $7 million for these costs. Former operations Williams has potential obligations in connection with assets and businesses it no longer operates. These potential obligations include remediation activities at the direction of federal and state environmental authorities and the indemnification of the purchasers of certain of these assets and businesses for environmental and other liabilities existing at the time the sale was consummated. At December 31, 2024, Williams has accrued environmental liabilities of $23 million related to these matters. Transco Transco has had studies underway for many years to test some of its facilities for the presence of toxic and hazardous substances such as polychlorinated biphenyls (PCBs) and mercury to determine to what extent, if any, remediation may be necessary. Transco has also similarly evaluated past on-site disposal of hydrocarbons at a number of its facilities. Transco has worked closely with and responded to data requests from the EPA and state agencies regarding such potential contamination of certain of their sites. Transco is conducting environmental assessments and implementing a variety of remedial measures that may result in increases or decreases in the total estimated costs. Transco also has a program for monitoring certain environmental activities at their Eminence storage facility. At December 31, 2024, Transco has accrued liabilities of approximately $ 11 million Transco has been identified as a potentially responsible party (PRP) at various Superfund and state waste disposal sites. Based on present volumetric estimates and other factors, their estimated aggregate exposure for remediation of these sites is less than $1 million. The estimated remediation costs for all of these sites are included in the environmental liabilities discussed above. Liability under the Comprehensive Environmental Response, Compensation and Liability Act and applicable state law can be joint and several with other PRPs. Although volumetric allocation is a factor in assessing liability, it is not necessarily determinative; thus, the ultimate liability could be substantially greater than the amounts described above. Transco considers prudently incurred environmental assessment and remediation costs and the costs associated with compliance with environmental standards to be recoverable through rates. Historically, with limited exceptions, it has been permitted recovery of environmental costs, and it is Transco’s intent to continue seeking recovery of such costs through future rate filings. NWP Beginning in the mid-1980s, NWP evaluated many of its facilities for the presence of toxic and hazardous substances to determine to what extent, if any, remediation might be necessary. NWP identified PCB contamination in air compressor systems, soils, and related properties at certain compressor station sites. Similarly, it identified hydrocarbon impacts at these facilities due to the former use of earthen pits, lubricating oil leaks or spills, and excess pipe coating released to the environment. In addition, heavy metals have been identified at these sites due to the former use of mercury containing meters and paint and welding rods containing lead, cadmium, and arsenic. The PCBs were remediated pursuant to a Consent Decree with the EPA in the late 1980s, and NWP conducted a voluntary clean-up of the hydrocarbon and mercury impacts in the early 1990s. In 2005, the Washington Department of Ecology required NWP to re-evaluate previous clean-ups in Washington. During 2006 to 2015, 129 meter stations were evaluated, of which 82 required remediation. As of December 31, 2024, two meter stations are still being remediated. During 2006 to 2018, 14 compressor stations were evaluated, of which 11 required remediation. As of December 31, 2024, four compressor stations are still being remediated. NWP had accrued liabilities totaling approximately $ 1 million Environmental expenditures are expensed or capitalized depending on their future economic benefit and potential for rate recovery. NWP believes that, with respect to any expenditures required to meet applicable standards and regulations, the FERC would grant the requisite rate relief so that substantially all of such expenditures would be permitted to be recovered through rates. Washington State Climate Commitment Act In 2021, the state of Washington passed its Climate Commitment Act establishing a market-based cap-and-invest program to reduce carbon emissions. This program took effect on January 1, 2023, and sets a limit, or cap, on overall carbon emissions in the state and requires businesses like NWP to obtain allowances equal to their annual covered carbon emissions. The state’s cap will be reduced over time to meet the state’s carbon emissions reduction targets, which means fewer carbon emissions allowances will be available to purchase each year. These allowances can be purchased through quarterly auctions hosted by the state or bought and sold on a secondary market. In 2023, NWP began purchasing allowances for the carbon emissions from nine of its thirteen compressor stations within the state whose annual carbon emissions have exceeded 25,000 metric tons of carbon dioxide equivalent at least once since 2015. NWP also began purchasing allowances for NWP’s delivery of natural gas to certain of their customers and certain of their facilities in the state whose annual carbon emissions are insufficient to require their direct participation in the program. NWP’s latest rate case settlement allows them to recover the costs of purchasing allowances under the program in their next rate case. At December 31, 2024 and December 31, 2023, a total of $38 million and $22 million, respectively, were included in Regulatory assets in NWP’s Balance Sheet and was comprised of the cost of the purchased allowances held, the estimated difference between the allowances held and the allowances required, and the interest income component of the regulatory asset. At December 31, 2024 and December 31, 2023, $3 million and $4 million, respectively, were recorded in Other current liabilities on NWP’s Balance Sheet as the estimated difference. Interest income of $2 million for the year ended December 31, 2024 and $1 million for the year ended December 31, 2023 is reflected in Other income (expense) – net in NWP’s Statement of Net Income. Other Divestiture Indemnifications Pursuant to various purchase and sale agreements relating to divested businesses and assets, Williams has indemnified certain purchasers against liabilities that they may incur with respect to the businesses and assets acquired. The indemnities provided to the purchasers are customary in sale transactions and are contingent upon the purchasers incurring liabilities that are not otherwise recoverable from third parties. At December 31, 2024, other than as previously disclosed, Williams is not aware of any material claims against it involving the above-described indemnities. Any claim for indemnity brought against Williams in the future may have a material adverse effect on Williams’ results of operations in the period in which the claim is made. In addition to the foregoing, various other proceedings are pending against Williams that are incidental to its operations, none of which are expected to be material to Williams’ expected future annual results of operations, liquidity, and financial position. Summary Williams, Transco and NWP have disclosed estimated ranges of reasonably possible losses for certain matters above, as well as all significant matters for which they are unable to reasonably estimate a range of possible loss. Williams, Transco and NWP estimate that for all other matters for which they are able to reasonably estimate a range of loss, the aggregate reasonably possible losses beyond amounts accrued are immaterial to expected future annual results of operations, liquidity, and financial position. These calculations have been made without consideration of any potential recovery from third parties. Commitments Commitments for Gas & NGL Marketing Services pipeline transportation capacity and storage capacity are approximately $954 million at December 31, 2024.

Segment Disclosures

Segment Disclosures	12 Months Ended
	Dec. 31, 2024
Segment Reporting [Abstract]
Segment Disclosures [Text Block]	Note 19 – Segment Disclosures Williams Williams’ reportable segments are Transmission & Gulf of America, Northeast G&P, West, and Gas & NGL Marketing Services. All remaining business activities are included in Other. (See Note 1 – General, Description of Business, Basis of Presentation, and Summary of Significant Accounting Policies.) Performance Measurement Williams’ chief operating decision maker is the Chief Executive Officer. Williams' chief operating decision maker primarily utilizes Modified EBITDA, its measure of segment profit and loss, to evaluate performance and make decisions on capital allocation and human resources. Such evaluation includes periodic comparisons of actual performance versus historical and budget, as well as projections of Modified EBITDA . Williams defines Modified EBITDA as follows: • Income (loss) before income taxes from continuing operations before: ◦ Depreciation and amortization expenses; ◦ Equity earnings (losses); ◦ Other investing income (loss) – net; ◦ Interest expense; and ◦ Accretion expense associated with AROs for nonregulated operations. • This measure is further adjusted to include Williams’ proportionate share (based on ownership interest) of Modified EBITDA from its equity-method investments calculated consistently with the definition described above. Significant noncash items which are components of Modified EBITDA may include net unrealized gain (loss) from commodity derivatives within Total revenues, net unrealized gain (loss) from commodity derivatives within Net processing commodity expenses for Williams’ Gas & NGL Marketing Services segment, charges associated with lower of cost or net realizable value adjustments to the Gas & NGL Marketing Services segment inventory within Product sales (for natural gas marketing inventory as these sales are presented net of the related costs) and Product costs (for NGL marketing inventory), and impairments of certain assets within Other (income) expense – net within Operating income (loss) . Intersegment Service revenues primarily represent transportation services provided to Williams’ marketing business and gathering services provided to its oil and gas properties. Intersegment Product sales primarily represent the sale of natural gas and NGLs from Williams’ natural gas processing plants and its oil and gas properties to its marketing business. Segment assets include Investments , Property, plant, and equipment – net, and Intangible assets – net of accumulated amortization . The following tables present revenues, Modified EBITDA , significant expenses, and certain segment assets measures, as well as reconciliations to the consolidated totals: Transmission & Gulf of America Northeast G&P West Gas & NGL Marketing Services (1) Total (Millions) 2024 Segment revenues: Service revenues External $ 4,157 $ 1,900 $ 1,558 $ — $ 7,615 Internal 89 13 160 — 262 Total service revenues 4,246 1,913 1,718 — 7,877 Total service revenues – commodity consideration 54 2 78 — 134 Product sales External 144 24 178 2,500 2,846 Internal 184 86 691 (448) 513 Total product sales 328 110 869 2,052 3,359 Net gain (loss) from commodity derivatives Realized — — 4 72 76 Unrealized — — — (335) (335) Total net gain (loss) from commodity derivatives (2) — — 4 (263) (259) Total revenues of reportable segments $ 4,628 $ 2,025 $ 2,669 $ 1,789 $ 11,111 Reconciliation of revenues: Revenues from upstream operations, corporate, and other business activities 470 Net unrealized gain (loss) from commodity derivatives for upstream operations (26) Eliminations (1,052) Total consolidated revenues $ 10,503 Segment costs and expenses and Proportional Modified EBITDA of equity-method investments: Product costs and net realized processing commodity expenses (329) (88) (844) (1,799) Net unrealized gain (loss) from commodity derivatives within Net processing commodity expenses — — — (6) Operating and administrative expenses (3) (1,104) (441) (591) (108) Recoverable power, transportation, and storage costs (4) (250) (143) (49) — Other segment income (expenses) - net (5) 155 3 (5) — Proportional Modified EBITDA of equity-method investments 173 602 132 — Modified EBITDA of reportable segments $ 3,273 $ 1,958 $ 1,312 $ (124) $ 6,419 Modified EBITDA from upstream operations, corporate, and other business activities 237 Total consolidated Modified EBITDA $ 6,656 Reconciliation of Modified EBITDA: Depreciation and amortization expenses $ (2,219) Equity earnings (losses) 560 Other investing income (loss) - net 343 Interest expense (1,364) Accretion expense associated with AROs for nonregulated operations (81) Proportional Modified EBITDA of equity-method investments (909) Income (loss) before income taxes from continuing operations $ 2,986 Equity-method investments by reportable segment $ 272 $ 3,346 $ 476 $ — $ 4,094 Other equity-method investments 13 Total equity-method investments $ 4,107 Segment assets $ 23,149 $ 12,918 $ 12,144 $ 46 $ 48,257 Total current assets 2,661 Regulatory assets, deferred charges, and noncurrent assets 1,830 Assets of upstream operations, corporate, and other business activities 1,784 Total assets $ 54,532 Additions to long-lived segment assets $ 4,399 $ 210 $ 529 $ 2 $ 5,140 Additions to long-lived assets of upstream operations, corporate, and other business activities 458 Total additions to long-lived assets $ 5,598 Transmission & Gulf of America Northeast G&P West Gas & NGL Marketing Services (1) Total (Millions) 2023 Segment revenues: Service revenues External $ 3,766 $ 1,868 $ 1,376 $ 1 $ 7,011 Internal 92 28 126 — 246 Total service revenues 3,858 1,896 1,502 1 7,257 Total service revenues – commodity consideration 38 5 103 — 146 Product sales External 146 34 80 2,382 2,642 Internal 106 98 361 (322) 243 Total product sales 252 132 441 2,060 2,885 Net gain (loss) from commodity derivatives Realized 2 — 89 115 206 Unrealized — — — 702 702 Total net gain (loss) from commodity derivatives (2) 2 — 89 817 908 Total revenues of reportable segments $ 4,150 $ 2,033 $ 2,135 $ 2,878 $ 11,196 Reconciliation of revenues: Revenues from upstream operations, corporate, and other business activities 505 Net unrealized gain (loss) from commodity derivatives for upstream operations 1 Eliminations (795) Total consolidated revenues $ 10,907 Segment costs and expenses and Proportional Modified EBITDA of equity-method investments: Product costs and net realized processing commodity expenses (259) (125) (517) (1,786) Net unrealized gain (loss) from commodity derivatives within Net processing commodity expenses — — — (43) Operating and administrative expenses (3) (1,034) (424) (502) (98) Recoverable power, transportation, and storage costs (4) (241) (132) (37) — Other segment income (expenses) - net (5) 118 (10) (3) (1) Gain on sale of business (6) 129 — — — Proportional Modified EBITDA of equity-method investments 205 574 162 — Modified EBITDA of reportable segments $ 3,068 $ 1,916 $ 1,238 $ 950 $ 7,172 Modified EBITDA from upstream operations, corporate, and other business activities 307 Unallocated Net gain from Energy Transfer litigation judgment (7) 534 Total consolidated Modified EBITDA $ 8,013 Reconciliation of Modified EBITDA: Depreciation and amortization expenses $ (2,071) Equity earnings (losses) 589 Other investing income (loss) - net 108 Interest expense (1,236) Accretion expense associated with AROs for nonregulated operations (59) Proportional Modified EBITDA of equity-method investments (939) Income (loss) before income taxes from continuing operations $ 4,405 Equity-method investments by reportable segment $ 652 $ 3,477 $ 477 $ — $ 4,606 Other equity-method investments 8 Total equity-method investments $ 4,614 Segment assets $ 19,705 $ 13,319 $ 12,188 $ 77 $ 45,289 Total current assets 4,513 Regulatory assets, deferred charges, and noncurrent assets 1,573 Assets of upstream operations, corporate, and other business activities 1,252 Total assets $ 52,627 Additions to long-lived segment assets $ 2,501 $ 340 $ 1,186 $ 7 $ 4,034 Additions to long-lived assets of upstream operations, corporate, and other business activities 279 Total additions to long-lived assets $ 4,313 Transmission & Gulf of America Northeast G&P West Gas & NGL Marketing Services (1) Total (Millions) 2022 Segment revenues: Service revenues External $ 3,461 $ 1,613 $ 1,443 $ 3 $ 6,520 Internal 118 41 99 — 258 Total service revenues 3,579 1,654 1,542 3 6,778 Total service revenues – commodity consideration 64 14 182 — 260 Product sales External 228 28 145 4,052 4,453 Internal 176 106 696 (518) 460 Total product sales 404 134 841 3,534 4,913 Net gain (loss) from commodity derivatives Realized — — (4) 17 13 Unrealized — — — (321) (321) Total net gain (loss) from commodity derivatives (2) — — (4) (304) (308) Total revenues of reportable segments $ 4,047 $ 1,802 $ 2,561 $ 3,233 $ 11,643 Reconciliation of revenues: Revenues from upstream operations, corporate, and other business activities 626 Net unrealized gain (loss) from commodity derivatives for upstream operations 25 Eliminations (1,329) Total consolidated revenues $ 10,965 Segment costs and expenses and Proportional Modified EBITDA of equity-method investments: Product costs and net realized processing commodity expenses (425) (138) (918) (3,228) Net unrealized gain (loss) from commodity derivatives within Net processing commodity expenses — — — 47 Operating and administrative expenses (3) (906) (384) (507) (96) Recoverable power, transportation, and storage costs (4) (254) (132) (43) — Other segment income (expenses) - net (5) 19 (6) (14) 4 Proportional Modified EBITDA of equity-method investments 193 654 132 — Modified EBITDA of reportable segments $ 2,674 $ 1,796 $ 1,211 $ (40) $ 5,641 Modified EBITDA from upstream operations, corporate, and other business activities 434 Total consolidated Modified EBITDA $ 6,075 Reconciliation of Modified EBITDA: Depreciation and amortization expenses $ (2,009) Equity earnings (losses) 637 Other investing income (loss) - net 16 Interest expense (1,147) Accretion expense associated with AROs for nonregulated operations (51) Proportional Modified EBITDA of equity-method investments (979) Income (loss) before income taxes from continuing operations $ 2,542 Equity-method investments by reportable segment $ 629 $ 3,566 $ 843 $ — $ 5,038 Other equity-method investments 10 Total equity-method investments $ 5,048 Segment assets $ 17,795 $ 13,539 $ 10,710 $ 130 $ 42,174 Total current assets 3,797 Regulatory assets, deferred charges, and noncurrent assets 1,319 Assets of upstream operations, corporate, and other business activities 1,143 Total assets $ 48,433 Additions to long-lived segment assets $ 1,420 $ 261 $ 1,507 $ 4 $ 3,192 Additions to long-lived assets of upstream operations, corporate, and other business activities 406 Total additions to long-lived assets $ 3,598 _______________________ (1) As Williams is acting as agent for natural gas marketing customers or engages in energy trading activities, the resulting revenues are presented net of the related costs of those activities. (2) Williams records transactions that qualify as commodity derivatives at fair value with changes in fair value recognized in earnings in the period of change and characterized as unrealized gains or losses. Gains and losses from commodity derivatives held for energy trading purposes are presented on a net basis in revenue. (3) Segment operating and administrative expenses primarily include payroll, maintenance and operating costs and taxes, and general and administrative expenses, including acquisition and transition-related expenses. It also includes project execution, information technology, finance and accounting, real estate and aviation, central engineering services, safety and operational discipline, supply chain and digital transformation, corporate strategic development, human resources, legal and government affairs, and executive and audit support services costs which are centrally managed and allocated to segments. (4) Recoverable power, transportation and storage costs are charges incurred which are reimbursable pursuant to FERC stipulations or customer contracts. (5) Other segment income (expenses) primarily includes equity AFUDC and regulatory credits and charges related to Williams’ regulated operations. (6) Gain on sale of business reflects a gain recognized on the sale of certain liquids pipelines in the Gulf Coast region in September 2023 (see Note 3 – Acquisitions and Divestitures). (7) Net gain from Energy Transfer litigation judgment resulted from a favorable ruling in November 2023 (see Note 1 – General, Description of Business, Basis of Presentation, and Summary of Significant Accounting Policies). Transco Transco manages and evaluates its business as a single reportable segment. Transco’s chief operating decision maker is the Senior Vice President, Transmission & Gulf of America. Transco’s chief operating decision maker determines resource allocation, measures and evaluates segment operating performance based upon Net income (loss) as reported on the Statement of Net Income. Significant expenses within net income, include Operating and maintenance expenses and Selling, general, and administrative expenses , which are each separately presented on Transco’s Statement of Net Income. Other segment items within net income include natural gas product costs, depreciation and amortization expense, taxes, other than income taxes, interest expense, interest income, other income (expense) – net, and AFUDC. Transco’s segment assets include Property, plant, and equipment – net as presented on the Balance Sheet. NWP NWP manages and evaluates its business as a single reportable segment. NWP’s chief operating decision maker is the Senior Vice President, Transmission & Gulf of America. NWP’s chief operating decision maker determines resource allocation, measures and evaluates segment operating performance based upon Net income (loss) as reported on the Statement of Net Income. Significant expenses within net income, include Operating and maintenance expenses and Selling, general, and administrative expenses , which are each separately presented on NWP’s Statement of Net Income. Other segment items within net income include depreciation and amortization expense, taxes, other than income taxes, interest expense, other income (expense) – net, and AFUDC. NWP’s segment assets include Property, plant, and equipment – net as presented on the Balance Sheet.

Subsequent Events

Subsequent Events	12 Months Ended
	Dec. 31, 2024
Subsequent Events [Abstract]
Subsequent Events [Text Block]	Note 20 – Subsequent Events Quarterly Dividends to Common Stockholders On January 28, 2025, Williams’ board of directors approved a regular quarterly dividend to common stockholders of $0.500 per share payable on March 31, 2025. Long-term Debt Issuance and Retirement In January 2025, Williams issued $1 billion of 5.6 percent senior unsecured notes due March 15, 2035 and $500 million of 6.0 percent senior unsecured notes due March 15, 2055 (see Note 13 – Debt and Banking Arrangements). Also in January 2025, Williams retired $750 million of senior unsecured debt.

Schedule II - Valuation and Qua

Schedule II - Valuation and Qualifying Accounts	12 Months Ended
	Dec. 31, 2024
SEC Schedule, 12-09, Valuation and Qualifying Accounts [Abstract]
Schedule II - Valuation and Qualifying Accounts [Text Block]	The Williams Companies, Inc. Schedule II — Valuation and Qualifying Accounts Additions Beginning Charged Other Deductions Ending (Millions) 2024 Deferred tax asset valuation allowance (1) $ 183 $ (92) $ — $ — $ 91 2023 Deferred tax asset valuation allowance (1) 200 (17) — — 183 2022 Deferred tax asset valuation allowance (1) 297 (97) — — 200 __________ (1) Deducted from related assets.

Pay vs Performance Disclosure

Pay vs Performance Disclosure - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Pay vs Performance Disclosure
Net income	$ 2,225	$ 3,179	$ 2,049

Insider Trading Arrangements

Insider Trading Arrangements	3 Months Ended
	Dec. 31, 2024
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

Insider Trading Policies and Pr

Insider Trading Policies and Procedures	12 Months Ended
	Dec. 31, 2024
Insider Trading Policies and Procedures [Line Items]
Insider Trading Policies and Procedures Adopted	true

Cybersecurity Risk Management a

Cybersecurity Risk Management and Strategy Disclosure	12 Months Ended
	Dec. 31, 2024
Cybersecurity Risk Management, Strategy, and Governance [Line Items]
Cybersecurity Risk Management Processes for Assessing, Identifying, and Managing Threats [Text Block]	Item 1C. Cybersecurity Management for Williams, Transco, and NWP recognizes the increasing volume and sophistication of cyber threats and takes its responsibility to protect the information and systems under its purview seriously. Management’s cybersecurity processes aim to provide a comprehensive approach to assess, identify, and manage material risks arising from these cybersecurity threats. Comprehensive Cybersecurity Program : Management has implemented a comprehensive cybersecurity risk management program (Cybersecurity Program) that is aligned with the National Institute for Standards and Technology Cybersecurity Framework. The Cybersecurity Program provides a risk-based approach to cybersecurity, and security controls are tailored so that cost-effective controls can be applied commensurate with the risk and sensitivity of specific information systems, control systems, and enterprise data. The Cybersecurity Program incorporates best practices and industry standards from multiple sources and is designed to comply with applicable regulations. The Cybersecurity Program includes, but is not limited to, the following elements: risk assessment, policies and procedures, contract management, training and awareness, auditing, compliance monitoring and testing, table-top exercises, and incident response. Integration with Overall Risk Management : Management’s cybersecurity processes have been integrated into overall risk management system and processes. Management considers cybersecurity threat risks alongside other Company risks as part of its overall risk assessment process. Cybersecurity risk professionals collaborate with subject matter specialists, as necessary, to gather insights for identifying and assessing material cybersecurity threat risks, their severity, and potential mitigations. Engagement of Third Parties : Management often engages with specialized third-party assessors, consultants, auditors, and other experts to review, validate, and enhance its cybersecurity practices. Third-party independent assessments provide an external perspective on management’s cybersecurity posture, allowing it to leverage best practices from the industry and ensure its defenses remain robust. All third parties engaged for such processes are subjected to rigorous scrutiny to ensure the third parties meet management’s security standards. Oversight of Third-party Service Providers : Management acknowledges the potential risks associated with the use of third-party service providers. Therefore, management has established processes to oversee and identify material cybersecurity risks that may be associated with third-party service providers with whom it engages. This includes conducting thorough, risk-based due diligence before onboarding, performing security assessments, and confirming adherence to management’s cybersecurity requirements. Management also maintains active communication channels with these providers to stay informed about any potential security incidents or concerns. Disclosure of Risks : Management describes how risks from cybersecurity threats could materially affect its business strategy, results of operations, or financial condition, as part of its risk factor disclosures at Part I, Item 1A of this Annual Report on Form 10-K. Management is committed to continually enhancing its cybersecurity processes and practices to address the dynamic nature of the threats it faces and to ensure the security and integrity of its systems and data. Cybersecurity Governance Cybersecurity is an important part of the risk management processes and an area of focus for the Board of Directors and management. Each member of Williams’ organization, which includes Transco and NWP, from facility operators to board members, has a responsibility to safeguard the organization’s cybersecurity. The Chief Information Security Officer (CISO) is responsible for the cybersecurity strategy and execution, while the Board and the Audit Committee are responsible for oversight of cybersecurity risk. The Cybersecurity Governance Committee is led by the CISO and includes cybersecurity managers and other subject matter experts as standing members. The Cybersecurity Governance Committee is tasked with developing, implementing, and maintaining the Cybersecurity Program. The Cybersecurity Executive Advisory Board (Executive Advisory Board) is led by the CISO, with the Chief Information Officer (CIO), Chief Financial Officer, Chief Human Resources Officer, the General Counsel, and the Chief Operations Officer as standing members. The Executive Advisory Board’s purpose is to ensure enterprise alignment with the Cybersecurity Program and provide executive oversight of the Cybersecurity Program. The Board of Directors oversees cybersecurity-related policy and strategy. As part of this oversight, the CISO provides a cybersecurity dashboard that is reviewed by the Board at every regularly scheduled Board meeting, which includes key performance indicators for cybersecurity process maturity, operational performance, and enterprise performance toward Transportation Security Administration (TSA) compliance. Additionally, the CIO and/or CISO presents to the Board bi-annually regarding the cybersecurity risks and strategies, including as part of the Board’s annual long-term strategy session. The Audit Committee, comprised of independent directors, reviews the implementation and effectiveness of cybersecurity risk management protocols and reviews the effectiveness of cybersecurity as part of the Company’s accounting and internal control policies. As part of this oversight, the CIO presents to the Audit Committee bi-annually, as well as periodically in conjunction with any internal audits related to cybersecurity. Additionally, management has protocols by which cybersecurity incidents that meet established reporting thresholds are escalated internally and, where appropriate, are reported to the Board, as well as ongoing updates regarding any such incident until it has been addressed. Williams’ new CIO joined the company in February 2025, and will succeed the company’s retiring CIO, who is retiring in March 2025. The new CIO brings over 20 years of experience in information technology and leadership within the energy industry and has extensive expertise in digital transformation, cloud strategies, enterprise AI initiatives, and cybersecurity, as well as managing large-scale system implementations and integrations. He holds an Executive MBA from the University of Texas at San Antonio, a Master of Computer Science and Engineering from the University of Texas at Arlington, and a Bachelor of Information Science and Engineering from Bangalore University. The retiring CIO had been in his role at Williams for over 10 years and had over 30 years of combined information technology experience with a broad scope of responsibility. He provided senior leadership support of the cybersecurity and risk management programs since 2013. He holds a bachelor’s degree in management information systems (MIS) from the University of Oklahoma and a Master of Business Administration in MIS from the University of Dallas.
Cybersecurity Risk Management Processes Integrated [Flag]	true
Cybersecurity Risk Management Processes Integrated [Text Block]	Integration with Overall Risk Management :
Cybersecurity Risk Management Third Party Engaged [Flag]	true
Cybersecurity Risk Third Party Oversight and Identification Processes [Flag]	true
Cybersecurity Risk Materially Affected or Reasonably Likely to Materially Affect Registrant [Flag]	false
Cybersecurity Risk Materially Affected or Reasonably Likely to Materially Affect Registrant [Text Block]	Disclosure of Risks : Management describes how risks from cybersecurity threats could materially affect its business strategy, results of operations, or financial condition, as part of its risk factor disclosures at Part I, Item 1A of this Annual Report on Form 10-K. Management is committed to continually enhancing its cybersecurity processes and practices to address the dynamic nature of the threats it faces and to ensure the security and integrity of its systems and data.
Cybersecurity Risk Board of Directors Oversight [Text Block]	Cybersecurity Governance Cybersecurity is an important part of the risk management processes and an area of focus for the Board of Directors and management. Each member of Williams’ organization, which includes Transco and NWP, from facility operators to board members, has a responsibility to safeguard the organization’s cybersecurity. The Chief Information Security Officer (CISO) is responsible for the cybersecurity strategy and execution, while the Board and the Audit Committee are responsible for oversight of cybersecurity risk. The Cybersecurity Governance Committee is led by the CISO and includes cybersecurity managers and other subject matter experts as standing members. The Cybersecurity Governance Committee is tasked with developing, implementing, and maintaining the Cybersecurity Program. The Cybersecurity Executive Advisory Board (Executive Advisory Board) is led by the CISO, with the Chief Information Officer (CIO), Chief Financial Officer, Chief Human Resources Officer, the General Counsel, and the Chief Operations Officer as standing members. The Executive Advisory Board’s purpose is to ensure enterprise alignment with the Cybersecurity Program and provide executive oversight of the Cybersecurity Program. The Board of Directors oversees cybersecurity-related policy and strategy. As part of this oversight, the CISO provides a cybersecurity dashboard that is reviewed by the Board at every regularly scheduled Board meeting, which includes key performance indicators for cybersecurity process maturity, operational performance, and enterprise performance toward Transportation Security Administration (TSA) compliance. Additionally, the CIO and/or CISO presents to the Board bi-annually regarding the cybersecurity risks and strategies, including as part of the Board’s annual long-term strategy session. The Audit Committee, comprised of independent directors, reviews the implementation and effectiveness of cybersecurity risk management protocols and reviews the effectiveness of cybersecurity as part of the Company’s accounting and internal control policies. As part of this oversight, the CIO presents to the Audit Committee bi-annually, as well as periodically in conjunction with any internal audits related to cybersecurity. Additionally, management has protocols by which cybersecurity incidents that meet established reporting thresholds are escalated internally and, where appropriate, are reported to the Board, as well as ongoing updates regarding any such incident until it has been addressed. Williams’ new CIO joined the company in February 2025, and will succeed the company’s retiring CIO, who is retiring in March 2025. The new CIO brings over 20 years of experience in information technology and leadership within the energy industry and has extensive expertise in digital transformation, cloud strategies, enterprise AI initiatives, and cybersecurity, as well as managing large-scale system implementations and integrations. He holds an Executive MBA from the University of Texas at San Antonio, a Master of Computer Science and Engineering from the University of Texas at Arlington, and a Bachelor of Information Science and Engineering from Bangalore University. The retiring CIO had been in his role at Williams for over 10 years and had over 30 years of combined information technology experience with a broad scope of responsibility. He provided senior leadership support of the cybersecurity and risk management programs since 2013. He holds a bachelor’s degree in management information systems (MIS) from the University of Oklahoma and a Master of Business Administration in MIS from the University of Dallas.
Cybersecurity Risk Board Committee or Subcommittee Responsible for Oversight [Text Block]	The Cybersecurity Governance Committee is led by the CISO and includes cybersecurity managers and other subject matter experts as standing members. The Cybersecurity Governance Committee is tasked with developing, implementing, and maintaining the Cybersecurity Program. The Cybersecurity Executive Advisory Board (Executive Advisory Board) is led by the CISO, with the Chief Information Officer (CIO), Chief Financial Officer, Chief Human Resources Officer, the General Counsel, and the Chief Operations Officer as standing members. The Executive Advisory Board’s purpose is to ensure enterprise alignment with the Cybersecurity Program and provide executive oversight of the Cybersecurity Program.
Cybersecurity Risk Process for Informing Board Committee or Subcommittee Responsible for Oversight [Text Block]	The Board of Directors oversees cybersecurity-related policy and strategy. As part of this oversight, the CISO provides a cybersecurity dashboard that is reviewed by the Board at every regularly scheduled Board meeting, which includes key performance indicators for cybersecurity process maturity, operational performance, and enterprise performance toward Transportation Security Administration (TSA) compliance. Additionally, the CIO and/or CISO presents to the Board bi-annually regarding the cybersecurity risks and strategies, including as part of the Board’s annual long-term strategy session. The Audit Committee, comprised of independent directors, reviews the implementation and effectiveness of cybersecurity risk management protocols and reviews the effectiveness of cybersecurity as part of the Company’s accounting and internal control policies. As part of this oversight, the CIO presents to the Audit Committee bi-annually, as well as periodically in conjunction with any internal audits related to cybersecurity. Additionally, management has protocols by which cybersecurity incidents that meet established reporting thresholds are escalated internally and, where appropriate, are reported to the Board, as well as ongoing updates regarding any such incident until it has been addressed.
Cybersecurity Risk Role of Management [Text Block]	Cybersecurity is an important part of the risk management processes and an area of focus for the Board of Directors and management. Each member of Williams’ organization, which includes Transco and NWP, from facility operators to board members, has a responsibility to safeguard the organization’s cybersecurity. The Chief Information Security Officer (CISO) is responsible for the cybersecurity strategy and execution, while the Board and the Audit Committee are responsible for oversight of cybersecurity risk.
Cybersecurity Risk Management Positions or Committees Responsible [Flag]	true
Cybersecurity Risk Management Positions or Committees Responsible [Text Block]	The Chief Information Security Officer (CISO) is responsible for the cybersecurity strategy and execution, while the Board and the Audit Committee are responsible for oversight of cybersecurity risk. The Cybersecurity Governance Committee is led by the CISO and includes cybersecurity managers and other subject matter experts as standing members. The Cybersecurity Governance Committee is tasked with developing, implementing, and maintaining the Cybersecurity Program. The Cybersecurity Executive Advisory Board (Executive Advisory Board) is led by the CISO, with the Chief Information Officer (CIO), Chief Financial Officer, Chief Human Resources Officer, the General Counsel, and the Chief Operations Officer as standing members. The Executive Advisory Board’s purpose is to ensure enterprise alignment with the Cybersecurity Program and provide executive oversight of the Cybersecurity Program.
Cybersecurity Risk Management Expertise of Management Responsible [Text Block]	Williams’ new CIO joined the company in February 2025, and will succeed the company’s retiring CIO, who is retiring in March 2025. The new CIO brings over 20 years of experience in information technology and leadership within the energy industry and has extensive expertise in digital transformation, cloud strategies, enterprise AI initiatives, and cybersecurity, as well as managing large-scale system implementations and integrations. He holds an Executive MBA from the University of Texas at San Antonio, a Master of Computer Science and Engineering from the University of Texas at Arlington, and a Bachelor of Information Science and Engineering from Bangalore University. The retiring CIO had been in his role at Williams for over 10 years and had over 30 years of combined information technology experience with a broad scope of responsibility. He provided senior leadership support of the cybersecurity and risk management programs since 2013. He holds a bachelor’s degree in management information systems (MIS) from the University of Oklahoma and a Master of Business Administration in MIS from the University of Dallas.
Cybersecurity Risk Process for Informing Management or Committees Responsible [Text Block]	The Board of Directors oversees cybersecurity-related policy and strategy. As part of this oversight, the CISO provides a cybersecurity dashboard that is reviewed by the Board at every regularly scheduled Board meeting, which includes key performance indicators for cybersecurity process maturity, operational performance, and enterprise performance toward Transportation Security Administration (TSA) compliance. Additionally, the CIO and/or CISO presents to the Board bi-annually regarding the cybersecurity risks and strategies, including as part of the Board’s annual long-term strategy session. The Audit Committee, comprised of independent directors, reviews the implementation and effectiveness of cybersecurity risk management protocols and reviews the effectiveness of cybersecurity as part of the Company’s accounting and internal control policies. As part of this oversight, the CIO presents to the Audit Committee bi-annually, as well as periodically in conjunction with any internal audits related to cybersecurity. Additionally, management has protocols by which cybersecurity incidents that meet established reporting thresholds are escalated internally and, where appropriate, are reported to the Board, as well as ongoing updates regarding any such incident until it has been addressed.
Cybersecurity Risk Management Positions or Committees Responsible Report to Board [Flag]	true

