Consolidated Edison (ED) 10-K20 Feb 252024 FY Annual reportFinancial data

Company Profile

Cover Page

Cover Page - USD ($) $ in Billions	12 Months Ended
Cover Page - USD ($) $ in Billions	Dec. 31, 2024	Jan. 31, 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 File Number	1-14514
Entity Registrant Name	Consolidated Edison, Inc.
Entity Incorporation, State or Country Code	NY
Entity Tax Identification Number	13-3965100
Entity Address, Address Line One	4 Irving Place,
Entity Address, City or Town	New York,
Entity Address, State or Province	NY
Entity Address, Postal Zip Code	10003
City Area Code	(212)
Local Phone Number	460-4600
Title of 12(b) Security	Common Shares ($.10 par value)
Trading Symbol	ED
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
Document Financial Statement Error Correction [Flag]	false
Entity Shell Company	false
Entity Public Float			$ 30.8
Entity Common Stock, Shares Outstanding		346,711,639
Documents Incorporated by Reference	Documents Incorporated By Reference Portions of Con Edison’s definitive proxy statement for its Annual Meeting of Stockholders to be held on May 19, 2025, to be filed with the Commission pursuant to Regulation 14A, not later than 120 days after December 31, 2024, is incorporated in Part III of this report.
Amendment Flag	false
Document Fiscal Year Focus	2024
Document Fiscal Period Focus	FY
Entity Central Index Key	0001047862
Current Fiscal Year End Date	--12-31
CECONY
Document Information [Line Items]
Entity File Number	1-1217
Entity Registrant Name	Consolidated Edison Company of New York, Inc.
Entity Incorporation, State or Country Code	NY
Entity Tax Identification Number	13-5009340
Entity Address, Address Line One	4 Irving Place,
Entity Address, City or Town	New York,
Entity Address, State or Province	NY
Entity Address, Postal Zip Code	10003
City Area Code	(212)
Local Phone Number	460-4600
Entity Well-known Seasoned Issuer	Yes
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	true
Entity Shell Company	false
Amendment Flag	false
Document Fiscal Year Focus	2024
Document Fiscal Period Focus	FY
Entity Central Index Key	0000023632
Current Fiscal Year End Date	--12-31

Audit Information

Audit Information	12 Months Ended
Audit Information	Dec. 31, 2024
Auditor Information [Abstract]
Auditor Name	PricewaterhouseCoopers LLP
Auditor Location	New York, New York
Auditor Firm ID	238

Consolidated Income Statement

Consolidated Income Statement - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
OPERATING REVENUES
TOTAL OPERATING REVENUES	$ 15,256	$ 14,663	$ 15,670
OPERATING EXPENSES
Depreciation and amortization	2,155	2,031	2,056
Taxes, other than income taxes	3,280	3,043	3,005
TOTAL OPERATING EXPENSES	12,524	12,332	13,046
Gain (Loss) on sale of the Clean Energy Businesses	(62)	865	0
OPERATING INCOME	2,670	3,196	2,624
OTHER INCOME (DEDUCTIONS)
Investment income	62	62	20
Other income	635	834	402
Allowance for equity funds used during construction	38	26	19
Other deductions	(80)	(92)	(115)
TOTAL OTHER INCOME	655	830	326
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	3,325	4,026	2,950
INTEREST EXPENSE (INCOME)
Interest on long-term debt	1,084	962	987
Other interest expense (income)	166	113	(99)
Allowance for borrowed funds used during construction	(63)	(52)	(36)
NET INTEREST EXPENSE	1,187	1,023	852
INCOME BEFORE INCOME TAX EXPENSE	2,138	3,003	2,098
INCOME TAX EXPENSE	318	487	498
NET INCOME	1,820	2,516	1,600
Loss attributable to non-controlling interest	0	(3)	(60)
NET INCOME FOR COMMON STOCK	$ 1,820	$ 2,519	$ 1,660
Net income per common share — basic (in dollars per share)	$ 5.26	$ 7.25	$ 4.68
Net income per common share — diluted (in dollars per share)	$ 5.24	$ 7.21	$ 4.66
AVERAGE NUMBER OF SHARES OUTSTANDING — BASIC (in shares)	346	347.7	354.5
AVERAGE NUMBER OF SHARES OUTSTANDING — DILUTED (in shares)	347.3	349.3	355.8
Electric
OPERATING REVENUES
TOTAL OPERATING REVENUES	$ 11,568	$ 10,835	$ 10,522
Gas
OPERATING REVENUES
TOTAL OPERATING REVENUES	3,107	3,127	3,237
OPERATING EXPENSES
Operating costs	599	829	1,245
Steam
OPERATING REVENUES
TOTAL OPERATING REVENUES	578	569	593
Non-utility
OPERATING REVENUES
TOTAL OPERATING REVENUES	3	132	1,318
Purchased power
OPERATING EXPENSES
Operating costs	2,569	2,541	2,479
Fuel
OPERATING EXPENSES
Operating costs	170	282	356
Other operations and maintenance
OPERATING EXPENSES
Operating costs	$ 3,751	$ 3,606	$ 3,905

Consolidated Statement of Compr

Consolidated Statement of Comprehensive Income - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Statement of Comprehensive Income [Abstract]
Net income	$ 1,820	$ 2,516	$ 1,600
LOSS ATTRIBUTABLE TO NON-CONTROLLING INTEREST	0	3	60
OTHER COMPREHENSIVE INCOME, NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	7	0	16
Other income, net of taxes	0	0	1
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	7	0	17
COMPREHENSIVE INCOME	$ 1,827	$ 2,519	$ 1,677

Consolidated Statement of Cash

Consolidated Statement of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
OPERATING ACTIVITIES
Net income	$ 1,820	$ 2,516	$ 1,600
PRINCIPAL NON-CASH CHARGES (CREDITS) TO INCOME
Depreciation and amortization	2,155	2,031	2,056
Deferred income taxes	416	132	435
Rate case amortization and accruals	201	92	73
Net derivative (gains) losses	0	12	(181)
Pre-tax loss (gain) on sale of the Clean Energy Businesses	62	(865)	0
Other non-cash items, net	(85)	(93)	102
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable - customers, net	(263)	(275)	(296)
Unbilled revenue and net unbilled revenue deferrals	75	(48)	(96)
Materials and supplies, including fuel oil and gas in storage	(16)	38	(111)
Revenue decoupling mechanism receivable	0	(39)	26
Other receivables, net and other current assets	87	141	(36)
Taxes receivable	(144)	3	3
Prepayments	25	(200)	26
Accounts payable	(1)	(285)	558
Pensions and retiree benefits obligations, net	(284)	(179)	155
Pensions and retiree benefits contributions	(26)	(33)	(39)
Accrued taxes	(5)	(13)	7
Accrued interest	28	(7)	42
Superfund and environmental remediation costs, net	(43)	(12)	(22)
Distributions from equity investments	35	31	20
Deferred charges, noncurrent assets, leases, net and other regulatory assets	(797)	(1,200)	(833)
Deferred credits, noncurrent liabilities and other regulatory liabilities	475	196	445
Other current liabilities	(101)	213	1
NET CASH FLOWS FROM OPERATING ACTIVITIES	3,614	2,156	3,935
INVESTING ACTIVITIES
Utility capital expenditures	(4,770)	(4,353)	(3,824)
Cost of removal less salvage	(474)	(387)	(337)
Non-utility capital expenditures	(1)	(141)	(344)
Proceeds from sale of the Clean Energy Businesses, net of cash and cash equivalents sold	0	3,927	0
Other investing activities	(28)	(49)	(60)
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(5,273)	(1,003)	(4,565)
FINANCING ACTIVITIES
Net issuance (payment) of short-term debt	(118)	(202)	1,152
Issuance of term loan	500	200	550
Retirement of term loan	0	(750)	0
Issuance of long-term debt	2,975	2,050	800
Retirement of long-term debt	(477)	(710)	(406)
Debt issuance costs	(43)	(32)	(13)
Common stock dividends	(1,100)	(1,096)	(1,089)
Issuance of common shares for stock plans	60	56	57
Repurchase of common shares	0	(1,000)	0
Distribution to noncontrolling interest	0	(4)	(37)
NET CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES	1,797	(1,488)	1,014
CASH, TEMPORARY CASH INVESTMENTS, AND RESTRICTED CASH:
NET CHANGE FOR THE PERIOD	138	(335)	384
BALANCE AT BEGINNING OF PERIOD	1,195	1,530	1,146
BALANCE AT END OF PERIOD	1,333	1,195	1,530
Total cash, temporary cash investments and restricted cash	1,333	1,195	1,530
LESS: CASH AND RESTRICTED CASH BALANCES HELD FOR SALE	9	5	248
BALANCE AT END OF PERIOD EXCLUDING HELD FOR SALE	1,324	1,190	1,282
Cash paid during the period for:
Interest, net of capitalized interest	1,072	987	900
Income taxes	7	397	47
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures in accounts payable	501	598	681
Issuance of common shares for dividend reinvestment	49	31	31
Software Licenses
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	0	0	2
Equipment
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	$ 6	$ 11	$ 17

Consolidated Balance Sheet

Consolidated Balance Sheet - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
CURRENT ASSETS
Cash and temporary cash investments	$ 1,324	$ 1,189
Accounts receivable - customers, less allowance for uncollectible accounts	2,440	2,418
Other receivables, less allowance for uncollectible accounts	292	444
Accrued unbilled revenue	848	722
Taxes receivable	145	1
Fuel oil, gas in storage, materials and supplies, at average cost	485	469
Prepayments	445	470
Regulatory assets	141	281
Revenue decoupling mechanism receivable	202	203
Fair value of derivative assets	15	52
Assets held for sale	133	163
Other current assets	194	125
TOTAL CURRENT ASSETS	6,664	6,537
INVESTMENTS	1,126	999
UTILITY PLANT, AT ORIGINAL COST
General	4,851	4,835
TOTAL	64,371	61,309
Less: Accumulated depreciation	15,384	14,157
Net	48,987	47,152
Construction work in progress	3,165	2,442
NET UTILITY PLANT	52,152	49,594
NON-UTILITY PLANT
Non-utility property, net accumulated depreciation	12	13
Construction work in progress	1	1
NET PLANT	52,165	49,608
OTHER NONCURRENT ASSETS
Goodwill	408	408
Operating lease right-of-use-asset	493	533
Regulatory assets	5,523	4,607
Pension and retiree benefits	3,791	3,275
Fair value of derivative assets	27	48
Other deferred charges and noncurrent assets	365	316
TOTAL OTHER NONCURRENT ASSETS	10,607	9,187
TOTAL ASSETS	70,562	66,331
CURRENT LIABILITIES
Long-term debt due within one year	0	250
Term loan	500	0
Notes payable	2,170	2,288
Accounts payable	1,676	1,775
Customer deposits	412	396
Accrued taxes	70	73
Accrued interest	199	170
Accrued wages	127	125
Fair value of derivative liabilities	52	193
Regulatory liabilities	102	145
System benefit charge	447	444
Operating lease liabilities	118	116
Liabilities held for sale	79	76
Other current liabilities	481	411
TOTAL CURRENT LIABILITIES	6,433	6,462
NONCURRENT LIABILITIES
Provision for injuries and damages	181	188
Pensions and retiree benefits	551	592
Superfund and other environmental costs	1,037	1,118
Asset retirement obligations	453	522
Fair value of derivative liabilities	96	121
Deferred income taxes and unamortized investment tax credits	8,874	8,069
Operating lease liabilities	386	429
Regulatory liabilities	5,444	5,328
Other deferred credits and noncurrent liabilities	494	417
TOTAL NONCURRENT LIABILITIES	17,516	16,784
LONG-TERM DEBT	24,651	21,927
COMMITMENTS, CONTINGENCIES, AND GUARANTEES (Note B, Note G, and Note H)
SHAREHOLDERS' EQUITY	21,962	21,158
TOTAL LIABILITIES AND EQUITY	70,562	66,331
Electric
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	41,206	39,071
Gas
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	15,127	14,318
Steam
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	$ 3,187	$ 3,085

Consolidated Balance Sheet (Par

Consolidated Balance Sheet (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Statement of Financial Position [Abstract]
Accounts receivable - customers, allowance for uncollectible accounts	$ 620	$ 360
Other receivables, allowance for uncollectible accounts	41	13
Non-utility property, accumulated depreciation	$ 25	$ 24

Consolidated Statement of Equit

Consolidated Statement of Equity - USD ($) $ in Millions	Total	Common Stock	Additional Paid-In Capital	Retained Earnings	Treasury Stock	Capital Stock Expense	Accumulated Other Comprehensive Income	Non-controlling Interest
BALANCE AS OF BEGINNING OF PERIOD (in shares) at Dec. 31, 2021		354,000,000
BALANCE AS OF BEGINNING OF PERIOD at Dec. 31, 2021	$ 20,336	$ 37	$ 9,710	$ 11,445	$ (1,038)	$ (122)	$ 5	$ 299
Beginning Balance (in shares) at Dec. 31, 2021					23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	1,600			1,660				(60)
Common stock dividends	(1,120)			(1,120)
Issuance of common shares for stock plans (in shares)		1,000,000
Issuance of common shares for stock plans	93		93
Other comprehensive income (loss)	17						17
Distributions to noncontrolling interests	(37)							(37)
BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2022		355,000,000
BALANCE AS OF END OF PERIOD at Dec. 31, 2022	20,889	$ 37	9,803	11,985	$ (1,038)	(122)	22	202
Ending Balance (in shares) at Dec. 31, 2022					23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	2,516			2,519				(3)
Common stock dividends	(1,127)			(1,127)
Issuance of common shares for stock plans (in shares)		1,000,000
Issuance of common shares for stock plans	89		89
Distributions to noncontrolling interests	(4)							(4)
Common stock repurchases (in shares)		(11,000,000)			11,000,000
Common stock repurchases	(1,010)		(31)		$ (979)
Disposal of Clean Energy Businesses	$ (195)							195
BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2023	345,415,772	345,000,000
BALANCE AS OF END OF PERIOD at Dec. 31, 2023	$ 21,158	$ 37	9,861	13,377	$ (2,017)	(122)	22	0
Ending Balance (in shares) at Dec. 31, 2023					34,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	1,820			1,820
Common stock dividends	(1,149)			(1,149)
Issuance of common shares for stock plans (in shares)		2,000,000
Issuance of common shares for stock plans	113	$ 1	112
Other comprehensive income (loss)	$ 7						7
Common stock repurchases (in shares)	(10,543,263)
Stock Awards	$ 13		13
BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2024	346,597,693	347,000,000
BALANCE AS OF END OF PERIOD at Dec. 31, 2024	$ 21,962	$ 38	$ 9,986	$ 14,048	$ (2,017)	$ (122)	$ 29	$ 0
Ending Balance (in shares) at Dec. 31, 2024	33,753,963				34,000,000

Consolidated Statement of Equ_2

Consolidated Statement of Equity (Parenthetical) - $ / shares	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Statement of Stockholders' Equity [Abstract]
Common stock dividends per share (in dollars per share)	$ 3.32	$ 3.24	$ 3.16

Consolidated Statement of Capit

Consolidated Statement of Capitalization - USD ($) shares in Millions, $ in Millions	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Regulated Operations [Abstract]
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE LOSS (in shares)	347	345
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE INCOME	$ 21,933	$ 21,136
Pension and other postretirement benefit plan liability adjustments, net of taxes	30	23
Unrealized losses on derivatives qualified as cash flow hedges, less reclassification adjustment for gains (losses) included in net income and reclassification adjustment for unrealized losses included in regulatory assets, net of taxes	(1)	(1)
TOTAL ACCUMULATED OTHER COMPREHENSIVE INCOME, NET OF TAXES	29	22
SHAREHOLDERS' EQUITY	$ 21,962	$ 21,158	$ 20,889	$ 20,336

Consolidated Statement of Cap_2

Consolidated Statement of Capitalization - Long-term Debt - USD ($) $ in Millions		Dec. 31, 2024	Dec. 31, 2023
Schedule of Capitalization, Long-term Debt [Line Items]
Unamortized debt expense		$ (179)	$ (162)
Unamortized debt discount		(70)	(60)
TOTAL		24,710	22,240
Less: Long-term debt due within one year		0	251
TOTAL LONG-TERM DEBT		24,710	21,989
Less: Held for sale project debt, net		59	62
TOTAL LONG-TERM DEBT EXCLUDING HELD FOR SALE		24,651	21,927
TOTAL CAPITALIZATION		$ 46,613	43,085
Broken Bow II
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[1]	4.82%
TOTAL PROJECT DEBT	[1]	$ 59	62
Project Debt
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL PROJECT DEBT		59	62
Debentures
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL		$ 24,675	21,950
Debentures \| Debenture 2014B, 3.30 Percent, Due 2024
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.30%
TOTAL		$ 0	250
Debentures \| Debenture Series 2016B, 2.90% Due 2026
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		2.90%
TOTAL		$ 250	250
Debentures \| Debenture Series 1997F, 6.50% Due 2027
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		6.50%
TOTAL		$ 80	80
Debentures \| Debenture Series 2017B, 3.125% Due 2027
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.125%
TOTAL		$ 350	350
Debentures \| Debenture Series 2017B, 4.825% Due 2027
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[2]	4.825%
TOTAL	[2]	$ 350	0
Debentures \| Debenture Series 2018A, 3.80% Due 2028
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.80%
TOTAL		$ 300	300
Debentures \| Debenture Series 2018D, 4.00% Due 2028
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4%
TOTAL		$ 500	500
Debentures \| Debenture 2019B, 2.94 Percent, Due 2029
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		2.94%
TOTAL		$ 44	44
Debentures \| Debenture 2020A, 3.35 Percent, Due 2030
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.35%
TOTAL		$ 600	600
Debentures \| Debenture 2020A, 2.02 Percent, Due 2030
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		2.02%
TOTAL		$ 35	35
Debentures \| Debenture 2021A, 2.40 Percent, Due 2031
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		2.40%
TOTAL		$ 900	900
Debentures \| Debenture 2021A, 2.31 Percent, Due 2031
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		2.31%
TOTAL		$ 45	45
Debentures \| Debenture 2022A, 5.70 Percent, Due 2032
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.70%
TOTAL		$ 100	100
Debentures \| Debenture Series 2003A, 5.875% Due 2033
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.875%
TOTAL		$ 175	175
Debentures \| Debenture Series 2003C, 5.10% Due 2033
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.10%
TOTAL		$ 200	200
Debentures \| Debenture Series 2023A, 5.20% Due 2033
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.20%
TOTAL		$ 500	500
Debentures \| Debenture Series 2004B, 5.70% Due 2034
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.70%
TOTAL		$ 200	200
Debentures \| Debenture Series 2023B, 5.50% Due 2034
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.50%
TOTAL		$ 600	600
Debentures \| Debenture 2024A, 5.375 Percent, Due 2034
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.375%
TOTAL		$ 400	0
Debentures \| Debenture Series 2005A, 5.30% Due 2035
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.30%
TOTAL		$ 350	350
Debentures \| Debenture Series 2005 B 5.25% Due 2035
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.25%
TOTAL		$ 125	125
Debentures \| Debenture Series 2024 D 5.125% Due 2035
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.125%
TOTAL		$ 450	0
Debentures \| Debenture Series 2006A, 5.85% Due 2036
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.85%
TOTAL		$ 400	400
Debentures \| Debenture Series 2006B, 6.20% Due 2036
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		6.20%
TOTAL		$ 400	400
Debentures \| Debenture Series 2006E, 5.70% Due 2036
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.70%
TOTAL		$ 250	250
Debentures \| Debenture Series 2007A, 6.30% Due 2037
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		6.30%
TOTAL		$ 525	525
Debentures \| Debenture 2008B, 6.75 Percent, Due 2038
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		6.75%
TOTAL		$ 600	600
Debentures \| Debenture 2009B, 6.00 Percent, Due 2039
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		6%
TOTAL		$ 60	60
Debentures \| Debenture 2009C, 5.50 Percent, Due 2039
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.50%
TOTAL		$ 600	600
Debentures \| Debenture 2019C, 3.46 Percent, Due 2039
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.46%
TOTAL		$ 38	38
Debentures \| Debenture 2010B, 5.70 Percent, Due 2040
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.70%
TOTAL		$ 350	350
Debentures \| Debenture 2010B, 5.50 Percent, Due 2040
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.50%
TOTAL		$ 115	115
Debentures \| Debenture 2012A, 4.20 Percent, Due 2042
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.20%
TOTAL		$ 400	400
Debentures \| Debenture 2013A, 3.95 Percent, Due 2043
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.95%
TOTAL		$ 700	700
Debentures \| Debenture 2014A, 4.45 Percent, Due 2044
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.45%
TOTAL		$ 850	850
Debentures \| Debenture 2015A, 4.50 Percent, Due 2045
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.50%
TOTAL		$ 650	650
Debentures \| Debenture 2015A, 4.95 Percent, Due 2045
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.95%
TOTAL		$ 120	120
Debentures \| Debenture Series 2015B, 4.69% due 2045
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.69%
TOTAL		$ 100	100
Debentures \| Debenture 2016A, 3.85 Percent, Due 2046
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.85%
TOTAL		$ 550	550
Debentures \| Debenture Series 2016A. 3.88% Due 2046
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.88%
TOTAL		$ 75	75
Debentures \| Debenture Series 2017A, 3.875% Due 2047
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.875%
TOTAL		$ 500	500
Debentures \| Debenture Series 2018E, 4.65% Due 2048
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.65%
TOTAL		$ 600	600
Debentures \| Debenture Series 2018A, 4.35% Due 2048
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.35%
TOTAL		$ 125	125
Debentures \| Debenture Series 2018B, 4.35% Due 2048
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.35%
TOTAL		$ 25	25
Debentures \| Debenture 2019A, 4.125 Percent, Due 2049
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.125%
TOTAL		$ 700	700
Debentures \| Debenture 2019A, 3.73 Percent, Due 2049
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.73%
TOTAL		$ 43	43
Debentures \| Debenture 2020B, 3.95 Percent, Due 2050
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.95%
TOTAL		$ 1,000	1,000
Debentures \| Debenture 2020B, 3.24 Percent, Due 2050
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.24%
TOTAL		$ 40	40
Debentures \| Debenture 2021B, 3.170 Percent, Due 2051
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.17%
TOTAL		$ 30	30
Debentures \| Debenture 2021C, 3.20 Percent, Due 2051
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.20%
TOTAL		$ 600	600
Debentures \| Debenture 2022A, 6.15%, Due 2052
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		6.15%
TOTAL		$ 700	700
Debentures \| Debenture 2023C, 5.90%, Due 2053
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.90%
TOTAL		$ 900	900
Debentures \| Debenture 2023A, 6.59%, Due 2053
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		659%
TOTAL		$ 50	50
Debentures \| Debenture 2024B, 5.70 Percent, Due 2054
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.70%
TOTAL		$ 1,000	0
Debentures \| Debenture 2024A, 5.41 Percent, Due 2054
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.41%
TOTAL		$ 125	0
Debentures \| Debenture Series 2014C, 4.625% Due 2054
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.625%
TOTAL		$ 750	750
Debentures \| Debenture 2024E, 5.50 Percent, Due 2055
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.50%
TOTAL		$ 650	0
Debentures \| Debenture Series 2016C, 4.30% Due 2056
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.30%
TOTAL		$ 500	500
Debentures \| Debenture Series 2017C, 4.00% Due 2057
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4%
TOTAL		$ 350	350
Debentures \| Debenture Series 2018B, 4.50% Due 2058
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.50%
TOTAL		$ 700	700
Debentures \| Debenture 2019B, 3.70 Percent, Due 2059
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.70%
TOTAL		$ 600	600
Debentures \| Debenture 2020C, 3.00 Percent, Due 2060
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3%
TOTAL		$ 600	600
Debentures \| Debenture 2021B, 3.60 Percent, Due 2061
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.60%
TOTAL		$ 750	750
Tax-Exempt Debt
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL PROJECT DEBT		$ 225	450
Tax-Exempt Debt \| Tax Exempt Debt Series 2010A Due 2024
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[3]	3.23%
TOTAL PROJECT DEBT	[3]	$ 0	225
Tax-Exempt Debt \| Tax Exempt Debt Series 2004C, 1.663% Due 2039
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[4]	3.47%
TOTAL PROJECT DEBT	[4]	$ 99	99
Tax-Exempt Debt \| Tax-Exempt Debt Series 2005A, 1.627% Due 2039
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[4]	3.40%
TOTAL PROJECT DEBT	[4]	$ 126	$ 126