General, Description of Busin_2

General, Description of Business, Basis of Presentation, and Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2024
Accounting Policies [Abstract]
Principles of consolidation [Policy Text Block]	Principles of Consolidation Williams’ consolidated financial statements include the accounts of all entities that Williams controls and its proportionate interest in the accounts of certain ventures in which it owns an undivided interest. Management’s judgment is required to evaluate whether it controls an entity. Key areas of that evaluation include: • Determining whether an entity is a VIE (see Note 2 – Variable Interest Entities); • Determining whether Williams is the primary beneficiary of a VIE, including evaluating which activities of a VIE most significantly impact its economic performance and the degree of power that Williams and its related parties have over those activities through its variable interests; • Identifying events that require reconsideration of whether an entity is a VIE and continuously evaluating whether Williams is a VIE’s primary beneficiary; • Evaluating whether other owners in entities that are not VIEs are able to effectively participate in significant decisions that would be expected to be made in the ordinary course of business such that Williams does not have the power to control such entities. Williams applies the equity method of accounting to investments over which it exercises significant influence but does not control. Distributions received from equity-method investees are presented in the Consolidated Statement of Cash Flows according to the nature of the distributions approach, which classifies distributions received from equity-method investees as either returns on investment (cash inflows from operating activities) or returns of investment (cash inflows from investing activities) based on the nature of the activities of the equity-method investee that generated the distribution.
Use of estimates [Policy Text Block]	Use of Estimates 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 the financial statements and accompanying combined notes. Actual results could differ from those estimates. Significant estimates and assumptions may include: • Impairment assessments of investments, property, plant, and equipment, and intangible assets; • Litigation-related contingencies; • Environmental remediation obligations; • Depreciation and amortization of long-lived assets, which are comprised of property, plant, and equipment, and intangible assets; • Depreciation and/or amortization of equity-method investment basis differences; • Asset retirement obligations (AROs); • Measurement of fair value of commodity derivatives; • Pension and postretirement valuation variables; • Measurement of regulatory assets and liabilities; • Measurement of deferred income tax assets and liabilities, including assumptions related to the realization of deferred income tax assets; • Revenue recognition, including estimates utilized in recognition of deferred revenue; • Purchase price accounting. These estimates are discussed further throughout these combined notes.
Regulatory accounting [Policy Text Block]	Regulatory Accounting Transco, NWP, and MountainWest are regulated by the Federal Energy Regulatory Commission (FERC), and these regulated entities’ rates may also be negotiated with customers pursuant to the terms of tariffs and FERC policy. Therefore, management has determined that it is appropriate under Accounting Standards Codification (ASC) Topic 980, “Regulated Operations,” (ASC 980) that certain costs that would otherwise be charged to expense should be deferred as regulatory assets, based on the expected recovery from customers in future rates. Likewise, certain actual or anticipated credits that would otherwise reduce expense should be deferred as regulatory liabilities, based on the expected return to customers in future rates. Management’s expected recovery of deferred costs and return of deferred credits generally results from specific decisions by regulators granting such ratemaking treatment. Certain incurred costs and obligations are recorded as regulatory assets or liabilities if, based on regulatory orders or other available evidence, it is probable that the costs or obligations will be included in amounts allowable for recovery or refunded in future rates. Accounting for these operations that are regulated can differ from the accounting requirements for nonregulated operations. For example, for regulated operations, allowance for funds used during construction (AFUDC) represents the estimated cost of debt and equity funds applicable to utility plant in the process of construction and is capitalized as a cost of property, plant, and equipment because it constitutes an actual cost of construction under established regulatory practices; nonregulated operations are only allowed to capitalize the cost of debt funds related to construction activities, while a component for equity is prohibited. Management has determined that for its regulated entities, it is appropriate to apply the accounting prescribed by ASC 980 and, accordingly, the accompanying financial statements include the effects of the types of transactions described above that result from regulatory accounting requirements (see Note 10 – Regulatory Assets and Liabilities). The FERC has prescribed a formula to be used in computing separate allowances for borrowed and equity AFUDC. These allowances are recorded as follows: Transco Year Ended December 31, 2024 2023 2022 (Millions) Allowance for borrowed funds used during construction $ 17 $ 14 $ 5 Allowance for equity funds used during construction 71 63 23 Allowance for equity and borrowed funds used during construction (AFUDC) $ 88 $ 77 $ 28 NWP Year Ended December 31, 2024 2023 2022 (Millions) Allowance for borrowed funds used during construction $ 2 $ 1 $ 1 Allowance for equity funds used during construction 8 3 2 Allowance for equity and borrowed funds used during construction (AFUDC) $ 10 $ 4 $ 3
Revenue recognition [Policy Text Block]	Revenue Recognition Customers in Williams’ gas pipeline businesses, including Transco and NWP, are comprised of public utilities, municipalities, gas marketers and producers, intrastate pipelines, direct industrial users, and electrical power generators. Customers in Williams’ midstream businesses are comprised of oil and natural gas producer counterparties. Customers for Williams’ product sales are comprised of public utilities, gas marketers, and direct industrial users. Service revenue contracts from Williams’ gas pipeline and midstream businesses, including Transco and NWP, contain a series of distinct services, with the majority of the contracts having a single performance obligation that is satisfied over time as the customer simultaneously receives and consumes the benefits provided. Most of the product sales contracts have a single performance obligation with revenue recognized at a point in time when the products have been sold and delivered to the customer. Certain customers reimburse Williams for costs it incurs associated with construction of property, plant, and equipment utilized in its operations. For Williams’ rate-regulated gas pipeline businesses, including Transco and NWP, that apply ASC 980, Williams follows FERC guidelines with respect to reimbursement of construction costs. FERC tariffs only allow for cost reimbursement and are non-negotiable in nature; thus, in management’s judgment, the construction activities do not represent an ongoing major and central operation of the gas pipeline businesses and are not within the scope of ASC Topic 606, “Revenue from Contracts with Customers”. Accordingly, cost reimbursements are treated as a reduction to the cost of the constructed asset. For the midstream businesses, reimbursement and service contracts with customers are viewed together as providing the same commercial objective, as Williams has the ability to negotiate the mix of consideration between reimbursements and amounts billed over time. Accordingly, Williams generally recognizes reimbursements of construction costs from customers on a gross basis as a contract liability separate from the associated costs included within property, plant, and equipment. The contract liability is recognized into service revenues as the underlying performance obligations are satisfied. Service Revenues Gas pipeline businesses Revenues from the regulated interstate natural gas pipeline businesses, including Transco and NWP, which are subject to regulation by certain state and federal authorities, including the FERC, include both firm and interruptible transportation and storage contracts. Firm transportation and storage agreements provide for a daily or monthly reservation charge based on the pipeline or storage capacity reserved, and a commodity charge based on the volume of natural gas delivered/stored, each at rates specified in the FERC tariffs or based on negotiated contractual rates, with contract terms that are generally long-term in nature. Most of the long-term contracts contain an evergreen provision, which allows the contracts to be extended for periods primarily up to one year in length an indefinite number of times following the specified contract term and until terminated generally by either party. Interruptible transportation and storage agreements provide for a volumetric charge based on actual commodity transportation or storage utilized in the period in which those services are provided, and the contracts are generally limited to one-month periods or less. The related performance obligations include the following: • Firm transportation or storage under firm transportation and storage contracts—an integrated package of services typically constituting a single performance obligation, which includes standing ready to provide such services and receiving, transporting or storing (as applicable), and redelivering commodities; • Interruptible transportation or storage under interruptible transportation and storage contracts—an integrated package of services typically constituting a single performance obligation once scheduled, which includes receiving, transporting or storing (as applicable), and redelivering commodities. In situations where, in management’s judgment, it considers the integrated package of services as a single performance obligation, which represents a majority of its interstate natural gas pipeline contracts with customers, management does not consider there to be multiple performance obligations because the nature of the overall promise in the contract is to stand ready (with regard to firm transportation and storage contracts), receive, transport or store, and redeliver natural gas to the customer; therefore, revenue is recognized over time upon satisfaction of the daily stand ready performance obligation. Revenues are recognized for reservation charges over the performance obligation period, which is the contract term, regardless of the volume of natural gas that is transported or stored. Revenues for commodity charges from both firm and interruptible transportation services and storage services are recognized when natural gas is delivered at the agreed upon delivery point or when natural gas is injected or withdrawn from the storage facility because they specifically relate to efforts to provide these distinct services. Generally, reservation charges and commodity charges in the interstate natural gas pipeline businesses are recognized as revenue in the same period they are invoiced to its customers. As a result of the ratemaking process, certain amounts collected may be subject to refund upon the issuance of final orders by the FERC in pending rate proceedings. Management uses judgment to record estimates of rate refund liabilities considering its and other third-party regulatory proceedings, advice of counsel, and other risks. As of December 31, 2024 and 2023, there were no such rate refund liabilities for Transco and NWP. Midstream businesses Revenues from the nonregulated gathering, processing, transportation, and storage midstream businesses include contracts for natural gas gathering, processing, treating, compression, transportation, and other related services with contract terms that are generally long-term in nature and may extend up to the production life of the associated reservoir. Additionally, the midstream businesses generate revenues from fees charged for storing customers’ natural gas and NGLs, generally under prepaid contracted storage capacity contracts. In situations where, in management’s judgment, it provides an integrated package of services combined into a single performance obligation, which represents a majority of this class of contracts with customers, Williams does not consider there to be multiple performance obligations because the nature of the overall promise in the contract is to provide gathering, processing, transportation, storage, and related services resulting in the delivery, or redelivery in the context of storage services, of pipeline-quality natural gas and NGLs to the customer. As such, revenue is recognized at the daily completion of the integrated package of services as the integrated package represents a single performance obligation. Additionally, certain contracts in the midstream businesses contain fixed or upfront payment terms that result in the deferral of revenues until such services have been performed or such capacity has been made available. Williams also earns revenues from offshore crude oil and natural gas gathering and transportation and offshore production handling. These services represent an integrated package of services and are considered a single distinct performance obligation for which Williams recognizes revenues as the services are provided to the customer. Williams generally earns a contractually stated fee per unit for the volume of product transported, gathered, processed, or stored. The rate is generally fixed; however, certain contracts contain variable rates that are subject to change based on commodity prices, levels of throughput, or an annual adjustment based on a formulaic cost-of-service calculation. In addition, Williams has contracts with contractually stated fees that decline over the contract term, such as declines based on the passage of time periods or achievement of cumulative throughput amounts. The excess of consideration received over revenue recognized results in the deferral of those amounts until future periods based on a units of production or straight-line methodology as these methods appropriately match the consumption of services provided to the customer. The units of production methodology requires the use of production estimates that are uncertain and the use of judgment when developing estimates of future production volumes, thus impacting the rate of revenue recognition. Production estimates are monitored as circumstances and events warrant. Certain of Williams’ gas gathering and processing agreements have minimum volume commitments (MVC). If a customer under such an agreement fails to meet its MVC for a specified period (thus not exercising all the contractual rights to gathering and processing services within the specified period, herein referred to as “breakage”), it is obligated to pay a contractually determined fee based upon the shortfall between the actual gathered or processed volumes and the MVC for the period contained in the contract. When Williams concludes, based on management’s judgment, it is probable that the customer will not exercise all or a portion of its remaining rights, Williams recognizes revenue associated with such breakage amount in proportion to the pattern of exercised rights within the respective MVC period. Under keep-whole and percent-of-liquids processing contracts, Williams receives commodity consideration in the form of NGLs and takes title to the NGLs at the tailgate of the plant. Williams recognizes such commodity consideration as service revenue based on the market value of the NGLs retained at the time the processing is provided. The current market value, as opposed to the market value at the contract inception date, is used due to a combination of factors, including the fact that the volume, mix, and market price of NGL consideration to be received is unknown at the time of contract execution and is not specified in Williams’ contracts with customers. Additionally, product sales revenue (discussed below) is recognized upon the sale of the NGLs to a third party based on the sales price at the time of sale. As a result, revenue is recognized in the Consolidated Statement of Income both at the time the processing service is provided in Service revenues – commodity consideration and at the time the NGLs retained as part of the processing service are sold in Product sales . The recognition of revenue related to commodity consideration has the impact of increasing the book value of NGL inventory, resulting in higher cost of goods sold at the time of sale. Product Sales In the course of providing transportation services to customers of the gas pipeline businesses, including Transco, and gathering and processing services to customers of the midstream businesses, different quantities of natural gas may be received from customers than the quantities delivered on behalf of those customers. The resulting imbalances are primarily settled monthly through the purchase or sale of natural gas with each customer under terms provided for in FERC tariffs or gathering and processing agreements, respectively. Revenue is recognized for Transco from the sale of natural gas upon settlement of imbalances (see Gas Imbalances below). In certain instances, Williams purchases NGLs, crude oil, and natural gas from its oil and natural gas producer customers which Williams remarkets. In addition, Williams retains NGLs as consideration in certain processing arrangements, as discussed above in the Service Revenues - Midstream businesses section. Williams also markets natural gas and NGLs from the production at its upstream properties. Williams recognizes revenue from the sale of these commodities when the products have been sold and delivered. Williams’ product sales contracts are primarily short-term contracts based on prevailing market rates at the time of the transaction. Williams purchases natural gas for storage when the current market price paid to buy and transport natural gas plus the cost to store and finance the natural gas is less than an estimated, forward market price that can be received in the future, resulting in positive net product sales. Commodity-based exchange-traded futures contracts and over-the-counter (OTC) contracts are used to sell natural gas at that future price to substantially protect the natural gas revenues that will ultimately be realized when the stored natural gas is sold. Additionally, Williams enters into transactions to secure transportation capacity between delivery points in order to serve its customers and various markets. The physical purchase, transportation, storage, and sale of natural gas associated with these natural gas purchases are accounted for on a weighted-average cost or accrual basis, as appropriate, unlike the fair value basis utilized for the commodity derivatives used to mitigate the natural gas price risk associated with the storage and transportation portfolio. Monthly demand charges are incurred for contracted storage and transportation capacity and payments associated with asset management agreements and these demand charges and payments are recognized in the Consolidated Statement of Income in the period they are incurred. As Williams is acting as an agent for its natural gas marketing customers and engages in energy trading activities, its natural gas marketing revenues are presented net of the related costs of those activities. Contract Assets Williams Contract assets in the Consolidated Balance Sheet primarily consist of revenue recognized under contracts containing MVC features whereby management has concluded it is probable there will be a short-fall payment at the end of the current MVC period, which typically follows the calendar year, and that a significant reversal of revenue recognized currently for the future MVC payment will not occur. As a result, Williams’ contract assets related to its future MVC payments are generally expected to be collected within the next 12 months and are included within Other current assets and deferred charges in the Consolidated Balance Sheet until such time as the MVC short-fall payments are invoiced to the customer. Transco and NWP Transco’s contract assets primarily result from the modification of an existing contract resulting in increased rates. NWP’s contract assets consist of discounts provided to customers in the beginning of the contract term that are recognized on a straight-line basis over the entire contract term resulting in revenue recognition occurring prior to actual billings. Current and noncurrent contract assets are included within Other current assets and deferred charges and Deferred charges and other, respectively, in the Balance Sheets. Contract Liabilities Williams Contract liabilities in the Consolidated Balance Sheet consist of advance payments primarily from midstream business customers which include construction reimbursements, prepayments, and other billings and transactions for which future services are to be provided under the contract. These amounts are deferred until recognized in revenue when the associated performance obligation has been satisfied, which is primarily based on a units of production methodology over the remaining contractual service periods, and are classified as current or noncurrent according to when such amounts are expected to be recognized. Current and noncurrent contract liabilities are included within Other current liabilities and Regulatory liabilities, deferred income, and other , respectively, in the Consolidated Balance Sheet. Contracts requiring advance payments and the recognition of contract liabilities are evaluated to determine whether the advance payments provide Williams with a significant financing benefit. This determination is based on the combined effect of the expected length of time between when Williams transfers the promised good or service to the customer, when the customer pays for those goods or services, and the prevailing interest rates. Williams has assessed its contracts for significant financing components and determined, in management’s judgment, that one group of contracts entered into in contemplation of one another for certain capital reimbursements contains a significant financing component. As a result, Williams recognizes noncash interest expense based on the effective interest method and revenue (noncash) is recognized when the underlying asset is placed into service utilizing a units of production or straight-line methodology over the life of the corresponding customer contract. Transco and NWP Transco’s contract liabilities consist of advance payments from customers, which include prepayments, and other billings for which future services are to be provided under the contract, and NWP’s contract liabilities consist of a fixed rate facility charge billed to customers with a declining rate structure in its tariffs. Transco assessed its contracts and determined none contain a significant financing component. These liabilities are classified as current or noncurrent according to when such amounts are expected to be recognized. Current and noncurrent contract liabilities are included within Other current liabilities and Deferred charges and other,
Derivative instruments and hedging activities [Policy Text Block]	Commodity Derivative Instruments and Hedging Activities Williams is exposed to commodity price risk and utilizes derivatives to manage a portion of its commodity price risk. These instruments consist primarily of swaps, futures, and forward contracts involving short- and long-term purchases and sales of energy commodities. Williams purchases natural gas for storage when the current market price paid to buy and transport natural gas plus the cost to store and finance the natural gas is less than an estimated, forward market price that can be received in the future. Additionally, Williams enters into transactions to secure transportation capacity between delivery points in order to serve its customers and various markets. Commodity-based exchange-traded futures contracts and OTC contracts are used to capture the price differential or spread between the locations served by the capacity in order to substantially protect the natural gas revenues that will ultimately be realized when the physical flow of natural gas between receipt and delivery points occurs. Some commodity derivative contracts require physical delivery as opposed to financial settlement, and this type of derivative is both common and prevalent within the natural gas marketing operations. These contracts generally meet the definition of derivatives and are typically not designated as hedges for accounting purposes. When a commodity derivative contract is settled physically, any cumulative unrealized gain or loss is reversed, and the contract price is recognized in the respective line item in the Consolidated Statement of Income representing the actual price of the underlying goods being delivered. As of December 31, 2024 and 2023, Williams is not applying hedge accounting to any commodity derivative instruments. Unrealized gains and losses from physically settled commodity derivative contracts for commodity sales transactions are recognized in Net gain (loss) from commodity derivatives in the Consolidated Statement of Income. Realized and unrealized gains and losses from non-designated commodity derivative contracts for commodity sales transactions that are financially settled are reported in Net gain (loss) from commodity derivatives in the Consolidated Statement of Income. Net gains and losses from derivatives for shrink gas purchases for processing plants are reported in Net processing commodity expenses in the Consolidated Statement of Income. Williams experiences significant earnings volatility from the fair value accounting required for the derivatives used to hedge a portion of the economic value of the underlying transportation and storage portfolio as well as upstream related production. However, the unrealized fair value measurement gains and losses are generally offset by valuation changes in the economic value of the underlying production or transportation and storage contracts, which is not recognized until the underlying transaction occurs. (See Note 17 – Commodity Derivatives.) Williams reports the fair value of derivatives, except those for which the normal purchases and normal sales exception has been elected, in Derivative assets; Regulatory assets, deferred charges, and other; Derivative liabilities ; or Regulatory liabilities, deferred income, and other in the Consolidated Balance Sheet. These amounts are presented on a net basis and reflect the netting of asset and liability positions permitted under the terms of master netting arrangements and cash held on deposit in margin accounts that Williams has received or remitted to collateralize certain derivative positions. Williams determines the current and noncurrent classification based on the timing of expected future cash flows of individual trades. The accounting for the changes in fair value of a commodity derivative can be summarized as follows: Derivative Treatment Accounting Method Normal purchases and normal sales exception Accrual accounting All other derivatives Mark-to-market accounting
Interest capitalized [Policy Text Block]	Interest Capitalized For its non-regulated companies, Williams capitalizes interest on its debt using the weighted-average interest rate on debt excluding debt issued by Transco, NWP, and MountainWest. This is included in Interest expense in Williams’ Consolidated Statement of Income. For Williams’ regulated interstate natural gas pipelines, including Transco, NWP, and MountainWest, interest is capitalized from its borrowed funds and from internally generated funds (equity AFUDC) (see Regulatory Accounting). The former is included in Interest expense and the latter is included in Other income (expense) – net below Operating income (loss) in Williams’ Consolidated Statement of Income and Allowance for equity and borrowed funds used during construction (AFUDC) in Transco and NWP’s Statement of Net Income (see Note 9 – Property, Plant, and Equipment).
Income taxes [Policy Text Block]	Income Taxes Williams includes the operations of its domestic corporate subsidiaries and income from its subsidiary partnershi ps, as well as income from Transco and NWP which are treated as pass-through entities for state and local income tax purposes, in its consolidated fed e ral income tax return and also files tax return s in various foreign and state jurisdictions as required . Deferred income taxes are computed using the liability method and are provided on all temporary differences between the financial basis and the tax basis of its assets and liabilities. Management’s judgment and income tax assumptions are used to determine the levels, if any, of v aluation allowances associated with deferred tax assets.
Earnings (loss) per common share [Policy Text Block]	Earnings (Loss) Per Common Share Williams’ Basic earnings (loss) per common share in the Consolidated Statement of Income is based on the sum of the weighted-average number of common shares outstanding and vested restricted stock units. Diluted earnings (loss) per common share in the Consolidated Statement of Income primarily includes any dilutive effect of nonvested restricted stock units and stock options. Diluted earnings (loss) per common share may also include any dilutive effect of Williams’ preferred stock. Diluted earnings (loss) per common share is calculated using the treasury-stock method.
Cash and cash equivalents [Policy Text Block]	Cash and Cash Equivalents Cash and cash equivalents in the Consolidated Balance Sheet consist of highly liquid investments with original maturities of three months or less when acquired.
Accounts receivable [Policy Text Block]	Accounts Receivable Accounts receivable are carried on a gross basis, with no discounting, less an allowance for doubtful accounts. Management estimates the allowance for doubtful accounts, considering current expected credit losses using a forward-looking “expected loss” model, the financial condition of its customers, and the age of past due accounts. The majority of trade receivable balances are due within 30 days. Management monitors the credit quality of its counterparties through review of collection trends, credit ratings, and other analyses, such as bankruptcy monitoring. Williams’ financial assets from its natural gas transmission business, natural gas storage business, gathering, processing and transportation business, marketing business, and upstream operations, as applicable, are segregated into separate pools for evaluation due to different counterparty risks inherent in each business, with Transco’s and NWP’s financial assets each evaluated as one pool. Changes in counterparty risk factors could lead to reassessment of the composition of financial assets as one pool, separate pools, or the need for additional pools. Management calculates its allowance for credit losses incorporating an aging method. In estimating its expected credit losses, management utilizes historical loss rates over many years, which for Williams includes periods of both high and low commodity prices. Transco’s and NWP’s expected credit loss estimates considered both internal and external forward-looking commodity price expectations, as well as counterparty credit ratings, and factors impacting near-term liquidity. Commodity prices could have a significant impact on a portion of Williams’ gathering and processing and upstream counterparties’ financial health and ability to satisfy current obligations. Williams’ expected credit loss estimate considers both internal and external forward-looking commodity price expectations, as well as counterparty credit ratings, and factors impacting near-term liquidity. In addition, Williams’ expected credit loss estimate considers potential contractual, physical, and commercial protections and outcomes in the case of a counterparty bankruptcy. The physical location and nature of Williams’ services help to mitigate collectability concerns of its gathering and processing producer customers. Williams’ gathering lines in many cases are physically connected to the customers’ wellheads and pads, and there may not be alternative gathering lines nearby. The construction of gathering systems is capital intensive and it would be costly for others to replicate, especially considering the depletion to date of the associated reserves. As a result, Williams plays a critical role in getting customers’ production from the wellhead to a marketable condition and location. This tends to reduce collectability risk as Williams’ services enable producers to generate operating cash flows. Commodity price movements generally do not impact the majority of Williams’ natural gas transmission businesses customers’ financial condition. Williams also provides marketing and risk management services to retail and wholesale gas marketers, utility companies, upstream producers, and industrial customers. These counterparties utilize netting agreements that enable Williams to net receivables and payables by counterparty upon settlement. Williams also nets across product lines and against cash collateral received to collateralize receivable positions, provided the netting and cash collateral agreements include such provisions. While the amounts due from, or owed to, Williams’ counterparties are settled net, these amounts are recorded on a gross basis in the Consolidated Balance Sheet as accounts receivable and accounts payable. Extended payment terms are not offered and payments are typically received within one month. Receivables are considered past due if full payment is not received by the contractual due date. Past due accounts are generally written off against the allowance for doubtful accounts only after all collection attempts have been exhausted. Neither Williams, Transco, nor NWP have a material amount of significantly aged receivables at December 31, 2024 or 2023.
Oil and Gas, Gas-Balancing Arrangement	Gas Imbalances Transco Transco transports gas on various pipeline systems which may deliver different quantities of gas on behalf of Transco than the quantities of gas received from Transco. These transactions result in gas transportation and exchange imbalance receivables and payables which are recovered or repaid in cash or through the receipt or delivery of gas in the future and are recorded in the accompanying Balance Sheet. Revenues received from the cash-out of transportation imbalances in excess of costs incurred are deferred and offset by the deferral of costs incurred in excess of revenues received. At the end of each annual August through July reporting period, if the cumulative revenues received exceed the costs incurred, the over recovered amounts are applied to any prior under recovery balance or refunded. If the cumulative revenues received are less than the costs incurred, the net under recovered amounts are carried forward and offset against any future net over recoveries that may occur in a subsequent annual reporting period. These deferred recoveries are recognized as Regulatory assets in Transco’s Balance Sheet (see Note 10 – Regulatory Assets and Liabilities). The settlement of imbalances requires agreement between the pipelines and shippers as to allocations of volumes to specific transportation contracts and timing of delivery of gas based on operational conditions. These imbalances are classified as Other current assets and deferred charges and Other current liabilities in Transco’s Balance Sheet (see Note 10 – Regulatory Assets and Liabilities). Transco utilizes the average cost method of accounting for gas imbalances. NWP In the course of providing transportation services to customers, NWP may receive different quantities of natural gas from customers than the quantities delivered on behalf of those customers or consumed in fuel to operate NWP’s system. The resulting customer imbalances are typically settled through the receipt or delivery of gas in the future based on the timelines outlined in NWP’s tariff, whereas the over/under recovery of fuel is cleared up through NWP’s semi-annual fuel tracker. Customer imbalances to be repaid or recovered in-kind are recorded as Other current assets and deferred charges or Other current liabilities in NWP’s Balance Sheet. The under recovery of fuel is recorded as Regulatory assets and the over recovery is recorded in Regulatory liabilities in NWP’s Balance Sheet (see Note 10 – Regulatory Assets and Liabilities). These imbalances are valued at published spot rates.
Inventories [Policy Text Block]	Inventories Inventories in Williams’ Consolidated Balance Sheet primarily consist of NGLs, materials and supplies, and natural gas in underground storage and are primarily stated at the lower of cost or net realizable value. The cost of inventories are primarily determined using the average cost method. Inventories
Environmental Costs, Policy	Transco and NWP Transco and NWP are subject to federal, state, and local environmental laws and regulations. Environmental expenditures are expensed or capitalized depending on the economic benefit and potential for rate recovery. These entities believe that expenditures required to meet applicable environmental laws and regulations are prudently incurred in the ordinary course of business and such expenditures would be permitted to be recovered through rates with limited exceptions. In accordance with the Climate Commitment Act of the state of Washington, which established a market-based cap-and-invest program, NWP is required to obtain emission allowances for the carbon emissions from nine of NWP’s thirteen compressor stations within the state of Washington whose annual carbon emissions exceed 25,000 metric tons of carbon dioxide equivalent at least once since 2015. NWP records the purchased emission allowances at cost and the associated accumulated interest to a regulatory asset. The difference between the allowances held and the allowances required based on actual emissions for the period are measured using an estimate based on NWP’s most recent cost of allowances and accrued to a current liability and to a regulatory asset. NWP’s Petition for Approval of Pre-Filing Stipulation and Settlement Agreement (Settlement) in Docket No. RP22-1155, which FERC approved in 2022, allows NWP to recover the costs of purchasing allowances under the program in its next rate case (see Note 18 – Contingencies and Commitments).
Property, plant, and equipment [Policy Text Block]	Property, Plant, and Equipment Property, plant, and equipment is initially recorded at cost. The carrying value of these assets is based on estimates, assumptions, and judgments relative to capitalized costs, useful lives, and salvage values. For the Transco, NWP, and MountainWest interstate natural gas pipelines, these estimates, assumptions and judgments reflect FERC regulations, as well as historical experience and expectations regarding future industry conditions and operations. The FERC identifies installation, construction and replacement costs that are to be capitalized. All other costs are expensed as incurred. As regulated entities, Transco, NWP and MountainWest provide for depreciation primarily under the composite (group) method using straight-line FERC-prescribed rates. Under this method, assets with similar lives and characteristics are grouped and depreciated as one asset. These regulated entities’ depreciation rates are subject to change each time these regulated entities file a general rate case with the FERC. Included in Transco’s and NWP’s depreciation rates is a negative salvage component (net cost of removal) that Transco and NWP currently collect in rates that is recorded as a regulatory liability in the Balance Sheets (see Note 10 – Regulatory Assets and Liabilities). Depreciation for Williams’ nonregulated entities is provided primarily on the straight-line method over estimated useful lives. Williams follows the successful efforts method of accounting for its upstream properties. Its oil and gas producing property costs are depreciated using the units of production method. Gains or losses from the ordinary sale or retirement of property, plant, and equipment for the Transco, NWP, and MountainWest interstate natural gas pipelines are credited or charged to accumulated depreciation; certain other gains or losses are recorded in Other (income) expense – net included in Operating income (loss) in the statements of income. Gains or losses from the ordinary sale or retirement of property, plant, and equipment for Williams’ nonregulated assets are primarily recorded in Other (income) expense – net included in Operating income (loss) in the Consolidated Statement of Income. Ordinary maintenance and repair costs are generally expensed as incurred. Costs of major renewals and replacements are capitalized as property, plant, and equipment. Williams records a liability and increases the basis in the underlying asset for the present value of each expected future ARO at the time the liability is initially incurred, typically when the asset is acquired or constructed. For Williams’ upstream properties, the ARO is recorded based on Williams’ working interest in the underlying properties. As regulated entities, Transco’s and NWP’s depreciation expense and accretion expense are offset and recorded as a regulatory asset as the regulated entities expect to recover these accretion expenses in future rates and measure changes in the liability due to passage of time by applying an interest rate to the liability balance. This step is recognized as an increase in the carrying amount of the liability included in Operating and maintenance expenses and as a corresponding accretion expense included in Other (income) expense - net in the Consolidated Statement of Income. The regulatory asset is amortized commensurate with these regulated entities’ collection of those costs in rates. Measurements of AROs include, as a component of future expected costs, an estimate of the price that a third party would demand, and could expect to receive, for bearing the uncertainties inherent in the obligations, sometimes referred to as a market-risk premium.
Goodwill [Policy Text Block]	Goodwill Goodwill included within Intangible assets – net of accumulated amortization in Williams’ Consolidated Balance Sheet, as of December 31, 2024, represents the excess of the consideration, plus the fair value of any noncontrolling interest or any previously held equity interest, over the fair value of the net assets acquired. It is not subject to amortization but is evaluated annually as of October 1 for impairment or more frequently if impairment indicators are present that would indicate it is more likely than not that the fair value of the reporting unit is less than its carrying amount. Management first performs a qualitative assessment to test goodwill on a reporting unit by reporting unit basis to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount, management compares its estimate of fair value of the reporting unit to its carrying amount, including goodwill. Judgments and assumptions are inherent in management’s estimates of fair value.
Intangible assets [Policy Text Block]	Other Identifiable Intangible Assets Williams’ other identifiable intangible assets included within Intangible assets – net of accumulated amortization in the Consolidated Balance Sheet are primarily related to gas gathering, processing, and fractionation customer relationships. Williams’ other identifiable intangible assets are generally amortized on a straight-line basis over the period in which these assets contribute to its cash flows. Williams evaluates these assets for changes in the expected remaining useful lives and reflects any changes prospectively through amortization over the revised remaining useful life.
Impairment of property, plant, and equipment, intangible assets, and investments [Policy Text Block]	Impairment of Property, Plant, and Equipment, Intangible Assets, and Investments Management evaluates property, plant, and equipment and intangible assets for impairment when, in its judgment, events or circumstances, including probable abandonment, indicate that the carrying value of such assets may not be recoverable. When an indicator of impairment has occurred, management compares its estimate of undiscounted future cash flows attributable to the assets to the carrying value of the assets to determine whether an impairment has occurred and may apply a probability-weighted approach to consider the likelihood of different cash flow assumptions and possible outcomes, including selling the assets in the near term or holding them for the asset’s remaining estimated useful life. If an impairment of the carrying value has occurred, management determines the amount of the impairment to be recognized in the financial statements by estimating the fair value of the assets and recording a loss for the amount that the carrying value exceeds the estimated fair value. This evaluation is performed at the lowest level for which separately identifiable cash flows exist. For assets identified to be disposed of in the future and considered held for sale, management compares the carrying value to the estimated fair value less the cost to sell to determine if recognition of an impairment is required. Until the assets are disposed of, the estimated fair value, which includes estimated cash flows from operations until the assumed date of sale, is recalculated when related events or circumstances change. Williams’ investments are evaluated for impairment when, in management’s judgment, events or circumstances indicate that the carrying value of such investments may have experienced an other-than-temporary decline in value. When evidence of loss in value has occurred, management compares its estimate of fair value of the investment to the carrying value of the investment to determine whether an impairment has occurred. If the estimated fair value is less than the carrying value and management considers the decline in value to be other-than-temporary, the excess of the carrying value over the fair value is recognized in the financial statements as an impairment charge. Judgment and assumptions are inherent in the estimate of undiscounted future cash flows and an asset’s or investment’s fair value. Additionally, judgment is used to determine the probability of sale with respect to assets considered for disposal.
Equity-method investment basis differences [Policy Text Block]	Equity-Method Investment Basis Differences Differences between the carrying value of Williams’ equity-method investments and the underlying equity in the net assets of investees are accounted for as if the investees were consolidated subsidiaries. Equity earnings (losses)
Leases [Policy Text Block]	Leases Williams, Transco, and NWP recognize operating lease liabilities based on the present value of the future lease payments and have elected to combine lease and nonlease components for all classes of leased assets in the calculation of the lease liability and the offsetting right-of-use asset in the respective Balance Sheets. Williams’, Transco’s, and NWP’s lease agreements require both fixed and variable periodic payments, with initial terms typically ranging from one year to 20 years for Williams and up to 30 years for Transco and NWP. Payment provisions in certain lease agreements contain escalation factors which may be based on stated rates or a change in a published index at a future time. The amount by which a lease escalates based on the change in a published index, which is not known at lease commencement, is considered a variable payment and is not included in the present value of the future lease payments, which only includes those that are stated or can be calculated based on the lease agreement at lease commencement. In addition to the noncancellable periods, many of Williams’ lease agreements provide for one or more extensions of the lease agreement for periods ranging from one year in length to an indefinite number of times following the specified contract term. Other lease agreements provide for extension terms that allow Williams, Transco, and NWP to utilize the identified leased asset for an indefinite period of time so long as the asset continues to be utilized in its operations. In consideration of these renewal features, management assesses the term of the lease agreements, which includes using judgment in the determination of which renewal periods and termination provisions, when at its sole election, will be reasonably certain of being exercised. Periods after the initial term or extension terms that allow for either party to the lease to cancel the lease are not considered in the assessment of the lease term. Additionally, management has elected to exclude leases with an original term of one year or less, including renewal periods, from the calculation of the lease liability and the offsetting right-of-use asset. Judgment is used in determining the discount rate upon which the present value of the future lease payments is determined. This rate is based on a collateralized interest rate corresponding to the term of the lease agreement using company, industry, and market information available. When permitted under its lease agreements, Williams may sublease certain unused office space for fixed periods that could extend up to the length of the original lease agreement.
Pension and other postretirement benefits [Policy Text Block]	Pension and Other Postretirement Benefits The funded status of each of the pension and other postretirement benefit plans is recognized separately in Williams’ Consolidated Balance Sheet as either an asset or liability. The plans’ benefit obligations and net periodic benefit costs (credits) are actuarially determined and impacted by various assumptions and estimates. The discount rates are determined separately for each of Williams’ pension and other postretirement benefit plans based on an approach specific to Williams’ plans. The year-end discount rates are determined considering a yield curve comprised of high-quality corporate bonds and the timing of the expected benefit cash flows of each plan. The expected long-term rates of return on plan assets are determined by combining a review of the historical returns within the portfolio, the investment strategy included in the plans’ investment policy statement, and capital market projections for the asset classes in which the portfolio is invested, as well as the weighting of each asset class. Unrecognized actuarial gains and losses are deferred and recorded in AOCI or, for Transco and NWP, as a regulatory asset or liability, until amortized as a component of net periodic benefit cost (credit). The unrecognized net actuarial gains (losses) deferred in AOCI at December 31, 2024 and 2023 were $55 million and ($17) million, respectively. Unrecognized actuarial gains and losses in excess of 10 percent of the greater of the benefit obligation or the market-related value of plan assets are amortized over the participants’ average remaining future years of service, which is approximately 9 years for Williams’ pension plans and approximately 4 years for Williams’ other postretirement benefit plan. The expected return on plan assets component of net periodic benefit cost (credit) is calculated using the market-related value of plan assets. For Williams’ pension plans, the market-related value of plan assets is equal to the fair value of plan assets adjusted to reflect the amortization of gains or losses associated with the difference between the expected and actual return on plan assets over a 5-year period. Additionally, the market-related value of assets may be no more than 110 percent or less than 90 percent of the fair value of plan assets at the beginning of the year. The market-related value of plan assets for Williams’ other postretirement benefit plan is equal to the unadjusted fair value of plan assets at the beginning of the year.
Contingent liabilities [Policy Text Block]	Contingent Liabilities Liabilities for loss contingencies, including environmental matters, are recorded when management assesses that a loss is probable and the amount of the loss can be reasonably estimated. These liabilities are calculated based upon management’s assumptions and estimates with respect to the likelihood or amount of loss and upon advice of legal counsel, engineers, or other third parties regarding the probable outcomes of the matters. These calculations are made without consideration of any potential recovery from third parties. Insurance recoveries or reimbursements from others are recognized when realizable. Revisions to these liabilities are generally reflected in income when new or different facts or information become known or circumstances change that affect the previous assumptions or estimates.
Treasury stock [Policy Text Block]	Treasury Stock Treasury stock purchases are accounted for under the cost method whereby the entire cost of the acquired stock is recorded as Treasury stock, at cost in Williams’ Consolidated Balance Sheet. Gains and losses on the subsequent reissuance of shares are credited or charged to Capital in excess of par value in the Consolidated Balance Sheet using the average cost method.
Cash Flows From Operating Activities	Cash Flows from Operating Activities Williams, Transco, and NWP use the indirect method to report cash flows from operating activities, which requires adjustments to net income to reconcile to net cash flows provided by operating activities.
Cash flows from revolving credit facility and commercial paper program [Policy Text Block]	Cash Flows from Revolving Credit Facility and Commercial Paper Program Proceeds and payments related to borrowings under Williams’ revolving credit facility are reflected in the financing activities in the Consolidated Statement of Cash Flows on a gross basis. Proceeds and payments related to borrowings under Williams’ commercial paper program are reflected in the financing activities in the Consolidated Statement of Cash Flows on a net basis, as the outstanding notes generally have maturity dates less than three months from the date of issuance. (See Note 13 – Debt and Banking Arrangements.)
New Accounting Pronouncements, Policy	Accounting Standards Issued But Not Yet Adopted In December 2023, the Financial Accounting Standards Board (FASB) issued Accounting Standard Update (ASU) 2023-09, Income Taxes: Improvements to Income Tax Disclosures , which requires disclosure of specific categories in the rate reconciliation and additional information for reconciling items that meet a quantitative threshold. This ASU is effective for fiscal years beginning after December 15, 2024, and early adoption is permitted. The adoption of ASU 2023-09 is not expected to have a material impact on the financial statements. In November 2024, the FASB issued ASU 2024-03, Income Statement - Reporting Comprehensive Income - Expense Disaggregation Disclosures , which requires public entities to disclose additional information in the notes to financial statements for certain types of expenses (including purchases of inventory, employee compensation, depreciation, amortization, and depletion) in commonly presented expense captions (such as cost of sales, selling, general & administrative expenses, and research and development). The amendments are effective for annual periods beginning after December 15, 2026, and interim periods within fiscal years beginning after December 15, 2027 with early adoption permitted. The impact of this standard is currently being evaluated.

General, Description of Busin_3

General, Description of Business, Basis of Presentation, and Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2024
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Public Utilities General Disclosures	The FERC has prescribed a formula to be used in computing separate allowances for borrowed and equity AFUDC. These allowances are recorded as follows: Transco Year Ended December 31, 2024 2023 2022 (Millions) Allowance for borrowed funds used during construction $ 17 $ 14 $ 5 Allowance for equity funds used during construction 71 63 23 Allowance for equity and borrowed funds used during construction (AFUDC) $ 88 $ 77 $ 28 NWP Year Ended December 31, 2024 2023 2022 (Millions) Allowance for borrowed funds used during construction $ 2 $ 1 $ 1 Allowance for equity funds used during construction 8 3 2 Allowance for equity and borrowed funds used during construction (AFUDC) $ 10 $ 4 $ 3

Variable Interest Entities (Tab

Variable Interest Entities (Tables)	12 Months Ended
	Dec. 31, 2024
Variable Interest Entity Disclosures [Abstract]
Schedule of Variable Interest Entities [Table Text Block]	The following table presents amounts included in the Consolidated Balance Sheet that are only for the use or obligation of the consolidated VIEs: December 31, 2024 2023 (Millions) Assets (liabilities): Cash and cash equivalents $ 15 $ 33 Trade accounts and other receivables – net 178 215 Inventories 5 5 Other current assets and deferred charges 7 4 Property, plant, and equipment – net 4,896 5,046 Intangible assets – net of accumulated amortization 1,940 2,049 Regulatory assets, deferred charges, and other 27 31 Accounts payable (57) (109) Other current liabilities (29) (28) Regulatory liabilities, deferred income, and other (263) (268)

Acquisitions and Divestitures (

Acquisitions and Divestitures (Tables)	12 Months Ended
	Dec. 31, 2024
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Information [Table Text Block]	The following pro forma Revenues and Net income (loss) attributable to The Williams Companies, Inc. for 2024, 2023, and 2022, are presented as if the Crowheart Acquisition, Discovery Acquisition, and Gulf Coast Storage Acquisition had been completed on January 1, 2023, the DJ Basin Acquisitions and 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 acquisitions had in fact occurred on the dates or for the periods indicated, nor do they purport to project Revenues or Net income (loss) attributable to The Williams Companies, Inc. for any future periods or as of any date. These amounts do not give effect to any potential cost savings, operating synergies, or revenue enhancements to result from the transactions or the potential costs to achieve these cost savings, operating synergies, and revenue enhancements. Year Ended December 31, 2024 As Reported Pro Forma Crowheart (1) Pro Forma Discovery (1) Pro Forma Combined (Millions) Revenues $ 10,503 $ 60 $ 58 $ 10,621 Net income (loss) attributable to The Williams Companies, Inc. 2,225 8 (5) 2,228 Year Ended December 31, 2023 As Reported Pro Forma Crowheart Pro Forma Discovery Pro Forma Gulf Coast Storage Pro Forma DJ Basin (1) Pro Forma MountainWest (1) Pro Forma Combined (Millions) Revenues $ 10,907 $ 74 $ 129 $ 202 $ 270 $ 35 $ 11,617 Net income (loss) attributable to The Williams Companies, Inc. 3,179 19 (1) 53 17 6 3,273 Year Ended December 31, 2022 As Reported Pro Forma DJ Basin Pro Forma MountainWest Pro Forma Trace (1) Pro Forma Combined (Millions) Revenues $ 10,965 $ 218 $ 265 $ 45 $ 11,493 Net income (loss) attributable to The Williams Companies, Inc. 2,049 13 170 18 2,250 (1) Excludes results from operations acquired in the acquisition for the period beginning on the acquisition date, as these results are included in the amounts as reported.
Crowheart Acquisition
Business Acquisition [Line Items]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	The following table presents the preliminary allocation of the acquisition date fair value of the major classes of the assets acquired and liabilities assumed at November 1, 2024. The allocation is considered preliminary because the valuation work has not been completed due to the ongoing review of the valuation results and validation of significant inputs and assumptions. Preliminary fair value measurements were made for certain acquired assets and liabilities, primarily property, plant, and equipment, which utilized the income approach for proved developed producing reserves and the market approach for undeveloped reserves; 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. (Millions) Cash and cash equivalents $ 94 Other current assets 15 Property, plant, and equipment – net 400 Other noncurrent assets 2 Total assets acquired 511 Current liabilities (45) Noncurrent liabilities (115) Total liabilities assumed (160) Net assets acquired $ 351
Discovery Acquisition
Business Acquisition [Line Items]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	The following table presents the preliminary allocation of the acquisition date fair value of the major classes of the assets acquired and liabilities assumed at August 1, 2024. The allocation is considered preliminary because the valuation work has not been completed due to the ongoing review of the valuation results and validation of significant inputs and assumptions. Preliminary fair value measurements were made for certain acquired assets and liabilities, primarily property, plant, and equipment, which utilized the cost approach; 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. (Millions) Cash and cash equivalents $ 22 Other current assets 19 Property, plant, and equipment – net 941 Other noncurrent assets 39 Total assets acquired 1,021 Current liabilities (40) Noncurrent liabilities (296) Total liabilities assumed (336) Net assets acquired $ 685
Gulf Coast Storage Acquisition
Business Acquisition [Line Items]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	The following table presents the allocation of the acquisition date fair value of the major classes of the assets acquired and liabilities assumed at January 3, 2024. (Millions) Cash and cash equivalents $ 46 Other current assets 18 Property, plant, and equipment – net 2,035 Other noncurrent assets 2 Total assets acquired 2,101 Current liabilities (11) Noncurrent liabilities (107) Total liabilities assumed (118) Net assets acquired $ 1,983
Cureton Acquisition
Business Acquisition [Line Items]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	The following table presents the allocation of the acquisition date fair value of the major classes of the assets acquired and liabilities assumed at November 30, 2023. (Millions) Cash and cash equivalents $ 6 Other current assets 21 Property, plant, and equipment – net 433 Intangible assets – net of accumulated amortization 117 Other noncurrent assets 1 Total identifiable assets acquired 578 Current liabilities (29) Noncurrent liabilities (14) Total liabilities assumed (43) Net identifiable assets acquired 535 Goodwill included in Intangible assets – net of accumulated amortization 11 Net assets acquired $ 546
RMM Acquisition
Business Acquisition [Line Items]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	The following table presents the allocation of the acquisition date fair value of the major classes of the assets acquired and liabilities assumed at November 30, 2023. The net assets acquired primarily reflect the noncash consideration transferred, which includes the fair value of both Williams’ previous equity-method investment and the deferred consideration obligation. (Millions) Cash and cash equivalents $ 28 Other current assets 4 Investments 20 Property, plant, and equipment – net 1,041 Intangible assets – net of accumulated amortization 63 Other noncurrent assets 12 Total identifiable assets acquired 1,168 Current liabilities (44) Noncurrent liabilities (103) Total liabilities assumed (147) Net identifiable assets acquired 1,021 Goodwill included in Intangible assets – net of accumulated amortization 55 Net assets acquired $ 1,076
MountainWest Acquisition
Business Acquisition [Line Items]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	The following table presents the allocation of the acquisition date fair value of the major classes of the assets acquired and liabilities assumed at February 14, 2023. The fair value of accounts receivable acquired equals contractual amounts receivable. (Millions) Cash and cash equivalents $ 23 Trade accounts and other receivables 33 Other current assets 26 Investments 20 Property, plant, and equipment – net 1,019 Other noncurrent assets 33 Total identifiable assets acquired 1,154 Current liabilities (47) Long-term debt (365) Other noncurrent liabilities (95) Total liabilities assumed (507) Net identifiable assets acquired 647 Goodwill included in Intangible assets – net of accumulated amortization 400 Net assets acquired $ 1,047
Trace Midstream Acquisition
Business Acquisition [Line Items]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	Williams 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 and liabilities assumed at April 29, 2022. The valuation techniques used consisted of the income approach for valuation of intangible assets and the cost approach 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) Other current liabilities (5) Other noncurrent liabilities (8) Total liabilities assumed (25) Net assets acquired $ 972

Revenue Recognition (Tables)

Revenue Recognition (Tables)	12 Months Ended
	Dec. 31, 2024
Revenue Recognition [Abstract]
Disaggregation of Revenue [Table Text Block]	The following table presents Williams’ revenue disaggregated by major service line: Transmission & Gulf of America Northeast G&P West Gas & NGL Marketing Services Other Eliminations Total (Millions) 2024 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 3,500 $ — $ — $ — $ — $ (81) $ 3,419 Gathering, processing, transportation, fractionation, and storage: Monetary consideration 661 1,778 1,693 — — (162) 3,970 Commodity consideration 54 2 78 — — — 134 Other 46 92 21 — — (19) 140 Total service revenues 4,261 1,872 1,792 — — (262) 7,663 Product sales 328 110 869 4,530 420 (1,288) 4,969 Total revenues from contracts with customers 4,589 1,982 2,661 4,530 420 (1,550) 12,632 Other revenues (1) 39 43 8 2,236 24 (2) 2,348 Other adjustments (2) — — — (4,977) — 500 (4,477) Total revenues $ 4,628 $ 2,025 $ 2,669 $ 1,789 $ 444 $ (1,052) $ 10,503 2023 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 3,334 $ — $ — $ — $ — $ (60) $ 3,274 Gathering, processing, transportation, fractionation, and storage: Monetary consideration 443 1,782 1,478 — — (170) 3,533 Commodity consideration 38 5 103 — — — 146 Other 30 87 12 1 — (15) 115 Total service revenues 3,845 1,874 1,593 1 — (245) 7,068 Product sales 252 132 441 4,615 442 (954) 4,928 Total revenues from contracts with customers 4,097 2,006 2,034 4,616 442 (1,199) 11,996 Other revenues (1) 53 27 101 4,294 64 (2) 4,537 Other adjustments (2) — — — (6,032) — 406 (5,626) Total revenues $ 4,150 $ 2,033 $ 2,135 $ 2,878 $ 506 $ (795) $ 10,907 Transmission & Gulf of America Northeast G&P West Gas & NGL Marketing Services Other Eliminations Total (Millions) 2022 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 3,139 $ — $ — $ — $ — $ (72) $ 3,067 Gathering, processing, transportation, fractionation, and storage: Monetary consideration 381 1,526 1,518 — — (167) 3,258 Commodity consideration 64 14 182 — — — 260 Other 21 102 12 3 — (16) 122 Total service revenues 3,605 1,642 1,712 3 — (255) 6,707 Product sales 404 134 841 10,768 706 (1,787) 11,066 Total revenues from contracts with customers 4,009 1,776 2,553 10,771 706 (2,042) 17,773 Other revenues (1) 38 26 8 7,929 (55) (11) 7,935 Other adjustments (2) — — — (15,467) — 724 (14,743) Total revenues $ 4,047 $ 1,802 $ 2,561 $ 3,233 $ 651 $ (1,329) $ 10,965 ______________________________ (1) Revenues not derived from contracts with customers primarily consist of physical product sales related to commodity derivative contracts, realized and unrealized gains and losses associated with Williams’ commodity derivative contracts, which are reported in Net gain (loss) from commodity derivatives in the Consolidated Statement of Income, management fees received for certain services provided to operated equity-method investments, and leasing revenues associated with the Williams headquarters building. (2) Other adjustments reflect certain costs of Gas & NGL Marketing Services’ risk management activities. As Williams is acting as agent for natural gas marketing customers or engages in energy trading activities, the resulting revenues are presented net of the related costs of those activities in the Consolidated Statement of Income.
Contract with Customer, Asset and Liability [Table Text Block]	The following tables present a reconciliation of contract assets: Williams Year Ended December 31, 2024 2023 (Millions) Balance at beginning of year $ 36 $ 29 Revenue recognized in excess of amounts invoiced 170 183 Minimum volume commitments invoiced (144) (176) Contract assets acquired 36 — Balance at end of year $ 98 $ 36 Transco Year Ended December 31, 2024 2023 (Millions) Balance at beginning of year $ — $ — Revenue recognized in excess of amounts invoiced 10 — Balance at end of year $ 10 $ — NWP Year Ended December 31, 2024 2023 (Millions) Balance at beginning of year $ 17 $ 13 Revenue recognized in excess of amounts invoiced 6 6 Amortization of contract assets (2) (2) Balance at end of year $ 21 $ 17 Contract Liabilities The following tables present a reconciliation of contract liabilities: Williams Year Ended December 31, 2024 2023 (Millions) Balance at beginning of year $ 1,081 $ 1,043 Payments received and deferred 183 190 Significant financing component 8 9 Contract liability acquired (disposed) – net 53 115 Recognized in revenue (279) (276) Balance at end of year $ 1,046 $ 1,081 Transco Year Ended December 31, 2024 2023 (Millions) Balance at beginning of year $ 184 $ 194 Recognized in revenue (11) (10) Balance at end of year $ 173 $ 184 NWP Year Ended December 31, 2024 2023 (Millions) Balance at beginning of year $ 2 $ 3 Recognized in revenue (2) (1) Balance at end of year $ — $ 2
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Table Text Block]	The following tables present 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 December 31, 2024. Williams Contract Liabilities Remaining Performance Obligations (Millions) 2025 (one year) $ 173 $ 4,132 2026 (one year) 146 3,860 2027 (one year) 141 3,623 2028 (one year) 118 2,778 2029 (one year) 100 2,564 Thereafter 368 14,102 Total $ 1,046 $ 31,059 Transco Contract Liabilities Remaining Performance Obligations (Millions) 2025 (one year) $ 10 $ 2,726 2026 (one year) 10 2,536 2027 (one year) 11 2,438 2028 (one year) 11 1,784 2029 (one year) 11 1,693 Thereafter 120 10,421 Total $ 173 $ 21,598 NWP Contract Liabilities Remaining Performance Obligations (Millions) 2025 (one year) $ — $ 391 2026 (one year) — 386 2027 (one year) — 373 2028 (one year) — 368 2029 (one year) — 349 Thereafter — 2,234 Total $ — $ 4,101

Provision (Benefit) for Incom_2

Provision (Benefit) for Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2024
Income Tax Expense (Benefit), Continuing Operations [Abstract]
Schedule of Components of Provision (benefit) for income taxes [Table Text Block]	The Provision (benefit) for income taxes from continuing operations includes: Year Ended December 31, 2024 2023 2022 (Millions) Current: Federal $ 125 $ 3 $ (25) State 9 21 19 134 24 (6) Deferred: Federal 472 872 424 State 34 109 7 506 981 431 Provision (benefit) for income taxes $ 640 $ 1,005 $ 425
Provision for income taxes at federal statutory rate [Table Text Block]	Reconciliations from the Provision (benefit) at statutory rate from continuing operations to recorded Provision (benefit) for income taxes are as follows: Year Ended December 31, 2024 2023 2022 (Millions) Provision (benefit) at statutory rate $ 627 $ 925 $ 534 Increases (decreases) in taxes resulting from: State income taxes (net of federal benefit) 79 129 113 State deferred income tax rate change (44) (25) (92) Federal valuation allowance — — (70) Federal settlements — — (45) Impact of nontaxable noncontrolling interests (25) (26) (14) Other – net 3 2 (1) Provision (benefit) for income taxes $ 640 $ 1,005 $ 425
Deferred tax liabilities and Deferred tax assets [Table Text Block]	Significant components of Deferred income tax liabilities are as follows: December 31, 2024 2023 (Millions) Gross deferred income tax liabilities: Property, plant and equipment $ 4,501 $ 3,541 Investments 1,733 1,740 Other 193 146 Total gross deferred income tax liabilities 6,427 5,427 Gross deferred income tax assets: Accrued liabilities 1,146 868 Corporate alternative minimum tax credits 108 — Foreign tax credits — 35 Federal loss carryovers 325 398 Disallowed business interest expense carryforward 247 67 State losses and credits 224 293 Other 92 103 Total gross deferred income tax assets 2,142 1,764 Less valuation allowance 91 183 Net deferred income tax assets 2,051 1,581 Deferred income tax liabilities $ 4,376 $ 3,846

Employee Benefit Plans (Tables)

Employee Benefit Plans (Tables)	12 Months Ended
	Dec. 31, 2024
Retirement Benefits [Abstract]
Changes in Projected Benefit Obligations, Fair Value of Plan Assets, Funded Status, and Schedule of Amounts Recognized in Balance Sheet [Table Text Block]	The following table presents the changes in benefit obligations and plan assets for pension benefits and other postretirement benefits for the years indicated: Pension Benefits Other 2024 2023 2024 2023 (Millions) Change in benefit obligation: Benefit obligation at beginning of year $ 1,006 $ 940 $ 145 $ 152 Service cost 25 23 1 1 Interest cost 47 46 7 7 Plan participants’ contributions — — 2 2 Benefits paid (73) (71) (11) (13) Net actuarial loss (gain) (1) (65) 68 (12) (4) Settlements (3) — — — Net increase (decrease) in benefit obligation (69) 66 (13) (7) Benefit obligation at end of year 937 1,006 132 145 Change in plan assets: Fair value of plan assets at beginning of year 1,167 1,117 262 253 Actual return on plan assets 88 120 16 17 Employer contributions 4 1 3 3 Plan participants’ contributions — — 2 2 Benefits paid (73) (71) (11) (13) Settlements (3) — — — Net increase (decrease) in fair value of plan assets 16 50 10 9 Fair value of plan assets at end of year 1,183 1,167 272 262 Funded status — overfunded (underfunded) $ 246 $ 161 $ 140 $ 117 Amounts recognized in the Consolidated Balance Sheet: Noncurrent assets $ 270 $ 187 $ 143 $ 120 Current liabilities (4) (4) (3) (3) Noncurrent liabilities (20) (22) — — Funded status — overfunded (underfunded) $ 246 $ 161 $ 140 $ 117 Accumulated benefit obligation $ 929 $ 998 ____________ (1) 2024 amounts are due primarily to changes in the following factors: Pension Benefits - discount rate assumptions and interest crediting rate assumption; Other Postretirement Benefits - discount rate assumption. 2023 amounts are due primarily to changes in the following factors: Pension Benefits - interest crediting rate assumption and discount rate assumptions.
Defined Benefit Plan, Plan with Projected Benefit Obligation in Excess of Plan Assets [Table Text Block]	The following table summarizes information for pension plans with obligations in excess of plan assets at December 31. 2024 2023 (Millions) Projected benefit obligation $ 23 $ 26 Accumulated benefit obligation 22 24 Fair value of plan assets — —
Pre-tax amounts recognized in Accumulated other comprehensive income (loss)[Table Text Block]	Pre-tax amounts recognized in Accumulated other comprehensive income (loss) at December 31 are as follows: Pension Benefits Other 2024 2023 2024 2023 (Millions) Net actuarial gain (loss) $ 49 $ (45) $ 20 $ 19
Schedule of Net Benefit Cost (Credit) [Table Text Block]	Net periodic benefit cost (credit) for the years ended December 31 consist of the following: Pension Benefits Other 2024 2023 2022 2024 2023 2022 (Millions) Components of net periodic benefit cost (credit): Service cost $ 25 $ 23 $ 28 $ 1 $ 1 $ 1 Interest cost 47 46 31 7 7 6 Expected return on plan assets (60) (57) (44) (11) (10) (10) Amortization of net actuarial loss (gain) — 5 12 (5) (3) — Net actuarial loss from settlements 1 — 3 — — — Reclassification to regulatory liability — — — — — 1 Net periodic benefit cost (credit) (1) $ 13 $ 17 $ 30 $ (8) $ (5) $ (2) ____________ (1) Components other than Service cost are included in Other income (expense) – net below Operating income (loss) in Williams’ Consolidated Statement of Income
Other changes in plan assets and benefit obligations recognized in other comprehensive income (loss) [Table Text Block]	Other changes in plan assets and benefit obligations recognized in Other comprehensive income (loss) before taxes for the years ended December 31 consist of the following: Pension Benefits Other 2024 2023 2022 2024 2023 2022 (Millions) Net actuarial gain (loss) arising during the year $ 93 $ (5) $ (14) $ 3 $ 3 $ 14 Amortization of net actuarial loss (gain) — 5 12 (2) (2) — Net actuarial loss from settlements 1 — 3 — — — Total recognized in Other comprehensive income (loss) $ 94 $ — $ 1 $ 1 $ 1 $ 14
Defined Benefit Plan, Assumptions [Table Text Block]	The weighted-average assumptions utilized to determine benefit obligations and Net periodic benefit cost (credit) as of December 31 are as follows: Pension Benefits Other 2024 2023 2022 2024 2023 2022 Benefit obligations: Discount rate 5.60 % 4.98 % 5.16 % 5.67 % 5.01 % 5.20 % Rate of compensation increase 3.48 3.52 3.58 N/A N/A N/A Cash balance interest crediting rate 4.00 4.50 3.50 N/A N/A N/A Net periodic benefit cost (credit): Discount rate 4.98 % 5.16 % 2.84 % 5.01 % 5.20 % 2.93 % Expected long-term rate of return on plan assets 5.31 5.17 3.81 4.16 4.04 3.67 Rate of compensation increase 3.52 3.58 3.67 N/A N/A N/A Cash balance interest crediting rate 4.50 3.50 3.00 N/A N/A N/A
Fair values of plan assets [Table Text Block]	The fair values of Williams’ pension and other postretirement benefits plan assets by asset class at December 31 are as follows: 2024 Pension Benefits Other Postretirement Benefits Level 1 (1) Level 2 (2) Total Level 1 (1) Level 2 (2) Total (Millions) Cash management funds $ 29 $ — $ 29 $ 103 $ — $ 103 Government debt securities 74 19 93 11 3 14 Corporate debt securities — 295 295 — 43 43 Other 1 4 5 — — — $ 104 $ 318 422 $ 114 $ 46 160 Commingled investment funds (3): Equities 292 43 Fixed income 469 69 Total assets at fair value $ 1,183 $ 272 2023 Pension Benefits Other Postretirement Benefits Level 1 (1) Level 2 (2) Total Level 1 (1) Level 2 (2) Total (Millions) Cash management funds $ 17 $ — $ 17 $ 99 $ — $ 99 Government debt securities 61 17 78 9 2 11 Corporate debt securities — 311 311 — 44 44 Other 2 5 7 1 — 1 $ 80 $ 333 413 $ 109 $ 46 155 Commingled investment funds (3): Equities 287 41 Fixed income 467 66 Total assets at fair value $ 1,167 $ 262 ____________ (1) Level 1 includes assets with fair values based on quoted prices in active markets for identical assets. Cash management funds and U.S. Treasury securities are included in this level. (2) Level 2 includes assets with fair values determined by using significant other observable inputs. This level includes fixed income securities, other than U.S. Treasury securities, that are valued primarily using pricing models which incorporate observable inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads.
Expected benefit payments [Table Text Block]	Following are the expected benefit payments, which reflect the same assumptions previously discussed and future service as appropriate. Pension Other (Millions) 2025 $ 101 $ 11 2026 95 11 2027 91 11 2028 87 11 2029 83 10 2030-2034 389 48

Investing Activities (Tables)

Investing Activities (Tables)	12 Months Ended
	Dec. 31, 2024
Investments [Abstract]
Investments [Table Text Block]	Ownership Interest at December 31, 2024 December 31, 2024 2023 (Millions) Appalachia Midstream Investments (1) $ 2,810 $ 2,886 OPPL 50% 385 387 Blue Racer 50% 366 398 Gulfstream 50% 196 210 Laurel Mountain 69% 171 184 Discovery (2) 100% — 361 Other Various 179 188 $ 4,107 $ 4,614 ___________ (1) Includes equity-method investments in multiple gathering systems in the Marcellus Shale region with an approximate average 66 percent interest. (2) Discovery is a wholly owned subsidiary of Williams as of August 1, 2024. See Note 3 – Acquisitions and Divestitures.
Contributions [Table Text Block]	Purchases of and contributions to equity-method investments Williams generally funds its portion of significant expansion or development projects of these investees through additional capital contributions. These transactions increased the carrying value of Williams’ investments and included: Year Ended December 31, 2024 2023 2022 (Millions) Appalachia Midstream Investments $ 74 $ 59 $ 83 Discovery 37 40 41 OPPL 2 1 — Aux Sable Liquid Products LP 1 38 — Cardinal Pipeline Company, LLC — — 16 Gulfstream — — 14 Other — 3 12 $ 114 $ 141 $ 166
Dividends and distributions [Table Text Block]	Dividends and distributions The organizational documents of entities in which Williams has an equity-method investment generally require distribution of available cash to members on at least a quarterly basis. These transactions reduced the carrying value of its investments and included: Year Ended December 31, 2024 2023 2022 (Millions) Appalachia Midstream Investments $ 407 $ 405 $ 415 Gulfstream 103 98 89 Blue Racer 95 62 49 OPPL 90 56 34 Laurel Mountain 29 42 112 Discovery 22 49 49 RMM — 49 52 Other 43 35 65 $ 789 $ 796 $ 865
Summarized Financial Position and Results of Operations of Equity Method Investments [Table Text Block]	Summarized Financial Position and Results of Operations of All Equity-Method Investments December 31, 2024 2023 (Millions) Assets (liabilities): Current assets $ 564 $ 669 Noncurrent assets 9,439 11,058 Current liabilities (1,146) (358) Noncurrent liabilities (2,383) (3,619) Year Ended December 31, 2024 2023 2022 (Millions) Gross revenue $ 2,880 $ 3,714 $ 5,520 Operating income 1,190 966 1,268 Net income 987 748 1,102
Investment Income	Other investing income (loss) – net The following table presents certain items reflected in Other investing income (loss) – net in Williams’ Consolidated Statement of Income: Year Ended December 31, 2024 2023 2022 (Millions) Gain on sale of Aux Sable investments $ 149 $ — $ — Gain on remeasurement of Discovery investment (Note 3) 127 — — Interest income 67 79 15 Gain on remeasurement of RMM investment (Note 3) — 30 — Other — (1) 1 $ 343 $ 108 $ 16

Property, Plant, and Equipment

Property, Plant, and Equipment (Tables)	12 Months Ended
	Dec. 31, 2024
Property, Plant and Equipment [Abstract]
Property, Plant, and Equipment [Table Text Block]	The following tables present Property, plant, and equipment – net for the years ended: Williams Estimated Depreciation December 31, 2024 2023 (Millions) Nonregulated: Natural gas gathering and processing facilities 5 - 40 $ 23,134 $ 21,357 Construction in progress Not applicable 1,543 1,138 Oil and gas properties Units of production 1,685 1,111 Other 0 - 45 4,798 3,268 Regulated: Natural gas transmission facilities 0 - 25 1.25 - 10.2 22,763 21,083 Construction in progress Not applicable Not applicable 542 1,124 Other 5 - 45 0.00 - 33.33 2,930 2,761 Total property, plant, and equipment, at cost 57,395 51,842 Accumulated depreciation and amortization (18,703) (17,531) Property, plant, and equipment — net $ 38,692 $ 34,311 Transco Depreciation December 31, 2024 2023 (Millions) Onshore transmission facilities 2.50 - 7.13 $ 17,242 $ 16,031 Offshore transmission facilities 1.25 659 681 Storage facilities 1.86 - 2.05 948 830 Gathering facilities 0.00 - 1.00 136 158 Construction in progress Not applicable 420 1,008 Other 1.77 - 20.00 639 585 Total property, plant, and equipment, at cost 20,044 19,293 Accumulated depreciation and amortization (5,941) (5,963) Property, plant, and equipment — net $ 14,103 $ 13,330 NWP Depreciation December 31, 2024 2023 (Millions) Transmission facilities 2.70 - 10.20 $ 3,821 $ 3,570 Storage facilities 1.60 - 2.76 160 155 Construction in progress Not applicable 66 85 Other 0.00 - 33.33 171 165 Total property, plant, and equipment, at cost 4,218 3,975 Accumulated depreciation and amortization (2,089) (2,026) Property, plant, and equipment — net $ 2,129 $ 1,949 __________ (1) Estimated useful life and depreciation rates are presented as of December 31, 2024. Depreciation rates and estimated useful lives for regulated assets are prescribed by the FERC.
Schedule of Change in Asset Retirement Obligation	The following tables present the significant changes to AROs, of which $2.548 billion and $1.978 billion are included in Regulatory liabilities, deferred income, and other with the remaining current portion in Other current liabilities at December 31, 2024 and 2023, respectively. Williams Year Ended December 31, 2024 2023 (Millions) Balance at beginning of year $ 2,084 $ 1,914 Liabilities incurred (1) 474 42 Liabilities settled (68) (43) Accretion 118 97 Revisions (2) 31 74 Balance at end of year $ 2,639 $ 2,084 ___________ (1) Includes $250 million, $106 million, and $114 million of ARO in 2024 related to the Discovery, Gulf Coast Storage, and Crowheart Acquisitions, respectively. (2) Several factors are considered in the annual review process, including inflation rates, current estimates for removal cost, market risk premiums, discount rates, and the estimated remaining useful life of the assets. Transco Year Ended December 31, 2024 2023 (Millions) Balance at beginning of year $ 619 $ 563 Liabilities incurred — 8 Liabilities settled (32) (23) Accretion 29 31 Revisions (1) (1) 40 Balance at end of year $ 615 $ 619 ___________ (1) Changes in estimates of existing obligations are primarily due to the annual review process, which considers various factors including inflation rate, current estimates for removal costs, discount rates, and the estimated remaining life of assets. NWP Year Ended December 31, 2024 2023 (Millions) Balance at beginning of year $ 136 $ 129 Accretion 8 7 Balance at end of year $ 144 $ 136