[1] (d) The sale and transfer of Broken Bow II, including the related debt, was completed in January 2025. See Notes C, W and X. (a) Rates reset quarterly; December 31, 2024 floating rate equals SOFR+0.52 percent. (c) Rates reset weekly; December 31, 2024 rates shown

Consolidated Statement of Cap_3

Consolidated Statement of Capitalization - Long-term Debt (Parenthetical) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2024	Nov. 30, 2024	Dec. 31, 2023
Tax-Exempt Debt
Schedule of Capitalization, Long-term Debt [Line Items]
Long-Term Debt, Gross		$ 225		$ 450
Debenture Series 2017B, 4.825% Due 2027 \| Debentures
Schedule of Capitalization, Long-term Debt [Line Items]
Debt instrument, SOFR variable rate		52%
Tax Exempt Debt Series 2010A Due 2024 \| Tax-Exempt Debt
Schedule of Capitalization, Long-term Debt [Line Items]
Long-Term Debt, Gross	[1]	$ 0	$ 225	$ 225

[1]In November 2024, all of the $225 million of Series 2010A tax-exempt bonds issued for the benefit of CECONY, bearing interest at a weekly rate, were redeemed.

Consolidated Income Statement _

Consolidated Income Statement - CECONY - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
OPERATING REVENUES
TOTAL OPERATING REVENUES	$ 15,256	$ 14,663	$ 15,670
OPERATING EXPENSES
Depreciation and amortization	2,155	2,031	2,056
Taxes, other than income taxes	3,280	3,043	3,005
TOTAL OPERATING EXPENSES	12,524	12,332	13,046
Operating income	2,670	3,196	2,624
OTHER INCOME (DEDUCTIONS)
Investment income	62	62	20
Allowance for equity funds used during construction	38	26	19
Other deductions	(80)	(92)	(115)
TOTAL OTHER INCOME	655	830	326
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	3,325	4,026	2,950
INTEREST EXPENSE (INCOME)
Interest on long-term debt	1,084	962	987
Other interest expense (income)	166	113	(99)
Allowance for borrowed funds used during construction	(63)	(52)	(36)
NET INTEREST EXPENSE	1,187	1,023	852
INCOME BEFORE INCOME TAX EXPENSE	2,138	3,003	2,098
INCOME TAX EXPENSE	318	487	498
NET INCOME FOR COMMON STOCK	1,820	2,519	1,660
CECONY
OPERATING REVENUES
TOTAL OPERATING REVENUES	14,129	13,476	13,268
OPERATING EXPENSES
Depreciation and amortization	2,037	1,924	1,778
Taxes, other than income taxes	3,173	2,946	2,887
TOTAL OPERATING EXPENSES	11,536	11,299	11,133
Operating income	2,593	2,177	2,135
OTHER INCOME (DEDUCTIONS)
Investment income	603	759	376
Allowance for equity funds used during construction	33	22	18
Other deductions	(58)	(49)	(62)
TOTAL OTHER INCOME	578	732	332
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	3,171	2,909	2,467
INTEREST EXPENSE (INCOME)
Interest on long-term debt	1,029	886	808
Other interest expense (income)	138	108	47
Allowance for borrowed funds used during construction	(58)	(49)	(33)
NET INTEREST EXPENSE	1,109	945	822
INCOME BEFORE INCOME TAX EXPENSE	2,062	1,964	1,645
INCOME TAX EXPENSE	314	358	255
NET INCOME FOR COMMON STOCK	1,748	1,606	1,390
Electric
OPERATING REVENUES
TOTAL OPERATING REVENUES	11,568	10,835	10,522
Electric \| CECONY
OPERATING REVENUES
TOTAL OPERATING REVENUES	10,717	10,078	9,751
Gas
OPERATING REVENUES
TOTAL OPERATING REVENUES	3,107	3,127	3,237
OPERATING EXPENSES
Operating costs	599	829	1,245
Gas \| CECONY
OPERATING REVENUES
TOTAL OPERATING REVENUES	2,834	2,829	2,924
OPERATING EXPENSES
Operating costs	524	677	869
Steam
OPERATING REVENUES
TOTAL OPERATING REVENUES	578	569	593
Steam \| CECONY
OPERATING REVENUES
TOTAL OPERATING REVENUES	578	569	593
Purchased power
OPERATING EXPENSES
Operating costs	2,569	2,541	2,479
Purchased power \| CECONY
OPERATING EXPENSES
Operating costs	2,279	2,294	2,201
Fuel
OPERATING EXPENSES
Operating costs	170	282	356
Fuel \| CECONY
OPERATING EXPENSES
Operating costs	170	282	356
Other operations and maintenance
OPERATING EXPENSES
Operating costs	3,751	3,606	3,905
Other operations and maintenance \| CECONY
OPERATING EXPENSES
Operating costs	3,353	3,176	3,042
Non-utility
OPERATING REVENUES
TOTAL OPERATING REVENUES	$ 3	$ 132	$ 1,318

Consolidated Statement of Com_2

Consolidated Statement of Comprehensive Income - CECONY - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
NET INCOME	$ 1,820	$ 2,519	$ 1,660
Pension and other postretirement benefit plan liability adjustments, net of taxes	7	0	16
Other income, net of taxes	0	0	1
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	7	0	17
COMPREHENSIVE INCOME	1,827	2,519	1,677
CECONY
NET INCOME	1,748	1,606	1,390
Pension and other postretirement benefit plan liability adjustments, net of taxes	8	(2)	3
Other income, net of taxes	0	0	1
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	8	(2)	4
COMPREHENSIVE INCOME	$ 1,756	$ 1,604	$ 1,394

Consolidated Statement of Cas_2

Consolidated Statement of Cash Flows - CECONY - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
OPERATING ACTIVITIES
Net income for common stock	$ 1,820	$ 2,519	$ 1,660
PRINCIPAL NON-CASH CHARGES (CREDITS) TO INCOME
Depreciation and amortization	2,155	2,031	2,056
Deferred income taxes	416	132	435
Rate case amortization and accruals	201	92	73
Other non-cash items, net	(85)	(93)	102
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable	(263)	(275)	(296)
Materials and supplies, including fuel oil and gas in storage	(16)	38	(111)
Revenue decoupling mechanism receivable	0	(39)	26
Other receivables, net and other current assets	87	141	(36)
Unbilled revenue and net unbilled revenue deferrals	75	(48)	(96)
Prepayments	25	(200)	26
Accounts payable	(1)	(285)	558
Pensions and retiree benefits obligations, net	(284)	(179)	155
Pensions and retiree benefits contributions	(26)	(33)	(39)
Superfund and environmental remediation costs, net	(43)	(12)	(22)
Accrued taxes	(5)	(13)	7
Accrued interest	28	(7)	42
Deferred charges, noncurrent assets, leases, net and other regulatory assets	(797)	(1,200)	(833)
Deferred credits, noncurrent liabilities and other regulatory liabilities	475	196	445
Other current liabilities	(101)	213	1
NET CASH FLOWS FROM OPERATING ACTIVITIES	3,614	2,156	3,935
INVESTING ACTIVITIES
Utility capital expenditures	(4,770)	(4,353)	(3,824)
Cost of removal less salvage	(474)	(387)	(337)
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(5,273)	(1,003)	(4,565)
FINANCING ACTIVITIES
Net issuance (payment) of short-term debt	(118)	(202)	1,152
Issuance of long-term debt	2,975	2,050	800
Retirement of long-term debt	(477)	(710)	(406)
Debt issuance costs	(43)	(32)	(13)
NET CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES	1,797	(1,488)	1,014
CASH, TEMPORARY CASH INVESTMENTS, AND RESTRICTED CASH:
NET CHANGE FOR THE PERIOD	138	(335)	384
BALANCE AT BEGINNING OF PERIOD	1,195	1,530	1,146
BALANCE AT END OF PERIOD	1,333	1,195	1,530
Cash paid during the period for:
Interest, net of capitalized interest	1,072	987	900
Income taxes	7	397	47
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures in accounts payable	501	598	681
CECONY
OPERATING ACTIVITIES
Net income for common stock	1,748	1,606	1,390
PRINCIPAL NON-CASH CHARGES (CREDITS) TO INCOME
Depreciation and amortization	2,037	1,924	1,778
Deferred income taxes	464	556	85
Rate case amortization and accruals	179	72	55
Other non-cash items, net	(27)	(42)	160
CHANGES IN ASSETS AND LIABILITIES
Materials and supplies, including fuel oil and gas in storage	(7)	18	(71)
Revenue decoupling mechanism receivable	13	(26)	27
Other receivables, net and other current assets	86	(134)	99
Unbilled revenue and net unbilled revenue deferrals	64	(47)	(28)
Prepayments	(66)	(106)	(11)
Accounts payable	8	(137)	322
Accounts payable from (to) affiliated companies	6	(1)	(1)
Pensions and retiree benefits obligations, net	(283)	(181)	162
Pensions and retiree benefits contributions	(26)	(33)	(26)
Superfund and environmental remediation costs, net	(43)	(12)	(20)
Accrued interest	26	25	7
Deferred charges, noncurrent assets, leases, net and other regulatory assets	(677)	(1,142)	(814)
Deferred credits, noncurrent liabilities and other regulatory liabilities	447	199	332
Other current liabilities	(99)	239	7
NET CASH FLOWS FROM OPERATING ACTIVITIES	3,358	2,285	3,263
INVESTING ACTIVITIES
Utility capital expenditures	(4,456)	(4,059)	(3,596)
Cost of removal less salvage	(467)	(380)	(330)
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(4,923)	(4,439)	(3,926)
FINANCING ACTIVITIES
Net issuance (payment) of short-term debt	(209)	(397)	939
Issuance of term loan	500	0	0
Issuance of long-term debt	2,850	2,000	700
Retirement of long-term debt	(475)	0	0
Debt issuance costs	(42)	(31)	(12)
Capital contribution by Con Edison	130	1,720	150
Dividend to Con Edison	(1,073)	(1,056)	(978)
NET CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES	1,681	2,236	799
CASH, TEMPORARY CASH INVESTMENTS, AND RESTRICTED CASH:
NET CHANGE FOR THE PERIOD	116	82	136
BALANCE AT BEGINNING OF PERIOD	1,138	1,056	920
BALANCE AT END OF PERIOD	1,254	1,138	1,056
Cash paid during the period for:
Interest, net of capitalized interest	1,001	882	755
Income taxes	63	(27)	87
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures in accounts payable	461	564	561
CECONY \| Nonrelated Party
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable	(264)	(270)	(276)
Accrued taxes	10	(35)	15
CECONY \| Related Party
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable	(238)	(100)	(8)
Accrued taxes	0	(88)	79
Software Licenses
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	0	0	2
Software Licenses \| CECONY
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	0	0	2
Equipment
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	6	11	17
Equipment \| CECONY
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	$ 6	$ 11	$ 17

Consolidated Balance Sheet - CE

Consolidated Balance Sheet - CECONY - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
CURRENT ASSETS
Cash and temporary cash investments	$ 1,324	$ 1,189
Accounts receivable - customers, less allowance for uncollectible accounts	2,440	2,418
Other receivables, less allowance for uncollectible accounts	292	444
Accrued unbilled revenue	848	722
Fuel oil, gas in storage, materials and supplies, at average cost	485	469
Prepayments	445	470
Regulatory assets	141	281
Revenue decoupling mechanism receivable	202	203
Fair value of derivative assets	15	52
Other current assets	194	125
TOTAL CURRENT ASSETS	6,664	6,537
INVESTMENTS	1,126	999
UTILITY PLANT, AT ORIGINAL COST
General	4,851	4,835
TOTAL	64,371	61,309
Less: Accumulated depreciation	15,384	14,157
Net	48,987	47,152
Construction work in progress	3,165	2,442
NET UTILITY PLANT	52,152	49,594
NON-UTILITY PLANT
Non-utility property, net accumulated depreciation	12	13
NET PLANT	52,165	49,608
OTHER NONCURRENT ASSETS
Regulatory assets	5,523	4,607
Operating lease right-of-use-asset	493	533
Pension and retiree benefits	3,791	3,275
Fair value of derivative assets	27	48
Other deferred charges and noncurrent assets	365	316
Other deferred charges and noncurrent assets	10,607	9,187
TOTAL ASSETS	70,562	66,331
CURRENT LIABILITIES
Long-term debt due within one year	0	250
Term loan	500	0
Notes payable	2,170	2,288
Accounts payable	1,676	1,775
Customer deposits	412	396
Accrued taxes	70	73
Accrued interest	199	170
Accrued wages	127	125
Fair value of derivative liabilities	52	193
Regulatory liabilities	102	145
System benefit charge	447	444
Operating lease liabilities	118	116
Other current liabilities	481	411
TOTAL CURRENT LIABILITIES	6,433	6,462
NONCURRENT LIABILITIES
Provision for injuries and damages	181	188
Pensions and retiree benefits	551	592
Superfund and other environmental costs	1,037	1,118
Asset retirement obligations	453	522
Fair value of derivative liabilities	96	121
Deferred income taxes and unamortized investment tax credits	8,874	8,069
Operating lease liabilities	386	429
Regulatory liabilities	5,444	5,328
Other deferred credits and noncurrent liabilities	494	417
TOTAL NONCURRENT LIABILITIES	17,516	16,784
LONG-TERM DEBT	24,651	21,927
COMMITMENTS, CONTINGENCIES, AND GUARANTEES (Note B, Note G, and Note H)
TOTAL LIABILITIES AND EQUITY	70,562	66,331
Electric
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	41,206	39,071
Gas
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	15,127	14,318
Steam
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	3,187	3,085
CECONY
CURRENT ASSETS
Cash and temporary cash investments	1,254	1,138
Other receivables, less allowance for uncollectible accounts	216	332
Accrued unbilled revenue	803	678
Fuel oil, gas in storage, materials and supplies, at average cost	429	422
Prepayments	395	329
Regulatory assets	106	254
Revenue decoupling mechanism receivable	177	190
Fair value of derivative assets	11	49
Other current assets	181	113
TOTAL CURRENT ASSETS	6,298	5,981
INVESTMENTS	684	608
UTILITY PLANT, AT ORIGINAL COST
General	4,520	4,530
TOTAL	60,388	57,649
Less: Accumulated depreciation	14,319	13,171
Net	46,069	44,478
Construction work in progress	2,912	2,168
NET UTILITY PLANT	48,981	46,646
NON-UTILITY PLANT
Non-utility property, net accumulated depreciation	2	2
NET PLANT	48,983	46,648
OTHER NONCURRENT ASSETS
Regulatory assets	5,158	4,314
Operating lease right-of-use-asset	492	532
Pension and retiree benefits	3,692	3,184
Fair value of derivative assets	25	49
Other deferred charges and noncurrent assets	318	284
Other deferred charges and noncurrent assets	9,685	8,363
TOTAL ASSETS	65,650	61,600
CURRENT LIABILITIES
Long-term debt due within one year	0	250
Notes payable	1,694	1,903
Customer deposits	397	378
Accrued taxes	65	55
Accrued taxes to affiliated companies	1	1
Accrued interest	185	159
Accrued wages	116	114
Fair value of derivative liabilities	44	179
Regulatory liabilities	40	107
System benefit charge	406	406
Operating lease liabilities	118	116
Other current liabilities	437	381
TOTAL CURRENT LIABILITIES	5,559	5,694
NONCURRENT LIABILITIES
Provision for injuries and damages	176	185
Pensions and retiree benefits	506	542
Superfund and other environmental costs	942	1,026
Asset retirement obligations	452	520
Fair value of derivative liabilities	84	108
Deferred income taxes and unamortized investment tax credits	8,819	7,984
Operating lease liabilities	386	429
Regulatory liabilities	4,940	4,818
Other deferred credits and noncurrent liabilities	406	338
TOTAL NONCURRENT LIABILITIES	16,711	15,950
LONG-TERM DEBT		20,810
COMMITMENTS, CONTINGENCIES, AND GUARANTEES (Note B, Note G, and Note H)
SHAREHOLDER’S EQUITY (See Statement of Shareholder’s Equity)	19,971	19,146
TOTAL LIABILITIES AND EQUITY	65,650	61,600
CECONY \| Nonrelated Party
CURRENT ASSETS
Accounts receivable - customers, less allowance for uncollectible accounts	2,342	2,330
CURRENT LIABILITIES
Accounts payable	1,534	1,629
CECONY \| Related Party
CURRENT ASSETS
Accounts receivable - customers, less allowance for uncollectible accounts	384	146
CURRENT LIABILITIES
Accounts payable	22	16
CECONY \| Electric
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	38,747	36,808
CECONY \| Gas
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	13,934	13,226
CECONY \| Steam
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	$ 3,187	$ 3,085

Consolidated Balance Sheet - _2

Consolidated Balance Sheet - CECONY (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Accounts receivable - customers, allowance for uncollectible accounts	$ 620	$ 360
Other receivables, allowance for uncollectible accounts	41	13
Non-utility property, accumulated depreciation	25	24
CECONY
Accounts receivable - customers, allowance for uncollectible accounts	605	353
Other receivables, allowance for uncollectible accounts	38	9
Non-utility property, accumulated depreciation	$ 25	$ 25