Regulatory Assets and Liabili_2

Regulatory Assets and Liabilities (Tables)	12 Months Ended
	Dec. 31, 2024
Regulated Operations [Abstract]
Schedule of Regulatory Assets	Williams December 31, 2024 2023 (Millions) Current assets reported within Other current assets and deferred charges $ 84 $ 95 Noncurrent assets reported within Regulatory assets, deferred charges, and other 582 527 Total regulatory assets $ 666 $ 622 Current liabilities reported within Other current liabilities $ 85 $ 77 Noncurrent liabilities reported within Regulatory liabilities, deferred income, and other 1,300 1,288 Total regulatory liabilities $ 1,385 $ 1,365 Transco December 31, 2024 2023 (Millions) Current regulatory assets: Fuel recovery $ 47 $ 60 ARO 16 16 Deferred cash out 6 6 ARO - Eminence 5 5 Total current regulatory assets 74 87 Long-term regulatory assets: ARO 243 209 Grossed-up deferred taxes on equity AFUDC 29 31 ARO - Eminence 15 20 Slug catcher 6 6 Deferred cash out — 11 Other 27 22 Total long-term regulatory assets 320 299 Total regulatory assets $ 394 $ 386 Current regulatory liabilities: Deferred taxes - liability $ 31 $ 31 Postretirement benefits other than pension — 8 Electric power cost 26 7 Pension — 2 Other 1 1 Total current regulatory liabilities 58 49 Long-term regulatory liabilities: Negative salvage 632 605 Deferred taxes - liability 252 283 Postretirement benefits other than pension 31 23 Pension 30 24 Sentinel meter station depreciation 7 7 Other 24 14 Total long-term regulatory liabilities 976 956 Total regulatory liabilities $ 1,034 $ 1,005 NWP December 31, 2024 2023 (Millions) Current regulatory assets: Fuel recovery $ 4 $ — Levelized depreciation 2 2 Total current regulatory assets 6 2 Long-term regulatory assets: Levelized depreciation 7 10 Grossed-up deferred taxes on equity AFUDC 4 4 Washington State Carbon and Greenhouse Gas Tax 38 22 Total long-term regulatory assets 49 36 Total regulatory assets $ 55 $ 38 Current regulatory liabilities: Deferred taxes - liability $ 20 $ 20 Fuel recovery — 1 Total current regulatory liabilities 20 21 Long-term regulatory liabilities: Deferred taxes - liability 160 179 Postretirement benefits other than pension 43 42 Negative salvage - net 30 31 Total long-term regulatory liabilities 233 252 Total regulatory liabilities $ 253 $ 273
Schedule of Regulatory Liabilities	Williams December 31, 2024 2023 (Millions) Current assets reported within Other current assets and deferred charges $ 84 $ 95 Noncurrent assets reported within Regulatory assets, deferred charges, and other 582 527 Total regulatory assets $ 666 $ 622 Current liabilities reported within Other current liabilities $ 85 $ 77 Noncurrent liabilities reported within Regulatory liabilities, deferred income, and other 1,300 1,288 Total regulatory liabilities $ 1,385 $ 1,365 Transco December 31, 2024 2023 (Millions) Current regulatory assets: Fuel recovery $ 47 $ 60 ARO 16 16 Deferred cash out 6 6 ARO - Eminence 5 5 Total current regulatory assets 74 87 Long-term regulatory assets: ARO 243 209 Grossed-up deferred taxes on equity AFUDC 29 31 ARO - Eminence 15 20 Slug catcher 6 6 Deferred cash out — 11 Other 27 22 Total long-term regulatory assets 320 299 Total regulatory assets $ 394 $ 386 Current regulatory liabilities: Deferred taxes - liability $ 31 $ 31 Postretirement benefits other than pension — 8 Electric power cost 26 7 Pension — 2 Other 1 1 Total current regulatory liabilities 58 49 Long-term regulatory liabilities: Negative salvage 632 605 Deferred taxes - liability 252 283 Postretirement benefits other than pension 31 23 Pension 30 24 Sentinel meter station depreciation 7 7 Other 24 14 Total long-term regulatory liabilities 976 956 Total regulatory liabilities $ 1,034 $ 1,005 NWP December 31, 2024 2023 (Millions) Current regulatory assets: Fuel recovery $ 4 $ — Levelized depreciation 2 2 Total current regulatory assets 6 2 Long-term regulatory assets: Levelized depreciation 7 10 Grossed-up deferred taxes on equity AFUDC 4 4 Washington State Carbon and Greenhouse Gas Tax 38 22 Total long-term regulatory assets 49 36 Total regulatory assets $ 55 $ 38 Current regulatory liabilities: Deferred taxes - liability $ 20 $ 20 Fuel recovery — 1 Total current regulatory liabilities 20 21 Long-term regulatory liabilities: Deferred taxes - liability 160 179 Postretirement benefits other than pension 43 42 Negative salvage - net 30 31 Total long-term regulatory liabilities 233 252 Total regulatory liabilities $ 253 $ 273

Goodwill and Other Intangible_2

Goodwill and Other Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2024
Goodwill and Intangible Assets Disclosure [Abstract]
Schedule of Goodwill [Table Text Block]	Changes in the carrying amount of goodwill, included in Intangible assets – net of accumulated amortization in Williams’ Consolidated Balance Sheet, by reportable segment for the years indicated are as follows: Transmission & Gulf of America West Total (Millions) December 31, 2022 $ — $ — $ — MountainWest Acquisition (Note 3) 400 — 400 Cureton Acquisition (Note 3) — 6 6 RMM Acquisition (Note 3) — 57 57 December 31, 2023 400 63 463 Cureton Acquisition (Note 3) — 5 5 RMM Acquisition (Note 3) — (2) (2) December 31, 2024 $ 400 $ 66 $ 466
Schedule of Finite-Lived Intangible Assets [Table Text Block]	The gross carrying amount and accumulated amortization of other intangible assets, included in Intangible assets – net of accumulated amortization in Williams’ Consolidated Balance Sheet, at December 31 are as follows: 2024 2023 Gross Carrying Amount Accumulated Amortization Gross Carrying Amount Accumulated Amortization (Millions) Customer relationships $ 10,239 $ (3,523) $ 10,237 $ (3,155) Transportation and storage capacity contracts 267 (244) 267 (223) Other 6 (2) 6 (2) Other intangible assets $ 10,512 $ (3,769) $ 10,510 $ (3,380)

Other Current Liabilities (Tabl

Other Current Liabilities (Tables)	12 Months Ended
	Dec. 31, 2024
Accrued Liabilities, Current [Abstract]
Other Current Liabilities [Table Text Block]	Williams December 31, 2024 2023 (Millions) Interest on debt $ 350 $ 322 Employee costs 285 197 Contract liabilities (Note 5) 170 159 Alaska refinery contamination litigation (Note 1) — 134 Asset retirement obligations (Note 9) 91 106 Regulatory liabilities (Note 10) 85 77 Operating lease liabilities (Note 14) 26 24 Other, including accrued loss contingencies 353 265 $ 1,360 $ 1,284 Transco December 31, 2024 2023 (Millions) Interest on debt $ 76 $ 76 Contract liabilities 10 10 Customer deposits 38 35 Other 57 69 $ 181 $ 190 NWP December 31, 2024 2023 (Millions) Interest on debt $ 6 $ 6 Taxes, other than income taxes 8 7 Contract liabilities — 1 Transportation and gas exchange payables 10 5 Other 10 15 $ 34 $ 34

Debt and Banking Arrangements (

Debt and Banking Arrangements (Tables)	12 Months Ended
	Dec. 31, 2024
Debt Disclosure [Abstract]
Schedule of Long-term Debt Instruments [Table Text Block]	Long-Term Debt by Issuing Entity December 31, 2024 2023 (Millions) Transco: 7.08% Debentures due 2026 $ 8 $ 8 7.25% Debentures due 2026 200 200 7.85% Notes due 2026 1,000 1,000 4% Notes due 2028 400 400 3.25% Notes due 2030 700 700 5.4% Notes due 2041 375 375 4.45% Notes due 2042 400 400 4.6% Notes due 2048 600 600 3.95% Notes due 2050 500 500 Other financing obligation — Atlantic Sunrise 764 790 Other financing obligation — Leidy South 75 76 Other financing obligation — Dalton 247 250 Unamortized debt issuance costs (23) (26) Net unamortized debt premium (discount) (11) (12) Total debt — Transco $ 5,235 $ 5,261 MountainWest: 3.53% Notes due 2028 (Note 3) $ 100 $ 100 3.91% Notes due 2038 (Note 3) 150 150 4.875% Notes due 2041 (Note 3) 180 180 Net unamortized debt premium (discount) (58) (61) Total debt — MountainWest $ 372 $ 369 NWP: 7.125% Debentures due 2025 $ 85 $ 85 4% Notes due 2027 500 500 Unamortized debt issuance costs (1) (2) Net unamortized debt premium (discount) (2) (2) Total debt — NWP $ 582 $ 581 Williams: 4.3% Notes due 2024 $ — $ 1,000 4.55% Notes due 2024 — 1,250 3.9% Notes due 2025 750 750 4% Notes due 2025 750 750 5.4% Notes due 2026 1,100 1,100 7.7% Notes due 2027 2 2 3.75% Notes due 2027 1,450 1,450 5.3% Notes due 2028 900 900 4.9% Notes due 2029 1,100 — 4.8% Notes due 2029 450 — 3.5% Notes due 2030 1,000 1,000 2.6% Notes due 2031 1,500 1,500 7.5% Debentures due 2031 339 339 7.75% Notes due 2031 252 252 8.75% Notes due 2032 445 445 4.65% Notes due 2032 1,000 1,000 5.65% Notes due 2033 750 750 5.15% Notes due 2034 1,300 — 6.3% Notes due 2040 1,250 1,250 5.8% Notes due 2043 400 400 December 31, 2024 2023 (Millions) 5.4% Notes due 2044 500 500 5.75% Notes due 2044 650 650 4.9% Notes due 2045 500 500 5.1% Notes due 2045 1,000 1,000 4.85% Notes due 2048 800 800 3.5% Notes due 2051 650 650 5.3% Notes due 2052 750 750 5.8% Notes due 2054 750 — Unamortized debt issuance costs (130) (112) Net unamortized debt premium (discount) (41) (39) Total debt — Williams $ 20,167 $ 18,837 RMM deferred consideration obligation (Note 3) — 665 Gulf Coast Storage deferred consideration obligation (Note 3) 100 — Total debt $ 26,456 $ 25,713 Long-term debt due within one year — Williams (1,600) (2,305) Long-term debt due within one year — Transco (35) (32) Long-term debt due within one year — NWP (85) — Long-term debt $ 24,736 $ 23,376
Schedule of Maturities of Long-term Debt [Table Text Block]	The following table presents aggregate minimum maturities of long-term debt, other financing obligations, and the Gulf Coast Storage deferred consideration obligation, excluding net unamortized debt premium (discount) and debt issuance costs, for each of the next five years: December 31, 2024 (Millions) Williams: 2025 $ 1,720 2026 2,345 2027 1,994 2028 1,445 2029 1,600 Transco: 2025 $ 35 2026 1,245 2027 41 2028 445 2029 50 NWP: 2025 $ 85 2027 500
Schedule of Debt Issuances	Williams senior unsecured public debt issuances for the past three years and subsequent to the balance sheet date are as follows: Issue Date Maturity Date Amount Rate (Millions) January 9, 2025 March 15, 2035 $ 1,000 5.600% January 9, 2025 March 15, 2055 500 6.000% August 13, 2024 November 15, 2029 450 4.800% August 13, 2024 (1) March 15, 2034 300 5.150% August 13, 2024 November 15, 2054 750 5.800% January 5, 2024 March 15, 2029 1,100 4.900% January 5, 2024 March 15, 2034 1,000 5.150% August 10, 2023 (2) March 2, 2026 350 5.400% August 10, 2023 August 15, 2028 900 5.300% March 2, 2023 March 2, 2026 750 5.400% March 2, 2023 March 15, 2033 750 5.650% August 8, 2022 August 15, 2032 1,000 4.650% August 8, 2022 August 15, 2052 750 5.300% ________________ (1) Additional issuance of the 5.15 percent senior notes due 2034 issued on January 5, 2024, and trade interchangeably with such notes. (2) Additional issuance of the 5.40 percent senior notes due 2026 issued on March 2, 2023, and trade interchangeably with such notes.
Schedule of Extinguishment of Debt	Williams’ senior unsecured public debt retirements for the past three years and subsequent to the balance sheet date are as follows: Date of Retirement Maturity Date Amount Rate (Millions) January 15, 2025 January 15, 2025 $ 750 3.900% June 24, 2024 June 24, 2024 1,250 4.550% March 4, 2024 March 4, 2024 1,000 4.300% November 15, 2023 November 15, 2023 600 4.500% October 17, 2022 January 15, 2023 850 3.700% May 16, 2022 August 15, 2022 750 3.350% January 18, 2022 March 15, 2022 1,250 3.600%
Schedule of Line of Credit Facilities [Table Text Block]	Credit Facility December 31, 2024 Stated Capacity Outstanding (Millions) Long-term credit facility (1) $ 3,750 $ — Letters of credit under certain bilateral bank agreements 15 ________________ (1) In managing its available liquidity, Williams does not expect a maximum outstanding amount in excess of the capacity of its credit facility inclusive of any outstanding amounts under the commercial paper program.
Interest Income and Interest Expense Disclosure	Cash Payments for Interest by Registrant (Net of Amounts Capitalized) Year Ended December 31, 2024 2023 2022 (Millions) Williams $ 1,293 $ 1,152 $ 1,117 Transco 302 307 326 NWP 24 26 26

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2024
Leases [Abstract]
Lease, Cost [Table Text Block]	Williams Year Ended December 31, 2024 2023 2022 (Millions) Lease Cost: Operating lease cost $ 39 $ 38 $ 34 Variable lease cost 31 31 26 Sublease income — (1) — Total lease cost $ 70 $ 68 $ 60 Cash paid for operating lease liabilities $ 37 $ 37 $ 33 December 31, 2024 2023 (Dollars in Millions) Other Information: Right-of-use assets (included in Regulatory assets, deferred charges, and other ) $ 154 $ 159 Operating lease liabilities: Current (included in Other current liabilities ) $ 26 $ 24 Noncurrent (included in Regulatory liabilities, deferred income, and other ) $ 142 $ 148 Weighted-average remaining lease term – operating leases (years) 11 11 Weighted-average discount rate – operating leases 4.90% 4.78% Transco Year Ended December 31, 2024 2023 2022 (Millions) Lease Cost: Operating lease cost $ 9 $ 9 $ 9 Variable lease cost 7 7 7 Total lease cost $ 16 $ 16 $ 16 Cash paid for operating lease liabilities $ 9 $ 10 $ 10 December 31, 2024 2023 (Dollars in Millions) Other Information: Right-of-use assets (included in Deferred charges and other in Transco’s Balance Sheet) $ 48 $ 53 Operating lease liabilities: Current (included in Other current liabilities in Transco’s Balance Sheet) $ 6 $ 6 Noncurrent (included in Deferred income and other in Transco’s Balance Sheet) $ 51 $ 56 Weighted-average remaining lease term – operating leases (years) 13 13 Weighted-average discount rate – operating leases 4.77% 4.73% NWP Year Ended December 31, 2024 2023 2022 (Millions) Lease Cost: Operating lease cost $ 3 $ 1 $ 1 Variable lease cost 1 1 1 Total lease cost $ 4 $ 2 $ 2 Cash paid for operating lease liabilities $ 2 $ 1 $ 1 December 31, 2024 2023 (Dollars in Millions) Other Information: Right-of-use assets (included in Deferred charges and other in NWP’s Balance Sheet) $ 5 $ 9 Operating lease liabilities: Current (included in Other current liabilities in NWP’s Balance Sheet) $ 1 $ 1 Noncurrent (included in Deferred income and other in NWP’s Balance Sheet) $ 5 $ 7 Weighted-average remaining lease term – operating leases (years) 19 15 Weighted-average discount rate – operating leases 4.90% 4.18%
Lessee, Operating Lease, Liability, Maturity [Table Text Block]	At December 31, 2024, the following table represents operating lease maturities, including renewal provisions Williams has assessed as being reasonably certain of exercise, for each of the years ended December 31: (Millions) 2025 $ 34 2026 33 2027 30 2028 22 2029 19 Thereafter 86 Total future lease payments 224 Less: Amount representing interest 56 Total obligations under operating leases $ 168 As of December 31, 2024, the following table represents operating lease maturities, including renewal provisions that Transco has assessed as being reasonably certain of exercise, for each of the years ended December 31: (Millions) 2025 $ 9 2026 9 2027 10 2028 10 2029 10 Thereafter 32 Total future lease payments 80 Less: Amount representing interest 23 Total obligations under operating leases $ 57 As of December 31, 2024, the following table represents operating lease maturities, including renewal provisions that NWP has assessed as being reasonably certain of exercise, for each of the years ended December 31: (Millions) 2025 $ 1 2026 — 2027 1 2028 — 2029 1 Thereafter 6 Total future lease payments 9 Less: Amount representing interest 3 Total obligations under operating leases $ 6

Fair Value Measurements, Guar_2

Fair Value Measurements, Guarantees, and Concentration of Credit Risk (Tables)	12 Months Ended
	Dec. 31, 2024
Fair Value Disclosures [Abstract]
Fair Value Assets and Liabilities Measured On Recurring Basis [Table Text Block]	The following table presents, by level within the fair value hierarchy, certain of Williams’, Transco’s, and NWP’s 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 December 31, 2024: Measured on a recurring basis: ARO Trust investments - Transco $ 297 $ 297 $ 297 $ — $ — Commodity derivative assets (1) 344 726 427 188 111 Commodity derivative liabilities (1) (400) (1,070) (532) (475) (63) Additional disclosures: Debt by issuer, including current portion: Williams (20,167) (19,517) — (19,517) — Transco (5,235) (5,276) — (5,276) — NWP (582) (573) — (573) — MountainWest (372) (364) — (364) — Gulf Coast Storage deferred consideration obligation (Note 3) (100) (100) — (100) — Total debt (26,456) (25,830) — (25,830) — Guarantees (36) (28) — (12) (16) Assets (liabilities) at December 31, 2023: Measured on a recurring basis: ARO Trust investments - Transco $ 269 $ 269 $ 269 $ — $ — Commodity derivative assets (1)(2) 314 866 514 196 156 Commodity derivative liabilities (1)(2) (287) (841) (376) (362) (103) Interest rate derivatives 6 6 — 6 — Additional disclosures: Debt by issuer, including current portion: Williams (18,837) (18,494) — (18,494) — Transco (5,261) (5,438) — (5,438) — NWP (581) (581) — (581) — MountainWest (369) (375) — (375) — RMM deferred consideration obligation (Note 3) (665) (665) — (665) — Total debt (25,713) (25,553) — (25,553) — Guarantees (37) (28) — (12) (16) (1) The carrying amount is presented net of counterparty offsetting arrangements and collateral (see Note 17 – Commodity Derivatives). (2) Previously, the fair value of Williams’ commodity derivative assets and liabilities were disclosed by level within the fair value hierarchy net of counterparty offsetting arrangements. The December 31, 2023, amounts have been corrected to disclose the fair values by level on a gross basis, as presented above.
Debt Securities, Trading, and Equity Securities, FV-NI	Transco investments within the ARO Trust were as follows: December 31, 2024 December 31, 2023 Amortized Cost Basis Fair Value Amortized Cost Basis Fair Value (Millions) Money Market Funds $ 27 $ 27 $ 26 $ 26 U.S. Equity Funds 53 146 53 120 International Equity Funds 32 40 32 39 Municipal Bond Funds 88 84 87 84 Total $ 200 $ 297 $ 198 $ 269
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation	The following table presents a reconciliation of changes in fair value of the net commodity derivatives classified as Level 3 in the fair value hierarchy. Year Ended December 31, 2024 2023 (Millions) Balance at beginning of period $ 53 $ (56) Gains (losses) included in Williams’ Consolidated Statement of Income (5) 91 Purchases, issuances, and settlements (1) 20 Transfers into Level 3 1 — Transfers out of Level 3 — (2) Balance at end of period $ 48 $ 53
Contract With Customer Accounts Receivable	The following table summarizes Williams’ concentration of receivables, net of allowances: December 31, 2024 2023 (Millions) NGLs, natural gas, and related products and services $ 594 $ 589 Regulated interstate natural gas transportation and storage 339 310 Marketing of natural gas and NGLs 516 321 Upstream activities 45 72 Accounts receivable related to revenues from contracts with customers 1,494 1,292 Receivables from derivatives 294 311 Other accounts receivable 75 52 Trade accounts and other receivables - net $ 1,863 $ 1,655
Fair Value, Concentration of Risk	Customers representing 10 percent or more of Transco’s and NWP’s revenues include: Year Ended December 31, 2024 2023 2022 (Millions) Transco: Dominion Energy, Inc (1) $ 217 $ 287 $ 293 NWP: Puget Sound Energy, Inc. $ 136 $ 126 $ 131 Cascade Natural Gas Corporation 46 47 49 Northwest Natural Gas Company 47 47 49 _______________ (1) The 2024 amount is less than 10 percent of Transco’s revenue.

Commodity Derivatives (Tables)

Commodity Derivatives (Tables)	12 Months Ended
	Dec. 31, 2024
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Derivative Instruments	At December 31, 2024, the notional volume of the net long (short) positions for Williams’ commodity derivative contracts were as follows: Commodity Unit of Measure Net Long (Short) Position Index Risk Natural Gas MMBtu 592,842,257 Central Hub Risk - Henry Hub Natural Gas MMBtu (50,513,793) Basis Risk Natural Gas MMBtu 13,306,615 Central Hub Risk - Mont Belvieu Natural Gas Liquids Barrels (2,561,000) Basis Risk Natural Gas Liquids Barrels (205,000) Central Hub Risk - WTI Crude Oil Barrels (480,000)
Schedule of Derivatives Instruments Statements of Financial Performance and Financial Position, Location	The fair value of commodity derivatives, which are not designated as hedging instruments for accounting purposes, is reflected as follows: December 31, December 31, Commodity Derivatives Categories Assets (Liabilities) Assets (Liabilities) (Millions) Current $ 508 $ (635) $ 623 $ (496) Noncurrent 218 (435) 243 (345) Total commodity derivatives $ 726 $ (1,070) $ 866 $ (841) Counterparty and collateral netting offset (382) 670 (552) 554 Amounts recognized in Williams’ Consolidated Balance Sheet $ 344 $ (400) $ 314 $ (287) The pre-tax impacts of Williams’ commodity derivatives, which are not designated as hedging instruments for accounting purposes, are reflected as follows: Year Ended December 31, 2024 2023 2022 (Millions) Net gain (loss) from commodity derivatives within Total revenues : Realized $ 111 $ 253 $ (91) Unrealized (361) 703 (296) $ (250) $ 956 $ (387) Net gain (loss) from commodity derivatives within Net processing commodity expenses : Realized $ (8) $ (4) $ 16 Unrealized (6) (43) 47 $ (14) $ (47) $ 63 Total net gain (loss) from commodity derivatives $ (264) $ 909 $ (324)

Segment Disclosures (Tables)

Segment Disclosures (Tables)	12 Months Ended
	Dec. 31, 2024
Segment Reporting [Abstract]
Reconciliation of revenue from segment to consolidated [Table Text Block]	The following tables present revenues, Modified EBITDA , significant expenses, and certain segment assets measures, as well as reconciliations to the consolidated totals: Transmission & Gulf of America Northeast G&P West Gas & NGL Marketing Services (1) Total (Millions) 2024 Segment revenues: Service revenues External $ 4,157 $ 1,900 $ 1,558 $ — $ 7,615 Internal 89 13 160 — 262 Total service revenues 4,246 1,913 1,718 — 7,877 Total service revenues – commodity consideration 54 2 78 — 134 Product sales External 144 24 178 2,500 2,846 Internal 184 86 691 (448) 513 Total product sales 328 110 869 2,052 3,359 Net gain (loss) from commodity derivatives Realized — — 4 72 76 Unrealized — — — (335) (335) Total net gain (loss) from commodity derivatives (2) — — 4 (263) (259) Total revenues of reportable segments $ 4,628 $ 2,025 $ 2,669 $ 1,789 $ 11,111 Reconciliation of revenues: Revenues from upstream operations, corporate, and other business activities 470 Net unrealized gain (loss) from commodity derivatives for upstream operations (26) Eliminations (1,052) Total consolidated revenues $ 10,503 Segment costs and expenses and Proportional Modified EBITDA of equity-method investments: Product costs and net realized processing commodity expenses (329) (88) (844) (1,799) Net unrealized gain (loss) from commodity derivatives within Net processing commodity expenses — — — (6) Operating and administrative expenses (3) (1,104) (441) (591) (108) Recoverable power, transportation, and storage costs (4) (250) (143) (49) — Other segment income (expenses) - net (5) 155 3 (5) — Proportional Modified EBITDA of equity-method investments 173 602 132 — Modified EBITDA of reportable segments $ 3,273 $ 1,958 $ 1,312 $ (124) $ 6,419 Modified EBITDA from upstream operations, corporate, and other business activities 237 Total consolidated Modified EBITDA $ 6,656 Reconciliation of Modified EBITDA: Depreciation and amortization expenses $ (2,219) Equity earnings (losses) 560 Other investing income (loss) - net 343 Interest expense (1,364) Accretion expense associated with AROs for nonregulated operations (81) Proportional Modified EBITDA of equity-method investments (909) Income (loss) before income taxes from continuing operations $ 2,986 Equity-method investments by reportable segment $ 272 $ 3,346 $ 476 $ — $ 4,094 Other equity-method investments 13 Total equity-method investments $ 4,107 Segment assets $ 23,149 $ 12,918 $ 12,144 $ 46 $ 48,257 Total current assets 2,661 Regulatory assets, deferred charges, and noncurrent assets 1,830 Assets of upstream operations, corporate, and other business activities 1,784 Total assets $ 54,532 Additions to long-lived segment assets $ 4,399 $ 210 $ 529 $ 2 $ 5,140 Additions to long-lived assets of upstream operations, corporate, and other business activities 458 Total additions to long-lived assets $ 5,598 Transmission & Gulf of America Northeast G&P West Gas & NGL Marketing Services (1) Total (Millions) 2023 Segment revenues: Service revenues External $ 3,766 $ 1,868 $ 1,376 $ 1 $ 7,011 Internal 92 28 126 — 246 Total service revenues 3,858 1,896 1,502 1 7,257 Total service revenues – commodity consideration 38 5 103 — 146 Product sales External 146 34 80 2,382 2,642 Internal 106 98 361 (322) 243 Total product sales 252 132 441 2,060 2,885 Net gain (loss) from commodity derivatives Realized 2 — 89 115 206 Unrealized — — — 702 702 Total net gain (loss) from commodity derivatives (2) 2 — 89 817 908 Total revenues of reportable segments $ 4,150 $ 2,033 $ 2,135 $ 2,878 $ 11,196 Reconciliation of revenues: Revenues from upstream operations, corporate, and other business activities 505 Net unrealized gain (loss) from commodity derivatives for upstream operations 1 Eliminations (795) Total consolidated revenues $ 10,907 Segment costs and expenses and Proportional Modified EBITDA of equity-method investments: Product costs and net realized processing commodity expenses (259) (125) (517) (1,786) Net unrealized gain (loss) from commodity derivatives within Net processing commodity expenses — — — (43) Operating and administrative expenses (3) (1,034) (424) (502) (98) Recoverable power, transportation, and storage costs (4) (241) (132) (37) — Other segment income (expenses) - net (5) 118 (10) (3) (1) Gain on sale of business (6) 129 — — — Proportional Modified EBITDA of equity-method investments 205 574 162 — Modified EBITDA of reportable segments $ 3,068 $ 1,916 $ 1,238 $ 950 $ 7,172 Modified EBITDA from upstream operations, corporate, and other business activities 307 Unallocated Net gain from Energy Transfer litigation judgment (7) 534 Total consolidated Modified EBITDA $ 8,013 Reconciliation of Modified EBITDA: Depreciation and amortization expenses $ (2,071) Equity earnings (losses) 589 Other investing income (loss) - net 108 Interest expense (1,236) Accretion expense associated with AROs for nonregulated operations (59) Proportional Modified EBITDA of equity-method investments (939) Income (loss) before income taxes from continuing operations $ 4,405 Equity-method investments by reportable segment $ 652 $ 3,477 $ 477 $ — $ 4,606 Other equity-method investments 8 Total equity-method investments $ 4,614 Segment assets $ 19,705 $ 13,319 $ 12,188 $ 77 $ 45,289 Total current assets 4,513 Regulatory assets, deferred charges, and noncurrent assets 1,573 Assets of upstream operations, corporate, and other business activities 1,252 Total assets $ 52,627 Additions to long-lived segment assets $ 2,501 $ 340 $ 1,186 $ 7 $ 4,034 Additions to long-lived assets of upstream operations, corporate, and other business activities 279 Total additions to long-lived assets $ 4,313 Transmission & Gulf of America Northeast G&P West Gas & NGL Marketing Services (1) Total (Millions) 2022 Segment revenues: Service revenues External $ 3,461 $ 1,613 $ 1,443 $ 3 $ 6,520 Internal 118 41 99 — 258 Total service revenues 3,579 1,654 1,542 3 6,778 Total service revenues – commodity consideration 64 14 182 — 260 Product sales External 228 28 145 4,052 4,453 Internal 176 106 696 (518) 460 Total product sales 404 134 841 3,534 4,913 Net gain (loss) from commodity derivatives Realized — — (4) 17 13 Unrealized — — — (321) (321) Total net gain (loss) from commodity derivatives (2) — — (4) (304) (308) Total revenues of reportable segments $ 4,047 $ 1,802 $ 2,561 $ 3,233 $ 11,643 Reconciliation of revenues: Revenues from upstream operations, corporate, and other business activities 626 Net unrealized gain (loss) from commodity derivatives for upstream operations 25 Eliminations (1,329) Total consolidated revenues $ 10,965 Segment costs and expenses and Proportional Modified EBITDA of equity-method investments: Product costs and net realized processing commodity expenses (425) (138) (918) (3,228) Net unrealized gain (loss) from commodity derivatives within Net processing commodity expenses — — — 47 Operating and administrative expenses (3) (906) (384) (507) (96) Recoverable power, transportation, and storage costs (4) (254) (132) (43) — Other segment income (expenses) - net (5) 19 (6) (14) 4 Proportional Modified EBITDA of equity-method investments 193 654 132 — Modified EBITDA of reportable segments $ 2,674 $ 1,796 $ 1,211 $ (40) $ 5,641 Modified EBITDA from upstream operations, corporate, and other business activities 434 Total consolidated Modified EBITDA $ 6,075 Reconciliation of Modified EBITDA: Depreciation and amortization expenses $ (2,009) Equity earnings (losses) 637 Other investing income (loss) - net 16 Interest expense (1,147) Accretion expense associated with AROs for nonregulated operations (51) Proportional Modified EBITDA of equity-method investments (979) Income (loss) before income taxes from continuing operations $ 2,542 Equity-method investments by reportable segment $ 629 $ 3,566 $ 843 $ — $ 5,038 Other equity-method investments 10 Total equity-method investments $ 5,048 Segment assets $ 17,795 $ 13,539 $ 10,710 $ 130 $ 42,174 Total current assets 3,797 Regulatory assets, deferred charges, and noncurrent assets 1,319 Assets of upstream operations, corporate, and other business activities 1,143 Total assets $ 48,433 Additions to long-lived segment assets $ 1,420 $ 261 $ 1,507 $ 4 $ 3,192 Additions to long-lived assets of upstream operations, corporate, and other business activities 406 Total additions to long-lived assets $ 3,598 _______________________ (1) As Williams is acting as agent for natural gas marketing customers or engages in energy trading activities, the resulting revenues are presented net of the related costs of those activities. (2) Williams records transactions that qualify as commodity derivatives at fair value with changes in fair value recognized in earnings in the period of change and characterized as unrealized gains or losses. Gains and losses from commodity derivatives held for energy trading purposes are presented on a net basis in revenue. (3) Segment operating and administrative expenses primarily include payroll, maintenance and operating costs and taxes, and general and administrative expenses, including acquisition and transition-related expenses. It also includes project execution, information technology, finance and accounting, real estate and aviation, central engineering services, safety and operational discipline, supply chain and digital transformation, corporate strategic development, human resources, legal and government affairs, and executive and audit support services costs which are centrally managed and allocated to segments. (4) Recoverable power, transportation and storage costs are charges incurred which are reimbursable pursuant to FERC stipulations or customer contracts. (5) Other segment income (expenses) primarily includes equity AFUDC and regulatory credits and charges related to Williams’ regulated operations. (6) Gain on sale of business reflects a gain recognized on the sale of certain liquids pipelines in the Gulf Coast region in September 2023 (see Note 3 – Acquisitions and Divestitures). (7) Net gain from Energy Transfer litigation judgment resulted from a favorable ruling in November 2023 (see Note 1 – General, Description of Business, Basis of Presentation, and Summary of Significant Accounting Policies).

General, Description of Busin_4

General, Description of Business, and Basis of Presentation (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
General and Description Of Business [Abstract]
Equity-method investments		$ 4,107	$ 4,614	$ 5,048
Loss Contingencies [Line Items]
Proceeds from Legal Settlements			627
Gain (Loss) Related to Litigation Settlement		$ 0	534	$ 0
Gulfstream Natural Gas System, LLC [Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage		50%
Equity-method investments		$ 196	210
Discovery Producer Services LLC [Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage		100%
Equity-method investments	[1]	$ 0	361
Laurel Mountain Midstream, LLC [Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage		69%
Equity-method investments		$ 171	184
Blue Racer Midstream LLC [Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage		50%
Equity-method investments		$ 366	398
Overland Pass Pipeline Company LLC [Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage		50%
Equity-method investments		$ 385	$ 387
Williams Companies Inc [Member] | Gulfstar One [Member] | Variable Interest Entity, Primary Beneficiary [Member]
General and Description Of Business [Abstract]
Variable Interest Entity Ownership Percentage		51%
Williams Companies Inc [Member] | Northeast JV [Member] | Variable Interest Entity, Primary Beneficiary [Member]
General and Description Of Business [Abstract]
Variable Interest Entity Ownership Percentage		65%
Williams Companies Inc [Member] | Cardinal Gas Services LLC [Member] | Variable Interest Entity, Primary Beneficiary [Member]
General and Description Of Business [Abstract]
Variable Interest Entity Ownership Percentage		66%
Transmission And Gulf Of America [Member] | Gulfstream Natural Gas System, LLC [Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage		50%
Transmission And Gulf Of America [Member] | Discovery Producer Services LLC [Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage			60%
Northeast G And P [Member] | Laurel Mountain Midstream, LLC [Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage		69%
Northeast G And P [Member] | Blue Racer Midstream LLC [Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage		50%
Northeast G And P [Member] | Williams Companies Inc [Member] | Appalachia Midstream Services, LLC [Member]
General and Description Of Business [Abstract]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest		66%
West [Member] | Overland Pass Pipeline Company LLC [Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage		50%
West [Member] | Rocky Mountain Midstream Holdings LLC [Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage				50%
West [Member] | Williams Companies Inc [Member] | Conway Fractionator [Member]
General and Description Of Business [Abstract]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest		50%
Former Alaska Refinery [Member]
Loss Contingencies [Line Items]
Loss Contingency Accrual, Period Increase (Decrease)			$ 125
[1] Discovery is a wholly owned subsidiary of Williams as of August 1, 2024. See Note 3 – Acquisitions and Divestitures.

Summary of Significant Accounti

Summary of Significant Accounting Policies (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Sep. 03, 2021
Retirement Benefits, Description [Abstract]
Accumulated Other Comprehensive Income (Loss), Net of Tax	$ 76	$ 0
Threshold For Amortization Of Unrecognized Actuarial Gains Losses	10%
Share Repurchase Program [Abstract]
Stock Repurchase Program, Authorized Amount				$ 1,500
Purchases of treasury stock	$ 0	130	$ 9
Stock Repurchase Program Cumulative Amount Purchased	139
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member]
Retirement Benefits, Description [Abstract]
Accumulated Other Comprehensive Income (Loss), Net of Tax	$ 55	(17)
Pension Benefits [Member]
Retirement Benefits, Description [Abstract]
Approximate Amortization Period Of Net Actuarial Gain Loss	9 years
Amortization Period Of Difference Between Expected And Actual Return On Plan Assets	5 years
Other Postretirement Benefits [Member]
Retirement Benefits, Description [Abstract]
Approximate Amortization Period Of Net Actuarial Gain Loss	4 years
Minimum [Member]
Leases [Abstract]
Lessee, Operating Lease, Term of Contract	1 year
Minimum [Member] | Pension Benefits [Member]
Retirement Benefits, Description [Abstract]
Threshold For Market Related Value	90%
Maximum [Member]
Leases [Abstract]
Lessee, Operating Lease, Term of Contract	20 years
Maximum [Member] | Pension Benefits [Member]
Retirement Benefits, Description [Abstract]
Threshold For Market Related Value	110%
Transcontinental Gas Pipe Line Company, LLC [Member]
Regulated Operations [Abstract]
Public Utilities, Allowance For Funds Used During Construction, Capitalized Cost of Debt	$ 17	14	5
Public Utilities, Allowance for Funds Used During Construction, Capitalized Cost of Equity	71	63	23
Public Utilities, Allowance for Funds Used During Construction, Additions	$ 88	77	28
Transcontinental Gas Pipe Line Company, LLC [Member] | Minimum [Member]
Leases [Abstract]
Lessee, Operating Lease, Term of Contract	1 year
Transcontinental Gas Pipe Line Company, LLC [Member] | Maximum [Member]
Leases [Abstract]
Lessee, Operating Lease, Term of Contract	30 years
Northwest Pipeline LLC [Member]
Regulated Operations [Abstract]
Public Utilities, Allowance For Funds Used During Construction, Capitalized Cost of Debt	$ 2	1	1
Public Utilities, Allowance for Funds Used During Construction, Capitalized Cost of Equity	8	3	2
Public Utilities, Allowance for Funds Used During Construction, Additions	$ 10	$ 4	$ 3
Northwest Pipeline LLC [Member] | Minimum [Member]
Leases [Abstract]
Lessee, Operating Lease, Term of Contract	1 year
Northwest Pipeline LLC [Member] | Maximum [Member]
Leases [Abstract]
Lessee, Operating Lease, Term of Contract	30 years

Variable Interest Entities (Det

Variable Interest Entities (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Variable Interest Entity [Line Items]
Equity-method investments	$ 4,107	$ 4,614	$ 5,048
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents	60	2,150	152	$ 1,680
Receivables, Net, Current	1,863	1,655
Inventory, Net	279	274
Other current assets and deferred charges	192	195
Property, Plant and Equipment, Net	38,692	34,311
Intangible assets – net of accumulated amortization	7,209	7,593
Other Assets, Noncurrent	1,830	1,573	$ 1,319
Accounts payable	(1,613)	(1,379)
Other current liabilities	(1,360)	(1,284)
Other Liabilities and Deferred Revenue, Noncurrent	(5,268)	(4,684)
Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents	15	33
Receivables, Net, Current	178	215
Inventory, Net	5	5
Other current assets and deferred charges	7	4
Property, Plant and Equipment, Net	4,896	5,046
Intangible assets – net of accumulated amortization	1,940	2,049
Other Assets, Noncurrent	27	31
Accounts payable	(57)	(109)
Other current liabilities	(29)	(28)
Other Liabilities and Deferred Revenue, Noncurrent	$ (263)	$ (268)
Variable Interest Entity, Primary Beneficiary [Member] | Williams Companies Inc [Member] | Northeast JV [Member]
Variable Interest Entity [Line Items]
Variable Interest Entity Ownership Percentage	65%
Variable Interest Entity, Primary Beneficiary [Member] | Williams Companies Inc [Member] | Gulfstar One [Member]
Variable Interest Entity [Line Items]
Variable Interest Entity Ownership Percentage	51%
Variable Interest Entity, Primary Beneficiary [Member] | Williams Companies Inc [Member] | Cardinal Gas Services LLC [Member]
Variable Interest Entity [Line Items]
Variable Interest Entity Ownership Percentage	66%
Variable Interest Entity, Not Primary Beneficiary [Member] | Williams Companies Inc [Member]
Variable Interest Entity [Line Items]
Equity-method investments	$ 72

Acquisitions (Details)

Acquisitions (Details) - USD ($) $ in Millions										1 Months Ended	2 Months Ended	3 Months Ended	5 Months Ended	8 Months Ended	11 Months Ended	12 Months Ended
		Jan. 03, 2025	Nov. 01, 2024	Aug. 01, 2024	Jan. 03, 2024	Nov. 30, 2023	Feb. 14, 2023	Aug. 31, 2022	Apr. 29, 2022	Dec. 31, 2023	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2024	Dec. 31, 2022	Dec. 31, 2023	Dec. 31, 2024	Dec. 31, 2024		Dec. 31, 2023		Dec. 31, 2022
Business Acquisition [Line Items]
Payments to Acquire Businesses, Net of Cash Acquired																	$ 2,244		$ 1,568		$ 933
Revenues																	10,503		10,907		10,965
Modified EBITDA Earnings Loss																	6,656		8,013		6,075
Gain on remeasurement of equity-method investment (Note 2)																	127		30		0
Goodwill										$ 463	$ 466	$ 463	$ 466	$ 0	$ 463	$ 466	466		463		0
Net income																	2,225		3,179		2,049
Payments to Acquire Productive Assets																	5,598		4,313		3,598
Pro Forma [Member]
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Revenue																	10,621		11,617		11,493
Business Acquisition, Pro Forma Net Income (Loss)																	2,228		3,273		2,250
Transmission And Gulf Of America [Member]
Business Acquisition [Line Items]
Goodwill										400	400	400	400	0	400	400	400		400		0
Transmission And Gulf Of America [Member] | NorTex Acquisition
Business Acquisition [Line Items]
Payments to Acquire Productive Assets								$ 424
West [Member]
Business Acquisition [Line Items]
Goodwill										$ 63	66	$ 63	66	$ 0	$ 63	66	66		$ 63		0
Crowheart Acquisition
Business Acquisition [Line Items]
Business Combination, Step Acquisition, Equity Interest in Acquiree, Percentage										75%		75%			75%				75%
Business Combination, Consideration Transferred			$ 307
Crowheart Acquisition | Pro Forma [Member]
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Revenue																	60	[1]	$ 74
Business Acquisition, Pro Forma Net Income (Loss)																	8	[1]	19
Crowheart Acquisition | Minimum [Member]
Business Acquisition [Line Items]
Business Combination Step Acquisition Equity Interest In Acquiree After Acquisition Percentage			90%
Crowheart Acquisition | Other Operating Segment
Business Acquisition [Line Items]
Revenues											20
Modified EBITDA Earnings Loss											$ 7
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Cash and Equivalents			$ 94
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Other			15
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment			400
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets			2
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets			511
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Other			(45)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Other			(115)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities			(160)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net			351
Discovery Acquisition
Business Acquisition [Line Items]
Business Combination, Consideration Transferred				$ 170
Business Combination, Step Acquisition, Equity Interest in Acquiree, Fair Value				381
Gain on remeasurement of equity-method investment (Note 2)				127													127		0		0
Discovery Acquisition | Pro Forma [Member]
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Revenue																	58	[1]	129
Business Acquisition, Pro Forma Net Income (Loss)																	(5)	[1]	$ (1)
Discovery Acquisition | Transmission And Gulf Of America [Member]
Business Acquisition [Line Items]
Revenues													144
Modified EBITDA Earnings Loss													$ 42
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Cash and Equivalents				22
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Other				19
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment				941
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets				39
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets				1,021
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Other				(40)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Other				(296)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities				(336)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net				$ 685
Discovery Acquisition | Transmission And Gulf Of America [Member] | Discovery Producer Services LLC [Member]
Business Acquisition [Line Items]
Business Combination, Step Acquisition, Equity Interest in Acquiree, Percentage										60%		60%			60%				60%
Business Acquisition, Percentage of Voting Interests Acquired				40%
Discovery Acquisition | Transmission And Gulf Of America [Member] | Selling, general and administrative expenses [Member]
Business Acquisition [Line Items]
Business Combination Acquisition Related Costs Cumulative																	1
Gulf Coast Storage Acquisition
Business Acquisition [Line Items]
Business Acquisition, Percentage of Voting Interests Acquired					100%
Business Combination, Consideration Transferred					$ 1,950
Business Combination, Consideration Transferred, Liabilities Incurred					100												100		$ 0
Gulf Coast Storage Acquisition | Pro Forma [Member]
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Revenue																			202
Business Acquisition, Pro Forma Net Income (Loss)																			53
Gulf Coast Storage Acquisition | Subsequent Event [Member]
Business Acquisition [Line Items]
Extinguishment of Debt, Amount		$ 100
Gulf Coast Storage Acquisition | Transmission And Gulf Of America [Member]
Business Acquisition [Line Items]
Revenues																228
Modified EBITDA Earnings Loss																$ 160
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Cash and Equivalents					46
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Other					18
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment					2,035
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets					2
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets					2,101
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Other					(11)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Other					(107)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities					(118)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net					$ 1,983
Gulf Coast Storage Acquisition | Transmission And Gulf Of America [Member] | Selling, general and administrative expenses [Member]
Business Acquisition [Line Items]
Business Combination Acquisition Related Costs Cumulative																	15
Business Combination, Acquisition Related Costs																	14
Cureton Acquisition
Business Acquisition [Line Items]
Business Acquisition, Percentage of Voting Interests Acquired						100%
Business Combination, Consideration Transferred						$ 546
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life						20 years
Percentage Of Finite Lived Intangible Assets Impacted By Our Intent Or Ability To Renew Or Extend Arrangement						24%
Acquired Finite-lived Intangible Asset, Weighted-Average Period before Renewal or Extension						10 years
Cureton Acquisition | West [Member]
Business Acquisition [Line Items]
Revenues										$ 35
Modified EBITDA Earnings Loss										7
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Cash and Equivalents						$ 6
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Other						21
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment						433
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Finite-Lived Intangibles						117
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets						1
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets						578
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Other						(29)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Other						(14)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities						(43)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net						535
Goodwill						11
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Net						546
Cureton Acquisition | West [Member] | Selling, general and administrative expenses [Member]
Business Acquisition [Line Items]
Business Combination Acquisition Related Costs Cumulative																	8
Business Combination, Acquisition Related Costs																			6
RMM Acquisition
Business Acquisition [Line Items]
Business Combination, Consideration Transferred						704
Business Combination, Consideration Transferred, Liabilities Incurred																	0		665
Extinguishment of Debt, Amount			$ 651
Business Combination, Step Acquisition, Equity Interest in Acquiree, Fair Value						$ 406
Gain on remeasurement of equity-method investment (Note 2)												$ 30					0		30		$ 0
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life						20 years
Percentage Of Finite Lived Intangible Assets Impacted By Our Intent Or Ability To Renew Or Extend Arrangement						18%
Acquired Finite-lived Intangible Asset, Weighted-Average Period before Renewal or Extension						10 years
RMM Acquisition | West [Member]
Business Acquisition [Line Items]
Revenues										53
Modified EBITDA Earnings Loss										$ 12
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Cash and Equivalents						$ 28
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Other						4
Business Combination Recognized Identifiable Assets Acquired And Liabilities Assumed Investments						20
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment						1,041
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Finite-Lived Intangibles						63
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets						12
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets						1,168
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Other						(44)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Other						(103)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities						(147)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net						1,021
Goodwill						55
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Net						1,076
Business Acquisition, Goodwill, Expected Tax Deductible Amount						$ 55
RMM Acquisition | West [Member] | Rocky Mountain Midstream Holdings LLC [Member]
Business Acquisition [Line Items]
Business Combination, Step Acquisition, Equity Interest in Acquiree, Percentage														50%							50%
Business Acquisition, Percentage of Voting Interests Acquired						50%
DJ Basin Acquisitions | Pro Forma [Member]
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Revenue																			270	[1]	$ 218
Business Acquisition, Pro Forma Net Income (Loss)																			17	[1]	13
MountainWest Acquisition
Business Acquisition [Line Items]
Business Acquisition, Percentage of Voting Interests Acquired							100%
Business Combination, Consideration Transferred							$ 1,080
Business Combination, Consideration Transferred, Liabilities Incurred							430
Payments to Acquire Businesses, Net of Cash Acquired																			1,024
MountainWest Acquisition | Pro Forma [Member]
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Revenue																			35	[1]	265
Business Acquisition, Pro Forma Net Income (Loss)																			6	[1]	170
MountainWest Acquisition | Transmission And Gulf Of America [Member]
Business Acquisition [Line Items]
Revenues															$ 225
Modified EBITDA Earnings Loss															122
Business Combination, Transition Related Costs															$ 27
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Cash and Equivalents							23
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Receivables							33
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Other							26
Business Combination Recognized Identifiable Assets Acquired And Liabilities Assumed Investments							20
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment							1,019
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets							33
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets							1,154
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Other							(47)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-Term Debt							(365)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Other							(95)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities							(507)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net							647
Goodwill							400
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Net							1,047
Business Acquisition, Goodwill, Expected Tax Deductible Amount							$ 400
MountainWest Acquisition | Transmission And Gulf Of America [Member] | Selling, general and administrative expenses [Member]
Business Acquisition [Line Items]
Business Combination Acquisition Related Costs Cumulative																	$ 18
Business Combination, Acquisition Related Costs																			$ 16
Trace Midstream Acquisition
Business Acquisition [Line Items]
Business Acquisition, Percentage of Voting Interests Acquired									100%
Business Combination, Consideration Transferred									$ 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 [Member]
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Revenue	[1]																				45
Business Acquisition, Pro Forma Net Income (Loss)	[1]																				$ 18
Trace Midstream Acquisition | West [Member]
Business Acquisition [Line Items]
Revenues														$ 148
Modified EBITDA Earnings Loss														73
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
Trace Midstream Acquisition | West [Member] | Selling, general and administrative expenses [Member]
Business Acquisition [Line Items]
Business Combination, Acquisition Related Costs														$ 8
[1] Excludes results from operations acquired in the acquisition for the period beginning on the acquisition date, as these results are included in the amounts as reported.

Divestitures (Details)

Divestitures (Details) - USD ($) $ in Millions		12 Months Ended
	Sep. 29, 2023	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Business Acquisition [Line Items]
Gain (Loss) on Disposition of Business		$ 0	$ 129	$ 0
Transmission And Gulf Of America [Member] | Certain Gulf Coast Liquids Pipelines
Business Acquisition [Line Items]
Disposal Group, Consideration	$ 348
Gain (Loss) on Disposition of Business	$ 129

Related Party Transactions - Wi

Related Party Transactions - Williams (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Related Party Transaction [Line Items]
Operating Costs and Expenses	$ 2,179	$ 1,984	$ 1,817
Accounts payable	1,613	1,379
Revenues	10,503	10,907	10,965
Investee
Related Party Transaction [Line Items]
Operating Costs and Expenses	266	776	1,300
Other Operating Income	2	5	76
Accounts Receivable, after Allowance for Credit Loss, Current	1	2
Accounts payable	19	33
OperatingFeesAndCostsBilledToThirdParty	52	64	65
Director
Related Party Transaction [Line Items]
Revenues	59	90	180
Cost of Revenue	$ 40	$ 25	$ 86

Related Party Transactions - Tr

Related Party Transactions - Transco and NWP (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Jan. 31, 2025	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Mar. 01, 2019
Related Party Transaction [Line Items]
Regulatory Liabilities		$ 1,385	$ 1,365
Employer's contributions charged to expense under defined contribution plan		69	60	$ 53
Accounts payable		$ 1,613	1,379
Related Party Transaction, Rate		4%
Revenues		$ 10,503	10,907	10,965
Transcontinental Gas Pipe Line Company, LLC [Member]
Related Party Transaction [Line Items]
Regulatory Liabilities		1,034	1,005
Employer's contributions charged to expense under defined contribution plan		13	12	11
Equity-based compensation expense		6	6	6
Interest Income, Other		58	87	36
Revenues		2,964	2,866	2,909
Credit To Expenses From Affiliates		6	14	10
Cash distributions to parent		1,145	1,220	838
Transcontinental Gas Pipe Line Company, LLC [Member] | Affiliated Entity
Related Party Transaction [Line Items]
Accounts and Financing Receivable, after Allowance for Credit Loss, Current		638	1,400
Interest Income, Other		51	81	31
Revenues		76	56	89
Related Party Transaction, Purchases from Related Party		5	7	18
Operating Expenses		344	324	345
Transcontinental Gas Pipe Line Company, LLC [Member] | Affiliated Entity | Subsequent Event [Member]
Related Party Transaction [Line Items]
Cash distributions to parent	$ 246
Transcontinental Gas Pipe Line Company, LLC [Member] | Pension Benefits [Member]
Related Party Transaction [Line Items]
Pension Cost (Reversal of Cost)		1	2	4
Regulatory Liability, Deferred For Future Rate Treatment		30	26
Regulatory Liability, Amortization Period					5 years
Transcontinental Gas Pipe Line Company, LLC [Member] | Other Postretirement Benefits [Member]
Related Party Transaction [Line Items]
Regulatory Liability, Amortization Period					5 years
Other Postretirement Benefits Cost (Reversal of Cost)		8	6	5
Regulatory Liabilities		31	31
Northwest Pipeline LLC [Member]
Related Party Transaction [Line Items]
Regulatory Liabilities		253	273
Employer's contributions charged to expense under defined contribution plan		3	3	3
Equity-based compensation expense		2	2	1
Interest Income, Other		2	1
Revenues		444	440	448
Operating Expenses		253	246	289
Cash distributions to parent		150	155	138
Northwest Pipeline LLC [Member] | Affiliated Entity
Related Party Transaction [Line Items]
Accounts and Financing Receivable, after Allowance for Credit Loss, Current			158
Accounts payable		26	0
Interest Income, Other		5	8	5
Operating Expenses		91	86	88
Northwest Pipeline LLC [Member] | Affiliated Entity | Subsequent Event [Member]
Related Party Transaction [Line Items]
Cash distributions to parent	24
Northwest Pipeline LLC [Member] | Pension Benefits [Member]
Related Party Transaction [Line Items]
Pension Cost (Reversal of Cost)		1	0	1
Northwest Pipeline LLC [Member] | Other Postretirement Benefits [Member]
Related Party Transaction [Line Items]
Other Postretirement Benefits Cost (Reversal of Cost)		1	0	$ 1
Regulatory Liabilities		$ 43	$ 42
Williams Companies Inc [Member] | Affiliated Entity | Subsequent Event [Member]
Related Party Transaction [Line Items]
Cash distributions to parent	$ 85

Revenue by Category (Details)

Revenue by Category (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		$ 12,632	$ 11,996	$ 17,773
Revenue Not from Contract with Customer, Other	[1]	2,348	4,537	7,935
Revenues Adjustments For Certain Risk Management Activities Costs	[2]	(4,477)	(5,626)	(14,743)
Total revenues		10,503	10,907	10,965
Regulated Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		3,419	3,274	3,067
NonRegulated Service Monetary Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		3,970	3,533	3,258
NonRegulated Service Commodity Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		134	146	260
Total revenues		134	146	260
Other Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		140	115	122
Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		7,663	7,068	6,707
Total revenues		7,628	7,026	6,536
Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		4,969	4,928	11,066
Total revenues		2,991	2,779	4,556
Operating Segments [Member] | Transmission And Gulf Of America [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		4,589	4,097	4,009
Revenue Not from Contract with Customer, Other	[1]	39	53	38
Revenues Adjustments For Certain Risk Management Activities Costs	[2]	0	0	0
Total revenues		4,628	4,150	4,047
Operating Segments [Member] | Transmission And Gulf Of America [Member] | Regulated Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		3,500	3,334	3,139
Operating Segments [Member] | Transmission And Gulf Of America [Member] | NonRegulated Service Monetary Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		661	443	381
Operating Segments [Member] | Transmission And Gulf Of America [Member] | NonRegulated Service Commodity Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		54	38	64
Total revenues		54	38	64
Operating Segments [Member] | Transmission And Gulf Of America [Member] | Other Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		46	30	21
Operating Segments [Member] | Transmission And Gulf Of America [Member] | Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		4,261	3,845	3,605
Total revenues		4,246	3,858	3,579
Operating Segments [Member] | Transmission And Gulf Of America [Member] | Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		328	252	404
Total revenues		328	252	404
Operating Segments [Member] | Northeast G And P [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		1,982	2,006	1,776
Revenue Not from Contract with Customer, Other	[1]	43	27	26
Revenues Adjustments For Certain Risk Management Activities Costs	[2]	0	0	0
Total revenues		2,025	2,033	1,802
Operating Segments [Member] | Northeast G And P [Member] | Regulated Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0
Operating Segments [Member] | Northeast G And P [Member] | NonRegulated Service Monetary Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		1,778	1,782	1,526
Operating Segments [Member] | Northeast G And P [Member] | NonRegulated Service Commodity Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		2	5	14
Total revenues		2	5	14
Operating Segments [Member] | Northeast G And P [Member] | Other Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		92	87	102
Operating Segments [Member] | Northeast G And P [Member] | Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		1,872	1,874	1,642
Total revenues		1,913	1,896	1,654
Operating Segments [Member] | Northeast G And P [Member] | Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		110	132	134
Total revenues		110	132	134
Operating Segments [Member] | West [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		2,661	2,034	2,553
Revenue Not from Contract with Customer, Other	[1]	8	101	8
Revenues Adjustments For Certain Risk Management Activities Costs	[2]	0	0	0
Total revenues		2,669	2,135	2,561
Operating Segments [Member] | West [Member] | Regulated Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0
Operating Segments [Member] | West [Member] | NonRegulated Service Monetary Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		1,693	1,478	1,518
Operating Segments [Member] | West [Member] | NonRegulated Service Commodity Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		78	103	182
Total revenues		78	103	182
Operating Segments [Member] | West [Member] | Other Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		21	12	12
Operating Segments [Member] | West [Member] | Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		1,792	1,593	1,712
Total revenues		1,718	1,502	1,542
Operating Segments [Member] | West [Member] | Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		869	441	841
Total revenues		869	441	841
Operating Segments [Member] | Gas & NGL Marketing Services
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		4,530	4,616	10,771
Revenue Not from Contract with Customer, Other	[1]	2,236	4,294	7,929
Revenues Adjustments For Certain Risk Management Activities Costs	[2]	(4,977)	(6,032)	(15,467)
Total revenues	[3]	1,789	2,878	3,233
Operating Segments [Member] | Gas & NGL Marketing Services | Regulated Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0
Operating Segments [Member] | Gas & NGL Marketing Services | NonRegulated Service Monetary Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0
Operating Segments [Member] | 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
Total revenues	[3]	0	0	0
Operating Segments [Member] | Gas & NGL Marketing Services | Other Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	1	3
Operating Segments [Member] | Gas & NGL Marketing Services | Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	1	3
Total revenues	[3]	0	1	3
Operating Segments [Member] | Gas & NGL Marketing Services | Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		4,530	4,615	10,768
Total revenues	[3]	2,052	2,060	3,534
Corporate, Non-Segment | Other Operating Segment
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		420	442	706
Revenue Not from Contract with Customer, Other	[1]	24	64	(55)
Revenues Adjustments For Certain Risk Management Activities Costs	[2]	0	0	0
Total revenues		444	506	651
Corporate, Non-Segment | Other Operating Segment | Regulated Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0
Corporate, Non-Segment | Other Operating Segment | NonRegulated Service Monetary Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0
Corporate, Non-Segment | Other Operating Segment | NonRegulated Service Commodity Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0
Corporate, Non-Segment | Other Operating Segment | Other Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0
Corporate, Non-Segment | Other Operating Segment | Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0
Corporate, Non-Segment | Other Operating Segment | Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		420	442	706
Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		(1,550)	(1,199)	(2,042)
Revenue Not from Contract with Customer, Other	[1]	(2)	(2)	(11)
Revenues Adjustments For Certain Risk Management Activities Costs	[2]	500	406	724
Total revenues		(1,052)	(795)	(1,329)
Intersegment Eliminations [Member] | Regulated Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		(81)	(60)	(72)
Intersegment Eliminations [Member] | NonRegulated Service Monetary Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		(162)	(170)	(167)
Intersegment Eliminations [Member] | NonRegulated Service Commodity Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0
Intersegment Eliminations [Member] | Other Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		(19)	(15)	(16)
Intersegment Eliminations [Member] | Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		(262)	(245)	(255)
Intersegment Eliminations [Member] | Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		$ (1,288)	$ (954)	$ (1,787)
[1] Revenues not derived from contracts with customers primarily consist of physical product sales related to commodity derivative contracts, realized and unrealized gains and losses associated with Williams’ commodity derivative contracts, which are reported in Net gain (loss) from commodity derivatives in the Consolidated Statement of Income, management fees received for certain services provided to operated equity-method investments, and leasing revenues associated with the Williams headquarters building. Other adjustments reflect certain costs of Gas & NGL Marketing Services’ risk management activities. As Williams is acting as agent for natural gas marketing customers or engages in energy trading activities, the resulting revenues are presented net of the related costs of those activities in the Consolidated Statement of Income.

Revenue Recognition Contract As

Revenue Recognition Contract Assets (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Contract With Customer, Asset [Line Items]
Contract with Customer, Asset, Net - Beginning of Period	$ 36	$ 29
Contract with Customer, Asset, Cumulative Catch-up Adjustment to Revenue, Change in Measure of Progress	170	183
Contract with Customer, Asset, Reclassified to Receivable	(144)	(176)
Contract with Customer, Asset, Increase (Decrease) for Contract Acquired in Business Combination	36	0
Contract with Customer, Asset, Net - End of Period	98	36
Transcontinental Gas Pipe Line Company, LLC [Member]
Contract With Customer, Asset [Line Items]
Contract with Customer, Asset, Net - Beginning of Period	0	0
Contract with Customer, Asset, Cumulative Catch-up Adjustment to Revenue, Change in Measure of Progress	10	0
Contract with Customer, Asset, Net - End of Period	10	0
Northwest Pipeline LLC [Member]
Contract With Customer, Asset [Line Items]
Contract with Customer, Asset, Net - Beginning of Period	17	13
Contract with Customer, Asset, Cumulative Catch-up Adjustment to Revenue, Change in Measure of Progress	6	6
Contract with Customer, Asset, Reclassified to Receivable	(2)	(2)
Contract with Customer, Asset, Net - End of Period	$ 21	$ 17

Revenue Recognition Contract Li

Revenue Recognition Contract Liabilities (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Contract With Customer, Liability [Line Items]
Contract with Customer, Liability - Beginning of Period	$ 1,081	$ 1,043
Contract with Customer, Liability, Cumulative Catch-up Adjustment to Revenue, Change in Measure of Progress	183	190
Other Significant Noncash Transaction, Value of Consideration Received	8	9
Contract with Customer, Liability, Increase (Decrease) for Contract Acquired in Business Combination	53	115
Contract with Customer, Liability, Revenue Recognized	(279)	(276)
Contract with Customer, Liability - End of Period	1,046	1,081
Transcontinental Gas Pipe Line Company, LLC [Member]
Contract With Customer, Liability [Line Items]
Contract with Customer, Liability - Beginning of Period	184	194
Contract with Customer, Liability, Revenue Recognized	(11)	(10)
Contract with Customer, Liability - End of Period	173	184
Northwest Pipeline LLC [Member]
Contract With Customer, Liability [Line Items]
Contract with Customer, Liability - Beginning of Period	2	3
Contract with Customer, Liability, Revenue Recognized	(2)	(1)
Contract with Customer, Liability - End of Period	$ 0	$ 2

Revenue Recognition Contract _2

Revenue Recognition Contract Liabilities Performance Obligations (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	$ 1,046	$ 1,081	$ 1,043
Transcontinental Gas Pipe Line Company, LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	173	184	194
Northwest Pipeline LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	0	$ 2	$ 3
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	173
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 | Transcontinental Gas Pipe Line Company, LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	10
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 | Northwest Pipeline LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	0
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	146
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01 | Transcontinental Gas Pipe Line Company, LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	10
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01 | Northwest Pipeline LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	0
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	141
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01 | Transcontinental Gas Pipe Line Company, LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	11
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01 | Northwest Pipeline LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	0
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	118
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01 | Transcontinental Gas Pipe Line Company, LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	11
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01 | Northwest Pipeline LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	0
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	100
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01 | Transcontinental Gas Pipe Line Company, LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	11
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01 | Northwest Pipeline LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	0
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2030-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	368
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2030-01-01 | Transcontinental Gas Pipe Line Company, LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	120
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2030-01-01 | Northwest Pipeline LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	$ 0
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]: 2025-01-01 | Transcontinental Gas Pipe Line Company, LLC [Member]
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 | Northwest Pipeline LLC [Member]
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]: 2026-01-01 | Transcontinental Gas Pipe Line Company, LLC [Member]
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 | Northwest Pipeline LLC [Member]
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]: 2027-01-01 | Transcontinental Gas Pipe Line Company, LLC [Member]
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 | Northwest Pipeline LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Performance Obligations Related To Contract Liabilities [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Performance Obligations Related To Contract Liabilities [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01 | Transcontinental Gas Pipe Line Company, LLC [Member]
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 | Northwest Pipeline LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Performance Obligations Related To Contract Liabilities [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Performance Obligations Related To Contract Liabilities [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01 | Transcontinental Gas Pipe Line Company, LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Performance Obligations Related To Contract Liabilities [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01 | Northwest Pipeline LLC [Member]
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]: 2030-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period
Performance Obligations Related To Contract Liabilities [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2030-01-01 | Transcontinental Gas Pipe Line Company, LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period
Performance Obligations Related To Contract Liabilities [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2030-01-01 | Northwest Pipeline LLC [Member]
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	Dec. 31, 2024 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 31,059
Transcontinental Gas Pipe Line Company, LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	21,598
Northwest Pipeline LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	4,101
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	4,132
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 | Transcontinental Gas Pipe Line Company, LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	2,726
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 | Northwest Pipeline LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	391
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	3,860
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01 | Transcontinental Gas Pipe Line Company, LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	2,536
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01 | Northwest Pipeline LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	386
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	3,623
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01 | Transcontinental Gas Pipe Line Company, LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	2,438
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01 | Northwest Pipeline LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	373
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	2,778
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01 | Transcontinental Gas Pipe Line Company, LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	1,784
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01 | Northwest Pipeline LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	368
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	2,564
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01 | Transcontinental Gas Pipe Line Company, LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	1,693
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01 | Northwest Pipeline LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	349
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2030-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	14,102
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2030-01-01 | Transcontinental Gas Pipe Line Company, LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	10,421
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2030-01-01 | Northwest Pipeline LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 2,234
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]: 2025-01-01 | Transcontinental Gas Pipe Line Company, LLC [Member]
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 | Northwest Pipeline LLC [Member]
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]: 2026-01-01 | Transcontinental Gas Pipe Line Company, LLC [Member]
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 | Northwest Pipeline LLC [Member]
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]: 2027-01-01 | Transcontinental Gas Pipe Line Company, LLC [Member]
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 | Northwest Pipeline LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Remaining Performance Obligations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Remaining Performance Obligations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01 | Transcontinental Gas Pipe Line Company, LLC [Member]
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 | Northwest Pipeline LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Remaining Performance Obligations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Remaining Performance Obligations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01 | Transcontinental Gas Pipe Line Company, LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Remaining Performance Obligations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01 | Northwest Pipeline LLC [Member]
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]: 2030-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period
Remaining Performance Obligations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2030-01-01 | Transcontinental Gas Pipe Line Company, LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period
Remaining Performance Obligations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2030-01-01 | Northwest Pipeline LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period

Provision (Benefit) for Incom_3

Provision (Benefit) for Income Taxes Tax Provison (Benefit) Table (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Current :
Federal	$ 125	$ 3	$ (25)
State	9	21	19
Total	134	24	(6)
Deferred:
Federal	472	872	424
State	34	109	7
Total	506	981	431
Less: Provision (benefit) for income taxes	$ 640	$ 1,005	$ 425

Provision (Benefit) for Incom_4

Provision (Benefit) for Income Taxes Reconciliations to Recorded Tax Provision (Benefit) Table (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Effective Income Tax Rate Reconciliation [Abstract]
Provision (benefit) at statutory rate	$ 627	$ 925	$ 534
Increases (decreases) in taxes resulting from:
State income taxes (net of federal benefit)	79	129	113
State deferred income tax rate change	(44)	(25)	(92)
Federal valuation allowance	0	0	(70)
Federal settlements	0	0	(45)
Impact of nontaxable noncontrolling interests	(25)	(26)	(14)
Other – net	3	2	(1)
Less: Provision (benefit) for income taxes	$ 640	$ 1,005	$ 425

Provision (Benefit) for Incom_5

Provision (Benefit) for Income Taxes Deferred Tax Table (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Gross deferred income tax liabilities:
Property, plant and equipment	$ 4,501	$ 3,541
Investments	1,733	1,740
Other	193	146
Total gross deferred income tax liabilities	6,427	5,427
Gross deferred income tax assets:
Accrued liabilities	1,146	868
Corporate alternative minimum tax credits	108	0
Foreign tax credits	0	35
Federal loss carryovers	325	398
Disallowed business interest expense carryforward	247	67
State losses and credits	224	293
Other	92	103
Total gross deferred income tax assets	2,142	1,764
Less valuation allowance	91	183
Net deferred income tax assets	2,051	1,581
Deferred income tax liabilities	$ 4,376	$ 3,846

Provision (Benefit) for Incom_6

Provision (Benefit) for Income Taxes Textuals (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Income Tax Contingency [Line Items]
State deferred income tax rate change	$ (44)	$ (25)	$ (92)
Deferred Tax Assets, Tax Credit Carryforwards, Foreign, Expired	35
Income Taxes Paid	68	31	13
Total interest and penalties accrued as uncertain tax positions	$ 0	0
Internal Revenue Service (IRS) [Member]
Income Tax Contingency [Line Items]
Income Taxes Paid		$ 5
Tax Adjustments, Settlements, and Unusual Provisions			45
Proceeds from Income Tax Refunds			$ 7

EBPs Funded Status (Details)

EBPs Funded Status (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Defined Contribution Plan
Percentage of eligible compensation the employer will match of employee contributions		6%
Employer's contributions charged to expense under defined contribution plan		$ 69	$ 60	$ 53
Pension Benefits [Member]
Change in benefit obligation:
Benefit obligation at beginning of year		1,006	940
Service cost		25	23	28
Interest cost		47	46	31
Plan participants’ contributions		0	0
Benefits paid		(73)	(71)
Net actuarial loss (gain) (1)	[1]	(65)	68
Settlements		(3)	0
Net increase (decrease) in benefit obligation		(69)	66
Benefit obligation at end of year		937	1,006	940
Other Postretirement Benefits [Member]
Change in benefit obligation:
Benefit obligation at beginning of year		145	152
Service cost		1	1	1
Interest cost		7	7	6
Plan participants’ contributions		2	2
Benefits paid		(11)	(13)
Net actuarial loss (gain) (1)	[1]	(12)	(4)
Settlements		0	0
Net increase (decrease) in benefit obligation		(13)	(7)
Benefit obligation at end of year		$ 132	$ 145	$ 152
[1]2024 amounts are due primarily to changes in the following factors: Pension Benefits - discount rate assumptions and interest crediting rate assumption; Other Postretirement Benefits - discount rate assumption. 2023 amounts are due primarily to changes in the following factors: Pension Benefits - interest crediting rate assumption and discount rate assumptions.