Consolidated Statement of Share

Consolidated Statement of Shareholder’s Equity - CECONY - USD ($) $ in Millions	Total	CECONY	Common Stock	Common Stock CECONY	Additional Paid-In Capital	Additional Paid-In Capital CECONY	Retained Earnings	Retained Earnings CECONY	Repurchased Con Edison Stock CECONY	Capital Stock Expense CECONY	Accumulated Other Comprehensive Income	Accumulated Other Comprehensive Income CECONY
BALANCE AS OF BEGINNING OF PERIOD (in shares) at Dec. 31, 2021			354,000,000	235,000,000
BALANCE AS OF BEGINNING OF PERIOD at Dec. 31, 2021		$ 16,312		$ 589		$ 7,269		$ 9,478	$ (962)	$ (62)		$ 0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
NET INCOME	$ 1,660	1,390						1,390
Common stock dividend to Con Edison	(1,120)	(978)					$ (1,120)	(978)
Capital contribution by Con Edison		150				150
Other comprehensive income (loss)	17	4									$ 17	4
BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2022			355,000,000	235,000,000
BALANCE AS OF END OF PERIOD at Dec. 31, 2022		16,878		$ 589		7,419		9,890	(962)	(62)		4
Increase (Decrease) in Stockholders' Equity [Roll Forward]
NET INCOME	2,519	1,606						1,606
Common stock dividend to Con Edison	$ (1,127)	(1,056)					(1,127)	(1,056)
Capital contribution by Con Edison		1,720				1,720
Other comprehensive income (loss)		$ (2)										(2)
BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2023	345,415,772	235,488,094	345,000,000	235,000,000
BALANCE AS OF END OF PERIOD at Dec. 31, 2023		$ 19,146		$ 589		9,139		10,440	(962)	(62)		2
Increase (Decrease) in Stockholders' Equity [Roll Forward]
NET INCOME	$ 1,820	1,748						1,748
Common stock dividend to Con Edison	(1,149)	(1,073)					$ (1,149)	(1,073)
Capital contribution by Con Edison		130				130
Other comprehensive income (loss)	7	8									$ 7	8
Stock Awards	$ 13	$ 12			$ 13	12
BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2024	346,597,693	235,488,094	347,000,000	235,000,000
BALANCE AS OF END OF PERIOD at Dec. 31, 2024		$ 19,971		$ 589		$ 9,281		$ 11,115	$ (962)	$ (62)		$ 10

Consolidated Statement of Cap_4

Consolidated Statement of Capitalization - CECONY - USD ($) shares in Millions, $ in Millions	Dec. 31, 2024	Dec. 31, 2023
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE LOSS (in shares)	347	345
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE INCOME	$ 21,933	$ 21,136
Pension and other postretirement benefit plan liability adjustments, net of taxes	30	23
Unrealized losses on derivatives qualified as cash flow hedges, less reclassification adjustment for gains (losses) included in net income and reclassification adjustment for unrealized losses included in regulatory assets, net of taxes	(1)	(1)
TOTAL ACCUMULATED OTHER COMPREHENSIVE INCOME, NET OF TAXES	$ 29	$ 22
CECONY
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE LOSS (in shares)	235	235
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE INCOME	$ 19,961	$ 19,144
Pension and other postretirement benefit plan liability adjustments, net of taxes	11	3
Unrealized losses on derivatives qualified as cash flow hedges, less reclassification adjustment for gains (losses) included in net income and reclassification adjustment for unrealized losses included in regulatory assets, net of taxes	(1)	(1)
TOTAL ACCUMULATED OTHER COMPREHENSIVE INCOME, NET OF TAXES	10	2
TOTAL SHAREHOLDER’S EQUITY (See Statement of Shareholder’s Equity)	$ 19,971	$ 19,146

Consolidated Statement of Cap_5

Consolidated Statement of Capitalization - Long-Term Debt - CECONY - USD ($) $ in Millions		Dec. 31, 2024	Dec. 31, 2023
Long-term debt		$ 24,710	$ 22,240
Unamortized debt expense		(179)	(162)
Unamortized debt discount		(70)	(60)
Less: Long-term debt due within one year		0	251
LONG-TERM DEBT		24,710	21,989
TOTAL CAPITALIZATION		46,613	43,085
CECONY
Long-term debt		23,409	21,060
Unamortized debt expense		(171)	(155)
Unamortized debt discount		(70)	(60)
Less: Long-term debt due within one year			250
LONG-TERM DEBT		23,409	20,810
TOTAL CAPITALIZATION		43,380	39,956
Debentures
Long-term debt		24,675	21,950
Debentures \| CECONY
Long-term debt		23,425	20,825
Tax-Exempt Debt \| CECONY
Long-term debt		$ 225	450
Debenture 2014B, 3.30 Percent, Due 2024 \| Debentures
Interest Rate		3.30%
Long-term debt		$ 0	250
Debenture 2014B, 3.30 Percent, Due 2024 \| Debentures \| CECONY
Interest Rate		3.30%
Long-term debt		$ 0	250
Debenture Series 2016B, 2.90% Due 2026 \| Debentures
Interest Rate		2.90%
Long-term debt		$ 250	250
Debenture Series 2016B, 2.90% Due 2026 \| Debentures \| CECONY
Interest Rate		2.90%
Long-term debt		$ 250	250
Debenture Series 2017B, 3.125% Due 2027 \| Debentures
Interest Rate		3.125%
Long-term debt		$ 350	350
Debenture Series 2017B, 3.125% Due 2027 \| Debentures \| CECONY
Interest Rate		3.125%
Long-term debt		$ 350	350
Debenture Series 2024C, 4.825% Due 2027 \| Debentures \| CECONY
Interest Rate	[1]	4.825%
Long-term debt	[1]	$ 350	0
Debenture Series 2018A, 3.80% Due 2028 \| Debentures
Interest Rate		3.80%
Long-term debt		$ 300	300
Debenture Series 2018A, 3.80% Due 2028 \| Debentures \| CECONY
Interest Rate		3.80%
Long-term debt		$ 300	300
Debenture Series 2018D, 4.00% Due 2028 \| Debentures
Interest Rate		4%
Long-term debt		$ 500	500
Debenture Series 2018D, 4.00% Due 2028 \| Debentures \| CECONY
Interest Rate		4%
Long-term debt		$ 500	500
Debenture 2020A, 3.35 Percent, Due 2030 \| Debentures
Interest Rate		3.35%
Long-term debt		$ 600	600
Debenture 2020A, 3.35 Percent, Due 2030 \| Debentures \| CECONY
Interest Rate		3.35%
Long-term debt		$ 600	600
Debenture 2021A, 2.40 Percent, Due 2031 \| Debentures
Interest Rate		2.40%
Long-term debt		$ 900	900
Debenture 2021A, 2.40 Percent, Due 2031 \| Debentures \| CECONY
Interest Rate		2.40%
Long-term debt		$ 900	900
Debenture Series 2003A, 5.875% Due 2033 \| Debentures
Interest Rate		5.875%
Long-term debt		$ 175	175
Debenture Series 2003A, 5.875% Due 2033 \| Debentures \| CECONY
Interest Rate		5.875%
Long-term debt		$ 175	175
Debenture Series 2003C, 5.10% Due 2033 \| Debentures
Interest Rate		5.10%
Long-term debt		$ 200	200
Debenture Series 2003C, 5.10% Due 2033 \| Debentures \| CECONY
Interest Rate		5.10%
Long-term debt		$ 200	200
Debenture Series 2023A, 5.20% Due 2033 \| Debentures
Interest Rate		5.20%
Long-term debt		$ 500	500
Debenture Series 2023A, 5.20% Due 2033 \| Debentures \| CECONY
Interest Rate		5.20%
Long-term debt		$ 500	500
Debenture Series 2004B, 5.70% Due 2034 \| Debentures
Interest Rate		5.70%
Long-term debt		$ 200	200
Debenture Series 2004B, 5.70% Due 2034 \| Debentures \| CECONY
Interest Rate		5.70%
Long-term debt		$ 200	200
Debenture Series 2023B, 5.50% Due 2034 \| Debentures
Interest Rate		5.50%
Long-term debt		$ 600	600
Debenture Series 2023B, 5.50% Due 2034 \| Debentures \| CECONY
Interest Rate		5.50%
Long-term debt		$ 600	600
Debenture Series 2005A, 5.30% Due 2035 \| Debentures
Interest Rate		5.30%
Long-term debt		$ 350	350
Debenture Series 2005A, 5.30% Due 2035 \| Debentures \| CECONY
Interest Rate		5.30%
Long-term debt		$ 350	350
Debenture Series 2005B, 5.25% Due 2035 \| Debentures \| CECONY
Interest Rate		5.25%
Long-term debt		$ 125	125
Debenture Series 2024 D, 5.13% Due 2035 \| Debentures \| CECONY
Interest Rate		5.125%
Long-term debt		$ 450	0
Debenture Series 2006A, 5.85% Due 2036 \| Debentures
Interest Rate		5.85%
Long-term debt		$ 400	400
Debenture Series 2006A, 5.85% Due 2036 \| Debentures \| CECONY
Interest Rate		5.85%
Long-term debt		$ 400	400
Debenture Series 2006B, 6.20% Due 2036 \| Debentures
Interest Rate		6.20%
Long-term debt		$ 400	400
Debenture Series 2006B, 6.20% Due 2036 \| Debentures \| CECONY
Interest Rate		6.20%
Long-term debt		$ 400	400
Debenture Series 2006E, 5.70% Due 2036 \| Debentures
Interest Rate		5.70%
Long-term debt		$ 250	250
Debenture Series 2006E, 5.70% Due 2036 \| Debentures \| CECONY
Interest Rate		5.70%
Long-term debt		$ 250	250
Debenture Series 2007A, 6.30% Due 2037 \| Debentures
Interest Rate		6.30%
Long-term debt		$ 525	525
Debenture Series 2007A, 6.30% Due 2037 \| Debentures \| CECONY
Interest Rate		6.30%
Long-term debt		$ 525	525
Debenture 2008B, 6.75 Percent, Due 2038 \| Debentures
Interest Rate		6.75%
Long-term debt		$ 600	600
Debenture 2008B, 6.75 Percent, Due 2038 \| Debentures \| CECONY
Interest Rate		6.75%
Long-term debt		$ 600	600
Debenture 2009C, 5.50 Percent, Due 2039 \| Debentures
Interest Rate		5.50%
Long-term debt		$ 600	600
Debenture 2009C, 5.50 Percent, Due 2039 \| Debentures \| CECONY
Interest Rate		5.50%
Long-term debt		$ 600	600
Debenture 2010B, 5.70 Percent, Due 2040 \| Debentures
Interest Rate		5.70%
Long-term debt		$ 350	350
Debenture 2010B, 5.70 Percent, Due 2040 \| Debentures \| CECONY
Interest Rate		5.70%
Long-term debt		$ 350	350
Debenture 2012A, 4.20 Percent, Due 2042 \| Debentures
Interest Rate		4.20%
Long-term debt		$ 400	400
Debenture 2012A, 4.20 Percent, Due 2042 \| Debentures \| CECONY
Interest Rate		4.20%
Long-term debt		$ 400	400
Debenture 2013A, 3.95 Percent, Due 2043 \| Debentures
Interest Rate		3.95%
Long-term debt		$ 700	700
Debenture 2013A, 3.95 Percent, Due 2043 \| Debentures \| CECONY
Interest Rate		3.95%
Long-term debt		$ 700	700
Debenture 2014A, 4.45 Percent, Due 2044 \| Debentures
Interest Rate		4.45%
Long-term debt		$ 850	850
Debenture 2014A, 4.45 Percent, Due 2044 \| Debentures \| CECONY
Interest Rate		4.45%
Long-term debt		$ 850	850
Debenture 2015A, 4.50 Percent, Due 2045 \| Debentures
Interest Rate		4.50%
Long-term debt		$ 650	650
Debenture 2015A, 4.50 Percent, Due 2045 \| Debentures \| CECONY
Interest Rate		4.50%
Long-term debt		$ 650	650
Debenture 2016A, 3.85 Percent, Due 2046 \| Debentures
Interest Rate		3.85%
Long-term debt		$ 550	550
Debenture 2016A, 3.85 Percent, Due 2046 \| Debentures \| CECONY
Interest Rate		3.85%
Long-term debt		$ 550	550
Debenture Series 2017A, 3.875% Due 2047 \| Debentures
Interest Rate		3.875%
Long-term debt		$ 500	500
Debenture Series 2017A, 3.875% Due 2047 \| Debentures \| CECONY
Interest Rate		3.875%
Long-term debt		$ 500	500
Debenture Series 2018E, 4.65% Due 2048 \| Debentures
Interest Rate		4.65%
Long-term debt		$ 600	600
Debenture Series 2018E, 4.65% Due 2048 \| Debentures \| CECONY
Interest Rate		4.65%
Long-term debt		$ 600	600
Debenture 2019A, 4.125 Percent, Due 2049 \| Debentures
Interest Rate		4.125%
Long-term debt		$ 700	700
Debenture 2019A, 4.125 Percent, Due 2049 \| Debentures \| CECONY
Interest Rate		4.125%
Long-term debt		$ 700	700
Debenture 2020B, 3.95 Percent, Due 2050 \| Debentures
Interest Rate		3.95%
Long-term debt		$ 1,000	1,000
Debenture 2020B, 3.95 Percent, Due 2050 \| Debentures \| CECONY
Interest Rate		3.95%
Long-term debt		$ 1,000	1,000
Debenture 2021C, 3.200 Percent, Due 2051 \| Debentures \| CECONY
Interest Rate		3.20%
Long-term debt		$ 600	600
Debenture 2022A, 6.15%, Due 2052 \| Debentures
Interest Rate		6.15%
Long-term debt		$ 700	700
Debenture 2022A, 6.15%, Due 2052 \| Debentures \| CECONY
Interest Rate		6.15%
Long-term debt		$ 700	700
Debenture 2023C, 5.90%, Due 2053 \| Debentures
Interest Rate		5.90%
Long-term debt		$ 900	900
Debenture 2023C, 5.90%, Due 2053 \| Debentures \| CECONY
Interest Rate		5.90%
Long-term debt		$ 900	900
Debenture 2024A, 5.375 %, Due 2054 \| Debentures \| CECONY
Interest Rate		5.375%
Long-term debt		$ 400	0
Debenture 2024B, 5.700 %, Due 2054 \| Debentures \| CECONY
Interest Rate		5.70%
Long-term debt		$ 1,000	0
Debenture Series 2014C, 4.625% Due 2054 \| Debentures
Interest Rate		4.625%
Long-term debt		$ 750	750
Debenture Series 2014C, 4.625% Due 2054 \| Debentures \| CECONY
Interest Rate		4.625%
Long-term debt		$ 750	750
Debenture 2024E , 5.50%, Due 2055 \| Debentures \| CECONY
Interest Rate		5.50%
Long-term debt		$ 650	0
Debenture Series 2016C, 4.30% Due 2056 \| Debentures
Interest Rate		4.30%
Long-term debt		$ 500	500
Debenture Series 2016C, 4.30% Due 2056 \| Debentures \| CECONY
Interest Rate		4.30%
Long-term debt		$ 500	500
Debenture Series 2017C, 4.00% Due 2057 \| Debentures
Interest Rate		4%
Long-term debt		$ 350	350
Debenture Series 2017C, 4.00% Due 2057 \| Debentures \| CECONY
Interest Rate		4%
Long-term debt		$ 350	350
Debenture Series 2018B, 4.50% Due 2058 \| Debentures
Interest Rate		4.50%
Long-term debt		$ 700	700
Debenture Series 2018B, 4.50% Due 2058 \| Debentures \| CECONY
Interest Rate		4.50%
Long-term debt		$ 700	700
Debenture 2019B, 3.70 Percent, Due 2059 \| Debentures
Interest Rate		3.70%
Long-term debt		$ 600	600
Debenture 2019B, 3.70 Percent, Due 2059 \| Debentures \| CECONY
Interest Rate		3.70%
Long-term debt		$ 600	600
Debenture 2020C, 3.00 Percent, Due 2060 \| Debentures
Interest Rate		3%
Long-term debt		$ 600	600
Debenture 2020C, 3.00 Percent, Due 2060 \| Debentures \| CECONY
Interest Rate		3%
Long-term debt		$ 600	600
Debenture 2021B, 3.60 Percent, Due 2061 \| Debentures
Interest Rate		3.60%
Long-term debt		$ 750	750
Debenture 2021B, 3.60 Percent, Due 2061 \| Debentures \| CECONY
Interest Rate		3.60%
Long-term debt		$ 750	750
Tax Exempt Debt Series 2010A Due 2024 \| Tax-Exempt Debt
Interest Rate	[2]	3.23%
Tax Exempt Debt Series 2010A Due 2024 \| Tax-Exempt Debt \| CECONY
Interest Rate	[3]	3.23%
Long-term debt	[3]	$ 0	225
Tax Exempt Debt Series 2004C, 1.663% Due 2039 \| Tax-Exempt Debt
Interest Rate	[4]	3.47%
Tax Exempt Debt Series 2004C, 1.663% Due 2039 \| Tax-Exempt Debt \| CECONY
Interest Rate	[5]	3.47%
Long-term debt	[5]	$ 99	99
Tax-Exempt Debt Series 2005A, 1.627% Due 2039 \| Tax-Exempt Debt
Interest Rate	[4]	3.40%
Tax-Exempt Debt Series 2005A, 1.627% Due 2039 \| Tax-Exempt Debt \| CECONY
Interest Rate	[5]	3.40%
Long-term debt	[5]	$ 126	$ 126

[1] (a) Rates reset quarterly; December 31, 2024 floating rate equals SOFR+0.52 percent. (b) In November 2024, all of the $225 million of Series 2010A tax-exempt bonds issued for the benefit of CECONY, bearing interest at a weekly rate, were redeemed. (c) Rates reset weekly; December 31, 2024 rates shown (c) Rates reset weekly; December 31, 2024 rates shown.

Consolidated Statement of Cap_6

Consolidated Statement of Capitalization - CECONY (Parenthetical) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2024	Nov. 30, 2024	Dec. 31, 2023
Long-term debt		$ 24,710		$ 22,240
CECONY
Long-term debt		23,409		21,060
Debentures
Long-term debt		24,675		21,950
Debentures \| CECONY
Long-term debt		23,425		20,825
Tax-Exempt Debt \| CECONY
Long-term debt		$ 225		450
Debenture Series 2024C, 4.825% Due 2027 \| Debentures \| CECONY
Debt instrument, SOFR variable rate		52%
Long-term debt	[1]	$ 350		0
Tax Exempt Debt Series 2010A Due 2024 \| Tax-Exempt Debt \| CECONY
Long-term debt	[2]	$ 0	$ 225	$ 225

[1] (a) Rates reset quarterly; December 31, 2024 floating rate equals SOFR+0.52 percent. (b) In November 2024, all of the $225 million of Series 2010A tax-exempt bonds issued for the benefit of CECONY, bearing interest at a weekly rate, were redeemed.

General

General	12 Months Ended
General	Dec. 31, 2024
Organization, Consolidation and Presentation of Financial Statements [Abstract]
General	General These combined notes accompany and form an integral part of the separate consolidated financial statements of each of the two separate registrants: Consolidated Edison, Inc. and its subsidiaries (Con Edison) and Consolidated Edison Company of New York, Inc. and its subsidiaries (CECONY). CECONY is a subsidiary of Con Edison and as such its financial condition and results of operations and cash flows, that are presented separately in the CECONY consolidated financial statements, are also consolidated, along with those of Orange and Rockland Utilities, Inc. (O&R), Con Edison Transmission, Inc. (together with its subsidiaries, Con Edison Transmission) and its former subsidiary, Con Edison Clean Energy Businesses, Inc. (together with its subsidiaries, the Clean Energy Businesses), in Con Edison’s consolidated financial statements. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W and Note X. The term “Utilities” is used in these notes to refer to CECONY and O&R.