EBP Asset rollforward and B.S.

EBP Asset rollforward and B.S. classification (Details 1) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Amounts included in regulatory liabilities associated with Transco and Northwest Pipeline:
Net regulatory liabilities	$ 139	$ 123
Pension Benefits [Member]
Change in plan assets:
Fair value of plan assets at beginning of year	1,167	1,117
Actual return on plan assets	88	120
Employer contributions	4	1
Plan participants’ contributions	0	0
Benefits paid	(73)	(71)
Settlements	(3)	0
Net increase (decrease) in fair value of plan assets	16	50
Fair value of plan assets at end of year	1,183	1,167
Funded status — overfunded (underfunded)	246	161
Amounts recognized in the Consolidated Balance Sheet:
Noncurrent assets	270	187
Current liabilities	(4)	(4)
Noncurrent liabilities	(20)	(22)
Funded status - overfunded (underfunded)	246	161
Accumulated benefit obligation	929	998
Plans with a projected benefit obligation in excess of plan assets:
Projected benefit obligation	23	26
Plans with an accumulated benefit obligation in excess of plan assets:
Accumulated benefit obligation	22	24
Fair value of plan assets	0	0
Amounts recognized in Accumulated other comprehensive income (loss):
Net actuarial gain (loss)	49	(45)
Other Postretirement Benefits [Member]
Change in plan assets:
Fair value of plan assets at beginning of year	262	253
Actual return on plan assets	16	17
Employer contributions	3	3
Plan participants’ contributions	2	2
Benefits paid	(11)	(13)
Settlements	0	0
Net increase (decrease) in fair value of plan assets	10	9
Fair value of plan assets at end of year	272	262
Funded status — overfunded (underfunded)	140	117
Amounts recognized in the Consolidated Balance Sheet:
Noncurrent assets	143	120
Current liabilities	(3)	(3)
Noncurrent liabilities	0	0
Funded status - overfunded (underfunded)	140	117
Amounts recognized in Accumulated other comprehensive income (loss):
Net actuarial gain (loss)	$ 20	$ 19

EBP Net Periodic Benefit Cost &

EBP Net Periodic Benefit Cost & OCI (Details 2) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Pension Benefits [Member]
Components of net periodic benefit cost (credit):
Service cost		$ 25	$ 23	$ 28
Interest cost		47	46	31
Expected return on plan assets		(60)	(57)	(44)
Amortization of net actuarial loss (gain)		0	5	12
Net actuarial loss from settlements		1	0	3
Reclassification to regulatory liability		0	0	0
Net periodic benefit cost (credit) (1)	[1]	13	17	30
Items Recognized in Other Comprehensive Income (Loss)
Net actuarial gain (loss) arising during the year		93	(5)	(14)
Amortization of net actuarial loss (gain)		0	5	12
Net actuarial loss from settlements		1	0	3
Total recognized in Other comprehensive income (loss)		94	0	1
Other Postretirement Benefits [Member]
Components of net periodic benefit cost (credit):
Service cost		1	1	1
Interest cost		7	7	6
Expected return on plan assets		(11)	(10)	(10)
Amortization of net actuarial loss (gain)		(5)	(3)	0
Net actuarial loss from settlements		0	0	0
Reclassification to regulatory liability		0	0	1
Net periodic benefit cost (credit) (1)	[1]	(8)	(5)	(2)
Items Recognized in Other Comprehensive Income (Loss)
Net actuarial gain (loss) arising during the year		3	3	14
Amortization of net actuarial loss (gain)		(2)	(2)	0
Net actuarial loss from settlements		0	0	0
Total recognized in Other comprehensive income (loss)		$ 1	$ 1	$ 14
[1]Components other than Service cost are included in Other income (expense) – net below Operating income (loss) in Williams’ Consolidated Statement of Income

EBP Key Assumptions (Details 3)

EBP Key Assumptions (Details 3)	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Pension Benefits [Member]
Weighted average assumptions utilized to determine benefit obligations
Discount rate	5.60%	4.98%	5.16%
Rate of compensation increase	3.48%	3.52%	3.58%
Cash balance interest crediting rate	4%	4.50%	3.50%
Weighted average assumptions utilized to determine net periodic benefit cost (credit)
Discount rate	4.98%	5.16%	2.84%
Expected long-term rate of return on plan assets	5.31%	5.17%	3.81%
Rate of compensation increase	3.52%	3.58%	3.67%
Cash balance interest crediting rate	4.50%	3.50%	3%
Other Postretirement Benefits [Member]
Weighted average assumptions utilized to determine benefit obligations
Discount rate	5.67%	5.01%	5.20%
Weighted average assumptions utilized to determine net periodic benefit cost (credit)
Discount rate	5.01%	5.20%	2.93%
Expected long-term rate of return on plan assets	4.16%	4.04%	3.67%
Health care cost trend rate assumed for next fiscal year	9.20%
Direction and pattern of change for assumed health care cost trend rate	decreases
Ultimate health care cost trend rate	4.50%
Year that rate reaches ultimate trend rate	2034

EBP Plan Assets (Details 4)

EBP Plan Assets (Details 4) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Maximum [Member]
Defined Benefit Plan Disclosure [Line Items]
Redemption notification periods for commingled investment funds		15 days
Minimum [Member]
Defined Benefit Plan Disclosure [Line Items]
Redemption notification periods for commingled investment funds		1 day
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value		$ 1,183	$ 1,167	$ 1,117
Pension Benefits [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value	[1]	104	80
Pension Benefits [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value	[2]	318	333
Pension Benefits [Member] | Fair Value, Inputs, Level 1, 2 and 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value		$ 422	413
Pension Benefits [Member] | Equity securities
Defined Benefit Plan Disclosure [Line Items]
Plan asset target allocation		25%
Pension Benefits [Member] | Fixed income securities
Defined Benefit Plan Disclosure [Line Items]
Plan asset target allocation		75%
Pension Benefits [Member] | Cash management funds | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value	[1]	$ 29	17
Pension Benefits [Member] | Cash management funds | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value	[2]	0	0
Pension Benefits [Member] | Cash management funds | Fair Value, Inputs, Level 1, 2 and 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value		29	17
Pension Benefits [Member] | Government debt securities | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value	[1]	74	61
Pension Benefits [Member] | Government debt securities | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value	[2]	19	17
Pension Benefits [Member] | Government debt securities | Fair Value, Inputs, Level 1, 2 and 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value		93	78
Pension Benefits [Member] | Corporate debt securities | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value	[1]	0	0
Pension Benefits [Member] | Corporate debt securities | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value	[2]	295	311
Pension Benefits [Member] | Corporate debt securities | Fair Value, Inputs, Level 1, 2 and 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value		295	311
Pension Benefits [Member] | Other | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value	[1]	1	2
Pension Benefits [Member] | Other | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value	[2]	4	5
Pension Benefits [Member] | Other | Fair Value, Inputs, Level 1, 2 and 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value		5	7
Pension Benefits [Member] | Commingled investment funds - equities | Fair Value Measured at Net Asset Value Per Share [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value	[3]	292	287
Pension Benefits [Member] | Commingled investment funds - fixed income | Fair Value Measured at Net Asset Value Per Share [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value	[3]	469	467
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value		272	262	$ 253
Other Postretirement Benefits [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value	[1]	114	109
Other Postretirement Benefits [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value	[2]	46	46
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 1, 2 and 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value		160	155
Other Postretirement Benefits [Member] | Cash management funds | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value	[1]	103	99
Other Postretirement Benefits [Member] | Cash management funds | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value	[2]	0	0
Other Postretirement Benefits [Member] | Cash management funds | Fair Value, Inputs, Level 1, 2 and 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value		103	99
Other Postretirement Benefits [Member] | Government debt securities | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value	[1]	11	9
Other Postretirement Benefits [Member] | Government debt securities | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value	[2]	3	2
Other Postretirement Benefits [Member] | Government debt securities | Fair Value, Inputs, Level 1, 2 and 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value		14	11
Other Postretirement Benefits [Member] | Corporate debt securities | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value	[1]	0	0
Other Postretirement Benefits [Member] | Corporate debt securities | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value	[2]	43	44
Other Postretirement Benefits [Member] | Corporate debt securities | Fair Value, Inputs, Level 1, 2 and 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value		43	44
Other Postretirement Benefits [Member] | Other | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value	[1]	0	1
Other Postretirement Benefits [Member] | Other | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value	[2]	0	0
Other Postretirement Benefits [Member] | Other | Fair Value, Inputs, Level 1, 2 and 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value		0	1
Other Postretirement Benefits [Member] | Commingled investment funds - equities | Fair Value Measured at Net Asset Value Per Share [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value	[3]	43	41
Other Postretirement Benefits [Member] | Commingled investment funds - fixed income | Fair Value Measured at Net Asset Value Per Share [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets at fair value	[3]	$ 69	$ 66
[1]Level 1 includes assets with fair values based on quoted prices in active markets for identical assets. Cash management funds and U.S. Treasury securities are included in this level.[2]Level 2 includes assets with fair values determined by using significant other observable inputs. This level includes fixed income securities, other than U.S. Treasury securities, that are valued primarily using pricing models which incorporate observable inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads.[3]The commingled investment funds are measured at fair value using net asset value per share. Certain standard withdrawal restrictions generally apply, which may include redemption notification periods ranging from 1 day to 15 days.

EBP Benefit Pymts & Employer Co

EBP Benefit Pymts & Employer Contributions (Details 5) $ in Millions	Dec. 31, 2024 USD ($)
Pension Benefits [Member]
Expected benefit payments
2025	$ 101
2026	95
2027	91
2028	87
2029	83
2030-2034	389
Expected total plans contribution, approximate	1
Other Postretirement Benefits [Member]
Expected benefit payments
2025	11
2026	11
2027	11
2028	11
2029	10
2030-2034	48
Expected total plans contribution, approximate	$ 3

Investing Activities (Details)

Investing Activities (Details) - USD ($) $ in Millions			3 Months Ended	12 Months Ended
		Aug. 01, 2024	Dec. 31, 2023	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Schedule of Investments [Line Items]
Equity-method investments			$ 4,614	$ 4,107	$ 4,614	$ 5,048
Equity-method investment, difference between carrying amount and underlying equity			773	634	773
Equity-method investment, payments to purchase or contributions				114	141	166
Distributions from equity-method investees (Note 8)				789	796	865
Current assets			4,513	2,661	4,513	3,797
Current liabilities			(5,830)	(5,312)	(5,830)
Revenues				10,503	10,907	10,965
Net income				2,346	3,303	2,117
Proceeds from dispositions of equity-method investments (Note 8)				161	0	0
Equity Method Investment, Realized Gain (Loss) on Disposal				149	0	0
Gain on remeasurement of equity-method investment (Note 2)				127	30	0
Investment Income, Interest				67	79	15
Investment Income Nonoperating Other				0	(1)	1
Other investing income (loss) - net				343	108	16
Equity Method Investment, Nonconsolidated Investee or Group of Investees [Member]
Schedule of Investments [Line Items]
Current assets			669	564	669
Noncurrent assets			11,058	9,439	11,058
Current liabilities			(358)	(1,146)	(358)
Noncurrent liabilities			(3,619)	(2,383)	(3,619)
Revenues				2,880	3,714	5,520
Operating income				1,190	966	1,268
Net income				$ 987	748	1,102
Appalachia Midstream Investments [Member]
Schedule of Investments [Line Items]
Equity Method Investment, Ownership Percentage				66%
Equity-method investments	[1]		2,886	$ 2,810	2,886
Equity-method investment, difference between carrying amount and underlying equity			1,100	1,000	1,100
Equity-method investment, payments to purchase or contributions				74	59	83
Distributions from equity-method investees (Note 8)				$ 407	405	415
Blue Racer Midstream LLC [Member]
Schedule of Investments [Line Items]
Equity Method Investment, Ownership Percentage				50%
Equity-method investments			398	$ 366	398
Distributions from equity-method investees (Note 8)				$ 95	62	49
Blue Racer Midstream LLC [Member] | Northeast G And P [Member]
Schedule of Investments [Line Items]
Equity Method Investment, Ownership Percentage				50%
Overland Pass Pipeline Company LLC [Member]
Schedule of Investments [Line Items]
Equity Method Investment, Ownership Percentage				50%
Equity-method investments			387	$ 385	387
Equity-method investment, payments to purchase or contributions				2	1	0
Distributions from equity-method investees (Note 8)				$ 90	56	34
Discovery Producer Services LLC [Member]
Schedule of Investments [Line Items]
Equity Method Investment, Ownership Percentage				100%
Equity-method investments	[2]		361	$ 0	361
Equity-method investment, payments to purchase or contributions				37	40	41
Distributions from equity-method investees (Note 8)				$ 22	49	49
Gulfstream Natural Gas System, LLC [Member]
Schedule of Investments [Line Items]
Equity Method Investment, Ownership Percentage				50%
Equity-method investments			210	$ 196	210
Equity-method investment, payments to purchase or contributions				0	0	14
Distributions from equity-method investees (Note 8)				$ 103	98	89
Laurel Mountain Midstream, LLC [Member]
Schedule of Investments [Line Items]
Equity Method Investment, Ownership Percentage				69%
Equity-method investments			184	$ 171	184
Distributions from equity-method investees (Note 8)				$ 29	42	112
Laurel Mountain Midstream, LLC [Member] | Northeast G And P [Member]
Schedule of Investments [Line Items]
Equity Method Investment, Ownership Percentage				69%
Rocky Mountain Midstream Holdings LLC [Member]
Schedule of Investments [Line Items]
Distributions from equity-method investees (Note 8)				$ 0	49	52
Other [Member]
Schedule of Investments [Line Items]
Equity-method investments			188	179	188
Equity-method investment, payments to purchase or contributions				0	3	12
Distributions from equity-method investees (Note 8)				43	35	65
Aux Sable Liquid Products LP [Member]
Schedule of Investments [Line Items]
Equity-method investment, payments to purchase or contributions				1	38	0
Cardinal Pipeline Company, LLC
Schedule of Investments [Line Items]
Equity-method investment, payments to purchase or contributions				0	0	16
Aux Sable Liquid Products Inc And Aux Sable Liquid Products LP And Aux Sable Midstream LLC | Northeast G And P [Member]
Schedule of Investments [Line Items]
Proceeds from dispositions of equity-method investments (Note 8)		$ 161
Equity Method Investment, Realized Gain (Loss) on Disposal		149		149	0	0
RMM Acquisition
Schedule of Investments [Line Items]
Gain on remeasurement of equity-method investment (Note 2)			$ 30	0	30	0
Discovery Acquisition
Schedule of Investments [Line Items]
Gain on remeasurement of equity-method investment (Note 2)		$ 127		$ 127	$ 0	$ 0
[1]Includes equity-method investments in multiple gathering systems in the Marcellus Shale region with an approximate average 66 percent interest.[2] Discovery is a wholly owned subsidiary of Williams as of August 1, 2024. See Note 3 – Acquisitions and Divestitures.

Property, Plant, and Equipmen_2

Property, Plant, and Equipment (Details PPE) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Property, Plant, and Equipment
Property, plant, and equipment, at cost		$ 57,395	$ 51,842
Accumulated depreciation and amortization		(18,703)	(17,531)
Property, plant, and equipment - net		38,692	34,311
Depreciation and amortization expenses		1,800	1,700	$ 1,500
Interest Costs Capitalized		68	54	20
Finite-Lived Intangible Assets, Gross		10,512	10,510
Transcontinental Gas Pipe Line Company, LLC [Member]
Property, Plant, and Equipment
Property, plant, and equipment, at cost		20,044	19,293
Accumulated depreciation and amortization		(5,941)	(5,963)
Property, plant, and equipment - net		14,103	13,330
Finite-Lived Intangible Assets, Gross		1,500
Transcontinental Gas Pipe Line Company, LLC [Member] | Onshore Transmission Facilities
Property, Plant, and Equipment
Property, plant, and equipment, at cost		17,242	16,031
Transcontinental Gas Pipe Line Company, LLC [Member] | Offshore Transmission Facilities
Property, Plant, and Equipment
Property, plant, and equipment, at cost		$ 659	681
Property, Plant, and Equipment, Depreciation Rate	[1]	1.25%
Transcontinental Gas Pipe Line Company, LLC [Member] | Storage Facilities
Property, Plant, and Equipment
Property, plant, and equipment, at cost		$ 948	830
Transcontinental Gas Pipe Line Company, LLC [Member] | Gathering Facilities
Property, Plant, and Equipment
Property, plant, and equipment, at cost		136	158
Northwest Pipeline LLC [Member]
Property, Plant, and Equipment
Property, plant, and equipment, at cost		4,218	3,975
Accumulated depreciation and amortization		(2,089)	(2,026)
Property, plant, and equipment - net		2,129	1,949
Depreciation and amortization expenses		111	111	$ 114
Northwest Pipeline LLC [Member] | Storage Facilities
Property, Plant, and Equipment
Property, plant, and equipment, at cost		160	155
Construction in Progress [Member] | Transcontinental Gas Pipe Line Company, LLC [Member]
Property, Plant, and Equipment
Property, plant, and equipment, at cost		420	1,008
Construction in Progress [Member] | Northwest Pipeline LLC [Member]
Property, Plant, and Equipment
Property, plant, and equipment, at cost		66	85
Other Capitalized Property Plant and Equipment [Member] | Transcontinental Gas Pipe Line Company, LLC [Member]
Property, Plant, and Equipment
Property, plant, and equipment, at cost		639	585
Other Capitalized Property Plant and Equipment [Member] | Northwest Pipeline LLC [Member]
Property, Plant, and Equipment
Property, plant, and equipment, at cost		171	165
Natural gas transmission facilities [Member] | Northwest Pipeline LLC [Member]
Property, Plant, and Equipment
Property, plant, and equipment, at cost		3,821	3,570
Nonregulated [Member] | Natural gas gathering and processing facilities [Member]
Property, Plant, and Equipment
Property, plant, and equipment, at cost		23,134	21,357
Nonregulated [Member] | Construction in Progress [Member]
Property, Plant, and Equipment
Property, plant, and equipment, at cost		1,543	1,138
Nonregulated [Member] | Oil and Gas Properties
Property, Plant, and Equipment
Property, plant, and equipment, at cost		1,685	1,111
Nonregulated [Member] | Other Capitalized Property Plant and Equipment [Member]
Property, Plant, and Equipment
Property, plant, and equipment, at cost		4,798	3,268
Regulated [Member] | Construction in Progress [Member]
Property, Plant, and Equipment
Property, plant, and equipment, at cost		542	1,124
Regulated [Member] | Other Capitalized Property Plant and Equipment [Member]
Property, Plant, and Equipment
Property, plant, and equipment, at cost		2,930	2,761
Regulated [Member] | Natural gas transmission facilities [Member]
Property, Plant, and Equipment
Property, plant, and equipment, at cost		22,763	21,083
Regulated [Member] | Acquisition Adjustment Of Regulated Facilities [Member]
Property, Plant, and Equipment
Property, Plant and Equipment, Plant Acquisition Adjustments for Intangible Utility Plants		$ 354	$ 389
Period of straight-line amortization		40 years
Minimum [Member] | Transcontinental Gas Pipe Line Company, LLC [Member] | Onshore Transmission Facilities
Property, Plant, and Equipment
Property, Plant, and Equipment, Depreciation Rate	[1]	2.50%
Minimum [Member] | Transcontinental Gas Pipe Line Company, LLC [Member] | Storage Facilities
Property, Plant, and Equipment
Property, Plant, and Equipment, Depreciation Rate	[1]	1.86%
Minimum [Member] | Transcontinental Gas Pipe Line Company, LLC [Member] | Gathering Facilities
Property, Plant, and Equipment
Property, Plant, and Equipment, Depreciation Rate	[1]	0%
Minimum [Member] | Northwest Pipeline LLC [Member] | Storage Facilities
Property, Plant, and Equipment
Property, Plant, and Equipment, Depreciation Rate	[1]	1.60%
Minimum [Member] | Other Capitalized Property Plant and Equipment [Member] | Transcontinental Gas Pipe Line Company, LLC [Member]
Property, Plant, and Equipment
Property, Plant, and Equipment, Depreciation Rate	[1]	1.77%
Minimum [Member] | Other Capitalized Property Plant and Equipment [Member] | Northwest Pipeline LLC [Member]
Property, Plant, and Equipment
Property, Plant, and Equipment, Depreciation Rate	[1]	0%
Minimum [Member] | Natural gas transmission facilities [Member] | Northwest Pipeline LLC [Member]
Property, Plant, and Equipment
Property, Plant, and Equipment, Depreciation Rate	[1]	2.70%
Minimum [Member] | Nonregulated [Member] | Natural gas gathering and processing facilities [Member]
Property, Plant, and Equipment
Property, Plant and Equipment, Useful Life	[1]	5 years
Minimum [Member] | Nonregulated [Member] | Other Capitalized Property Plant and Equipment [Member]
Property, Plant, and Equipment
Property, Plant and Equipment, Useful Life	[1]	0 years
Minimum [Member] | Regulated [Member] | Other Capitalized Property Plant and Equipment [Member]
Property, Plant, and Equipment
Property, Plant and Equipment, Useful Life	[1]	5 years
Property, Plant, and Equipment, Depreciation Rate	[1]	0%
Minimum [Member] | Regulated [Member] | Natural gas transmission facilities [Member]
Property, Plant, and Equipment
Property, Plant and Equipment, Useful Life	[1]	0 years
Property, Plant, and Equipment, Depreciation Rate	[1]	1.25%
Maximum [Member] | Transcontinental Gas Pipe Line Company, LLC [Member] | Onshore Transmission Facilities
Property, Plant, and Equipment
Property, Plant, and Equipment, Depreciation Rate	[1]	7.13%
Maximum [Member] | Transcontinental Gas Pipe Line Company, LLC [Member] | Storage Facilities
Property, Plant, and Equipment
Property, Plant, and Equipment, Depreciation Rate	[1]	2.05%
Maximum [Member] | Transcontinental Gas Pipe Line Company, LLC [Member] | Gathering Facilities
Property, Plant, and Equipment
Property, Plant, and Equipment, Depreciation Rate	[1]	1%
Maximum [Member] | Northwest Pipeline LLC [Member] | Storage Facilities
Property, Plant, and Equipment
Property, Plant, and Equipment, Depreciation Rate	[1]	2.76%
Maximum [Member] | Other Capitalized Property Plant and Equipment [Member] | Transcontinental Gas Pipe Line Company, LLC [Member]
Property, Plant, and Equipment
Property, Plant, and Equipment, Depreciation Rate	[1]	20%
Maximum [Member] | Other Capitalized Property Plant and Equipment [Member] | Northwest Pipeline LLC [Member]
Property, Plant, and Equipment
Property, Plant, and Equipment, Depreciation Rate	[1]	33.33%
Maximum [Member] | Natural gas transmission facilities [Member] | Northwest Pipeline LLC [Member]
Property, Plant, and Equipment
Property, Plant, and Equipment, Depreciation Rate	[1]	10.20%
Maximum [Member] | Nonregulated [Member] | Natural gas gathering and processing facilities [Member]
Property, Plant, and Equipment
Property, Plant and Equipment, Useful Life	[1]	40 years
Maximum [Member] | Nonregulated [Member] | Other Capitalized Property Plant and Equipment [Member]
Property, Plant, and Equipment
Property, Plant and Equipment, Useful Life	[1]	45 years
Maximum [Member] | Regulated [Member] | Other Capitalized Property Plant and Equipment [Member]
Property, Plant, and Equipment
Property, Plant and Equipment, Useful Life	[1]	45 years
Property, Plant, and Equipment, Depreciation Rate	[1]	33.33%
Maximum [Member] | Regulated [Member] | Natural gas transmission facilities [Member]
Property, Plant, and Equipment
Property, Plant and Equipment, Useful Life	[1]	25 years
Property, Plant, and Equipment, Depreciation Rate	[1]	10.20%
[1]Estimated useful life and depreciation rates are presented as of December 31, 2024. Depreciation rates and estimated useful lives for regulated assets are prescribed by the FERC.

Property, Plant, and Equipmen_3

Property, Plant, and Equipment (Details ARO) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2024		Dec. 31, 2023
Unusual or Infrequent Item [Line Items]
Asset Retirement Obligation, Liabilities Incurred		$ 474	[1]	$ 42
Regulatory Assets		666		622
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance at beginning of year		2,084		1,914
Liabilities incurred (1)		474	[1]	42
Liabilities settled		(68)		(43)
Accretion		118		97
Revisions (2)	[2]	31		74
Balance at end of year		2,639		2,084
Transcontinental Gas Pipe Line Company, LLC [Member]
Unusual or Infrequent Item [Line Items]
Asset Retirement Obligations, Noncurrent		593		524
Asset Retirement Obligation, Liabilities Incurred		0		8
Regulatory Assets		394		386
Regulatory Liabilities, Noncurrent		976		956
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance at beginning of year		619		563
Liabilities incurred (1)		0		8
Liabilities settled		(32)		(23)
Accretion		29		31
Revisions (2)	[3]	(1)		40
Balance at end of year		615		619
Transcontinental Gas Pipe Line Company, LLC [Member] | Removal Costs
Unusual or Infrequent Item [Line Items]
Regulatory Liabilities, Noncurrent		632		605
Northwest Pipeline LLC [Member]
Unusual or Infrequent Item [Line Items]
Asset Retirement Obligations, Noncurrent		144		136
Regulatory Assets		55		38
Regulatory Liabilities, Noncurrent		233		252
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance at beginning of year		136		129
Accretion		8		7
Balance at end of year		144		136
Northwest Pipeline LLC [Member] | Removal Costs
Unusual or Infrequent Item [Line Items]
Regulatory Liabilities, Noncurrent		30		31
Northwest Pipeline LLC [Member] | Asset Retirement Obligation Costs [Member]
Unusual or Infrequent Item [Line Items]
Regulatory Assets		124		116
Discovery Acquisition
Unusual or Infrequent Item [Line Items]
Asset Retirement Obligation, Liabilities Incurred		250
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Liabilities incurred (1)		250
Gulf Coast Storage Acquisition
Unusual or Infrequent Item [Line Items]
Asset Retirement Obligation, Liabilities Incurred		106
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Liabilities incurred (1)		106
Crowheart Acquisition
Unusual or Infrequent Item [Line Items]
Asset Retirement Obligation, Liabilities Incurred		114
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Liabilities incurred (1)		114
Regulatory liabilities, deferred income, and other [Member]
Unusual or Infrequent Item [Line Items]
Asset Retirement Obligations, Noncurrent		2,548		1,978
Regulatory Liabilities, Noncurrent		$ 1,300		$ 1,288
[1] Includes $250 million, $106 million, and $114 million of ARO in 2024 related to the Discovery, Gulf Coast Storage, and Crowheart Acquisitions, respectively. Several factors are considered in the annual review process, including inflation rates, current estimates for removal cost, market risk premiums, discount rates, and the estimated remaining useful life of the assets. Changes in estimates of existing obligations are primarily due to the annual review process, which considers various factors including inflation rate, current estimates for removal costs, discount rates, and the estimated remaining life of assets.

Regulatory Assets and Liabili_3

Regulatory Assets and Liabilities - Williams (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Regulatory Liability [Line Items]
Total regulatory assets	$ 666	$ 622
Regulatory Liability, Current	85	77
Total regulatory liabilities	1,385	1,365
Other current assets and deferred charges [Member]
Regulatory Liability [Line Items]
Regulatory Assets, Current	84	95
Regulatory assets, deferred charges, and other [Member]
Regulatory Liability [Line Items]
Regulatory Assets, Noncurrent	582	527
Other Current Liabilities
Regulatory Liability [Line Items]
Regulatory Liability, Current	85	77
Regulatory liabilities, deferred income, and other [Member]
Regulatory Liability [Line Items]
Regulatory Liabilities, Noncurrent	$ 1,300	$ 1,288

Regulatory Assets and Liabili_4

Regulatory Assets and Liabilities - Transco (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets	$ 666	$ 622
Regulatory Liability [Line Items]
Regulatory Liability, Current	85	77
Regulatory Liabilities	1,385	1,365
Transcontinental Gas Pipe Line Company, LLC [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	74	87
Regulatory Assets, Noncurrent	320	299
Regulatory Assets	394	386
Regulatory Liability [Line Items]
Regulatory Liability, Current	58	49
Regulatory Liabilities, Noncurrent	976	956
Regulatory Liabilities	1,034	1,005
Transcontinental Gas Pipe Line Company, LLC [Member] | Deferred Income Tax Charge
Regulatory Liability [Line Items]
Regulatory Liability, Current	31	31
Regulatory Liabilities, Noncurrent	252	283
Regulatory Liabilities	13
Transcontinental Gas Pipe Line Company, LLC [Member] | Postretirement Benefit Costs
Regulatory Liability [Line Items]
Regulatory Liability, Current	0	8
Regulatory Liabilities, Noncurrent	31	23
Transcontinental Gas Pipe Line Company, LLC [Member] | Electric Power Cost
Regulatory Liability [Line Items]
Regulatory Liability, Current	26	7
Transcontinental Gas Pipe Line Company, LLC [Member] | Pension Costs
Regulatory Liability [Line Items]
Regulatory Liability, Current	0	2
Regulatory Liabilities, Noncurrent	30	24
Transcontinental Gas Pipe Line Company, LLC [Member] | Other Regulatory Assets (Liabilities)
Regulatory Liability [Line Items]
Regulatory Liability, Current	1	1
Regulatory Liabilities, Noncurrent	24	14
Transcontinental Gas Pipe Line Company, LLC [Member] | Removal Costs
Regulatory Liability [Line Items]
Regulatory Liabilities, Noncurrent	632	605
Transcontinental Gas Pipe Line Company, LLC [Member] | Sentinel Meter Station Depreciation
Regulatory Liability [Line Items]
Regulatory Liabilities, Noncurrent	7	7
Transcontinental Gas Pipe Line Company, LLC [Member] | Fuel Cost
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	47	60
Transcontinental Gas Pipe Line Company, LLC [Member] | Asset Retirement Obligation Costs [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	16	16
Regulatory Assets, Noncurrent	243	209
Transcontinental Gas Pipe Line Company, LLC [Member] | Deferred Cash Out
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	6	6
Regulatory Assets, Noncurrent	0	11
Transcontinental Gas Pipe Line Company, LLC [Member] | Asset Retirement Costs - Eminence
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	5	5
Regulatory Assets, Noncurrent	15	20
Transcontinental Gas Pipe Line Company, LLC [Member] | Deferred Taxes On Equity Funds Used During Construction
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Noncurrent	29	31
Transcontinental Gas Pipe Line Company, LLC [Member] | Slug Catcher
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Noncurrent	6	6
Transcontinental Gas Pipe Line Company, LLC [Member] | Other Regulatory Assets (Liabilities)
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Noncurrent	$ 27	$ 22

Regulatory Assets and Liabili_5

Regulatory Assets and Liabilities - NWP (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets	$ 666	$ 622
Regulatory Liability [Line Items]
Regulatory Liability, Current	85	77
Regulatory Liabilities	1,385	1,365
Northwest Pipeline LLC [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	6	2
Regulatory Assets, Noncurrent	49	36
Regulatory Assets	55	38
Regulatory Liability [Line Items]
Regulatory Liability, Current	20	21
Regulatory Liabilities, Noncurrent	233	252
Regulatory Liabilities	253	273
Northwest Pipeline LLC [Member] | Deferred Income Tax Charge
Regulatory Liability [Line Items]
Regulatory Liability, Current	20	20
Regulatory Liabilities, Noncurrent	160	179
Northwest Pipeline LLC [Member] | Deferred Fuel Costs
Regulatory Liability [Line Items]
Regulatory Liability, Current	0	1
Northwest Pipeline LLC [Member] | Postretirement Benefit Costs
Regulatory Liability [Line Items]
Regulatory Liabilities, Noncurrent	43	42
Northwest Pipeline LLC [Member] | Removal Costs
Regulatory Liability [Line Items]
Regulatory Liabilities, Noncurrent	30	31
Northwest Pipeline LLC [Member] | Deferred Fuel Costs
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	4	0
Northwest Pipeline LLC [Member] | Levelized Depreciation
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	2	2
Regulatory Assets, Noncurrent	7	10
Northwest Pipeline LLC [Member] | Deferred Taxes On Equity Funds Used During Construction
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Noncurrent	4	4
Northwest Pipeline LLC [Member] | Washington State Climate Commitment Act
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Noncurrent	$ 38	$ 22

Goodwill and Other Intangible_3

Goodwill and Other Intangible Assets (Details) - USD ($) $ in Millions		12 Months Ended
	Nov. 30, 2023	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Feb. 14, 2023
Finite-Lived Intangible Assets [Line Items]
Goodwill		$ 466	$ 463	$ 0
Finite-Lived Intangible Assets, Gross		10,512	10,510
Finite-Lived Intangible Assets, Accumulated Amortization		(3,769)	(3,380)
Customer relationships [Member]
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross		10,239	10,237
Finite-Lived Intangible Assets, Accumulated Amortization		$ (3,523)	(3,155)
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life		30 years
Amortization of Intangible Assets		$ 368	360	353
Finite-Lived Intangible Assets, Amortization Expense, Next Twelve Months		368
Finite-Lived Intangible Assets, Amortization Expense, Year Two		364
Finite-Lived Intangible Assets, Amortization Expense, Year Three		360
Finite-Lived Intangible Assets, Amortization Expense, Year Four		360
Finite-Lived Intangible Assets, Amortization Expense, Year Five		360
Transportation and Storage Capacity [Member]
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross		267	267
Finite-Lived Intangible Assets, Accumulated Amortization		(244)	(223)
Amortization of Intangible Assets		21	51	158
Finite-Lived Intangible Assets, Amortization Expense, Next Twelve Months		10
Finite-Lived Intangible Assets, Amortization Expense, Year Two		7
Finite-Lived Intangible Assets, Amortization Expense, Year Three		4
Finite-Lived Intangible Assets, Amortization Expense, Year Four		2
Finite-Lived Intangible Assets, Amortization Expense, Year Five		0
Other Intangible Assets [Member]
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross		6	6
Finite-Lived Intangible Assets, Accumulated Amortization		(2)	(2)
MountainWest Acquisition
Finite-Lived Intangible Assets [Line Items]
Goodwill, Period Increase (Decrease)			400
Cureton Acquisition
Finite-Lived Intangible Assets [Line Items]
Goodwill, Period Increase (Decrease)		5	6
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life	20 years
RMM Acquisition
Finite-Lived Intangible Assets [Line Items]
Goodwill, Period Increase (Decrease)		(2)	57
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life	20 years
Transmission And Gulf Of America [Member]
Finite-Lived Intangible Assets [Line Items]
Goodwill		400	400	0
Transmission And Gulf Of America [Member] | MountainWest Acquisition
Finite-Lived Intangible Assets [Line Items]
Goodwill					$ 400
Goodwill, Period Increase (Decrease)			400
West [Member]
Finite-Lived Intangible Assets [Line Items]
Goodwill		66	63	$ 0
West [Member] | Cureton Acquisition
Finite-Lived Intangible Assets [Line Items]
Goodwill	$ 11
Goodwill, Period Increase (Decrease)		5	6
West [Member] | RMM Acquisition
Finite-Lived Intangible Assets [Line Items]
Goodwill	$ 55
Goodwill, Period Increase (Decrease)		$ (2)	$ 57

Other Current Liabilities (Deta

Other Current Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Accrued Liabilities [Line Items]
Interest on debt	$ 350	$ 322
Employee costs	285	197
Contract liabilities (Note 5)	170	159
Alaska refinery contamination litigation (Note 1)	0	134
Asset Retirement Obligation, Current	91	106
Regulatory Liability, Current	85	77
Operating lease liabilities (Note 14)	26	24
Other, including accrued loss contingencies	353	265
Other current liabilities	$ 1,360	$ 1,284
Operating Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Other current liabilities	Other current liabilities
Transcontinental Gas Pipe Line Company, LLC [Member]
Accrued Liabilities [Line Items]
Interest on debt	$ 76	$ 76
Contract liabilities (Note 5)	10	10
Asset Retirement Obligation, Current	22	96
Customer Deposits	38	35
Regulatory Liability, Current	58	49
Operating lease liabilities (Note 14)	6	6
Other, including accrued loss contingencies	57	69
Other current liabilities	$ 181	$ 190
Operating Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Other current liabilities	Other current liabilities
Northwest Pipeline LLC [Member]
Accrued Liabilities [Line Items]
Interest on debt	$ 6	$ 6
Accrual for Taxes Other than Income Taxes, Current	8	7
Asset Retirement Obligation, Current	0	1
Exchange Gas Due To Others	10	5
Regulatory Liability, Current	20	21
Operating lease liabilities (Note 14)	1	1
Other, including accrued loss contingencies	10	15
Other current liabilities	$ 34	$ 34
Operating Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Other current liabilities	Other current liabilities

Long-Term Debt (Details)

Long-Term Debt (Details) - USD ($) $ in Millions			12 Months Ended
		Jan. 03, 2024	Dec. 31, 2024	Dec. 31, 2023	Aug. 13, 2024		Jun. 24, 2024	Mar. 04, 2024	Jan. 05, 2024	Aug. 10, 2023		Mar. 02, 2023	Aug. 08, 2022
Long-term Debt
Long-term debt due within one year			$ (1,720)	$ (2,337)
Long-term debt			24,736	23,376
Debt, Long-Term and Short-Term, Combined Amount			26,456	25,713
RMM Acquisition
Long-term Debt
Business Combination, Consideration Transferred, Liabilities Incurred			0	665
Gulf Coast Storage Acquisition
Long-term Debt
Business Combination, Consideration Transferred, Liabilities Incurred		$ 100	100	0
Transcontinental Gas Pipe Line Company, LLC [Member]
Long-term Debt
Unamortized debt issuance costs			(23)	(26)
Debt Instrument, Unamortized Discount (Premium), Net			(11)	(12)
Total long-term debt, including current portion			5,235	5,261
Long-term debt due within one year			(35)	(32)
Transcontinental Gas Pipe Line Company, LLC [Member] | 7.08% Debentures Due 2026 [Member]
Long-term Debt
Long-term debt			$ 8	8
Long-term debt interest rate			7.08%
Transcontinental Gas Pipe Line Company, LLC [Member] | 7.25% Debentures Due 2026 [Member]
Long-term Debt
Long-term debt			$ 200	200
Long-term debt interest rate			7.25%
Transcontinental Gas Pipe Line Company, LLC [Member] | 7.85% Senior Unsecured Notes Due 2026 [Member]
Long-term Debt
Long-term debt			$ 1,000	1,000
Long-term debt interest rate			7.85%
Transcontinental Gas Pipe Line Company, LLC [Member] | 4% Senior Unsecured Notes Due 2028 [Member]
Long-term Debt
Long-term debt			$ 400	400
Long-term debt interest rate			4%
Transcontinental Gas Pipe Line Company, LLC [Member] | 3.25 Percent Senior Unsecured Notes Due 2030 [Member]
Long-term Debt
Long-term debt			$ 700	700
Long-term debt interest rate			3.25%
Transcontinental Gas Pipe Line Company, LLC [Member] | 5.4% Senior Unsecured Notes Due 2041 [Member]
Long-term Debt
Long-term debt			$ 375	375
Long-term debt interest rate			5.40%
Transcontinental Gas Pipe Line Company, LLC [Member] | 4.45% Senior Unsecured Notes Due 2042 [Member]
Long-term Debt
Long-term debt			$ 400	400
Long-term debt interest rate			4.45%
Transcontinental Gas Pipe Line Company, LLC [Member] | 4.6% Senior Unsecured Notes Due 2048 [Member]
Long-term Debt
Long-term debt			$ 600	600
Long-term debt interest rate			4.60%
Transcontinental Gas Pipe Line Company, LLC [Member] | 3.95 Percent Senior Unsecured Notes Due 2050 [Member]
Long-term Debt
Long-term debt			$ 500	500
Long-term debt interest rate			3.95%
Transcontinental Gas Pipe Line Company, LLC [Member] | Atlantic Sunrise [Member]
Long-term Debt
Other financing obligations			$ 764	790
Long-term debt interest rate			9%
Transcontinental Gas Pipe Line Company, LLC [Member] | Leidy South
Long-term Debt
Other financing obligations			$ 75	76
Long-term debt interest rate			13%
Transcontinental Gas Pipe Line Company, LLC [Member] | Dalton [Member]
Long-term Debt
Other financing obligations			$ 247	250
Long-term debt interest rate			9%
MountainWest [Member]
Long-term Debt
Debt Instrument, Unamortized Discount (Premium), Net			$ (58)	(61)
Total long-term debt, including current portion			372	369
MountainWest [Member] | 3.53 Percent Senior Unsecured Notes due 2028
Long-term Debt
Long-term debt			$ 100	100
Long-term debt interest rate			3.53%
MountainWest [Member] | 3.91 Percent Senior Unsecured Notes due 2038
Long-term Debt
Long-term debt			$ 150	150
Long-term debt interest rate			3.91%
MountainWest [Member] | 4.875 Percent Senior Unsecured Notes due 2041
Long-term Debt
Long-term debt			$ 180	180
Long-term debt interest rate			4.875%
Northwest Pipeline LLC [Member]
Long-term Debt
Unamortized debt issuance costs			$ (1)	(2)
Debt Instrument, Unamortized Discount (Premium), Net			(2)	(2)
Total long-term debt, including current portion			582	581
Long-term debt due within one year			(85)	0
Northwest Pipeline LLC [Member] | 7.125% Debentures Due 2025 [Member]
Long-term Debt
Long-term debt			$ 85	85
Long-term debt interest rate			7.125%
Northwest Pipeline LLC [Member] | 4% Senior Unsecured Notes Due 2027 [Member]
Long-term Debt
Long-term debt			$ 500	500
Long-term debt interest rate			4%
The Williams Companies, Inc. [Member]
Long-term Debt
Credit facility loans	[1]		$ 0
Unamortized debt issuance costs			(130)	(112)
Debt Instrument, Unamortized Discount (Premium), Net			(41)	(39)
Total long-term debt, including current portion			20,167	18,837
Long-term debt due within one year			(1,600)	(2,305)
The Williams Companies, Inc. [Member] | 4.3% Senior Unsecured Notes Due 2024 [Member]
Long-term Debt
Long-term debt			$ 0	1,000
Long-term debt interest rate			4.30%					4.30%
The Williams Companies, Inc. [Member] | 4.55% Senior Unsecured Notes Due 2024 [Member]
Long-term Debt
Long-term debt			$ 0	1,250
Long-term debt interest rate			4.55%				4.55%
The Williams Companies, Inc. [Member] | 3.9% Senior Unsecured Notes Due 2025 [Member]
Long-term Debt
Long-term debt			$ 750	750
Long-term debt interest rate			3.90%
The Williams Companies, Inc. [Member] | 4% Senior Unsecured Notes Due 2025 [Member]
Long-term Debt
Long-term debt			$ 750	750
Long-term debt interest rate			4%
The Williams Companies, Inc. [Member] | 5.40 Percent Senior Unsecured Notes Due 2026
Long-term Debt
Long-term debt			$ 1,100	1,100
Long-term debt interest rate			5.40%							5.40%	[2]	5.40%
The Williams Companies, Inc. [Member] | 7.7 Percent Senior Unsecured Notes Due 2027
Long-term Debt
Long-term debt			$ 2	2
Long-term debt interest rate			7.70%
The Williams Companies, Inc. [Member] | 3.75% Senior Unsecured Notes Due 2027 [Member]
Long-term Debt
Long-term debt			$ 1,450	1,450
Long-term debt interest rate			3.75%
The Williams Companies, Inc. [Member] | 5.30 Percent Senior Unsecured Notes Due 2028
Long-term Debt
Long-term debt			$ 900	900
Long-term debt interest rate			5.30%							5.30%
The Williams Companies, Inc. [Member] | 4.9 Percent Senior Unsecured Notes Due 2029
Long-term Debt
Long-term debt			$ 1,100	0
Long-term debt interest rate			4.90%						4.90%
The Williams Companies, Inc. [Member] | 4.8 Percent Senior Unsecured Notes Due 2029
Long-term Debt
Long-term debt			$ 450	0
Long-term debt interest rate			4.80%		4.80%
The Williams Companies, Inc. [Member] | 3.5 Percent Senior Unsecured Notes Due 2030 [Member]
Long-term Debt
Long-term debt			$ 1,000	1,000
Long-term debt interest rate			3.50%
The Williams Companies, Inc. [Member] | 2.6 Percent Senior Unsecured Notes Due 2031
Long-term Debt
Long-term debt			$ 1,500	1,500
Long-term debt interest rate			2.60%
The Williams Companies, Inc. [Member] | 7.5% Debentures Due 2031 [Member]
Long-term Debt
Long-term debt			$ 339	339
Long-term debt interest rate			7.50%
The Williams Companies, Inc. [Member] | 7.75% Senior Unsecured Notes Due 2031 [Member]
Long-term Debt
Long-term debt			$ 252	252
Long-term debt interest rate			7.75%
The Williams Companies, Inc. [Member] | 8.75% Senior Unsecured Notes Due 2032 [Member]
Long-term Debt
Long-term debt			$ 445	445
Long-term debt interest rate			8.75%
The Williams Companies, Inc. [Member] | 4.65 Percent Senior Unsecured Notes Due 2032
Long-term Debt
Long-term debt			$ 1,000	1,000
Long-term debt interest rate			4.65%										4.65%
The Williams Companies, Inc. [Member] | 5.65 Percent Senior Unsecured Notes Due 2033
Long-term Debt
Long-term debt			$ 750	750
Long-term debt interest rate			5.65%									5.65%
The Williams Companies, Inc. [Member] | 5.15 Percent Senior Unsecured Notes Due 2034
Long-term Debt
Long-term debt			$ 1,300	0
Long-term debt interest rate			5.15%		5.15%	[3]			5.15%
The Williams Companies, Inc. [Member] | 6.3% Senior Unsecured Notes Due 2040 [Member]
Long-term Debt
Long-term debt			$ 1,250	1,250
Long-term debt interest rate			6.30%
The Williams Companies, Inc. [Member] | 5.8% Senior Unsecured Notes Due 2043 [Member]
Long-term Debt
Long-term debt			$ 400	400
Long-term debt interest rate			5.80%
The Williams Companies, Inc. [Member] | 5.4% Senior Unsecured Notes Due 2044 [Member]
Long-term Debt
Long-term debt			$ 500	500
Long-term debt interest rate			5.40%
The Williams Companies, Inc. [Member] | 5.75% Senior Unsecured Notes Due 2044 [Member]
Long-term Debt
Long-term debt			$ 650	650
Long-term debt interest rate			5.75%
The Williams Companies, Inc. [Member] | 4.9% Senior Unsecured Notes Due 2045 [Member]
Long-term Debt
Long-term debt			$ 500	500
Long-term debt interest rate			4.90%
The Williams Companies, Inc. [Member] | 5.1% Senior Unsecured Notes Due 2045 [Member]
Long-term Debt
Long-term debt			$ 1,000	1,000
Long-term debt interest rate			5.10%
The Williams Companies, Inc. [Member] | 4.85 Percent Senior Unsecured Notes Due 2048 [Member]
Long-term Debt
Long-term debt			$ 800	800
Long-term debt interest rate			4.85%
The Williams Companies, Inc. [Member] | 3.5 Percent Senior Unsecured Notes Due 2051
Long-term Debt
Long-term debt			$ 650	650
Long-term debt interest rate			3.50%
The Williams Companies, Inc. [Member] | 5.3 Percent Senior Unsecured Notes Due 2052
Long-term Debt
Long-term debt			$ 750	750
Long-term debt interest rate			5.30%										5.30%
The Williams Companies, Inc. [Member] | 5.8 Percent Senior Unsecured Notes Due 2054
Long-term Debt
Long-term debt			$ 750	$ 0
Long-term debt interest rate			5.80%		5.80%
[1]In managing its available liquidity, Williams does not expect a maximum outstanding amount in excess of the capacity of its credit facility inclusive of any outstanding amounts under the commercial paper program.[2]Additional issuance of the 5.40 percent senior notes due 2026 issued on March 2, 2023, and trade interchangeably with such notes.[3]Additional issuance of the 5.15 percent senior notes due 2034 issued on January 5, 2024, and trade interchangeably with such notes.

Long-Term Debt Maturities (Deta

Long-Term Debt Maturities (Details) $ in Millions	Dec. 31, 2024 USD ($)
Debt Instrument [Line Items]
2025	$ 1,720
2026	2,345
2027	1,994
2028	1,445
2029	1,600
Transcontinental Gas Pipe Line Company, LLC [Member]
Debt Instrument [Line Items]
2025	35
2026	1,245
2027	41
2028	445
2029	50
Northwest Pipeline LLC [Member]
Debt Instrument [Line Items]
2025	85
2027	$ 500

Long-Term Debt Issuances and Re

Long-Term Debt Issuances and Retirements (Details) - The Williams Companies, Inc. [Member] - USD ($) $ in Millions

Jan. 15, 2025

Jun. 24, 2024

Mar. 04, 2024

Nov. 15, 2023

Oct. 17, 2022

May 16, 2022

Jan. 18, 2022

Jan. 09, 2025

Dec. 31, 2024

Aug. 13, 2024

Jan. 05, 2024

Aug. 10, 2023

Mar. 02, 2023

Aug. 08, 2022

5.6 Percent Senior Unsecured Notes Due 2035 | Subsequent Event [Member]

Debt Instrument [Line Items]

Long-term debt face amount

$ 1,000

Long-term debt interest rate

5.60%

6.0 Percent Senior Unsecured Notes Due 2055 | Subsequent Event [Member]

Debt Instrument [Line Items]

Long-term debt face amount

$ 500

Long-term debt interest rate

6%

4.8 Percent Senior Unsecured Notes Due 2029

Debt Instrument [Line Items]

Long-term debt face amount

$ 450

Long-term debt interest rate

4.80%

4.80%

5.15 Percent Senior Unsecured Notes Due 2034

Debt Instrument [Line Items]

Long-term debt face amount

$ 300

[1]

$ 1,000

Long-term debt interest rate

5.15%

5.15%

[1]

5.15%

5.8 Percent Senior Unsecured Notes Due 2054

Debt Instrument [Line Items]

Long-term debt face amount

$ 750

Long-term debt interest rate

5.80%

5.80%

4.9 Percent Senior Unsecured Notes Due 2029

Debt Instrument [Line Items]

Long-term debt face amount

$ 1,100

Long-term debt interest rate

4.90%

4.90%

5.40 Percent Senior Unsecured Notes Due 2026

Debt Instrument [Line Items]

Long-term debt face amount

$ 350

[2]

$ 750

Long-term debt interest rate

5.40%

5.40%

[2]

5.40%

5.30 Percent Senior Unsecured Notes Due 2028

Debt Instrument [Line Items]

Long-term debt face amount

$ 900

Long-term debt interest rate

5.30%

5.30%

5.65 Percent Senior Unsecured Notes Due 2033

Debt Instrument [Line Items]

Long-term debt face amount

$ 750

Long-term debt interest rate

5.65%

5.65%

4.65 Percent Senior Unsecured Notes Due 2032

Debt Instrument [Line Items]

Long-term debt face amount

$ 1,000

Long-term debt interest rate

4.65%

4.65%

5.3 Percent Senior Unsecured Notes Due 2052

Debt Instrument [Line Items]

Long-term debt face amount

$ 750

Long-term debt interest rate

5.30%

5.30%

3.9% Senior Unsecured Notes Due 2025 [Member]

Debt Instrument [Line Items]

Long-term debt interest rate

3.90%

3.9% Senior Unsecured Notes Due 2025 [Member] | Subsequent Event [Member]

Debt Instrument [Line Items]

Long-term debt interest rate

3.90%

Extinguishment of Debt, Amount

$ 750

4.55% Senior Unsecured Notes Due 2024 [Member]

Debt Instrument [Line Items]

Long-term debt interest rate

4.55%

4.55%

Extinguishment of Debt, Amount

$ 1,250

4.3% Senior Unsecured Notes Due 2024 [Member]

Debt Instrument [Line Items]

Long-term debt interest rate

4.30%

4.30%

Extinguishment of Debt, Amount

$ 1,000

4.5% Senior Unsecured Notes Due 2023 [Member]

Debt Instrument [Line Items]

Long-term debt interest rate

4.50%

Extinguishment of Debt, Amount

$ 600

3.7% Senior Unsecured Notes Due 2023 [Member]

Debt Instrument [Line Items]

Long-term debt interest rate

3.70%

Extinguishment of Debt, Amount

$ 850

3.35% Senior Unsecured Notes Due 2022 [Member]

Debt Instrument [Line Items]

Long-term debt interest rate

3.35%

Extinguishment of Debt, Amount

$ 750

3.6% Senior Unsecured Notes Due 2022 [Member]

Debt Instrument [Line Items]

Long-term debt interest rate

3.60%

Extinguishment of Debt, Amount

$ 1,250

[1]Additional issuance of the 5.15 percent senior notes due 2034 issued on January 5, 2024, and trade interchangeably with such notes.[2]Additional issuance of the 5.40 percent senior notes due 2026 issued on March 2, 2023, and trade interchangeably with such notes.

Credit Facility and Commercial

Credit Facility and Commercial Paper (Details) $ in Millions			12 Months Ended
		Oct. 08, 2021 USD ($)	Dec. 31, 2024 USD ($)		Dec. 31, 2023 USD ($)	Sep. 30, 2021 USD ($)
Credit Facility and Commercial Paper [Line Items]
Commercial paper, outstanding			$ 455		$ 725
Williams Companies Inc [Member]
Credit Facility and Commercial Paper [Line Items]
Credit facility, capacity		$ 3,750	3,750	[1]		$ 4,500
Credit facility, loans outstanding	[1]		0
Additional amount by which credit facility can be increased		$ 500
Maximum ratio of debt to EBITDA after acquisition		5.5
Acquisition Trigger Amount		$ 25
Williams Companies Inc [Member] | Swing Line Loan [Member]
Credit Facility and Commercial Paper [Line Items]
Credit facility, capacity		200
Williams Companies Inc [Member] | Commercial paper [Member]
Credit Facility and Commercial Paper [Line Items]
Credit facility, capacity		3,500
Commercial paper, outstanding			$ 455		$ 725
Commercial paper, maximum maturity			397 days
Short-Term Debt, Weighted Average Interest Rate, at Point in Time			4.60%		5.60%
Williams Companies Inc [Member] | Letters of credit [Member]
Credit Facility and Commercial Paper [Line Items]
Credit facility, capacity		$ 500
Williams Companies Inc [Member] | Letters Of Credit Under Certain Bilateral Bank Agreements [Member]
Credit Facility and Commercial Paper [Line Items]
Credit facility, letters of credit outstanding			$ 15
Transcontinental Gas Pipe Line Company, LLC [Member]
Credit Facility and Commercial Paper [Line Items]
Maximum ratio of debt to capitalization		65%
Transcontinental Gas Pipe Line Company, LLC [Member] | Letters of credit [Member]
Credit Facility and Commercial Paper [Line Items]
Credit facility, capacity		$ 500
Northwest Pipeline LLC [Member]
Credit Facility and Commercial Paper [Line Items]
Maximum ratio of debt to capitalization		65%
Northwest Pipeline LLC [Member] | Letters of credit [Member]
Credit Facility and Commercial Paper [Line Items]
Credit facility, capacity		$ 500
Dec21 And Subsequent Quarters [Member] | Williams Companies Inc [Member]
Credit Facility and Commercial Paper [Line Items]
Maximum ratio of debt to EBITDA		5
[1]In managing its available liquidity, Williams does not expect a maximum outstanding amount in excess of the capacity of its credit facility inclusive of any outstanding amounts under the commercial paper program.

Cash Payments For Interest (Net

Cash Payments For Interest (Net of Amounts Capitalized) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Williams Companies Inc [Member]
Debt Instrument [Line Items]
Cash payments for interest (net of amounts capitalized)	$ 1,293	$ 1,152	$ 1,117
Transcontinental Gas Pipe Line Company, LLC [Member]
Debt Instrument [Line Items]
Cash payments for interest (net of amounts capitalized)	302	307	326
Northwest Pipeline LLC [Member]
Debt Instrument [Line Items]
Cash payments for interest (net of amounts capitalized)	$ 24	$ 26	$ 26

Leases (Details)

Leases (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Lessee, Lease, Description [Line Items]
Operating Lease, Cost	$ 39	$ 38	$ 34
Variable Lease, Cost	31	31	26
Sublease Income	0	(1)	0
Lease, Cost	70	68	60
Operating Lease, Payments	37	37	33
Operating Lease, Right-of-Use Asset	$ 154	$ 159
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]	Other Assets, Noncurrent	Other Assets, Noncurrent
Operating Lease, Liability, Current	$ 26	$ 24
Operating Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Other current liabilities	Other current liabilities
Operating Lease, Liability, Noncurrent	$ 142	$ 148
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Other Liabilities and Deferred Revenue, Noncurrent	Other Liabilities and Deferred Revenue, Noncurrent
Operating Lease, Weighted Average Remaining Lease Term	11 years	11 years
Operating Lease, Weighted Average Discount Rate, Percent	4.90%	4.78%
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	$ 34
Lessee, Operating Lease, Liability, Payments, Due Year Two	33
Lessee, Operating Lease, Liability, Payments, Due Year Three	30
Lessee, Operating Lease, Liability, Payments, Due Year Four	22
Lessee, Operating Lease, Liability, Payments, Due Year Five	19
Lessee, Operating Lease, Liability, Payments, Due after Year Five	86
Lessee, Operating Lease, Liability, Payments, Due	224
Lessee, Operating Lease, Liability, Undiscounted Excess Amount	$ 56
Operating Lease, Liability, Statement of Financial Position [Extensible Enumeration]	Other Liabilities
Operating Lease, Liability	$ 168
Transcontinental Gas Pipe Line Company, LLC [Member]
Lessee, Lease, Description [Line Items]
Operating Lease, Cost	9	$ 9	9
Variable Lease, Cost	7	7	7
Lease, Cost	16	16	16
Operating Lease, Payments	9	10	10
Operating Lease, Right-of-Use Asset	$ 48	$ 53
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]	Other Assets, Noncurrent	Other Assets, Noncurrent
Operating Lease, Liability, Current	$ 6	$ 6
Operating Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Other current liabilities	Other current liabilities
Operating Lease, Liability, Noncurrent	$ 51	$ 56
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Other Liabilities, Noncurrent	Other Liabilities, Noncurrent
Operating Lease, Weighted Average Remaining Lease Term	13 years	13 years
Operating Lease, Weighted Average Discount Rate, Percent	4.77%	4.73%
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	$ 9
Lessee, Operating Lease, Liability, Payments, Due Year Two	9
Lessee, Operating Lease, Liability, Payments, Due Year Three	10
Lessee, Operating Lease, Liability, Payments, Due Year Four	10
Lessee, Operating Lease, Liability, Payments, Due Year Five	10
Lessee, Operating Lease, Liability, Payments, Due after Year Five	32
Lessee, Operating Lease, Liability, Payments, Due	80
Lessee, Operating Lease, Liability, Undiscounted Excess Amount	$ 23
Operating Lease, Liability, Statement of Financial Position [Extensible Enumeration]	Other Liabilities
Operating Lease, Liability	$ 57
Northwest Pipeline LLC [Member]
Lessee, Lease, Description [Line Items]
Operating Lease, Cost	3	$ 1	1
Variable Lease, Cost	1	1	1
Lease, Cost	4	2	2
Operating Lease, Payments	2	1	$ 1
Operating Lease, Right-of-Use Asset	$ 5	$ 9
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]	Other Assets, Noncurrent	Other Assets, Noncurrent
Operating Lease, Liability, Current	$ 1	$ 1
Operating Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Other current liabilities	Other current liabilities
Operating Lease, Liability, Noncurrent	$ 5	$ 7
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Other Liabilities, Noncurrent	Other Liabilities, Noncurrent
Operating Lease, Weighted Average Remaining Lease Term	19 years	15 years
Operating Lease, Weighted Average Discount Rate, Percent	4.90%	4.18%
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	$ 1
Lessee, Operating Lease, Liability, Payments, Due Year Two	0
Lessee, Operating Lease, Liability, Payments, Due Year Three	1
Lessee, Operating Lease, Liability, Payments, Due Year Four	0
Lessee, Operating Lease, Liability, Payments, Due Year Five	1
Lessee, Operating Lease, Liability, Payments, Due after Year Five	6
Lessee, Operating Lease, Liability, Payments, Due	9
Lessee, Operating Lease, Liability, Undiscounted Excess Amount	$ 3
Operating Lease, Liability, Statement of Financial Position [Extensible Enumeration]	Other Liabilities
Operating Lease, Liability	$ 6

Equity-Based Compensation (Deta

Equity-Based Compensation (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Williams Companies Incentive Plan [Member]
Equity-Based Compensation (Textuals) [Abstract]
Shares authorized for issuance	50,000
Shares reserved for future issuance	17,000
Shares available for future grants	9,000
Equity-based compensation expense	$ 99	$ 77	$ 73
Tax benefit from equity-based compensation expense	24	$ 19	$ 18
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized [Abstract]
Unrecognized equity-based compensation expense	$ 70
Unrecognized equity-based compensation expense, Weighted-average period of recognition in years	1 year 8 months 12 days
Williams Companies Incentive Plan [Member] | Nonvested Restricted Stock Units [Member]
Rollforward of nonvested restricted stock unit activity and related information
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	6,400	6,600
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	3 years
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 32.48	$ 28.34
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	3,100	3,800
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 31.77	$ 27.43
Williams Companies Incentive Plan [Member] | Performance Shares [Member]
Rollforward of nonvested restricted stock unit activity and related information
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	1,800
Williams Companies Incentive Plan [Member] | Performance Shares [Member] | Minimum [Member]
Rollforward of nonvested restricted stock unit activity and related information
Range of vested shares based on extent to which certain financial targets are achieved	0%
Williams Companies Incentive Plan [Member] | Performance Shares [Member] | Maximum [Member]
Rollforward of nonvested restricted stock unit activity and related information
Range of vested shares based on extent to which certain financial targets are achieved	200%
Williams Companies Incentive Plan [Member] | Stock options [Member]
Rollforward of stock option activity and related information
Options, Granted	0	0	0
Options Outstanding, Ending Balance	400
Options Exercisable at Period End	400
Options, Weighted Average Exercise Price, Ending Balance	$ 29.99
Options, Weighted Average Exercise Price, Exercisable at Period End	$ 29.99
Stock Options Outstanding, Weighted Average Remaining Contractual Life	2 years 4 months 24 days
Stock Options Exercisable, Weighted Average Remaining Contractual Life	2 years 4 months 24 days
Proceeds from Stock Options Exercised	$ 5	$ 2
Tax benefits realized on options exercised	$ 2	$ 2
Employee Stock Purchase Plan [Member]
Equity-Based Compensation (Textuals) [Abstract]
Shares authorized for issuance	5,200
Shares available for future grants	700
No. of shares purchases by employees	240
Average price of shares purchased	$ 33