Summary of Significant Accounti

Summary of Significant Accounting Policies and Other Matters	12 Months Ended
	Dec. 31, 2024
Accounting Policies [Abstract]
Summary of Significant Accounting Policies and Other Matters	Summary of Significant Accounting Policies and Other Matters Principles of Consolidation The Companies’ consolidated financial statements include the accounts of their respective majority-owned subsidiaries, and variable interest entities (see Note S), as required. All intercompany balances and intercompany transactions have been eliminated. Accounting Policies The accounting policies of Con Edison and its subsidiaries conform to generally accepted accounting principles in the United States of America (GAAP). For the Utilities, these accounting principles include the accounting rules for regulated operations and the accounting requirements of the Federal Energy Regulatory Commission (FERC) and the state regulators having jurisdiction. The accounting rules for regulated operations specify the economic effects that result from the causal relationship of costs and revenues in the rate-regulated environment and how these effects are to be accounted for by a regulated enterprise. Revenues intended to cover some costs may be recorded either before or after the costs are incurred. If regulation provides assurance that incurred costs will be recovered in the future, these costs would be recorded as deferred charges or “regulatory assets” under the accounting rules for regulated operations. If revenues are recorded for costs that are expected to be incurred in the future, these revenues would be recorded as deferred credits or “regulatory liabilities” under the accounting rules for regulated operations. The Utilities’ principal regulatory assets and liabilities are detailed in Note B. In general, the Utilities are receiving or being credited with a return on their regulatory assets for which a cash outflow has been made, and are paying or being charged with a return on their regulatory liabilities for which a cash inflow has been received. The Utilities’ regulatory assets and liabilities at December 31, 2024 are recoverable from customers, or to be applied for customer benefit, in accordance with rate provisions that have been approved by state regulators. Other significant accounting policies of the Companies are referenced below in this Note A and in the notes that follow. Revenues CECONY’s electric and gas rate plans and O&R’s New York electric and gas rate plans each contain a revenue decoupling mechanism, that covers all residential and most commercial customers, under which the company’s actual energy delivery revenues are compared with the authorized delivery revenues and the difference accrued, with interest, for refund to, or recovery from, customers, as applicable. See “Rate Plans” in Note B. The NYSPSC requires utilities to record gross receipts tax revenues and expenses on a gross income statement presentation basis (i.e., included in both revenue and expense). The recovery of these taxes is generally provided for in the revenue requirement within each of the respective NYSPSC-approved rate plans. Total excise taxes (inclusive of gross receipts taxes) recorded in operating revenues were as follows: For the Years Ended December 31, (Millions of Dollars) 2024 2023 2022 Con Edison $437 $409 $400 CECONY 425 396 387 For information about the Companies' revenue recognition policies, see Note M. Plant and Depreciation Utility Plant Utility plant is stated at original cost. The cost of repairs and maintenance is charged to expense and the cost of betterments is capitalized. The capitalized cost of additions to utility plant includes indirect costs such as engineering, supervision, payroll taxes, pensions, other benefits and an allowance for funds used during construction (AFUDC). The original cost of property is charged to expense over the estimated useful lives of the assets. Upon retirement, the original cost of property is charged to accumulated depreciation. See Note T. Rates used for AFUDC include the cost of borrowed funds and a reasonable rate of return on the Utilities’ own funds when so used, determined in accordance with regulations of the FERC or the state public utility regulatory authority having jurisdiction. The rate is compounded semiannually, and the amounts applicable to borrowed funds are treated as a reduction of interest charges, while the amounts applicable to the Utilities’ own funds are credited to other income (deductions). The AFUDC rates for CECONY were 5.9 percent, 5.9 percent and 5.2 percent for 2024, 2023 and 2022, respectively. The AFUDC rates for O&R were 6.0 percent, 6.2 percent and 5.0 percent for 2024, 2023 and 2022, respectively. The Utilities generally compute annual charges for depreciation using the straight-line method for financial statement purposes, with rates based on average service lives and net salvage factors. The average depreciation rates for CECONY were 3.6 percent for 2024, 3.6 percent for 2023 and 3.5 percent for 2022. The average depreciation rates for O&R were 3.3 percent for 2024, 3.1 percent for 2023 and 3.0 percent for 2022. The estimated lives for utility plant for CECONY range from 5 to 80 years for electric, 5 to 80 years for gas, 5 to 55 years for steam and 5 to 50 years for general plant. For O&R, the estimated lives for utility plant range from 5 to 75 years for electric and gas and 5 to 50 years for general plant. The capitalized cost of the Companies' utility plant (net of accumulated depreciation) on December 31, 2024 and 2023, was as follows: Con Edison CECONY (Millions of Dollars) 2024 2023 2024 2023 Electric Generation $577 $580 $577 $580 Transmission 5,072 4,652 4,703 4,333 Distribution 25,129 24,491 23,770 23,238 General 174 141 174 141 Gas (a) 12,703 12,023 11,830 11,226 Steam 2,006 1,990 2,006 1,990 General 3,249 3,158 2,940 2,860 Held for future use 77 118 69 110 Construction work in progress 3,165 2,442 2,912 2,168 Net Utility Plant $52,152 $49,594 $48,981 $46,646 (a) Primarily distribution. General utility plant of Con Edison and CECONY included $59 million and $56 million, respectively, at December 31, 2024, and $65 million and $62 million, respectively, at December 31, 2023, related to a May 2018 acquisition of software licenses. The estimated aggregate annual amortization expense related to the software licenses for Con Edison and CECONY is $7 million. The accumulated amortization for Con Edison and CECONY was $45 million and $43 million, respectively, at December 31, 2024 and $38 million and $36 million, respectively, at December 31, 2023. Under the Utilities’ rate plans, the aggregate annual depreciation allowance for the period ended December 31, 2024 was $2,228 million, including $2,109 million under CECONY’s electric, gas and steam rate plans that have been approved by the NYSPSC. Non–Utility Plant Non-utility plant is stated at original cost. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W and X. For Con Edison, non-utility plant consisted primarily of the Clean Energy Businesses’ renewable electric projects. Property, plant and equipment are stated at cost, less accumulated depreciation and include capitalized interest during construction. Depreciation is computed under the straight-line method over the useful lives of the assets. Solar power generating assets and wind power generating assets have useful lives of 35 years and 30 years, respectively. For the Utilities, non-utility plant consists of land and conduit for telecommunication use. Depreciation on non-utility plant, other than land, is computed using the straight-line method for financial statement purposes over their estimated useful lives, which is 10 years. Other Deferred Charges and Noncurrent Assets and Prepayments Other deferred charges and noncurrent assets and prepayments, net of accumulated depreciation, included the following related to implementation costs incurred in cloud computing arrangements: Con Edison CECONY (Millions of Dollars) 2024 2023 2024 2023 Prepayments (a)(b) $57 $50 $54 $49 Other Deferred Charges and Noncurrent Assets (a)(b) 254 179 243 178 (a) Amortization on these assets is computed using the straight-line method for financial statement purposes over their estimated useful lives. (b) Amortization expense related to these assets incurred during the year ended December 31, 2024 for Con Edison and CECONY was $33 million and $32 million, respectively, for the year ended December 31, 2023 for Con Edison and CECONY was $21 million and $20 million, respectively, and for the year ended December 31, 2022 for Con Edison and CECONY was $15 million and $14 million, respectively. Accumulated amortization related to these assets for Con Edison and CECONY was $91 million and $85 million, respectively at December 31, 2024 and was $58 million and $53 million, respectively at December 31, 2023. Long–Lived and Intangible Assets The Companies test long-lived and intangible assets for recoverability when events or changes in circumstances indicate that the carrying value of long-lived or intangible assets may not be recoverable. The carrying amount of a long-lived asset or intangible asset with a definite life is deemed not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the assets. In the event a test indicates that such cash flows cannot be expected to be sufficient to fully recover the assets, the assets are considered impaired and written down to their estimated fair value. Prior to the sale of the Clean Energy Businesses on March 1, 2023, Con Edison's intangible assets with definite lives consisted primarily of power purchase agreements. See Note W and Note X. Con Edison's and CECONY's intangible assets were immaterial at December 31, 2024 and 2023. Con Edison recorded amortization expense related to its intangible assets of $71 million in 2022. Con Edison expects amortization expense to be immaterial over each of the next five years, and recorded immaterial amounts in 2023 and 2024. No impairment charges were recorded on Con Edison's long-lived assets or intangible assets with definite lives in 2024, 2023 and 2022. Recoverable Energy Costs The Utilities generally recover all of their prudently incurred fuel, purchased power and gas costs, including hedging gains and losses, in accordance with rate provisions approved by the applicable state public utility regulators. If the actual energy supply costs for a given month are more or less than the amounts billed to customers for that month, the difference in most cases is recoverable from or refundable to customers. Differences between actual and billed electric and steam supply costs are generally deferred for charge or refund to customers during the next billing cycle (normally within one New York Independent System Operator (NYISO) The Utilities purchase electricity through the wholesale electricity market administered by the NYISO. The difference between purchased power and related costs initially billed to the Utilities by the NYISO and the actual cost of power subsequently calculated by the NYISO is refunded by the NYISO to the Utilities, or paid to the NYISO by the Utilities. The reconciliation payments or receipts are recoverable from or refundable to the Utilities’ customers. Certain other payments to or receipts from the NYISO are also subject to reconciliation, with shortfalls or amounts in excess of specified rate allowances recoverable from or refundable to customers. These include proceeds from the sale through the NYISO of transmission rights on CECONY’s transmission system (transmission congestion contracts or TCCs). Temporary Cash Investments Temporary cash investments are short-term, highly-liquid investments that generally have maturities of three months or less at the date of purchase. They are stated at cost, which approximates market. The Companies consider temporary cash investments to be cash equivalents. Investments Accounting for Investments Con Edison’s investments consist primarily of the investments of Con Edison Transmission that are accounted for under the equity method and the fair value of the Utilities’ supplemental retirement income plan and deferred income plan assets. The accounting rules require Con Edison to evaluate its investments periodically to determine whether they are impaired. The standard for determining whether an impairment exists and must be recorded is whether an other-than-temporary decline in carrying value has occurred. Changes in economic conditions, forecasted cash flows and the regulatory environment, among other factors, could require equity method investments to recognize a decrease in carrying value for an other-than-temporary decline. When management believes such a decline may have occurred, the fair value of the investment is estimated using market inputs, when observable, or a valuation model such as a discounted cash flow analysis. The fair value is compared to the carrying value of the investment in order to determine the amount of impairment to record, if any. The evaluation and measurement of impairments involve uncertainties. The judgments that Con Edison makes to estimate the fair value of its equity method investments are based on assumptions that management believes are reasonable, and variations in these estimates or the underlying assumptions, or the receipt of additional market information, could have a material impact on whether a triggering event is determined to exist or the amount of any such impairment. Additionally, if the projects in which Con Edison holds these investments recognize an impairment, Con Edison may record a share of that impairment loss and would evaluate its investment for an other-than-temporary decline in carrying value as described above. Con Edison Transmission is considering strategic alternatives with respect to its investment in MVP and both Con Edison Transmission and CECONY are considering strategic alternatives with respect to their investments in Honeoye. Investment in Mountain Valley Pipeline, LLC (MVP) In January 2016, a subsidiary of Con Edison Transmission, acquired a 12.5 percent interest in MVP, a company developing a proposed 300-mile gas transmission project (the Mountain Valley Pipeline) in West Virginia and Virginia. During 2019, Con Edison exercised its right to limit, and did limit, its cash contributions to the joint venture to approximately $530 million. In June 2024, the Mountain Valley Pipeline, a 303-mile gas transmission pipeline in West Virginia and Virginia, entered service. The project operator is continuing restoration of the right of way and estimates a total project cost of approximately $8,100 million (excluding allowance for funds used during construction (AFUDC)). At December 31, 2024, the carrying value of Con Edison Transmission's investment in MVP was $166 million, and its cash contributions to the joint venture amounted to $530 million. Con Edison records its pro rata share of earnings from its equity investment in MVP, adjusted for accretion of the basis difference and income taxes, on its consolidated income statement. Con Edison's pro rata share of earnings from its equity investment in MVP, adjusted for accretion of the basis difference, was $29 million ($21 million after-tax) for the twelve months ended December 31, 2024. As of December 31, 2024, Con Edison Transmission's interest in MVP, the company that developed the project, is 6.7 percent and is expected to be reduced to approximately 6.6 percent upon completion of the restoration of the right of way and based on Con Edison Transmission's previous capping of its cash contributions. There were no impairments to the carrying value of Con Edison Transmission's investment in MVP for the years ended December 31, 2022, 2023 and 2024. Summary of Investment Balances The following investment assets are included in the Companies' consolidated balance sheets at December 31, 2024 and 2023: Con Edison CECONY (Millions of Dollars) 2024 2023 2024 2023 Supplemental retirement income plan assets (b) $583 $524 $560 $502 Con Edison Transmission's investment in New York Transco (d) 254 221 — — Con Edison Transmission's investment in MVP (a) (d) 166 144 — — Deferred income plan assets 116 99 116 99 Virginia Tax Equity Projects (c) 4 8 — — Other 3 3 8 7 Total investments $1,126 $999 $684 $608 (a) At December 31, 2024 and 2023, Con Edison Transmission's cash investment in MVP was $530 million. In June 2024, MVP entered service at an overall project cost of approximately $8,100 million excluding allowance for funds used during construction. See "Investment in Mountain Valley Pipeline, LLC (MVP)" above. (b) See Note E. (c) See Note S. (d) At December 31, 2024 and 2023, Con Edison had undistributed earnings from MVP of $127 million and $114 million, respectively, and undistributed earnings from New York Transco of $16 million and $13 million, respectively. Pension and Other Postretirement Benefits The accounting rules for retirement benefits require an employer to recognize an asset or liability for the overfunded or underfunded status of its pension and other postretirement benefit plans. For a pension plan, the asset or liability is the difference between the fair value of the plan’s assets and the projected benefit obligation. For any other postretirement benefit plan, the asset or liability is the difference between the fair value of the plan’s assets and the accumulated postretirement benefit obligation. The accounting rules generally require employers to recognize all unrecognized prior service costs and credits and unrecognized actuarial gains and losses in accumulated other comprehensive income/(loss) (OCI), net of tax. Such amounts will be adjusted as they are subsequently recognized as components of total periodic benefit cost or income pursuant to the current recognition and amortization provisions. For the Utilities’ pension and other postretirement benefit plans, regulatory accounting treatment is generally applied in accordance with the accounting rules for regulated operations. Unrecognized prior service costs or credits and unrecognized actuarial gains and losses are recorded to regulatory assets or liabilities, rather than OCI. See Notes E and F. The total periodic benefit costs are recognized in accordance with the accounting rules for retirement benefits. Investment gains and losses are recognized in expense over a 15-year period and other actuarial gains and losses are recognized in expense over a 10-year period, subject to the deferral provisions in the rate plans. In accordance with the Statement of Policy issued by the NYSPSC and its current electric, gas and steam rate plans, CECONY defers for payment to or recovery from customers the difference between such expenses and the amounts for such expenses reflected in rates. O&R also defers such difference pursuant to its NY rate plans. See Note B. The Companies calculate the expected return on pension and other postretirement benefit plan assets by multiplying the expected rate of return on plan assets by the market-related value (MRV) of plan assets at the beginning of the year, taking into consideration anticipated contributions and benefit payments that are to be made during the year. The accounting rules allow the MRV of plan assets to be either fair value or a calculated value that recognizes changes in fair value in a systematic and rational manner over not more than five years. The Companies use a calculated value when determining the MRV of the plan assets that adjusts for 20 percent of the difference between fair value and expected MRV of plan assets. This calculated value has the effect of stabilizing variability in assets to which the Companies apply the expected return. Federal Income Tax In accordance with accounting rules for income taxes, the Companies have recorded an accumulated deferred federal income tax liability at current tax rates for temporary differences between the book and tax basis of assets and liabilities. In accordance with rate plans, the Utilities have recovered amounts from customers for a portion of the tax liability they will pay in the future as a result of the reversal or “turn-around” of these temporary differences. As to the remaining deferred tax liability, the Utilities had established regulatory assets for the net revenue requirements to be recovered from customers for the related future tax expense pursuant to the NYSPSC's 1993 Policy Statement approving accounting procedures consistent with accounting rules for income taxes and providing assurances that these future increases in taxes will be recoverable in rates. Accumulated deferred investment tax credits are amortized ratably over the lives of the related properties and applied as a reduction to future federal income tax expense. Con Edison and its subsidiaries file a consolidated federal income tax return. The consolidated income tax liability is allocated to each member of the consolidated group using the separate return method. Each member pays or receives an amount based on its own taxable income or loss in accordance with a consolidated tax allocation agreement. Tax loss and tax credit carryforwards are allocated among members in accordance with consolidated tax return regulations. State Income Tax Con Edison and its subsidiaries file a combined New York State Corporation Business Franchise Tax Return. Similar to a federal consolidated income tax return, the income of all entities in the combined group is subject to New York State taxation, after adjustments for differences between federal and New York law and apportionment of income among the states in which the company does business. Each member’s share of the New York State tax is based on its own New York State taxable income or loss. Reclassification Certain prior period amounts have been reclassified to conform with current period presentation. These reclassifications include short-term debt activity within the financing section of the Con Edison Statement of Cash Flows. Earnings Per Share Con Edison presents basic and diluted earnings per share (EPS) on the face of its consolidated income statement. Basic EPS is calculated by dividing earnings available to common shareholders (“Net income for common stock” on Con Edison’s consolidated income statement) by the weighted average number of Con Edison common shares outstanding during the period. In the calculation of diluted EPS, weighted average shares outstanding are increased for additional shares that would be outstanding if potentially dilutive securities were converted to common stock. Potentially dilutive securities for Con Edison consist of restricted stock units and deferred stock units for which the average market price of the common shares for the period was greater than the estimated vesting price (see Note O) and its common shares that are subject to forward sale agreement (see Note C). Before the issuance of common shares upon settlement of the forward sale agreement, the shares will be reflected in the company’s diluted earnings per share calculations using the treasury stock method. Under this method, the number of common shares used in calculating diluted earnings per share is deemed to be increased by the excess, if any, of the number of shares that would be issued upon physical settlement of the forward sale agreement over the number of shares that could be purchased by the company in the market (based on the average market price during the period) using the proceeds due upon physical settlement (based on the adjusted forward sale price at the end of the reporting period). Basic and diluted EPS for Con Edison are calculated as follows: For the Years Ended December 31, (Millions of Dollars, except per share amounts/Shares in Millions) 2024 2023 2022 Net income for common stock $1,820 $2,519 $1,660 Weighted average common shares outstanding – basic 346.0 347.7 354.5 Add: Incremental shares attributable to effect of potentially dilutive securities 1.3 1.6 1.3 Adjusted weighted average common shares outstanding – diluted 347.3 349.3 355.8 Net Income per common share – basic $5.26 $7.25 $4.68 Net Income per common share – diluted $5.24 $7.21 $4.66 The computation of diluted EPS for the year ended December 31, 2024 excludes immaterial amounts of performance share awards that were not included because of their anti-dilutive effect. Estimates The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Reconciliation of Cash, Temporary Cash Investments and Restricted Cash Cash, temporary cash investments and restricted cash are presented on a combined basis in the Companies’ consolidated statements of cash flows. At December 31, 2024 and 2023, cash, temporary cash investments and restricted cash for Con Edison were as follows; CECONY did not have material restricted cash balances as of December 31, 2024 and 2023: At December 31, Con Edison (Millions of Dollars) 2024 2023 Cash and temporary cash investments $1,324 $1,189 Restricted cash (a) 9 6 Total cash, temporary cash investments and restricted cash $1,333 $1,195 (a) On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W. Con Edison retained one deferred project, Broken Bow II, a 75 MW nameplate capacity wind power project located in Nebraska. Con Edison's restricted cash for the 2023 and 2024 periods primarily include restricted cash of Broken Bow II, which was held for sale as of December 31, 2024. Broken Bow II was sold and transferred in January 2025. See Note W and Note X. Variable Interest Entities The accounting rules for consolidation address the consolidation of a variable interest entity (VIE) by a business enterprise that is the primary beneficiary. A VIE is an entity that does not have a sufficient equity investment at risk to permit it to finance its activities without additional subordinated financial support, or whose equity investors lack the characteristics of a controlling financial interest. The primary beneficiary is the business enterprise that has the power to direct the activities of the VIE that most significantly impact the VIE’s economic performance and either absorbs a significant amount of the VIE’s losses or has the right to receive benefits that could be significant to the VIE. The Companies enter into arrangements including leases, partnerships and electricity purchase agreements, with various entities. As a result of these arrangements, the Companies retain or may retain a variable interest in these entities. Use of Hypothetical Liquidation at Book Value For certain investments of the Clean Energy Businesses and of Con Edison, Con Edison has determined that the use of HLBV accounting is reasonable and appropriate to attribute income and loss to the tax equity investors. Using the HLBV method, the company's earnings from the projects are adjusted to reflect the income or loss allocable to the tax equity investors calculated based on how the project would allocate and distribute its cash if it were to sell all of its assets for their carrying amounts and liquidate at a particular point in time. Under the HLBV method, the company calculates the liquidation value allocable to the tax equity investors at the beginning and end of each period based on the contractual liquidation waterfall and adjusts its income for the period to reflect the change in the liquidation value allocable to the tax equity investors based on the terms of the partnerships' operating agreements. See Note S. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W. Assets Held for Sale Generally, a long-lived asset or business to be sold is classified as held for sale in the period in which management, with approval from the Board of Directors, commits to a plan to sell, and a sale is expected to be completed within one year. Con Edison records assets and liabilities, once held for sale, at the lower of their carrying value or their estimated fair value less cost to sell, and also stops recording depreciation and amortization on assets held for sale. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses (which was classified as held for sale as of December 31, 2022) with the exception of two tax equity interests and one deferred project, Broken Bow II. In January 2025, Con Edison completed the sale and transfer of Broken Bow II to RWE. For further information, see Note W and Note X. The sale of the Clean Energy Businesses did not represent a strategic shift that had or would have had a major effect on Con Edison, and as such, the sale did not qualify for treatment as a discontinued operation. For further information, see Note W and Note X.