Fair Value Measurements and Gua

Fair Value Measurements and Guarantees Recurring Measurements and Additional (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2024	Dec. 31, 2023
Additional disclosures:
Derivative, Notional Amount		$ 350	$ 1,150
Derivative, Additional Notional Amount		950
Derivative Notional Amount Terminated		1,750
Energy Related Derivative
Measured on a recurring basis
Derivative Asset		344	314
Derivative Liability		(400)	(287)
Carrying Amount [Member]
Additional disclosures:
Long-term debt, including current portion		(26,456)	(25,713)
Guarantees		(36)	(37)
Carrying Amount [Member] | Gulf Coast Storage Acquisition
Additional disclosures:
Long-term debt, including current portion		(100)
Carrying Amount [Member] | RMM Acquisition
Additional disclosures:
Long-term debt, including current portion			(665)
Carrying Amount [Member] | Williams Companies Inc [Member]
Additional disclosures:
Long-term debt, including current portion		(20,167)	(18,837)
Carrying Amount [Member] | Transcontinental Gas Pipe Line Company, LLC [Member]
Additional disclosures:
Long-term debt, including current portion		(5,235)	(5,261)
Carrying Amount [Member] | Northwest Pipeline LLC [Member]
Additional disclosures:
Long-term debt, including current portion		(582)	(581)
Carrying Amount [Member] | MountainWest [Member]
Additional disclosures:
Long-term debt, including current portion		(372)	(369)
Fair Value [Member]
Additional disclosures:
Long-term debt, including current portion		(25,830)	(25,553)
Guarantees		(28)	(28)
Fair Value [Member] | Gulf Coast Storage Acquisition
Additional disclosures:
Long-term debt, including current portion		(100)
Fair Value [Member] | RMM Acquisition
Additional disclosures:
Long-term debt, including current portion			(665)
Fair Value [Member] | Williams Companies Inc [Member]
Additional disclosures:
Long-term debt, including current portion		(19,517)	(18,494)
Fair Value [Member] | Transcontinental Gas Pipe Line Company, LLC [Member]
Additional disclosures:
Long-term debt, including current portion		(5,276)	(5,438)
Fair Value [Member] | Northwest Pipeline LLC [Member]
Additional disclosures:
Long-term debt, including current portion		(573)	(581)
Fair Value [Member] | MountainWest [Member]
Additional disclosures:
Long-term debt, including current portion		(364)	(375)
Level 1 [Member]
Additional disclosures:
Long-term debt, including current portion		0	0
Guarantees		0	0
Level 1 [Member] | Gulf Coast Storage Acquisition
Additional disclosures:
Long-term debt, including current portion		0
Level 1 [Member] | RMM Acquisition
Additional disclosures:
Long-term debt, including current portion			0
Level 1 [Member] | Williams Companies Inc [Member]
Additional disclosures:
Long-term debt, including current portion		0	0
Level 1 [Member] | Transcontinental Gas Pipe Line Company, LLC [Member]
Additional disclosures:
Long-term debt, including current portion		0	0
Level 1 [Member] | Northwest Pipeline LLC [Member]
Additional disclosures:
Long-term debt, including current portion		0	0
Level 1 [Member] | MountainWest [Member]
Additional disclosures:
Long-term debt, including current portion		0	0
Level 2 [Member]
Additional disclosures:
Long-term debt, including current portion		(25,830)	(25,553)
Guarantees		(12)	(12)
Level 2 [Member] | Gulf Coast Storage Acquisition
Additional disclosures:
Long-term debt, including current portion		(100)
Level 2 [Member] | RMM Acquisition
Additional disclosures:
Long-term debt, including current portion			(665)
Level 2 [Member] | Williams Companies Inc [Member]
Additional disclosures:
Long-term debt, including current portion		(19,517)	(18,494)
Level 2 [Member] | Transcontinental Gas Pipe Line Company, LLC [Member]
Additional disclosures:
Long-term debt, including current portion		(5,276)	(5,438)
Level 2 [Member] | Northwest Pipeline LLC [Member]
Additional disclosures:
Long-term debt, including current portion		(573)	(581)
Level 2 [Member] | MountainWest [Member]
Additional disclosures:
Long-term debt, including current portion		(364)	(375)
Level 3 [Member]
Additional disclosures:
Long-term debt, including current portion		0	0
Guarantees		(16)	(16)
Level 3 [Member] | Gulf Coast Storage Acquisition
Additional disclosures:
Long-term debt, including current portion		0
Level 3 [Member] | RMM Acquisition
Additional disclosures:
Long-term debt, including current portion			0
Level 3 [Member] | Williams Companies Inc [Member]
Additional disclosures:
Long-term debt, including current portion		0	0
Level 3 [Member] | Transcontinental Gas Pipe Line Company, LLC [Member]
Additional disclosures:
Long-term debt, including current portion		0	0
Level 3 [Member] | Northwest Pipeline LLC [Member]
Additional disclosures:
Long-term debt, including current portion		0	0
Level 3 [Member] | MountainWest [Member]
Additional disclosures:
Long-term debt, including current portion		0	0
Fair Value, Recurring [Member] | Carrying Amount [Member]
Measured on a recurring basis
Interest Rate Derivatives, at Fair Value, Net			6
Fair Value, Recurring [Member] | Carrying Amount [Member] | Energy Related Derivative
Measured on a recurring basis
Derivative Asset	[1]	344	314
Derivative Liability	[1]	(400)	(287)
Fair Value, Recurring [Member] | Carrying Amount [Member] | Transcontinental Gas Pipe Line Company, LLC [Member]
Measured on a recurring basis
ARO Trust investments		297	269
Fair Value, Recurring [Member] | Fair Value [Member]
Measured on a recurring basis
Derivative Asset, Fair Value, Gross Asset		726	866	[2]
Derivative Liability, Fair Value, Gross Liability		(1,070)	(841)	[2]
Interest Rate Derivatives, at Fair Value, Net			6
Fair Value, Recurring [Member] | Fair Value [Member] | Transcontinental Gas Pipe Line Company, LLC [Member]
Measured on a recurring basis
ARO Trust investments		297	269
Fair Value, Recurring [Member] | Level 1 [Member]
Measured on a recurring basis
Derivative Asset, Fair Value, Gross Asset		427	514	[2]
Derivative Liability, Fair Value, Gross Liability		(532)	(376)	[2]
Interest Rate Derivatives, at Fair Value, Net			0
Fair Value, Recurring [Member] | Level 1 [Member] | Transcontinental Gas Pipe Line Company, LLC [Member]
Measured on a recurring basis
ARO Trust investments		297	269
Fair Value, Recurring [Member] | Level 2 [Member]
Measured on a recurring basis
Derivative Asset, Fair Value, Gross Asset		188	196	[2]
Derivative Liability, Fair Value, Gross Liability		(475)	(362)	[2]
Interest Rate Derivatives, at Fair Value, Net			6
Fair Value, Recurring [Member] | Level 2 [Member] | Transcontinental Gas Pipe Line Company, LLC [Member]
Measured on a recurring basis
ARO Trust investments		0	0
Fair Value, Recurring [Member] | Level 3 [Member]
Measured on a recurring basis
Derivative Asset, Fair Value, Gross Asset		111	156	[2]
Derivative Liability, Fair Value, Gross Liability		(63)	(103)	[2]
Interest Rate Derivatives, at Fair Value, Net			0
Fair Value, Recurring [Member] | Level 3 [Member] | Transcontinental Gas Pipe Line Company, LLC [Member]
Measured on a recurring basis
ARO Trust investments		0	$ 0
Wiltel Guarantee [Member]
Additional disclosures:
Guarantor Obligations, Maximum Exposure, Undiscounted		22
Indemnification Agreement [Member] | Carrying Amount [Member]
Additional disclosures:
Guarantees		$ 0
[1] The carrying amount is presented net of counterparty offsetting arrangements and collateral (see Note 17 – Commodity Derivatives). Previously, the fair value of Williams’ commodity derivative assets and liabilities were disclosed by level within the fair value hierarchy net of counterparty offsetting arrangements. The December 31, 2023, amounts have been corrected to disclose the fair values by level on a gross basis, as presented above.

Fair Value Measurements - ARO T

Fair Value Measurements - ARO Trust (Details) - Transcontinental Gas Pipe Line Company, LLC [Member] - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt Securities, Trading, and Equity Securities, FV-NI, Cost	$ 200	$ 198
Debt Securities, Trading, and Equity Securities, FV-NI	297	269
External Trust
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Transco's annual funding commitment for ARO	16
Cash management funds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt Securities, Trading, and Equity Securities, FV-NI, Cost	27	26
Debt Securities, Trading, and Equity Securities, FV-NI	27	26
Private Equity Funds, US
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt Securities, Trading, and Equity Securities, FV-NI, Cost	53	53
Debt Securities, Trading, and Equity Securities, FV-NI	146	120
Private Equity Funds, Non-US
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt Securities, Trading, and Equity Securities, FV-NI, Cost	32	32
Debt Securities, Trading, and Equity Securities, FV-NI	40	39
Municipal Bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt Securities, Trading, and Equity Securities, FV-NI, Cost	88	87
Debt Securities, Trading, and Equity Securities, FV-NI	$ 84	$ 84

Fair Value Net Derivative Asset

Fair Value Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Balance at beginning of period	$ 53	$ (56)
Realized and unrealized gains (losses): Included in income (loss)	$ (5)	$ 91
Fair Value, Net Derivative Asset (Liability), Recurring Basis, Unobservable Input Reconciliation, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	Cost of Goods and Service, Excluding Depreciation, Depletion, and Amortization	Cost of Goods and Service, Excluding Depreciation, Depletion, and Amortization
Purchases, issuances, and settlements	$ (1)	$ 20
Transfers into Level 3	1	0
Transfers out of Level 3	0	(2)
Balance at end of period	$ 48	$ 53

Fair Value Measurements Concent

Fair Value Measurements Concentration of Credit Risk (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024		Dec. 31, 2023	Dec. 31, 2022
Concentration Risk [Line Items]
Receivables, Net, Current	$ 1,863		$ 1,655
Revenues	10,503		10,907	$ 10,965
Transcontinental Gas Pipe Line Company, LLC [Member]
Concentration Risk [Line Items]
Revenues	2,964		2,866	2,909
Transcontinental Gas Pipe Line Company, LLC [Member] | Dominion Energy, Inc
Concentration Risk [Line Items]
Revenues	217	[1]	287	293
Northwest Pipeline LLC [Member]
Concentration Risk [Line Items]
Revenues	444		440	448
Northwest Pipeline LLC [Member] | Puget Sound Energy, Inc
Concentration Risk [Line Items]
Revenues	136		126	131
Northwest Pipeline LLC [Member] | Cascade Natural Gas Corporation
Concentration Risk [Line Items]
Revenues	46		47	49
Northwest Pipeline LLC [Member] | Northwest Natural Gas Company
Concentration Risk [Line Items]
Revenues	47		47	$ 49
NGLs, natural gas, and related products and services [Member]
Concentration Risk [Line Items]
Receivables, Net, Current	594		589
Transportation of natural gas and related products [Member]
Concentration Risk [Line Items]
Receivables, Net, Current	339		310
Marketing Of Natural Gas And NGLs
Concentration Risk [Line Items]
Receivables, Net, Current	516		321
Oil and Gas, Exploration and Production
Concentration Risk [Line Items]
Receivables, Net, Current	45		72
Accounts Receivable related to revenues from contracts with customers [Member]
Concentration Risk [Line Items]
Receivables, Net, Current	1,494		1,292
Derivative Receivables
Concentration Risk [Line Items]
Receivables, Net, Current	294		311
Other Receivable [Member]
Concentration Risk [Line Items]
Receivables, Net, Current	$ 75		$ 52
[1]The 2024 amount is less than 10 percent of Transco’s revenue

Commodity Derivatives - Notiona

Commodity Derivatives - Notional Volumes (Details) - Not Designated as Hedging Instrument [Member]	Dec. 31, 2024 MMBTU Boe
Public Utilities, Inventory, Natural Gas | IndexRisk
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Nonmonetary Notional Amount Net Long Short Position Volume | MMBTU	592,842,257
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	(50,513,793)
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	13,306,615
Natural Gas Liquids | Central Hub Risk
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Nonmonetary Notional Amount Net Long Short Position Volume | Boe	(2,561,000)
Natural Gas Liquids | Basis Risk
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Nonmonetary Notional Amount Net Long Short Position Volume | Boe	(205,000)
Crude Oil | Central Hub Risk
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Nonmonetary Notional Amount Net Long Short Position Volume | Boe	(480,000)

Commodity Derivatives - Financi

Commodity Derivatives - Financial Statement Presentation (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Asset, Current, Statement of Financial Position [Extensible Enumeration]	Derivative assets	Derivative assets
Derivative Asset, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Other Assets, Noncurrent	Other Assets, Noncurrent
Derivative Liability, Current, Statement of Financial Position [Extensible Enumeration]	Derivative Liability, Current	Derivative Liability, Current
Derivative Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Other Liabilities and Deferred Revenue, Noncurrent	Other Liabilities and Deferred Revenue, Noncurrent
Energy Related Derivative
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Asset, Fair Value, Gross Liability	$ (382)	$ (552)
Derivative Liability, Fair Value, Gross Asset	670	554
Derivative Asset	344	314
Derivative Liability	(400)	(287)
Gain (Loss) on Derivative Instruments, Net, Pretax	(264)	909	$ (324)
Energy Related Derivative | Gain (Loss) on Derivative Instruments
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Gain (Loss) on Derivative Instruments, Net, Pretax	(250)	956	(387)
Energy Related Derivative | Cost of Sales
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Gain (Loss) on Derivative Instruments, Net, Pretax	(14)	(47)	63
Not Designated as Hedging Instrument [Member] | Energy Related Derivative
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Asset, Fair Value, Gross Asset	726	866
Derivative Liability, Fair Value, Gross Liability	(1,070)	(841)
Not Designated as Hedging Instrument [Member] | Energy Related Derivative | Gain (Loss) on Derivative Instruments
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Realized	111	253	(91)
Unrealized	(361)	703	(296)
Not Designated as Hedging Instrument [Member] | Energy Related Derivative | Cost of Sales
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Realized	(8)	(4)	16
Unrealized	(6)	(43)	$ 47
Derivative assets [Member] | Not Designated as Hedging Instrument [Member] | Energy Related Derivative
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Asset, Fair Value, Gross Asset	508	623
Regulatory assets, deferred charges, and other [Member] | Not Designated as Hedging Instrument [Member] | Energy Related Derivative
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Asset, Fair Value, Gross Asset	218	243
Derivative Liabilities [Member] | Not Designated as Hedging Instrument [Member] | Energy Related Derivative
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Liability, Fair Value, Gross Liability	(635)	(496)
Regulatory liabilities, deferred income, and other [Member] | Not Designated as Hedging Instrument [Member] | Energy Related Derivative
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Liability, Fair Value, Gross Liability	$ (435)	$ (345)

Commodity Derivatives - Conting

Commodity Derivatives - Contingent Features (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Additional Collateral, Aggregate Fair Value	$ 6
Collateral Already Posted, Aggregate Fair Value	$ 288	$ 2

Contingencies and Commitments (

Contingencies and Commitments (Details) $ in Millions	1 Months Ended	12 Months Ended
	Feb. 28, 2025 USD ($)	Dec. 31, 2024 USD ($)	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)
Loss Contingencies [Line Items]
Accrued environmental loss liabilities		$ 42
Environmental Loss Contingency, Statement of Financial Position [Extensible Enumeration]		Other current liabilities
Other current liabilities		$ 1,360	$ 1,284
Transcontinental Gas Pipe Line Company, LLC [Member]
Loss Contingencies [Line Items]
Regulatory Assets, Current		74	87
Other current liabilities		181	190
Interest Income, Other		58	87	$ 36
Transcontinental Gas Pipe Line Company, LLC [Member] | Environmental Restoration Costs
Loss Contingencies [Line Items]
Accrued environmental loss liabilities		$ 11
Environmental Loss Contingency, Statement of Financial Position [Extensible Enumeration]		Other current liabilities, Other Liabilities, Noncurrent
Transcontinental Gas Pipe Line Company, LLC [Member] | Potentially Responsible Party At Various Superfund And State Waste Disposal Sites | Maximum [Member]
Loss Contingencies [Line Items]
Site Contingency, Loss Exposure Not Accrued, Best Estimate		$ 1
Northwest Pipeline LLC [Member]
Loss Contingencies [Line Items]
Regulatory Assets, Current		6	2
Other current liabilities		34	34
Interest Income, Other		2	1
Northwest Pipeline LLC [Member] | Environmental Restoration Costs
Loss Contingencies [Line Items]
Accrued environmental loss liabilities		$ 1
Environmental Loss Contingency, Statement of Financial Position [Extensible Enumeration]		Other current liabilities, Other Liabilities, Noncurrent
Northwest Pipeline LLC [Member] | Washington State Climate Commitment Act
Loss Contingencies [Line Items]
Regulatory Assets, Current		$ 38	22
Other current liabilities		3	$ 4
Capital Addition Purchase Commitments [Member]
Loss Contingencies [Line Items]
Commitments for construction and acquisition of property, plant, and equipment		155
Capital Addition Purchase Commitments [Member] | Transcontinental Gas Pipe Line Company, LLC [Member]
Loss Contingencies [Line Items]
Commitments for construction and acquisition of property, plant, and equipment		2
Capital Addition Purchase Commitments [Member] | Northwest Pipeline LLC [Member]
Loss Contingencies [Line Items]
Commitments for construction and acquisition of property, plant, and equipment		1
Gas & NGL Marketing Services
Loss Contingencies [Line Items]
Other Commitment		954
Gas Pipeline [Member]
Loss Contingencies [Line Items]
Accrued environmental loss liabilities		12
Recoverable through rates [Member]
Loss Contingencies [Line Items]
Accrued environmental loss liabilities		4
Natural Gas Underground Storage Facilities [Member]
Loss Contingencies [Line Items]
Accrued environmental loss liabilities		7
Former Operations [Member]
Loss Contingencies [Line Items]
Accrued environmental loss liabilities		$ 23
Construction Project | Transcontinental Gas Pipe Line Company, LLC [Member] | Subsequent Event [Member]
Loss Contingencies [Line Items]
Loss Contingency Accrual, Period Increase (Decrease)	$ 110
Loss Contingency Expected Recovery Percentage	0.29

Segment Disclosures Recon from

Segment Disclosures Recon from Segment to Consolidated - Revenues, Modified EBITDA, and Significant Expenses (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Segment revenues [Line Items]
Revenues		$ 10,503	$ 10,907	$ 10,965
Other financial information:
Gain (Loss) on Disposition of Business		0	129	0
Proportional Modified EBITDA Equity Method Investments		(909)	(939)	(979)
Modified EBITDA		6,656	8,013	6,075
Gain (Loss) Related to Litigation Settlement		0	534	0
Depreciation, Depletion and Amortization		(2,219)	(2,071)	(2,009)
Income (Loss) from Equity Method Investments		560	589	637
Other investing income (loss) - net		343	108	16
Interest Expense, Nonoperating		(1,364)	(1,236)	(1,147)
Asset Retirement Obligation Accretion Expense For Nonregulated Operations		(81)	(59)	(51)
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest		2,986	4,405	2,542
Energy Related Derivative | Not Designated as Hedging Instrument [Member] | Cost of Sales
Other financial information:
Unrealized Gain (Loss) on Derivatives		(6)	(43)	47
Service [Member]
Segment revenues [Line Items]
Revenues		7,628	7,026	6,536
NonRegulated Service Commodity Consideration [Member]
Segment revenues [Line Items]
Revenues		134	146	260
Product [Member]
Segment revenues [Line Items]
Revenues		2,991	2,779	4,556
Energy Commodities and Service
Segment revenues [Line Items]
Revenues		(250)	956	(387)
Operating Segments [Member] | Transmission And Gulf Of America [Member]
Segment revenues [Line Items]
Revenues		4,628	4,150	4,047
Other financial information:
Product Costs And Net Realized Processing Commodity Expenses		(329)	(259)	(425)
Operating And Administrative Expenses	[1]	(1,104)	(1,034)	(906)
Recovery of Direct Costs	[2]	(250)	(241)	(254)
Other Segment Income (Expenses) - Net	[3]	155	118	19
Gain (Loss) on Disposition of Business	[4]		129
Proportional Modified EBITDA Equity Method Investments		173	205	193
Modified EBITDA		3,273	3,068	2,674
Operating Segments [Member] | Transmission And Gulf Of America [Member] | Energy Related Derivative | Not Designated as Hedging Instrument [Member] | Cost of Sales
Other financial information:
Unrealized Gain (Loss) on Derivatives		0	0	0
Operating Segments [Member] | Transmission And Gulf Of America [Member] | Service [Member]
Segment revenues [Line Items]
Revenues		4,246	3,858	3,579
Operating Segments [Member] | Transmission And Gulf Of America [Member] | Service [Member] | External Customer
Segment revenues [Line Items]
Revenues		4,157	3,766	3,461
Operating Segments [Member] | Transmission And Gulf Of America [Member] | Service [Member] | Internal Customer
Segment revenues [Line Items]
Revenues		89	92	118
Operating Segments [Member] | Transmission And Gulf Of America [Member] | NonRegulated Service Commodity Consideration [Member]
Segment revenues [Line Items]
Revenues		54	38	64
Operating Segments [Member] | Transmission And Gulf Of America [Member] | Product [Member]
Segment revenues [Line Items]
Revenues		328	252	404
Operating Segments [Member] | Transmission And Gulf Of America [Member] | Product [Member] | External Customer
Segment revenues [Line Items]
Revenues		144	146	228
Operating Segments [Member] | Transmission And Gulf Of America [Member] | Product [Member] | Internal Customer
Segment revenues [Line Items]
Revenues		184	106	176
Operating Segments [Member] | Transmission And Gulf Of America [Member] | Energy Commodities and Service
Segment revenues [Line Items]
Revenues	[5]	0	2	0
Operating Segments [Member] | Transmission And Gulf Of America [Member] | Energy Commodities and Service | Realized Gain (Loss)
Segment revenues [Line Items]
Revenues		0	2	0
Operating Segments [Member] | Transmission And Gulf Of America [Member] | Energy Commodities and Service | Unrealized Gain (Loss)
Segment revenues [Line Items]
Revenues		0	0	0
Operating Segments [Member] | Northeast G And P [Member]
Segment revenues [Line Items]
Revenues		2,025	2,033	1,802
Other financial information:
Product Costs And Net Realized Processing Commodity Expenses		(88)	(125)	(138)
Operating And Administrative Expenses	[1]	(441)	(424)	(384)
Recovery of Direct Costs	[2]	(143)	(132)	(132)
Other Segment Income (Expenses) - Net	[3]	3	(10)	(6)
Gain (Loss) on Disposition of Business	[4]		0
Proportional Modified EBITDA Equity Method Investments		602	574	654
Modified EBITDA		1,958	1,916	1,796
Operating Segments [Member] | Northeast G And P [Member] | Energy Related Derivative | Not Designated as Hedging Instrument [Member] | Cost of Sales
Other financial information:
Unrealized Gain (Loss) on Derivatives		0	0	0
Operating Segments [Member] | Northeast G And P [Member] | Service [Member]
Segment revenues [Line Items]
Revenues		1,913	1,896	1,654
Operating Segments [Member] | Northeast G And P [Member] | Service [Member] | External Customer
Segment revenues [Line Items]
Revenues		1,900	1,868	1,613
Operating Segments [Member] | Northeast G And P [Member] | Service [Member] | Internal Customer
Segment revenues [Line Items]
Revenues		13	28	41
Operating Segments [Member] | Northeast G And P [Member] | NonRegulated Service Commodity Consideration [Member]
Segment revenues [Line Items]
Revenues		2	5	14
Operating Segments [Member] | Northeast G And P [Member] | Product [Member]
Segment revenues [Line Items]
Revenues		110	132	134
Operating Segments [Member] | Northeast G And P [Member] | Product [Member] | External Customer
Segment revenues [Line Items]
Revenues		24	34	28
Operating Segments [Member] | Northeast G And P [Member] | Product [Member] | Internal Customer
Segment revenues [Line Items]
Revenues		86	98	106
Operating Segments [Member] | Northeast G And P [Member] | Energy Commodities and Service
Segment revenues [Line Items]
Revenues	[5]	0	0	0
Operating Segments [Member] | Northeast G And P [Member] | Energy Commodities and Service | Realized Gain (Loss)
Segment revenues [Line Items]
Revenues		0	0	0
Operating Segments [Member] | Northeast G And P [Member] | Energy Commodities and Service | Unrealized Gain (Loss)
Segment revenues [Line Items]
Revenues		0	0	0
Operating Segments [Member] | West [Member]
Segment revenues [Line Items]
Revenues		2,669	2,135	2,561
Other financial information:
Product Costs And Net Realized Processing Commodity Expenses		(844)	(517)	(918)
Operating And Administrative Expenses	[1]	(591)	(502)	(507)
Recovery of Direct Costs	[2]	(49)	(37)	(43)
Other Segment Income (Expenses) - Net	[3]	(5)	(3)	(14)
Gain (Loss) on Disposition of Business	[4]		0
Proportional Modified EBITDA Equity Method Investments		132	162	132
Modified EBITDA		1,312	1,238	1,211
Operating Segments [Member] | West [Member] | Energy Related Derivative | Not Designated as Hedging Instrument [Member] | Cost of Sales
Other financial information:
Unrealized Gain (Loss) on Derivatives		0	0	0
Operating Segments [Member] | West [Member] | Service [Member]
Segment revenues [Line Items]
Revenues		1,718	1,502	1,542
Operating Segments [Member] | West [Member] | Service [Member] | External Customer
Segment revenues [Line Items]
Revenues		1,558	1,376	1,443
Operating Segments [Member] | West [Member] | Service [Member] | Internal Customer
Segment revenues [Line Items]
Revenues		160	126	99
Operating Segments [Member] | West [Member] | NonRegulated Service Commodity Consideration [Member]
Segment revenues [Line Items]
Revenues		78	103	182
Operating Segments [Member] | West [Member] | Product [Member]
Segment revenues [Line Items]
Revenues		869	441	841
Operating Segments [Member] | West [Member] | Product [Member] | External Customer
Segment revenues [Line Items]
Revenues		178	80	145
Operating Segments [Member] | West [Member] | Product [Member] | Internal Customer
Segment revenues [Line Items]
Revenues		691	361	696
Operating Segments [Member] | West [Member] | Energy Commodities and Service
Segment revenues [Line Items]
Revenues	[5]	4	89	(4)
Operating Segments [Member] | West [Member] | Energy Commodities and Service | Realized Gain (Loss)
Segment revenues [Line Items]
Revenues		4	89	(4)
Operating Segments [Member] | West [Member] | Energy Commodities and Service | Unrealized Gain (Loss)
Segment revenues [Line Items]
Revenues		0	0	0
Operating Segments [Member] | Gas & NGL Marketing Services
Segment revenues [Line Items]
Revenues	[6]	1,789	2,878	3,233
Other financial information:
Product Costs And Net Realized Processing Commodity Expenses		(1,799)	(1,786)	(3,228)
Operating And Administrative Expenses	[1]	(108)	(98)	(96)
Recovery of Direct Costs	[2]	0	0	0
Other Segment Income (Expenses) - Net	[3]	0	(1)	4
Gain (Loss) on Disposition of Business	[4]		0
Proportional Modified EBITDA Equity Method Investments		0	0	0
Modified EBITDA		(124)	950	(40)
Operating Segments [Member] | Gas & NGL Marketing Services | Energy Related Derivative | Not Designated as Hedging Instrument [Member] | Cost of Sales
Other financial information:
Unrealized Gain (Loss) on Derivatives		(6)	(43)	47
Operating Segments [Member] | Gas & NGL Marketing Services | Service [Member]
Segment revenues [Line Items]
Revenues	[6]	0	1	3
Operating Segments [Member] | Gas & NGL Marketing Services | Service [Member] | External Customer
Segment revenues [Line Items]
Revenues	[6]	0	1	3
Operating Segments [Member] | Gas & NGL Marketing Services | Service [Member] | Internal Customer
Segment revenues [Line Items]
Revenues	[6]	0	0	0
Operating Segments [Member] | Gas & NGL Marketing Services | NonRegulated Service Commodity Consideration [Member]
Segment revenues [Line Items]
Revenues	[6]	0	0	0
Operating Segments [Member] | Gas & NGL Marketing Services | Product [Member]
Segment revenues [Line Items]
Revenues	[6]	2,052	2,060	3,534
Operating Segments [Member] | Gas & NGL Marketing Services | Product [Member] | External Customer
Segment revenues [Line Items]
Revenues	[6]	2,500	2,382	4,052
Operating Segments [Member] | Gas & NGL Marketing Services | Product [Member] | Internal Customer
Segment revenues [Line Items]
Revenues	[6]	(448)	(322)	(518)
Operating Segments [Member] | Gas & NGL Marketing Services | Energy Commodities and Service
Segment revenues [Line Items]
Revenues	[5],[6]	(263)	817	(304)
Operating Segments [Member] | Gas & NGL Marketing Services | Energy Commodities and Service | Realized Gain (Loss)
Segment revenues [Line Items]
Revenues	[6]	72	115	17
Operating Segments [Member] | Gas & NGL Marketing Services | Energy Commodities and Service | Unrealized Gain (Loss)
Segment revenues [Line Items]
Revenues	[6]	(335)	702	(321)
Operating Segments [Member] | Reportable Segment, Aggregation before Other Operating Segment
Segment revenues [Line Items]
Revenues		11,111	11,196	11,643
Other financial information:
Modified EBITDA		6,419	7,172	5,641
Operating Segments [Member] | Reportable Segment, Aggregation before Other Operating Segment | Service [Member]
Segment revenues [Line Items]
Revenues		7,877	7,257	6,778
Operating Segments [Member] | Reportable Segment, Aggregation before Other Operating Segment | Service [Member] | External Customer
Segment revenues [Line Items]
Revenues		7,615	7,011	6,520
Operating Segments [Member] | Reportable Segment, Aggregation before Other Operating Segment | Service [Member] | Internal Customer
Segment revenues [Line Items]
Revenues		262	246	258
Operating Segments [Member] | Reportable Segment, Aggregation before Other Operating Segment | NonRegulated Service Commodity Consideration [Member]
Segment revenues [Line Items]
Revenues		134	146	260
Operating Segments [Member] | Reportable Segment, Aggregation before Other Operating Segment | Product [Member]
Segment revenues [Line Items]
Revenues		3,359	2,885	4,913
Operating Segments [Member] | Reportable Segment, Aggregation before Other Operating Segment | Product [Member] | External Customer
Segment revenues [Line Items]
Revenues		2,846	2,642	4,453
Operating Segments [Member] | Reportable Segment, Aggregation before Other Operating Segment | Product [Member] | Internal Customer
Segment revenues [Line Items]
Revenues		513	243	460
Operating Segments [Member] | Reportable Segment, Aggregation before Other Operating Segment | Energy Commodities and Service
Segment revenues [Line Items]
Revenues	[5]	(259)	908	(308)
Operating Segments [Member] | Reportable Segment, Aggregation before Other Operating Segment | Energy Commodities and Service | Realized Gain (Loss)
Segment revenues [Line Items]
Revenues		76	206	13
Operating Segments [Member] | Reportable Segment, Aggregation before Other Operating Segment | Energy Commodities and Service | Unrealized Gain (Loss)
Segment revenues [Line Items]
Revenues		(335)	702	(321)
Corporate, Non-Segment | Other Operating Segment
Segment revenues [Line Items]
Revenues		444	506	651
Other financial information:
Modified EBITDA		237	307	434
Corporate, Non-Segment | Other Operating Segment | Energy Commodities and Service
Segment revenues [Line Items]
Revenues		(26)	1	25
Corporate, Non-Segment | Other Operating Segment | Other [Member]
Segment revenues [Line Items]
Revenues		470	505	626
Intersegment Eliminations [Member]
Segment revenues [Line Items]
Revenues		$ (1,052)	(795)	$ (1,329)
Segment Reporting, Reconciling Item, Excluding Corporate Nonsegment
Other financial information:
Gain (Loss) Related to Litigation Settlement	[7]		$ 534
[1]Segment operating and administrative expenses primarily include payroll, maintenance and operating costs and taxes, and general and administrative expenses, including acquisition and transition-related expenses. It also includes project execution, information technology, finance and accounting, real estate and aviation, central engineering services, safety and operational discipline, supply chain and digital transformation, corporate strategic development, human resources, legal and government affairs, and executive and audit support services costs which are centrally managed and allocated to segments.[2]Recoverable power, transportation and storage costs are charges incurred which are reimbursable pursuant to FERC stipulations or customer contracts.[3]Other segment income (expenses) primarily includes equity AFUDC and regulatory credits and charges related to Williams’ regulated operations.[4]Gain on sale of business reflects a gain recognized on the sale of certain liquids pipelines in the Gulf Coast region in September 2023 (see Note 3 – Acquisitions and Divestitures).[5]Williams records transactions that qualify as commodity derivatives at fair value with changes in fair value recognized in earnings in the period of change and characterized as unrealized gains or losses. Gains and losses from commodity derivatives held for energy trading purposes are presented on a net basis in revenue.[6]As Williams is acting as agent for natural gas marketing customers or engages in energy trading activities, the resulting revenues are presented net of the related costs of those activities.[7]Net gain from Energy Transfer litigation judgment resulted from a favorable ruling in November 2023 (see Note 1 – General, Description of Business, Basis of Presentation, and Summary of Significant Accounting Policies).

Segment Disclosures Recon fro_2

Segment Disclosures Recon from Segment to Consolidated - Assets and Investments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Segment Reporting, Asset Reconciling Item [Line Items]
Equity-method investments	$ 4,107	$ 4,614	$ 5,048
Total assets	54,532	52,627	48,433
Current assets	2,661	4,513	3,797
Other Assets, Noncurrent	1,830	1,573	1,319
Payments to Acquire Productive Assets	5,598	4,313	3,598
Operating Segments [Member] | Transmission And Gulf Of America [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Equity-method investments	272	652	629
Total assets	23,149	19,705	17,795
Payments to Acquire Productive Assets	4,399	2,501	1,420
Operating Segments [Member] | Northeast G And P [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Equity-method investments	3,346	3,477	3,566
Total assets	12,918	13,319	13,539
Payments to Acquire Productive Assets	210	340	261
Operating Segments [Member] | West [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Equity-method investments	476	477	843
Total assets	12,144	12,188	10,710
Payments to Acquire Productive Assets	529	1,186	1,507
Operating Segments [Member] | Gas & NGL Marketing Services
Segment Reporting, Asset Reconciling Item [Line Items]
Equity-method investments	0	0	0
Total assets	46	77	130
Payments to Acquire Productive Assets	2	7	4
Operating Segments [Member] | Reportable Segment, Aggregation before Other Operating Segment
Segment Reporting, Asset Reconciling Item [Line Items]
Equity-method investments	4,094	4,606	5,038
Total assets	48,257	45,289	42,174
Payments to Acquire Productive Assets	5,140	4,034	3,192
Corporate, Non-Segment | Other Operating Segment
Segment Reporting, Asset Reconciling Item [Line Items]
Equity-method investments	13	8	10
Total assets	1,784	1,252	1,143
Payments to Acquire Productive Assets	$ 458	$ 279	$ 406

Subsequent Events (Details)

Subsequent Events (Details) - USD ($) $ / shares in Units, $ in Millions			12 Months Ended
	Jan. 28, 2025	Jan. 15, 2025	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Jan. 09, 2025
Subsequent Event [Line Items]
Common Stock, Dividends, Per Share, Declared			$ 1.90	$ 1.79	$ 1.70
3.9% Senior Unsecured Notes Due 2025 [Member] | Williams Companies Inc [Member]
Subsequent Event [Line Items]
Long-term debt interest rate			3.90%
Subsequent Event [Member]
Subsequent Event [Line Items]
Common Stock, Dividends, Per Share, Declared	$ 0.500
Subsequent Event [Member] | 5.6 Percent Senior Unsecured Notes Due 2035 | Williams Companies Inc [Member]
Subsequent Event [Line Items]
Debt Instrument, Face Amount						$ 1,000
Long-term debt interest rate						5.60%
Subsequent Event [Member] | 6.0 Percent Senior Unsecured Notes Due 2055 | Williams Companies Inc [Member]
Subsequent Event [Line Items]
Debt Instrument, Face Amount						$ 500
Long-term debt interest rate						6%
Subsequent Event [Member] | 3.9% Senior Unsecured Notes Due 2025 [Member] | Williams Companies Inc [Member]
Subsequent Event [Line Items]
Long-term debt interest rate		3.90%
Extinguishment of Debt, Amount		$ 750

Schedule II Valuation and Quali

Schedule II Valuation and Qualifying Accounts (Details) - Deferred Tax Asset Valuation Allowance [Member] - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Valuation And Qualifying Accounts
Beginning Balance	[1]	$ 183	$ 200	$ 297
Additions Charged (Credited) To Cost and Expenses		(92)	(17)	(97)
Additions Other		0	0	0
Deductions		0	0	0
Ending Balance	[1]	$ 91	$ 183	$ 200
[1]Deducted from related assets.