Regulatory Matters

Regulatory Matters	12 Months Ended
Regulatory Matters	Dec. 31, 2024
Regulated Operations [Abstract]
Regulatory Matters	Regulatory Matters Rate Plans The Utilities provide service to New York customers according to the terms of tariffs approved by the NYSPSC. Tariffs for service to customers of Rockland Electric Company (RECO), O&R’s New Jersey regulated utility subsidiary, are approved by the New Jersey Board of Public Utilities (NJBPU). The tariffs include schedules of rates for service that limit the rates charged by the Utilities to amounts that the Utilities recover from their customers costs approved by the regulator, including capital costs, of providing service to customers as defined by the tariff. The tariffs implement rate plans adopted by state utility regulators in rate orders issued at the conclusion of rate proceedings. Pursuant to the Utilities’ rate plans, there generally can be no change to the charges to customers during the respective terms of the rate plans other than specified adjustments provided for in the rate plans. The Utilities’ rate plans each cover specified periods, but rates determined pursuant to a plan generally continue in effect until a new rate plan is approved by the state utility regulator. Common provisions of the Utilities’ New York rate plans include: Base Rates are designed to recover core costs of providing electric, gas or steam delivery service such as the costs of constructing, operating and maintaining a service’s system. Earnings sharing that require the Utilities to defer for customer benefit a portion of earnings over specified rates of return on common equity. There is no symmetric mechanism for earnings below specified rates of return on common equity. Negative revenue adjustments for failure to meet certain performance standards relating to service, reliability, safety and other matters. Net utility plant reconciliations that require deferral as a regulatory liability of the revenue requirement impact of the amount, if any, by which actual average net utility plant balances are less than amounts reflected in rates. There is generally no symmetric mechanism if actual average net utility plant balances are more than amounts reflected in rates. Other revenue adjustments that represent positive revenue adjustments, positive incentives, and earnings adjustments mechanisms for achievement of performance standards related to achievement of clean energy goals, safety and other matters. Rate base , as reflected in the rate plans, is, in general, the sum of the Utilities’ net plant, working capital and certain regulatory assets less deferred taxes and certain regulatory liabilities. For each rate plan, the NYSPSC uses a forecast of the average rate base for each year that new rates would be in effect (“rate year”). Recoverable energy costs that allow the Utilities to recover on a current basis the costs for the energy they supply with no mark-up to their full-service customers. Regulatory reconciliations that reconcile pension and other postretirement benefit costs, environmental remediation costs, property taxes, variable-rate tax-exempt debt and certain other costs (including late payment charges and write-offs of customer accounts receivable balances) to amounts reflected in delivery rates for such costs. In addition, changes in the Utilities' costs not reflected in rates, in excess of certain amounts, resulting from changes in tax or changes in legislation, regulation or related actions, are deferred as a regulatory asset or regulatory liability to be reflected in the Utilities' next rate plan or in a manner to be determined by the NYSPSC. Also, the Utilities generally retain the right to petition for recovery or accounting deferral of extraordinary and material cost increases and provision is sometimes made for the utility to retain a share of cost reductions, for example, property tax refunds. Revenue decoupling mechanisms that reconcile actual energy delivery revenues to the authorized delivery revenues approved by the NYSPSC. The difference is accrued with interest for refund to, or recovery from customers, as applicable. Weighted average cost of capital is determined based on the authorized common equity ratio, return on common equity, cost of long-term debt and cost of customer deposits reflected in each rate plan. For each rate plan, the revenues designed to provide the utility a return on invested capital for each rate year are determined by multiplying each utility rate base by its pre – tax weighted average cost of capital. The Utilities’ actual return on common equity will reflect their actual operations for each rate year, and may be more or less than the authorized return on equity reflected in their rate plans (and if more, may be subject to earnings sharing). The following tables contain a summary of the Utilities’ rate plans: CECONY – Electric Effective period January 2020 – December 2022 January 2023 – December 2025 Base rate changes Yr. 1 – $113 million (a) Yr. 2 – $370 million (a) Yr. 3 – $326 million (a) Yr. 1 – $442 million (c) Yr. 2 – $518 million (c) Yr. 3 – $382 million (c) Amortizations to income of net regulatory (assets) and liabilities Yr. 1 – $267 million (b) Yr. 2 – $269 million (b) Yr. 3 – $272 million (b) Yr. 1 – $104 million (j) Yr. 2 – $49 million (j) Yr. 3 – $(205) million (j) Other revenue sources Retention of $75 million of annual transmission congestion revenues. Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $69 million Yr. 2 - $74 million Yr. 3 - $79 million In 2020, 2021 and 2022, the company recorded $34 million, $64 million and $33 million primarily related to earnings adjustment mechanism incentives for energy efficiency, respectively. In 2022, the company recorded a positive incentive of $4 million. Retention of $75 million of annual transmission congestion revenues. Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $70 million Yr. 2 - $75 million Yr. 3 - $79 million In 2023 and 2024, the company recorded $34.4 million and $52.3 million primarily related to earnings adjustment mechanism incentives for energy efficiency, respectively. Revenue decoupling mechanisms Continuation of reconciliation of actual to authorized electric delivery revenues. In 2020, 2021 and 2022, the company deferred for recovery from customers $242 million, $226 million and $90 million of revenues, respectively. Continuation of reconciliation of actual to authorized electric delivery revenues. In 2023 and 2024, the company deferred for recovery from customers $162 million and $164 million of revenues, respectively. Recoverable energy costs Continuation of current rate recovery of purchased power and fuel costs. Continuation of current rate recovery of purchased power and fuel costs. Negative revenue adjustments Potential charges if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 - $450 million Yr. 2 - $461 million Yr. 3 - $476 million In 2020, the company recorded negative revenue adjustments of $5 million. In 2021, the company did not record any negative revenue adjustments. In 2022, the company recorded negative revenue adjustments of $3 million. Potential charges if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 - $516 million Yr. 2 - $557 million Yr. 3 - $597 million In 2023 and 2024, the company did not record any negative revenue adjustments. Regulatory reconciliations Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate debt, major storms, property taxes (d), municipal infrastructure support costs (e), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (f). In 2020 and 2021, the company deferred $288 million and $191 million of net regulatory assets, respectively. In 2022, the company deferred $138 million of net regulatory liabilities. Reconciliation of late payment charges (i) and expenses for uncollectibles, pension and other postretirement benefits, variable-rate debt, major storms, property taxes (d), municipal infrastructure support costs (e), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (f). In 2023 and 2024, the company deferred $140 million and $52 million of net regulatory liabilities, respectively. Net utility plant reconciliations Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 - $24,491 million Yr. 2 - $25,092 million Yr. 3 - $25,708 million AMI (h): Yr. 1 - $572 million Yr. 2 - $740 million Yr. 3 - $806 million In 2020, the company deferred $4.1 million as a regulatory asset. In 2021 and 2022, the company deferred $3.2 million and $1.8 million, as a regulatory liability, respectively. Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI) and Customer Service System (CSS) for Yr. 1: Yr. 1 - $27,847 million Yr. 2 - $29,884 million Yr. 3 - $31,026 million AMI (h): Yr. 1 - $744 million CSS: Yr. 1 - $11 million In 2023 and 2024, the company deferred $1.2 million and $(25.3) million as a regulatory asset and regulatory liability, respectively. Average rate base Yr. 1 - $21,660 million Yr. 2 - $22,783 million Yr. 3 - $23,926 million Yr. 1 - $26,095 million Yr. 2 - $27,925 million Yr. 3 - $29,362 million Weighted average cost of capital (after-tax) Yr. 1 to Yr. 3 – 6.61 percent Yr. 1 - 6.75 percent Yr. 2 - 6.79 percent Yr. 3 - 6.85 percent Authorized return on common equity 8.8 percent 9.25 percent Actual return on common equity (h) (i) Yr. 1 – 8.5 percent Yr. 2 – 8.03 percent Yr. 3 – 8.41 percent Yr. 1 – 9.46 percent Yr. 2 - 9.21 percent Earnings sharing Most earnings above an annual earnings threshold of 9.3 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2020, 2021 and 2022, the company had no earnings sharing above the threshold. A reserve of $4.3 million was recorded in 2021 related to a potential adjustment to the excess earnings sharing amount for 2016. Most earnings above an annual earnings threshold of 9.75 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2023 and 2024, the company had no earnings sharing above the threshold. Cost of long-term debt Yr. 1 to Yr. 3 – 4.63 percent Yr. 1 – 4.46 percent Yr. 2 – 4.54 percent Yr. 3 – 4.64 percent Common equity ratio 48 percent 48 percent (a) Base rates reflect recovery by the company of certain costs of its energy efficiency, demonstration projects, non-wire alternative projects (including the Brooklyn Queens demand management program), and off-peak electric vehicle charging programs (Yr. 1 - $206 million; Yr. 2 - $245 million; and Yr. 3 - $251 million) over a 10-year period, including the overall pre-tax rate of return on such costs. (b) Amounts reflect amortization of the 2018 tax savings under the federal Tax Cuts and Jobs Act of 2017 (TCJA) allocable to CECONY’s electric customers ($377 million) over a three-year period ($126 million annually), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s electric customers ($1,663 million) over the remaining lives of the related assets ($49 million in Yr. 1, $50 million in Yr. 2, and $53 million in Yr. 3) and the unprotected portion of the net regulatory liability ($784 million) over five years ($157 million annually). Amounts also reflect amortization of the regulatory asset for deferred MTA power reliability costs ($238 million) over a five-year period ($48 million annually). (c) The electric base rate increases shown above will be implemented with increases of $457 million in Yr. 1; $457 million in Yr. 2; and $457 million in Yr. 3 in order to levelize the customer bill impact. New rates were effective as of January 1, 2023 and CECONY began billing customers at the new levelized rate in August 2023. The shortfall in revenues due to the timing of billing to customers ($216 million) were collected through a surcharge billed through 2024, including a carrying charge on the outstanding balance. Base rates reflect recovery by the company of certain costs of its energy efficiency, demonstration projects, non-wire alternative projects (including the Brooklyn Queens demand management program), and off-peak electric vehicle charging programs (Yr. 1 - $244 million; Yr. 2 - $237 million; and Yr. 3 - $281 million) over periods varying between seven and fifteen years, including the overall pre-tax rate of return on such costs. (d) Deferrals for property taxes are limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a maximum number of basis points impact on return on common equity of 10.0 basis points, 7.5 basis points and 5.0 basis points for each of Yr. 1, Yr. 2 and Yr. 3, respectively, of the 2020 – 2022 rate plan and 10.0 basis points, 5.0 basis points and 5.0 basis points for each of Yr. 1, Yr. 2 and Yr. 3, respectively, of the 2023 – 2025 rate plan. (e) In general, if actual expenses for municipal infrastructure support (other than company labor) are below the amounts reflected in rates the company will defer the difference for credit to customers, and if the actual expenses are above the amount reflected in rates the company will defer for recovery from customers 80 percent of the difference subject to a maximum deferral, subject to certain conditions, of 15 percent of the amount reflected in the rate plans. (f) In addition, the NYSPSC continues its focused operations audit to investigate CECONY's financial accounting for income taxes. Any NYSPSC ordered adjustment to CECONY’s financial accounting for income taxes is expected to be refunded to or collected from customers, as determined by the NYSPSC. See "Other Regulatory Matters," below. (g) Reconciliation of net utility plant for AMI will be done on a combined basis for electric and gas. (h) Calculated in accordance with the earnings calculation method prescribed in the rate order. (i) In November 2021, the NYSPSC issued an order that allowed CECONY to recover $43 million of late payment charges and fees that were not billed for the year ended December 31, 2020. The recalculated return on equity for 2020 which reflects the recovery of these fees is 8.81 percent. (j) Amounts reflect amortization of the TCJA allocable to CECONY’s electric customers ($256 million) over a two-year period ($128 million in Yr. 1 and Yr. 2), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s electric customers ($1,512 million) over the remaining lives of the related assets ($34 million in Yr. 1, $63 million in Yr. 2, and $34 million in Yr. 3) and the unprotected portion of the net regulatory liability ($306 million) over two years ($153 million annually). Amounts also reflect amortization of the regulatory asset for deferred MTA power reliability costs ($93 million) over a three-year period ($31 million annually). In April 2023, the NYSPSC approved CECONY’s December 2022 petition seeking cost recovery approval for a proposed clean energy hub in Brooklyn, New York (Brooklyn Clean Energy Hub). The Brooklyn Clean Energy Hub primarily addresses an identified reliability need in 2028 due to a forecasted increase in electric demand. Construction began in September 2023 and is expected to be completed by 2028. CECONY’s January 2025 electric rate case filing reflected the costs for the Brooklyn Clean Energy Hub in base rates. In January 2024, the NYSPSC approved CECONY's August 2023 petition requesting authorization and cost recovery to construct two new substations in Jamaica, Queens (Idlewild Project) that is in addition to the capital expenditures approved in CECONY's 2023 - 2025 electric rate plan summarized above. The project is expected to be completed by May 2028 to meet anticipated reliability needs and to support New York State’s Climate Leadership and Community Protection Act goals. CECONY estimates that construction will cost $1,200 million. CECONY's January 2025 electric rate case filing reflected the costs for the Idlewild Project in base rates. In January 2025, CECONY filed a request with the NYSPSC for an electric rate increase of $1,612 million, effective January 1, 2026. The filing reflects a return on common equity of 10.1 percent and a common equity ratio of 48 percent. The company is requesting provisions pursuant to which expenses for pension and other post-retirement benefits, long-term debt, storm restoration, property taxes, municipal infrastructure support, the impact of new laws, late payment charges, and environmental site investigation and remediation are reconciled to amounts reflected in rates. In addition, the company is proposing a continued reconciliation and current recovery or surcharge mechanism of uncollectible write-offs to the level in rates. The company is proposing the continuation of earnings opportunities from Earnings Adjustment Mechanisms for meeting energy efficiency goals. The filing also reflects continuation of the revenue decoupling mechanism and the provisions pursuant to which the company recovers its purchased power and fuel costs from customers. The filing includes supplemental information regarding electric rate plans for 2027 and 2028, which the company is not requesting, but would consider through settlement discussions. For purposes of illustration, rate increases of $932 million and $880 million effective January 2027 and 2028, respectively, were calculated based upon an assumed return on common equity of 10.1 percent and a common equity ratio of 48 percent. CECONY – Gas Effective period January 2020 – December 2022 January 2023 – December 2025 Base rate changes Yr. 1 – $84 million (a) Yr. 2 – $122 million (a) Yr. 3 – $167 million (a) Yr. 1 – $217 million (c) Yr. 2 – $173 million (c) Yr. 3 – $122 million (c) Amortizations to income of net Yr. 1 – $45 million (b) Yr. 2 – $43 million (b) Yr. 3 – $10 million (b) Yr. 1 – $31 million (j) Yr. 2 – $24 million (j) Yr. 3 – $(11) million (j) Other revenue sources Retention of annual revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. Potential incentives if performance targets related to gas leak backlog, leak prone pipe and service terminations are met: Yr. 1 – $20 million Yr. 2 – $22 million Yr. 3 – $25 million In 2020, 2021 and 2022, the company recorded $3 million, $26 million and $8 million of earnings adjustment mechanism incentives for energy efficiency, respectively. In 2020, 2021 and 2022, the company recorded positive incentives of $13 million, $7 million, and $9 million respectively. In 2021, the company reversed $6 million of positive incentives recorded in 2020 pursuant to an order issued by the NYSPSC in December 2021. Retention of annual revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. Potential earnings adjusted mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $18 million Yr. 2 - $20 million Yr. 3 - $21 million In 2023 and 2024, the company recorded $5 million and $7 million of earnings adjustment mechanism incentives for energy efficiency, respectively. In 2023 and 2024, the company recorded positive incentives of $3 million each year, respectively. Revenue decoupling mechanisms Continuation of reconciliation of actual to authorized gas delivery revenues, modified to be calculated based upon revenue per customer class instead of revenue per customer. In 2020, 2021 and 2022, the company deferred for recovery from customers $27 million, $100 million and $141 million of revenues, respectively. Continuation of reconciliation of actual to authorized gas delivery revenues, modified to be calculated based upon revenue per customer class instead of revenue per customer. In 2023 and 2024, the company deferred for recovery from customers $162 million and $93 million of revenues, respectively. Recoverable energy costs Continuation of current rate recovery of purchased gas costs. Continuation of current rate recovery of purchased gas costs. Negative revenue adjustments Potential charges if performance targets relating to service, safety and other matters are not met: Yr. 1 – $81 million Yr. 2 – $88 million Yr. 3 – $96 million In 2020 and 2021, the company did not record any negative revenue adjustments. In 2022, the company recorded negative revenue adjustments of $8 million. Potential charges if performance targets relating to service, safety and other matters are not met: Yr. 1 - $107 million Yr. 2 - $119 million Yr. 3 - $130 million In 2023 and 2024, the company recorded negative revenue adjustments of $3 million and $2 million, respectively. Regulatory reconciliations Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes (d), municipal infrastructure support costs (e), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (f). In 2020 and 2021, the company deferred $91 million and $14 million of net regulatory assets, respectively. In 2022, the company deferred $70 million of net regulatory liabilities. Reconciliation of late payment charges (i) and expenses for uncollectibles, pension and other postretirement benefits, variable-rate debt, major storms, property taxes (d), municipal infrastructure support costs (e), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (f). In 2023 and 2024, the company deferred $12 million and $29 million of net regulatory liabilities, respectively. Net utility plant reconciliations Target levels reflected in rates: Gas average net plant target excluding AMI: Yr. 1 – $8,108 million Yr. 2 – $8,808 million Yr. 3 – $9,510 million AMI (g): Yr. 1 – $142 million Yr. 2 – $183 million Yr. 3 – $211 million In 2020 and 2021, the company deferred $24.7 million and $26 million, as a regulatory liability, respectively. In 2022, the company deferred $10.8 million as a regulatory asset. Target levels reflected in rates: Gas average net plant target excluding AMI and CSS for Yr. 1: Yr. 1 - $10,466 million Yr. 2 - $11,442 million Yr. 3 - $12,142 million AMI (g): Yr. 1 - $234 million CSS: Yr. 1 - $2 million In 2023 and 2024, the company deferred $15.5 million and $31.5 million as regulatory liabilities, respectively. Average rate base Yr. 1 – $7,171 million Yr. 2 – $7,911 million Yr. 3 – $8,622 million Yr. 1 - $9,647 million Yr. 2 - $10,428 million Yr. 3 - $11,063 million Weighted average cost of capital Yr. 1 – Yr. 3 - 6.61 percent Yr. 1 – 6.75 percent Yr. 2 – 6.79 percent Yr. 3 – 6.85 percent Authorized return on common equity 8.8 percent 9.25 percent Actual return on common equity (h) (i) Yr. 1 – 8.4 percent Yr. 2 – 8.48 percent Yr. 3 – 8.93 percent Yr. 1 – 9.00 percent Yr. 2 - 9.82 percent Earnings sharing Most earnings above an annual earnings threshold of 9.3 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2020, 2021 and 2022, the company had no earnings above the threshold. Most earnings above an annual earnings threshold of 9.75 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2023, the company had no earnings above the threshold. In 2024, the company had $4.3 million above the threshold. Cost of long-term debt Yr. 1 – Yr. 3 - 4.63 percent Yr. 1 – 4.46 percent Yr. 2 – 4.54 percent Yr. 3 – 4.64 percent Common equity ratio 48 percent 48 percent (a) The gas base rate increases shown above will be implemented with increases of $47 million in Yr. 1; $176 million in Yr. 2; and $170 million in Yr. 3 in order to levelize customer bill impacts. Base rates reflect recovery by the company of certain costs of its energy efficiency program (Yr. 1 - $30 million; Yr. 2 - $37 million; and Yr. 3 - $40 million) over a ten-year period, including the overall pre-tax rate of return on such costs. (b) Amounts reflect amortization of t he remaining 2018 TCJA tax savings allocable to CECONY’s gas customers ($63 million) over a two year period ($32 million annually), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s gas customers ($725 million) over the remaining lives of the related assets ($14 million in Yr. 1, $14 million in Yr. 2, and $12 million in Yr. 3) and the unprotected portion of the net regulatory liability ($107 million) over five years ($21 million annually) (c) The gas base rate increases shown above will be implemented with increases of $187 million in Yr. 1; $187 million in Yr. 2; and $187 million in Yr. 3 in order to levelize the customer bill impact. New rates were effective as of January 1, 2023. CECONY began billing customers at the new levelized rate in August 2023. The shortfall in revenues due to the timing of billing to customers ($99 million) are being collected through a surcharge billed through 2025, including a carrying charge on the outstanding balance. Base rates reflect recovery by the company of certain costs of its energy efficiency programs (Yr. 1 - $45 million; Yr. 2 - $78 million; and Yr. 3 - $62 million) over a fifteen-year period, including the overall pre-tax rate of return on such costs. (d)-(h) See footnotes (d) - (h) to the table under “CECONY Electric,” above. (i) In November 2021, the NYSPSC issued an order that allowed CECONY to recover $7 million of late payment charges and fees that were not billed for the year ended December 31, 2020. The recalculated return on equity for 2020 which reflects the recovery of these fees is 8.56 percent. (j) Amounts reflect amortization of the TCJA allocable to CECONY’s gas customers ($32 million) over a two-year period ($16 million in Yr. 1 and Yr. 2), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s gas customers ($679 million) over the remaining lives of the related assets ($9 million in Yr. 1, $10 million in Yr. 2, and $10 million in Yr. 3) and the unprotected portion of the net regulatory liability ($42 million) over two years ($21 million annually). In January 2025, CECONY filed a request with the NYSPSC for a gas rate increase of $441 million, effective January 1, 2026. The filing reflects a return on common equity of 10.1 percent and a common equity ratio of 48 percent. The company is requesting provisions pursuant to which expenses for pension and other post-retirement benefits, long-term debt, storm restoration, property taxes, municipal infrastructure support, the impact of new laws, late payment charges, and environmental site investigation and remediation are reconciled to amounts reflected in rates. In addition, the company is proposing a continued reconciliation and current recovery or surcharge mechanism of uncollectible write-offs to the level in rates. The company is proposing the continuation of earnings opportunities from Earnings Adjustment Mechanisms for meeting energy efficiency goals. The filing also reflects continuation of the revenue decoupling mechanism and the provisions pursuant to which the company recovers its purchased gas costs from customers. The filing includes supplemental information regarding gas rate plans for 2027 and 2028, which the company is not requesting, but would consider through settlement discussions. For purposes of illustration, rate increases of $266 million and $166 million effective January 2027 and 2028, respectively, were calculated based upon an assumed return on common equity of 10.1 percent and a common equity ratio of 48 percent. CECONY – Steam Effective period January 2014 – December 2016 (g) November 2023 – October 2026 Base rate changes Yr. 1 – $(22.4) million (h) Yr. 2 –$19.8 million (h) Yr. 3 –$20.3 million(h) Yr. 4 – None Yr. 5 – None Yr. 6 – None Yr. 7 – None Yr. 8 – None Yr. 9 – None Yr.10 – None Yr. 1 – $110 million (a) Yr. 2 – $44 million (a) Yr. 3 – $45 million (a) Amortizations to income of net $37 million over three years Yr. 1 – $15 million (b) Yr. 2 – $3 million (b) Yr. 3 – $3 million (b) Weather Normalization Adjustment Implementation of a weather normalization adjustment to reflect normal weather conditions during the heating season. Recoverable energy costs Current rate recovery of purchased power and fuel costs. Continuation of current rate recovery of purchased power and fuel costs. Negative revenue adjustments Potential charges (up to $1 million annually) if certain performance targets are not met. The company did not record any negative revenue adjustments under this rate plan. Potential charges if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 - $3.7 million Yr. 2 - $3.8 million Yr. 3 - $3.8 million In Yr. 1, the company did not record any negative revenue adjustments. Regulatory reconciliations (i) (j) In 2014, 2015, 2016, 2017, 2018, 2019, 2020, 2021, 2022 and 2023, the company deferred $42 million of net regulatory liabilities, $17 million of net regulatory assets, $8 million and $14 million of net regulatory liabilities, $1 million of net regulatory assets, $8 million of net regulatory liabilities, $35 million of net regulatory assets, $32 million of net regulatory assets, $11 million of net regulatory assets and $18 million net regulatory liabilities, respectively. Reconciliation of uncollectible expenses and late payment charges (c) and expenses for pension and other postretirement benefits, variable-rate debt, property taxes (d), municipal infrastructure support costs (e), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates. (f) In Yr. 1, the company deferred $7 million of net regulatory assets. Net utility plant reconciliations Target levels reflected in rates were: Production: Yr. 1 – $1,752 million Yr. 2 – $1,732 million Yr. 3 – $1,720 million Distribution: Yr. 1 – $6 million Yr. 2 – $11 million Yr. 3 – $25 million The company reduced its regulatory liability by $0.1 in 2014 and immaterial amounts in 2015 and 2016 and no deferrals were recorded in 2017, 2018, 2019. In 2020 and 2021, the company deferred $2 million and $1 million as a regulatory liability, respectively. In 2022, the company deferred $0.1 million as a regulatory asset. No deferral was recorded in 2023. Yr. 1 - $2,025 million Yr. 2 - $2,029 million Yr. 3 - $2,015 million In Yr. 1, the company deferred $2.4 million as a regulatory liability. Average rate base Yr. 1 – $1,511 million Yr. 2 – $1,547 million Yr. 3 – $1,604 million Yr. 1 - $1,799 million Yr. 2 - $1,848 million Yr. 3 - $1,882 million Weighted average cost of capital (after-tax) Yr. 1 – 7.10 percent Yr. 2 – 7.13 percent Yr. 3 – 7.21 percent Yr. 1 - 6.78 percent Yr. 2 - 6.81 percent Yr. 3 - 6.83 percent Authorized return on common equity 9.3 percent 9.25 percent Actual return on common equity (j) Yr. 1 – 9.82 percent Yr. 2 – 10.88 percent Yr. 3 – 10.54 percent Yr. 4 – 9.51 percent Yr. 5 – 11.73 percent Yr. 6 – 10.45 percent Yr. 7 – 7.91 percent Yr. 8 – 5.99 percent Yr. 9 - 5.72 percent Yr. 10 - (0.10) percent . Yr. 1 – 6.55 percent Earnings sharing Weather normalized earnings above an annual earnings threshold of 9.9 percent are to be applied to reduce regulatory assets for environmental remediation and other costs. In 2014, the company had no earnings above the threshold. Actual earnings were $11.5 million and $7.8 million above the threshold in 2015 and 2016, respectively. In 2017, actual earnings were $8.5 million above the threshold, offset in part by a positive adjustment related to 2016 of $4 million. In 2018, actual earnings were $16.5 million above the threshold, and an additional $1.1 million related to 2017 was recorded. In 2019 actual earnings were $5 million above the threshold, offset in part by an adjustment related to 2018 of $2.3 million. In 2020, 2021, 2022 and 2023, the company had no earnings sharing above the threshold. Reserve adjustments of $0.4 million and $0.2 million were recorded in 2021 related to potential adjustment to the excess earnings sharing amounts for 2016 and 2018, respectively. Most earnings above an annual earnings threshold of 9.75 percent are to be applied

Capitalization

Capitalization	12 Months Ended
Capitalization	Dec. 31, 2024
Debt Disclosure [Abstract]
Capitalization	Capitalization Common Stock Con Edison is authorized to issue 500,000,000 shares of its common stock and CECONY is authorized to issue 340,000,000 of its common stock. At December 31, 2024 and 2023, 346,597,693 and 345,415,772 shares, respectively, of Con Edison common stock were outstanding. At December 31, 2024 and 2023, 235,488,094 million shares of CECONY common stock were outstanding, all of which were owned by Con Edison. At December 31, 2024 and 2023, Con Edison had 33,753,963 treasury shares, including 21,976,200 shares of Con Edison stock that CECONY purchased prior to 2001 in connection with Con Edison’s stock repurchase plan and 10,543,263 common shares of Con Edison purchased in 2023 in connection with Con Edison's accelerated share repurchase agreements. CECONY presents in the financial statements the cost of the Con Edison stock it owns as a reduction of common shareholder’s equity. In December 2024, Con Edison entered into a forward sale agreement relating to 7,000,000 of its common shares. The company expects the common shares under the forward sale agreement to settle by December 31, 2025. The company or the forward purchaser may accelerate the forward sale agreement upon the occurrence of certain events. On a settlement date, if the company decides to physically settle, it will issue shares to the forward purchaser at the then-applicable forward sale price. The forward sale price is equal to $96.66 per share and is subject to adjustment on a daily basis based on a floating interest rate factor less a spread, and will be subject to decrease on each of certain dates by amounts related to expected dividends. The common shares under the forward sale agreement will be physically settled, unless the company elects cash settlement or net share settlement (which it has the right to do, subject to certain conditions, other than in limited circumstances). In the event the company elects to cash settle or net share settle, the settlement amount will be generally related to (1) (a) the market value of the common shares during the unwind period under the forward sale agreement minus (b) the applicable adjusted forward sale price; multiplied by (2) the number of shares subject to such cash settlement or net share settlement. If this settlement amount is a negative number, the forward purchaser will pay the company the absolute value of that amount or deliver to the company a number of shares having a value equal to the absolute value of such amount. If this settlement amount is a positive number, the company will pay the forward purchaser that amount or deliver to the forward purchaser a number of shares having a value equal to such amount. No amounts have been or will be recorded to the consolidated financial statements with respect to the equity offering until any settlement of the forward sale agreement occurs. In 2023, Con Edison entered into accelerated share repurchase agreements with two dealers to repurchase $1,000 million in aggregate of Con Edison’s Common Shares ($.10 par value) (Common Shares). The settlement of the accelerated share repurchase agreements occurred in the second quarter of 2023. Con Edison made payments of $1,000 million in aggregate to the dealers and received deliveries of 10,543,263 Common Shares in aggregate. Con Edison recorded the 2023 accelerated share repurchases as equity transactions, and at the time of receipt, shares were included in treasury stock at fair market value as of the corresponding trade date. Con Edison reflected shares received as a repurchase of common stock in the weighted average common shares outstanding calculation for basic and diluted earnings per share. Capitalization of Con Edison At December 31, 2024 and 2023, Con Edison's capitalization shown on its Consolidated Statement of Capitalization includes its outstanding common stock and long-term debt and the outstanding long-term debt of the Utilities. Dividends In accordance with NYSPSC requirements, the dividends that the Utilities generally pay are limited to not more than 100 percent of their respective income available for dividends calculated on a two–year rolling average basis. See Note U. Excluded from the calculation of “income available for dividends” are non-cash charges to income resulting from accounting changes or charges to income resulting from significant unanticipated events. The restriction also does not apply to dividends paid in order to transfer to Con Edison proceeds from major transactions, such as asset sales, or to dividends reducing each utility subsidiary’s equity ratio to a level appropriate to its business risk. Long-term Debt Long-term debt maturing in the period 2025-2029 is as follows: (Millions of Dollars) Con Edison (a) CECONY 2025 $— $— 2026 250 250 2027 780 700 2028 800 800 2029 44 — (a) Amounts shown exclude $59 million of debt for Broken Bow II, a deferred project, which was classified as held for sale as of December 31, 2024 and is shown under “Project Debt Held for Sale" on Con Edison's Consolidated Statement of Capitalization. See "Assets Held for Sale" in Note A and Note X for additional information. The sale and transfer of Broken Bow II, including the related debt, was completed in January 2025. At December 31, 2024 and December 31, 2023, long-term debt of CECONY included $225 million and $450 million , respectively, of tax–exempt debt through the New York State Energy Research and Development Authority (NYSERDA) that bore interest at a rate determined weekly and was subject to tender by bondholders for purchase by the company. The carrying amounts and fair values of long-term debt at December 31, 2024 and 2023 are: (Millions of Dollars) 2024 2023 Long-Term Debt (including current portion) (a) Carrying Fair Carrying Fair Con Edison (b) $24,651 $21,997 $22,177 $20,525 CECONY 23,409 20,915 21,060 19,517 (a) Amounts shown are net of unamortized debt expense and unamortized debt discount of $249 million and $241 million for Con Edison and CECONY, respectively, as of December 31, 2024 and $222 million and $215 million for Con Edison and CECONY, respectively, as of December 31, 2023. (b) Amounts shown exclude the debt of Broken Bow II, a deferred project that was classified as held for sale as of December 31, 2024 and as of December 31, 2023 and is shown under “Project Debt Held for Sale" on Con Edison's Consolidated Statement of Capitalization. The carrying value and fair value of Broken Bow II's long-term debt, including the current portion, as of December 31, 2024 was $59 million and $54 million, respectively, and as of December 31, 2023 was $62 million and $58 million, respectively. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W and Note X. The sale and transfer of Broken Bow II, including the related debt, was completed in January 2025. See Note W. The fair values of the Companies' long-term debt have been estimated primarily using available market information and at December 31, 2024 are classified as Level 2 liabilities (see Note R). Significant Debt Covenants The significant debt covenants under the financing arrangements for the Companies' debentures include obligations to pay principal and interest when due and covenants not to consolidate with or merge into any other entity unless certain conditions are met. The Companies' debentures have no cross default provisions. The tax–exempt financing arrangements of CECONY are subject to covenants for the debentures discussed above and the covenants discussed below. The Companies were in compliance with their significant debt covenants at December 31, 2024. The tax-exempt financing arrangements involved the issuance of uncollateralized promissory notes of CECONY to NYSERDA in exchange for the net proceeds of a like amount of tax–exempt bonds with substantially the same terms sold to the public by NYSERDA. The tax-exempt financing arrangements include covenants with respect to the tax–exempt status of the financing, including covenants with respect to the use of the facilities financed. The arrangements include provisions for the maintenance of liquidity and credit facilities, the failure to comply with which would, except as otherwise provided, constitute an event of default for the debt to which such provisions applied. The failure to comply with debt covenants would, except as otherwise provided, constitute an event of default for the debt to which such provisions applied. If an event of default were to occur, the principal and accrued interest on the debt to which such event of default applied and, in the case of the Con Edison notes, a make-whole premium might and, in the case of certain events of default would, become due and payable immediately. The liquidity and credit facilities currently in effect for the tax–exempt financing include covenants that the ratio of debt to total capital of CECONY will not at any time exceed 0.65 to 1 and that, subject to certain exceptions, CECONY will not mortgage, lien, pledge or otherwise encumber its assets. Certain of the facilities also include as events of default, defaults in payments of other debt obligations in excess of $100 million.

Short-Term Borrowing

Short-Term Borrowing	12 Months Ended
Short-Term Borrowing	Dec. 31, 2024
Debt Disclosure [Abstract]
Short-Term Borrowing	Short-Term Borrowing In March 2023, Con Edison and the Utilities entered into a $2,500 million credit agreement that replaced a December 2016 credit agreement, under which banks are committed to provide loans and letters of credit on a revolving credit basis. In March 2024, Con Edison and the Utilities also entered into a First Amendment to Credit Agreement (as so amended, the Credit Agreement) that, among other things, amended the mechanics relating to determining the interest rate to be paid with respect to a “Term SOFR Loan.” The Credit Agreement expires in March 2029, unless extended for up to one additional one-year term. There is a maximum of $2,500 million of credit available to CECONY and $800 million (subject to increase up to $1,000 million) available to Con Edison, including up to $900 million of letters of credit. The Companies have not borrowed under the Credit Agreement. The Credit Agreement supports the Companies’ commercial paper programs. Loans and letters of credit issued under the Credit Agreement may also be used for other general corporate purposes. Any borrowings under the Credit Agreement would generally be at variable interest rates. In March 2024, CECONY entered into a 364-Day Revolving Credit Agreement (the CECONY Credit Agreement) that replaced a March 2023 CECONY 364-Day Credit Agreement, under which banks are committed to provide loans up to $500 million on a revolving credit basis. The CECONY Credit Agreement expires in March 2025 and supports CECONY’s commercial paper program. Loans issued under the CECONY Credit Agreement may also be used for other general corporate purposes. Any borrowings under the CECONY Credit Agreement would generally be at variable interest rates. At December 31, 2024, Con Edison had $2,170 million of commercial paper outstanding, of which $1,694 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, 2024 was 4.7 percent for both Con Edison and CECONY. At December 31, 2023, Con Edison had $2,288 million of commercial paper outstanding of which $1,903 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, 2023 was 5.6 percent for both Con Edison and CECONY. At December 31, 2024 and 2023, no loans or letters of credit were outstanding under the Credit Agreement and no loans were outstanding under the CECONY Credit Agreement. The banks’ commitments under the Credit Agreement and the CECONY Credit Agreement are subject to certain conditions, including that there be no event of default. The commitments are not subject to maintenance of credit rating levels or the absence of a material adverse change. Upon a change of control of, or upon an event of default by one of the Companies under the Credit Agreement or by CECONY under the CECONY Credit Agreement, the banks may terminate their commitments with respect to that company, declare any amounts owed by that company immediately due and payable and for the Credit Agreement, require that company to provide cash collateral relating to the letters of credit issued for it under the Credit Agreement. Events of default for a company include that company exceeding at any time of a ratio of consolidated debt to consolidated total capital of 0.65 to 1 (at December 31, 2024 this ratio was 0.56 to 1 for Con Edison and 0.57 to 1 for CECONY); that company having liens on its assets in an aggregate amount exceeding 10 percent of its consolidated net tangible assets, subject to certain exceptions; that company or any of its material subsidiaries failing to make one or more payments in respect of material financial obligations (in excess of an aggregate $150 million of debt or derivative obligations other than non-recourse debt) of that company; the occurrence of an event or condition which results in the acceleration of the maturity of any material debt (in excess of an aggregate $150 million of debt other than non-recourse debt) of that company or enables the holders of such debt to accelerate the maturity thereof; and other customary events of default. Interest and fees charged for the revolving credit facilities and any loans made or letters of credit issued under the Credit Agreement reflect the Companies’ respective credit ratings. The Companies were in compliance with their significant debt covenants at December 31, 2024. In November 2024 and January 2025, CECONY borrowed $500 million and $200 million, respectively, at a variable rate under a 364-Day Senior Unsecured Delayed Draw Term Loan Credit Agreement entered into by the company in November 2024 (the CECONY Term Loan Credit Agreement). The term loans mature in November 2025. CECONY has the option to prepay the term loans issued under the CECONY Term Loan Credit Agreement prior to maturity. CECONY intends to use borrowings under the CECONY Term Loan Credit Agreement for general corporate purposes. Upon a change of control of CECONY or Con Edison, or upon an event of default by CECONY, the banks may declare the loans outstanding under the CECONY Term Loan Credit Agreement immediately due and payable. Events of default include, among other things, CECONY exceeding at any time a ratio of consolidated debt to consolidated total capital of 0.65 to 1; CECONY or its subsidiaries having liens on its or their assets in an aggregate amount exceeding ten percent of CECONY’s consolidated net tangible assets; CECONY or its material subsidiaries failing to make one or more payments in respect of material financial obligations (in excess of $150 million in aggregate of debt or derivative obligations other than non-recourse debt); the occurrence of an event or condition which results in the acceleration of the maturity of any material debt (in excess of $150 million in aggregate of debt other than non-recourse debt) or enables the holders of such debt to accelerate the maturity thereof; and other customary events of default. See Note U for information about short-term borrowing between related parties.

Pension Benefits

Pension Benefits	12 Months Ended
Pension Benefits	Dec. 31, 2024
Retirement Benefits [Abstract]
Pension Benefits	Pension Benefits Con Edison maintains a tax-qualified, non-contributory pension plan, the Consolidated Edison Retirement Plan, that covers substantially all employees of CECONY, O&R and Con Edison Transmission. The plan is designed to comply with the Internal Revenue Code and the Employee Retirement Income Security Act of 1974. Con Edison also maintains additional non – qualified supplemental pension plans. Total Periodic Benefit Cost/(Credit) The components of the Companies’ total periodic benefit cost/(credit) for 2024, 2023 and 2022 were as follows: Con Edison CECONY (Millions of Dollars) 2024 2023 2022 2024 2023 2022 Service cost – including administrative expenses $177 $161 $287 $167 $151 $270 Interest cost on projected benefit obligation 642 649 505 604 611 475 Expected return on plan assets (1,129) (1,114) (1,168) (1,076) (1,061) (1,109) Recognition of net actuarial loss/(gain) (5) (232) 377 (7) (219) 358 Recognition of prior service credit (17) (17) (16) (19) (19) (21) TOTAL PERIODIC BENEFIT COST/(CREDIT) $(332) $(553) $(15) $(331) $(537) $(27) Cost capitalized (94) (81) (137) (90) (78) (129) Reconciliation to rate level 55 282 259 43 261 245 Total expense/(benefit) recognized $(371) $(352) $107 $(378) $(354) $89 Accounting rules require that components of net periodic benefit cost other than service cost be presented outside of operating income on consolidated income statements, and that only the service cost component is eligible for capitalization. Accordingly, the service cost components are included in the line "Other operations and maintenance" and the non-service cost components are included in the lines "Other income" or “Other deductions” in the Companies' consolidated income statements. The rules also require disclosure of the weighted-average interest crediting rate used for cash balance plans for all periods presented, and a narrative description of significant changes in the benefit obligation which are included below and, as applicable, in Note F. Funded Status The funded status at December 31, 2024, 2023 and 2022 was as follows: Con Edison CECONY (Millions of Dollars) 2024 2023 2022 2024 2023 2022 CHANGE IN PROJECTED BENEFIT OBLIGATION Projected benefit obligation at beginning of year $12,712 $12,113 $17,357 $11,977 $11,395 $16,341 Service cost – excluding administrative expenses 172 156 283 162 146 266 Interest cost on projected benefit obligation 642 649 505 604 611 475 Net actuarial loss/(gain) (557) 599 (5,102) (557) 572 (4,845) Plan amendments — 3 — — — — Benefits paid (828) (808) (930) (751) (747) (842) PROJECTED BENEFIT OBLIGATION AT END OF YEAR $12,141 $12,712 $12,113 $11,435 $11,977 $11,395 CHANGE IN PLAN ASSETS Fair value of plan assets at beginning of year $15,404 $14,979 $18,504 $14,674 $14,248 $17,566 Actual return on plan assets 724 1,261 (2,583) 691 1,201 (2,453) Employer contributions 20 21 30 17 18 17 Benefits paid (828) (808) (930) (751) (747) (842) Administrative expenses (42) (49) (42) (40) (46) (40) FAIR VALUE OF PLAN ASSETS AT END OF YEAR $15,278 $15,404 $14,979 $14,591 $14,674 $14,248 FUNDED STATUS $3,137 $2,692 $2,866 $3,156 $2,697 $2,853 Unrecognized net loss/(gain) $(857) ($757) ($1,485) $(825) ($705) ($1,397) Unrecognized prior service credits (88) (105) (124) (104) (124) (143) Accumulated benefit obligation $11,236 $11,739 $11,167 $10,554 $11,031 $10,478 The increase in the pension funded status at December 31, 2024 for Con Edison and CECONY of $445 million and $459 million, respectively, compared with December 31, 2023, was primarily due to a decrease in the plan's projected benefit obligation as a result of an increase in the discount rate. The decrease in the pension funded status at December 31, 2023 for Con Edison and CECONY of $174 million and $156 million, respectively, compared with December 31, 2022, was primarily due to an increase in the plan's projected benefit obligation as a result of a decrease in the discount rate, partially offset by a return on plan assets that was greater than the expected return. See below for further information on the change in the discount rate and determination of the discount rate assumption. For Con Edison, the 2024 increase in pension funded status asset corresponds with an increase to regulatory liabilities of $86 million for unrecognized net gains and unrecognized prior service credits associated with the Utilities consistent with the accounting rules for regulated operations, a credit to OCI of $5 million (net of taxes) for the unrecognized net gains, and an immaterial change to OCI (net of taxes) for the unrecognized prior service credits associated with certain employees of Con Edison Transmission and RECO who previously worked for the Utilities. For 2024, included within the funded status are noncurrent liabilities of $319 million and $296 million for Con Edison and CECONY, respectively, and current liabilities of $63 million and $60 million for Con Edison and CECONY, respectively. For 2023, included within the funded status are noncurrent liabilities of $337 million and $313 million for Con Edison and CECONY, respectively. For 2022, included within the funded status are noncurrent liabilities of $311 million and $287 million for Con Edison and CECONY, respectively. For CECONY, the increase in pension funded status asset at December 31, 2024 corresponds with an increase to regulatory liabilities of $101 million for unrecognized net gains and unrecognized prior service credits consistent with the accounting rules for regulated operations, and also a credit to OCI of $7 million (net of taxes) for unrecognized net gains, and an immaterial change to OCI (net of taxes) for the unrecognized prior service costs associated with certain employees of Con Edison Transmission who previously worked for CECONY. At December 31, 2024 and 2023, Con Edison’s investments included $583 million and $524 million, respectively, held in external trust accounts for benefit payments pursuant to the supplemental retirement plans. Included in these amounts for CECONY were $560 million and $502 million, respectively. See Note R. The accumulated benefit obligations for the supplemental retirement plans for Con Edison and CECONY were $380 million and $354 million as of December 31, 2024, respectively, and $349 million and $323 million as of December 31, 2023, respectively. Assumptions The actuarial assumptions were as follows: 2024 2023 2022 Weighted-average assumptions used to determine benefit obligations at December 31: Discount rate 5.70 % 5.15 % 5.45 % Interest crediting rate for cash balance plan 4.30 % 4.20 % 4.00 % Rate of compensation increase CECONY 3.80 % 3.80 % 3.80 % O&R 3.20 % 3.20 % 3.20 % Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31: Discount rate 5.15 % 5.45 % 3.00 % Interest crediting rate for cash balance plan 4.20 % 4.00 % 3.50 % Expected return on plan assets 6.75 % 6.75 % 7.00 % Rate of compensation increase CECONY 3.80 % 3.80 % 3.80 % O&R 3.20 % 3.20 % 3.20 % The expected return assumption reflects anticipated returns on the plan’s current and future assets. The Companies’ expected return was based on an evaluation of the current environment, market and economic outlook, relationships between the economy and asset class performance patterns, and recent and long-term trends in asset class performance. The projections were based on the plan’s target asset allocation. Discount Rate Assumption To determine the assumed discount rate, the Companies use a model that produces a yield curve based on discounting plan specific cash flows with corresponding spot rates on a yield curve. Term structures of interest rates are based on AA rated corporate bonds. Bonds with questionable pricing information and bonds that are not representative of the overall market are excluded from consideration. For example, the bonds used in the model cannot be callable (with the exception of "make whole" callable bonds). The spot rates defined by the yield curve and the plan’s projected benefit payments are used to develop a weighted average discount rate. Expected Benefit Payments Based on current assumptions, the Companies expect to make the following benefit payments over the next ten years: (Millions of Dollars) Con Edison CECONY 2025 $840 $781 2026 808 749 2027 820 764 2028 824 766 2029 836 778 2030-2034 $4,227 $3,952 Expected Contributions Based on estimates as of December 31, 2024, the Companies expect to make contributions to the pension plans during 2025 of $3 million (none of which is to be made by CECONY). The Companies’ policy is to fund the total periodic benefit cost, if any, of the qualified plan to the extent tax deductible and to also contribute to the non-qualified supplemental plans. Plan Assets The asset allocations for the pension plan at the end of 2024, 2023 and 2022, and the target allocation for 2025 are as follows: Target Allocation Range Plan Assets at December 31, Asset Category 2025 2024 2023 2022 Equity Securities 26% - 30% 27 % 26 % 33 % Debt Securities 42% - 60% 51 % 50 % 50 % Real Estate and Other Alternatives 14% - 30% 22 % 24 % 17 % Total 100 % 100 % 100 % Con Edison has established a pension trust for the investment of assets to be used for the exclusive purpose of providing retirement benefits to participants and beneficiaries and payment of plan expenses. Pursuant to resolutions adopted by Con Edison’s Board of Directors, the Named Fiduciary Committee (the Committee) has general oversight responsibility for Con Edison’s pension and other employee benefit plans. The pension plan’s named fiduciaries have been granted the authority to control and manage the operation and administration of the plans, including overall responsibility for the investment of assets in the trust and the power to appoint and terminate investment managers. The investment objectives of the Con Edison pension plan are to maintain a level and form of assets adequate to meet benefit obligations to participants, to achieve the expected long-term total return on the trust assets within a prudent level of risk and maintain a level of volatility that is not expected to have a material impact on the company’s expected contribution and expense or the company’s ability to meet plan obligations. The assets of the plan have no significant concentration of risk in one country (other than the United States), industry or entity. The strategic asset allocation is intended to meet the objectives of the pension plan by diversifying its funds across asset classes, investment styles and fund managers. An asset/liability study typically is conducted every few years to determine whether the current strategic asset allocation continues to represent the appropriate balance of expected risk and reward for the plan to meet expected liabilities. Each study considers the investment risk of the asset allocation and determines the optimal asset allocation for the plan. The target asset allocation for 2025 reflects the results of such a study conducted in 2022. Individual fund managers operate under written guidelines provided by Con Edison that cover such areas as investment objectives, performance measurement, permissible investments, investment restrictions, trading and execution, and communication and reporting requirements. Con Edison management regularly monitors and the named fiduciaries review asset class performance, total fund performance, and compliance with asset allocation guidelines. Management changes fund managers and rebalances the portfolio as appropriate. The Utilities each participate in the Con Edison Retirement Plan, the assets of which are held in the pension trust. In accordance with the Utilities' current rate plans, pension plan costs and liabilities are allocated to each of the Utilities based on plan participant-level data, while pension plan assets are allocated based on historical and current amounts of contributions, if any, disbursements, and investment returns. Pension plan assets for Con Edison are shown below. Of the amounts disclosed below for Con Edison, 95% are attributable to CECONY. Assets measured at fair value on a recurring basis are summarized below as defined by the accounting rules for fair value measurements (see Note R). The fair values of the pension plan assets at December 31, 2024 by asset category are as follows: (Millions of Dollars) Level 1 Level 2 Total Investments within the fair value hierarchy U.S. Equity (a) $2,752 $— $2,752 International Equity (b) 1,508 — 1,508 U.S. Government Issued Debt (c) — 619 619 Corporate Bonds Debt (d) — 5,429 5,429 Structured Assets Debt (e) — 159 159 Other Fixed Income Debt (f) — 783 783 Commingled Trust Fund (g) — 478 478 Cash and Cash Equivalents (h) 51 292 343 Futures (i) (4) — (4) Total investments within the fair value hierarchy $4,307 $7,760 $12,067 Investments measured at NAV per share (o) Private Equity (j) 975 Real Estate (k) 1,609 Hedge Funds (l) 788 Total investments valued using NAV per share $3,372 Funds for retiree health benefits (m) (50) (90) (140) Funds for retiree health benefits measured at NAV per share (m)(o) (39) Total funds for retiree health benefits $(179) Investments (excluding funds for retiree health benefits) $4,257 $7,670 $15,260 Pending activities (n) 18 Total fair value of plan net assets $15,278 (a) U.S. Equity is comprised of both actively- and passively-managed investments in domestic equity index funds and actively-managed small-capitalization equities. (b) International Equity is comprised of investments in international equity index funds and actively-managed international equities. (c) U.S. Government Issued Debt is comprised of agency and treasury securities. (d) Corporate Bonds Debt is comprised of debt issued by various corporations. (e) Structured Assets Debt is comprised of commercial-mortgage-backed securities and collateralized mortgage obligations. (f) Other Fixed Income Debt is comprised of municipal bonds, sovereign debt and regional governments. (g) Commingled Trust Fund is comprised of an actively managed commingled trust fund benchmarked to the Bloomberg Aggregate Bond Index. (h) Cash and Cash Equivalents are comprised of short term investments, money markets, foreign currency and cash collateral. (i) Futures are comprised of exchange-traded financial contracts encompassing U.S. Equity, International Equity and U.S. Government indices. (j) Private Equity is comprised of global private market investments. Private equity's investment objective is to generate returns on capital from a diversified portfolio of primary fund investments, secondaries and co-investments. The plan's unfunded commitments to private equity were approximately $180 million at December 31, 2024. However, the managers also expect to make significant cash flow distributions in 2025 and 2026. While the investments in this asset class cannot be redeemed, the plan would be able to receive distributions from selling its limited partnership interests in the secondary market, which would be expected to take three (k) Real Estate investments are open-end real estate funds that invest in a portfolio of real properties that are broadly diversified by geography and property type. The real estate asset class is expected to produce returns from income and capital appreciation. Real estate also provides a hedge against inflation. The funds allow for quarterly redemptions, however the amount and timing of distributions are subject to market conditions and are currently uncertain. (l) Hedge Funds are structured as a custom fund of one and can invest in external hedge fund managers that pursue a wide array of strategies including event driven, fundamental long/short, relative value, directional trading, and direct sourcing. These investments seek to generate positive absolute returns with lower volatility than other investments. The various hedge fund managers can invest in all financial instruments. Substantially all of the investment could be liquidated within 18 months. (m) The Companies set aside funds for retiree health benefits through a separate account within the pension trust, as permitted under Section 401(h) of the Internal Revenue Code of 1986, as amended. In accordance with the Code, the plan’s investments in the 401(h) account may not be used for, or diverted to, any purpose other than providing health benefits for retirees. The net assets held in the 401(h) account are calculated based on a pro-rata percentage allocation of the net assets in the pension plan. The related obligations for health benefits are not included in the pension plan’s obligations and are included in the Companies’ other postretirement benefit obligation. See Note F. (n) Pending activities include security purchases and sales that have not settled, interest and dividends that have not been received and reflects adjustments for available estimates at year end. (o) In accordance with ASU 2015-07, Fair Value Measurements (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or its equivalent), certain investments that are measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy. The fair values of the pension plan assets at December 31, 2023 by asset category are as follows: (Millions of Dollars) Level 1 Level 2 Total Investments within the fair value hierarchy U.S. Equity (a) $2,474 $1 $2,475 International Equity (b) 1,584 — 1,584 U.S. Government Issued Debt (c) — 615 615 Corporate Bonds Debt (d) — 5,526 5,526 Structured Assets Debt (e) — 132 132 Other Fixed Income Debt (f) — 735 735 Commingled Trust Fund (g) — 475 475 Cash and Cash Equivalents (h) 36 302 338 Futures (i) 19 — 19 Total investments within the fair value hierarchy $4,113 $7,786 $11,899 Investments measured at NAV per share (o) Private Equity (j) 1,031 Real Estate (k) 1,876 Hedge Funds (l) 723 Total investments valued using NAV per share $3,630 Funds for retiree health benefits (m) (52) (96) (148) Funds for retiree health benefits measured at NAV per share (m)(o) (45) Total funds for retiree health benefits $(193) Investments (excluding funds for retiree health benefits) $4,061 $7,690 $15,336 Pending activities (n) $68 Total fair value of plan net assets $15,404 (a) - (o) Reference is made to footnotes (a) through (n) in the above table of pension plan assets at December 31, 2024 by asset category. The Companies also offer a defined contribution savings plan that covers substantially all employees and made contributions to the plan as follows: For the Years Ended December 31, (Millions of Dollars) 2024 2023 2022 Con Edison $57 $57 $57 CECONY 52 51 48

Environmental Matters

Environmental Matters	12 Months Ended
Environmental Matters	Dec. 31, 2024
Environmental Remediation Obligations [Abstract]
Environmental Matters	Environmental Matters Superfund Sites Hazardous substances, such as asbestos, polychlorinated biphenyls (PCBs) and coal tar, have been used or generated in the course of operations of the Utilities and their predecessors and are present at sites and in facilities and equipment they currently or previously owned, including sites at which gas was manufactured or stored. The Federal Comprehensive Environmental Response, Compensation and Liability Act of 1980 and similar state statutes (Superfund) impose joint and several liability, regardless of fault, upon generators of hazardous substances for investigation and remediation costs (which include costs of demolition, removal, disposal, storage, replacement, containment and monitoring) and natural resource damages. Liability under these laws can be material and may be imposed for contamination from past acts, even though such past acts may have been lawful at the time they occurred. The sites at which the Utilities have been asserted to have liability under these laws, including their manufactured gas plant sites and any neighboring areas to which contamination may have migrated, are referred to herein as “Superfund Sites.” For Superfund Sites where there are other potentially responsible parties and the Utilities are not managing the site investigation and remediation, the accrued liability represents an estimate of the amount the Utilities will need to pay to investigate and, where determinable, discharge their related obligations. For Superfund Sites (including the manufactured gas plant sites) for which one of the Utilities is managing the investigation and remediation, the accrued liability represents an estimate of the company’s share of the undiscounted cost to investigate the sites and, for sites that have been investigated in whole or in part, the cost to remediate the sites, if remediation is necessary and if a reasonable estimate of such cost can be made. Remediation costs are estimated in light of the information available, applicable remediation standards and experience with similar sites. The accrued liabilities and regulatory assets related to Superfund Sites at December 31, 2024 and 2023 were as follows: Con Edison CECONY (Millions of Dollars) 2024 2023 2024 2023 Accrued Liabilities: Manufactured gas plant sites $941 $1,016 $846 $924 Other Superfund Sites 96 102 96 102 Total $1,037 $1,118 $942 $1,026 Regulatory assets $1,038 $1,105 $952 $1,022 Most of the accrued Superfund Site liability relates to sites that have been investigated, in whole or in part. However, for some of the sites, the extent and associated cost of the required remediation has not yet been determined. As investigations progress and information pertaining to the required remediation becomes available, the Utilities expect that additional liability may be accrued, the amount of which is not presently determinable but may be materia l. The Utilities defer prudently incurred investigation and remediation costs as regulatory assets (for subsequent recovery through rates). Environmental remediation costs incurred related to Superfund Sites at December 31, 2024 and 2023 were as follows: Con Edison CECONY (Millions of Dollars) 2024 2023 2024 2023 Remediation costs incurred $44 $13 $44 $12 Insurance and other third party recoveries received by Con Edison or CECONY were immaterial in 2024 and 2023. Co n Edison and CECONY estimate that in 2025 they will incur costs for remediation of approximately $39 million and $38 million, respectively. The Companies are unable to estimate the time period over which the remaining accrued liability will be incurred because, among other things, the required remediation has not been determined for some of the sites. In 2024, Con Edison and CECONY estimated that for their manufactured gas plant sites (including CECONY’s Astoria site), the aggregate undiscounted potential liability for the investigation and remediation of coal tar and/or other environmental contaminants could range up to $3,391 million and $3,237 million, respectively. These estimates were based on the assumption that there is contamination at all sites, including those that have not yet been fully investigated and additional assumptions about the extent of the contamination and the type and extent of the remediation that may be required. Actual experience may be materially different. Asbestos Proceedings Suits have been brought in New York State and federal courts against the Utilities and many other defendants, wherein a large number of plaintiffs sought large amounts of compensatory and punitive damages for deaths and injuries allegedly caused by exposure to asbestos at various premises of the Utilities. The suits that have been resolved, that are many, have been resolved without any payment by the Utilities, or for amounts that were not, in the aggregate, material to them. The amounts specified in all the remaining thousands of suits total billions of dollars; however, the Utilities believe that these amounts are greatly exaggerated, based on the disposition of previous claims. At December 31, 2024, Con Edison and CECONY have accrued their estimated aggregate undiscounted potential liabilities for these suits and additional suits that may be brought through 2035 as shown in the following table. These estimates were based upon a combination of modeling, historical data analysis and risk factor assessment. Courts have applied, and may continue to apply, different standards for determining liability in asbestos suits than the standard that applied historically. As a result, the Companies currently believe that there is a reasonable possibility of an exposure to loss in excess of the liability accrued for the suits. The Companies are unable to estimate the amount or range of such loss. In addition, certain current and former employees have claimed or are claiming workers’ compensation benefits based on alleged disability from exposure to asbestos. CECONY is permitted to defer as regulatory assets (for subsequent recovery through rates) costs incurred for its asbestos lawsuits and workers’ compensation claims. The accrued liability for asbestos suits and workers’ compensation proceedings (including those related to asbestos exposure) and the amounts deferred as regulatory assets or liabilities for the Companies at December 31, 2024 and 2023 were as follows: Con Edison CECONY (Millions of Dollars) 2024 2023 2024 2023 Accrued liability – asbestos suits $8 $8 $7 $7 Regulatory assets – asbestos suits 8 8 7 7 Accrued liability – workers’ compensation 53 56 51 54 Regulatory liabilities – workers’ compensation 20 17 20 17

Material Contingencies

Material Contingencies	12 Months Ended
Material Contingencies	Dec. 31, 2024
Commitments and Contingencies Disclosure [Abstract]
Material Contingencies	10 years Total (Millions of Dollars) Con Edison Transmission $49 $— $49 Broken Bow II (a) — 9 9 Total $49 $9 $58 (a) Guarantee amount shown represents a guarantee issued on behalf of Broken Bow II associated with its investment in a wind energy facility. Broken Bow II was held for sale as of December 31, 2024, and was sold and transferred in January 2025. See Note W and Note X. Con Edison Transmission – Con Edison has guaranteed payment by Con Edison Transmission of the contributions Con Edison Transmission agreed to make to New York Transco LLC (New York Transco). Con Edison Transmission owns a 45.7 percent interest in New York Transco's New York Energy Solution project, the majority of which has been completed. The guarantee amount shown in the table above includes the maximum possible required amount of Con Edison Transmission's contributions for the remainder of this project as calculated based on the assumptions that the project is completed at 175 percent of its estimated remaining costs and New York Transco does not use any debt financing for the project." id="sjs-B4">Material Contingencies Manhattan Explosion and Fire On March 12, 2014, two multi-use five-story tall buildings located on Park Avenue between 116th and 117th Streets in Manhattan were destroyed by an explosion and fire. CECONY had delivered gas to the buildings through service lines from a distribution main located below ground on Park Avenue. Eight people died and more than 50 people were injured. Additional buildings were also damaged. The National Transportation Safety Board (NTSB) investigated. The parties to the investigation included CECONY, the City of New York, the Pipeline and Hazardous Materials Safety Administration and the NYSPSC. In June 2015, the NTSB issued a final report concerning the incident, its probable cause and safety recommendations. The NTSB determined that the probable cause of the incident was (1) the failure of a defective fusion joint at a service tee (which joined a plastic service line to a plastic distribution main) installed by CECONY that allowed gas to leak from the distribution main and migrate into a building where it ignited and (2) a breach in a city sewer line that allowed groundwater and soil to flow into the sewer, resulting in a loss of support for the distribution main, that caused it to sag and overstressed the defective fusion joint. The NTSB also made safety recommendations, including recommendations to CECONY that addressed its procedures for the preparation and examination of plastic fusions, training of its staff on conditions for notifications to the city’s Fire Department and extension of its gas main isolation valve installation program. In February 2017, the NYSPSC approved a settlement agreement with CECONY related to the NYSPSC's investigations of the incident and the practices of qualifying persons to perform plastic fusions. Pursuant to the agreement, CECONY provided $27 million of future benefits to customers (for which it accrued a regulatory liability) and did not recover from customers $126 million of costs for gas emergency response activities that it had previously incurred and expensed. Lawsuits are pending against CECONY seeking generally unspecified damages and, in some cases, punitive damages, for wrongful death, personal injury, property damage and business interruption. CECONY notified its insurers of the incident and believes that the policies in force at the time of the incident will cover CECONY's costs, in excess of a required retention (the amount of which is not material), to satisfy any liability it may have for damages in connection with the incident. During 2020, CECONY accrued its estimated liability for the suits of $40 million and an insurance receivable in the same amount, and such estimated liability and receivable did not change as of December 31, 2024. Other Contingencies For additional contingencies, see “Other Regulatory Matters” in Note B, Note G and "Uncertain Tax Positions" in Note L. Guarantees Con Edison and its subsidiaries have entered into various agreements providing financial or performance assurance primarily to third parties on behalf of their subsidiaries. In addition, Con Edison provided guarantees to third parties on behalf of the Clean Energy Business es, all of which were tr ansferred to the buyer of the Clean Energy Businesses, RWE. Maximum amounts guaranteed by Con Edison and its subsidiaries under these agreements totaled $58 million and $175 million at December 31, 2024 and 2023, respectively. A summary, by type and term, of Con Edison’s total guarantees under these other agreements at December 31, 2024 is as follows: Guarantee Type 0 – 3 years > 10 years Total (Millions of Dollars) Con Edison Transmission $49 $— $49 Broken Bow II (a) — 9 9 Total $49 $9 $58 (a) Guarantee amount shown represents a guarantee issued on behalf of Broken Bow II associated with its investment in a wind energy facility. Broken Bow II was held for sale as of December 31, 2024, and was sold and transferred in January 2025. See Note W and Note X. Con Edison Transmission – Con Edison has guaranteed payment by Con Edison Transmission of the contributions Con Edison Transmission agreed to make to New York Transco LLC (New York Transco). Con Edison Transmission owns a 45.7 percent interest in New York Transco's New York Energy Solution project, the majority of which has been completed. The guarantee amount shown in the table above includes the maximum possible required amount of Con Edison Transmission's contributions for the remainder of this project as calculated based on the assumptions that the project is completed at 175 percent of its estimated remaining costs and New York Transco does not use any debt financing for the project.

Electricity and Gas Purchase Ag

Electricity and Gas Purchase Agreements	12 Months Ended
Electricity and Gas Purchase Agreements	Dec. 31, 2024
Regulated Operations [Abstract]
Electricity and Gas Purchase Agreements	Regulatory Matters Rate Plans The Utilities provide service to New York customers according to the terms of tariffs approved by the NYSPSC. Tariffs for service to customers of Rockland Electric Company (RECO), O&R’s New Jersey regulated utility subsidiary, are approved by the New Jersey Board of Public Utilities (NJBPU). The tariffs include schedules of rates for service that limit the rates charged by the Utilities to amounts that the Utilities recover from their customers costs approved by the regulator, including capital costs, of providing service to customers as defined by the tariff. The tariffs implement rate plans adopted by state utility regulators in rate orders issued at the conclusion of rate proceedings. Pursuant to the Utilities’ rate plans, there generally can be no change to the charges to customers during the respective terms of the rate plans other than specified adjustments provided for in the rate plans. The Utilities’ rate plans each cover specified periods, but rates determined pursuant to a plan generally continue in effect until a new rate plan is approved by the state utility regulator. Common provisions of the Utilities’ New York rate plans include: Base Rates are designed to recover core costs of providing electric, gas or steam delivery service such as the costs of constructing, operating and maintaining a service’s system. Earnings sharing that require the Utilities to defer for customer benefit a portion of earnings over specified rates of return on common equity. There is no symmetric mechanism for earnings below specified rates of return on common equity. Negative revenue adjustments for failure to meet certain performance standards relating to service, reliability, safety and other matters. Net utility plant reconciliations that require deferral as a regulatory liability of the revenue requirement impact of the amount, if any, by which actual average net utility plant balances are less than amounts reflected in rates. There is generally no symmetric mechanism if actual average net utility plant balances are more than amounts reflected in rates. Other revenue adjustments that represent positive revenue adjustments, positive incentives, and earnings adjustments mechanisms for achievement of performance standards related to achievement of clean energy goals, safety and other matters. Rate base , as reflected in the rate plans, is, in general, the sum of the Utilities’ net plant, working capital and certain regulatory assets less deferred taxes and certain regulatory liabilities. For each rate plan, the NYSPSC uses a forecast of the average rate base for each year that new rates would be in effect (“rate year”). Recoverable energy costs that allow the Utilities to recover on a current basis the costs for the energy they supply with no mark-up to their full-service customers. Regulatory reconciliations that reconcile pension and other postretirement benefit costs, environmental remediation costs, property taxes, variable-rate tax-exempt debt and certain other costs (including late payment charges and write-offs of customer accounts receivable balances) to amounts reflected in delivery rates for such costs. In addition, changes in the Utilities' costs not reflected in rates, in excess of certain amounts, resulting from changes in tax or changes in legislation, regulation or related actions, are deferred as a regulatory asset or regulatory liability to be reflected in the Utilities' next rate plan or in a manner to be determined by the NYSPSC. Also, the Utilities generally retain the right to petition for recovery or accounting deferral of extraordinary and material cost increases and provision is sometimes made for the utility to retain a share of cost reductions, for example, property tax refunds. Revenue decoupling mechanisms that reconcile actual energy delivery revenues to the authorized delivery revenues approved by the NYSPSC. The difference is accrued with interest for refund to, or recovery from customers, as applicable. Weighted average cost of capital is determined based on the authorized common equity ratio, return on common equity, cost of long-term debt and cost of customer deposits reflected in each rate plan. For each rate plan, the revenues designed to provide the utility a return on invested capital for each rate year are determined by multiplying each utility rate base by its pre – tax weighted average cost of capital. The Utilities’ actual return on common equity will reflect their actual operations for each rate year, and may be more or less than the authorized return on equity reflected in their rate plans (and if more, may be subject to earnings sharing). The following tables contain a summary of the Utilities’ rate plans: CECONY – Electric Effective period January 2020 – December 2022 January 2023 – December 2025 Base rate changes Yr. 1 – $113 million (a) Yr. 2 – $370 million (a) Yr. 3 – $326 million (a) Yr. 1 – $442 million (c) Yr. 2 – $518 million (c) Yr. 3 – $382 million (c) Amortizations to income of net regulatory (assets) and liabilities Yr. 1 – $267 million (b) Yr. 2 – $269 million (b) Yr. 3 – $272 million (b) Yr. 1 – $104 million (j) Yr. 2 – $49 million (j) Yr. 3 – $(205) million (j) Other revenue sources Retention of $75 million of annual transmission congestion revenues. Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $69 million Yr. 2 - $74 million Yr. 3 - $79 million In 2020, 2021 and 2022, the company recorded $34 million, $64 million and $33 million primarily related to earnings adjustment mechanism incentives for energy efficiency, respectively. In 2022, the company recorded a positive incentive of $4 million. Retention of $75 million of annual transmission congestion revenues. Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $70 million Yr. 2 - $75 million Yr. 3 - $79 million In 2023 and 2024, the company recorded $34.4 million and $52.3 million primarily related to earnings adjustment mechanism incentives for energy efficiency, respectively. Revenue decoupling mechanisms Continuation of reconciliation of actual to authorized electric delivery revenues. In 2020, 2021 and 2022, the company deferred for recovery from customers $242 million, $226 million and $90 million of revenues, respectively. Continuation of reconciliation of actual to authorized electric delivery revenues. In 2023 and 2024, the company deferred for recovery from customers $162 million and $164 million of revenues, respectively. Recoverable energy costs Continuation of current rate recovery of purchased power and fuel costs. Continuation of current rate recovery of purchased power and fuel costs. Negative revenue adjustments Potential charges if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 - $450 million Yr. 2 - $461 million Yr. 3 - $476 million In 2020, the company recorded negative revenue adjustments of $5 million. In 2021, the company did not record any negative revenue adjustments. In 2022, the company recorded negative revenue adjustments of $3 million. Potential charges if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 - $516 million Yr. 2 - $557 million Yr. 3 - $597 million In 2023 and 2024, the company did not record any negative revenue adjustments. Regulatory reconciliations Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate debt, major storms, property taxes (d), municipal infrastructure support costs (e), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (f). In 2020 and 2021, the company deferred $288 million and $191 million of net regulatory assets, respectively. In 2022, the company deferred $138 million of net regulatory liabilities. Reconciliation of late payment charges (i) and expenses for uncollectibles, pension and other postretirement benefits, variable-rate debt, major storms, property taxes (d), municipal infrastructure support costs (e), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (f). In 2023 and 2024, the company deferred $140 million and $52 million of net regulatory liabilities, respectively. Net utility plant reconciliations Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 - $24,491 million Yr. 2 - $25,092 million Yr. 3 - $25,708 million AMI (h): Yr. 1 - $572 million Yr. 2 - $740 million Yr. 3 - $806 million In 2020, the company deferred $4.1 million as a regulatory asset. In 2021 and 2022, the company deferred $3.2 million and $1.8 million, as a regulatory liability, respectively. Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI) and Customer Service System (CSS) for Yr. 1: Yr. 1 - $27,847 million Yr. 2 - $29,884 million Yr. 3 - $31,026 million AMI (h): Yr. 1 - $744 million CSS: Yr. 1 - $11 million In 2023 and 2024, the company deferred $1.2 million and $(25.3) million as a regulatory asset and regulatory liability, respectively. Average rate base Yr. 1 - $21,660 million Yr. 2 - $22,783 million Yr. 3 - $23,926 million Yr. 1 - $26,095 million Yr. 2 - $27,925 million Yr. 3 - $29,362 million Weighted average cost of capital (after-tax) Yr. 1 to Yr. 3 – 6.61 percent Yr. 1 - 6.75 percent Yr. 2 - 6.79 percent Yr. 3 - 6.85 percent Authorized return on common equity 8.8 percent 9.25 percent Actual return on common equity (h) (i) Yr. 1 – 8.5 percent Yr. 2 – 8.03 percent Yr. 3 – 8.41 percent Yr. 1 – 9.46 percent Yr. 2 - 9.21 percent Earnings sharing Most earnings above an annual earnings threshold of 9.3 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2020, 2021 and 2022, the company had no earnings sharing above the threshold. A reserve of $4.3 million was recorded in 2021 related to a potential adjustment to the excess earnings sharing amount for 2016. Most earnings above an annual earnings threshold of 9.75 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2023 and 2024, the company had no earnings sharing above the threshold. Cost of long-term debt Yr. 1 to Yr. 3 – 4.63 percent Yr. 1 – 4.46 percent Yr. 2 – 4.54 percent Yr. 3 – 4.64 percent Common equity ratio 48 percent 48 percent (a) Base rates reflect recovery by the company of certain costs of its energy efficiency, demonstration projects, non-wire alternative projects (including the Brooklyn Queens demand management program), and off-peak electric vehicle charging programs (Yr. 1 - $206 million; Yr. 2 - $245 million; and Yr. 3 - $251 million) over a 10-year period, including the overall pre-tax rate of return on such costs. (b) Amounts reflect amortization of the 2018 tax savings under the federal Tax Cuts and Jobs Act of 2017 (TCJA) allocable to CECONY’s electric customers ($377 million) over a three-year period ($126 million annually), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s electric customers ($1,663 million) over the remaining lives of the related assets ($49 million in Yr. 1, $50 million in Yr. 2, and $53 million in Yr. 3) and the unprotected portion of the net regulatory liability ($784 million) over five years ($157 million annually). Amounts also reflect amortization of the regulatory asset for deferred MTA power reliability costs ($238 million) over a five-year period ($48 million annually). (c) The electric base rate increases shown above will be implemented with increases of $457 million in Yr. 1; $457 million in Yr. 2; and $457 million in Yr. 3 in order to levelize the customer bill impact. New rates were effective as of January 1, 2023 and CECONY began billing customers at the new levelized rate in August 2023. The shortfall in revenues due to the timing of billing to customers ($216 million) were collected through a surcharge billed through 2024, including a carrying charge on the outstanding balance. Base rates reflect recovery by the company of certain costs of its energy efficiency, demonstration projects, non-wire alternative projects (including the Brooklyn Queens demand management program), and off-peak electric vehicle charging programs (Yr. 1 - $244 million; Yr. 2 - $237 million; and Yr. 3 - $281 million) over periods varying between seven and fifteen years, including the overall pre-tax rate of return on such costs. (d) Deferrals for property taxes are limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a maximum number of basis points impact on return on common equity of 10.0 basis points, 7.5 basis points and 5.0 basis points for each of Yr. 1, Yr. 2 and Yr. 3, respectively, of the 2020 – 2022 rate plan and 10.0 basis points, 5.0 basis points and 5.0 basis points for each of Yr. 1, Yr. 2 and Yr. 3, respectively, of the 2023 – 2025 rate plan. (e) In general, if actual expenses for municipal infrastructure support (other than company labor) are below the amounts reflected in rates the company will defer the difference for credit to customers, and if the actual expenses are above the amount reflected in rates the company will defer for recovery from customers 80 percent of the difference subject to a maximum deferral, subject to certain conditions, of 15 percent of the amount reflected in the rate plans. (f) In addition, the NYSPSC continues its focused operations audit to investigate CECONY's financial accounting for income taxes. Any NYSPSC ordered adjustment to CECONY’s financial accounting for income taxes is expected to be refunded to or collected from customers, as determined by the NYSPSC. See "Other Regulatory Matters," below. (g) Reconciliation of net utility plant for AMI will be done on a combined basis for electric and gas. (h) Calculated in accordance with the earnings calculation method prescribed in the rate order. (i) In November 2021, the NYSPSC issued an order that allowed CECONY to recover $43 million of late payment charges and fees that were not billed for the year ended December 31, 2020. The recalculated return on equity for 2020 which reflects the recovery of these fees is 8.81 percent. (j) Amounts reflect amortization of the TCJA allocable to CECONY’s electric customers ($256 million) over a two-year period ($128 million in Yr. 1 and Yr. 2), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s electric customers ($1,512 million) over the remaining lives of the related assets ($34 million in Yr. 1, $63 million in Yr. 2, and $34 million in Yr. 3) and the unprotected portion of the net regulatory liability ($306 million) over two years ($153 million annually). Amounts also reflect amortization of the regulatory asset for deferred MTA power reliability costs ($93 million) over a three-year period ($31 million annually). In April 2023, the NYSPSC approved CECONY’s December 2022 petition seeking cost recovery approval for a proposed clean energy hub in Brooklyn, New York (Brooklyn Clean Energy Hub). The Brooklyn Clean Energy Hub primarily addresses an identified reliability need in 2028 due to a forecasted increase in electric demand. Construction began in September 2023 and is expected to be completed by 2028. CECONY’s January 2025 electric rate case filing reflected the costs for the Brooklyn Clean Energy Hub in base rates. In January 2024, the NYSPSC approved CECONY's August 2023 petition requesting authorization and cost recovery to construct two new substations in Jamaica, Queens (Idlewild Project) that is in addition to the capital expenditures approved in CECONY's 2023 - 2025 electric rate plan summarized above. The project is expected to be completed by May 2028 to meet anticipated reliability needs and to support New York State’s Climate Leadership and Community Protection Act goals. CECONY estimates that construction will cost $1,200 million. CECONY's January 2025 electric rate case filing reflected the costs for the Idlewild Project in base rates. In January 2025, CECONY filed a request with the NYSPSC for an electric rate increase of $1,612 million, effective January 1, 2026. The filing reflects a return on common equity of 10.1 percent and a common equity ratio of 48 percent. The company is requesting provisions pursuant to which expenses for pension and other post-retirement benefits, long-term debt, storm restoration, property taxes, municipal infrastructure support, the impact of new laws, late payment charges, and environmental site investigation and remediation are reconciled to amounts reflected in rates. In addition, the company is proposing a continued reconciliation and current recovery or surcharge mechanism of uncollectible write-offs to the level in rates. The company is proposing the continuation of earnings opportunities from Earnings Adjustment Mechanisms for meeting energy efficiency goals. The filing also reflects continuation of the revenue decoupling mechanism and the provisions pursuant to which the company recovers its purchased power and fuel costs from customers. The filing includes supplemental information regarding electric rate plans for 2027 and 2028, which the company is not requesting, but would consider through settlement discussions. For purposes of illustration, rate increases of $932 million and $880 million effective January 2027 and 2028, respectively, were calculated based upon an assumed return on common equity of 10.1 percent and a common equity ratio of 48 percent. CECONY – Gas Effective period January 2020 – December 2022 January 2023 – December 2025 Base rate changes Yr. 1 – $84 million (a) Yr. 2 – $122 million (a) Yr. 3 – $167 million (a) Yr. 1 – $217 million (c) Yr. 2 – $173 million (c) Yr. 3 – $122 million (c) Amortizations to income of net Yr. 1 – $45 million (b) Yr. 2 – $43 million (b) Yr. 3 – $10 million (b) Yr. 1 – $31 million (j) Yr. 2 – $24 million (j) Yr. 3 – $(11) million (j) Other revenue sources Retention of annual revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. Potential incentives if performance targets related to gas leak backlog, leak prone pipe and service terminations are met: Yr. 1 – $20 million Yr. 2 – $22 million Yr. 3 – $25 million In 2020, 2021 and 2022, the company recorded $3 million, $26 million and $8 million of earnings adjustment mechanism incentives for energy efficiency, respectively. In 2020, 2021 and 2022, the company recorded positive incentives of $13 million, $7 million, and $9 million respectively. In 2021, the company reversed $6 million of positive incentives recorded in 2020 pursuant to an order issued by the NYSPSC in December 2021. Retention of annual revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. Potential earnings adjusted mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $18 million Yr. 2 - $20 million Yr. 3 - $21 million In 2023 and 2024, the company recorded $5 million and $7 million of earnings adjustment mechanism incentives for energy efficiency, respectively. In 2023 and 2024, the company recorded positive incentives of $3 million each year, respectively. Revenue decoupling mechanisms Continuation of reconciliation of actual to authorized gas delivery revenues, modified to be calculated based upon revenue per customer class instead of revenue per customer. In 2020, 2021 and 2022, the company deferred for recovery from customers $27 million, $100 million and $141 million of revenues, respectively. Continuation of reconciliation of actual to authorized gas delivery revenues, modified to be calculated based upon revenue per customer class instead of revenue per customer. In 2023 and 2024, the company deferred for recovery from customers $162 million and $93 million of revenues, respectively. Recoverable energy costs Continuation of current rate recovery of purchased gas costs. Continuation of current rate recovery of purchased gas costs. Negative revenue adjustments Potential charges if performance targets relating to service, safety and other matters are not met: Yr. 1 – $81 million Yr. 2 – $88 million Yr. 3 – $96 million In 2020 and 2021, the company did not record any negative revenue adjustments. In 2022, the company recorded negative revenue adjustments of $8 million. Potential charges if performance targets relating to service, safety and other matters are not met: Yr. 1 - $107 million Yr. 2 - $119 million Yr. 3 - $130 million In 2023 and 2024, the company recorded negative revenue adjustments of $3 million and $2 million, respectively. Regulatory reconciliations Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes (d), municipal infrastructure support costs (e), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (f). In 2020 and 2021, the company deferred $91 million and $14 million of net regulatory assets, respectively. In 2022, the company deferred $70 million of net regulatory liabilities. Reconciliation of late payment charges (i) and expenses for uncollectibles, pension and other postretirement benefits, variable-rate debt, major storms, property taxes (d), municipal infrastructure support costs (e), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (f). In 2023 and 2024, the company deferred $12 million and $29 million of net regulatory liabilities, respectively. Net utility plant reconciliations Target levels reflected in rates: Gas average net plant target excluding AMI: Yr. 1 – $8,108 million Yr. 2 – $8,808 million Yr. 3 – $9,510 million AMI (g): Yr. 1 – $142 million Yr. 2 – $183 million Yr. 3 – $211 million In 2020 and 2021, the company deferred $24.7 million and $26 million, as a regulatory liability, respectively. In 2022, the company deferred $10.8 million as a regulatory asset. Target levels reflected in rates: Gas average net plant target excluding AMI and CSS for Yr. 1: Yr. 1 - $10,466 million Yr. 2 - $11,442 million Yr. 3 - $12,142 million AMI (g): Yr. 1 - $234 million CSS: Yr. 1 - $2 million In 2023 and 2024, the company deferred $15.5 million and $31.5 million as regulatory liabilities, respectively. Average rate base Yr. 1 – $7,171 million Yr. 2 – $7,911 million Yr. 3 – $8,622 million Yr. 1 - $9,647 million Yr. 2 - $10,428 million Yr. 3 - $11,063 million Weighted average cost of capital Yr. 1 – Yr. 3 - 6.61 percent Yr. 1 – 6.75 percent Yr. 2 – 6.79 percent Yr. 3 – 6.85 percent Authorized return on common equity 8.8 percent 9.25 percent Actual return on common equity (h) (i) Yr. 1 – 8.4 percent Yr. 2 – 8.48 percent Yr. 3 – 8.93 percent Yr. 1 – 9.00 percent Yr. 2 - 9.82 percent Earnings sharing Most earnings above an annual earnings threshold of 9.3 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2020, 2021 and 2022, the company had no earnings above the threshold. Most earnings above an annual earnings threshold of 9.75 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2023, the company had no earnings above the threshold. In 2024, the company had $4.3 million above the threshold. Cost of long-term debt Yr. 1 – Yr. 3 - 4.63 percent Yr. 1 – 4.46 percent Yr. 2 – 4.54 percent Yr. 3 – 4.64 percent Common equity ratio 48 percent 48 percent (a) The gas base rate increases shown above will be implemented with increases of $47 million in Yr. 1; $176 million in Yr. 2; and $170 million in Yr. 3 in order to levelize customer bill impacts. Base rates reflect recovery by the company of certain costs of its energy efficiency program (Yr. 1 - $30 million; Yr. 2 - $37 million; and Yr. 3 - $40 million) over a ten-year period, including the overall pre-tax rate of return on such costs. (b) Amounts reflect amortization of t he remaining 2018 TCJA tax savings allocable to CECONY’s gas customers ($63 million) over a two year period ($32 million annually), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s gas customers ($725 million) over the remaining lives of the related assets ($14 million in Yr. 1, $14 million in Yr. 2, and $12 million in Yr. 3) and the unprotected portion of the net regulatory liability ($107 million) over five years ($21 million annually) (c) The gas base rate increases shown above will be implemented with increases of $187 million in Yr. 1; $187 million in Yr. 2; and $187 million in Yr. 3 in order to levelize the customer bill impact. New rates were effective as of January 1, 2023. CECONY began billing customers at the new levelized rate in August 2023. The shortfall in revenues due to the timing of billing to customers ($99 million) are being collected through a surcharge billed through 2025, including a carrying charge on the outstanding balance. Base rates reflect recovery by the company of certain costs of its energy efficiency programs (Yr. 1 - $45 million; Yr. 2 - $78 million; and Yr. 3 - $62 million) over a fifteen-year period, including the overall pre-tax rate of return on such costs. (d)-(h) See footnotes (d) - (h) to the table under “CECONY Electric,” above. (i) In November 2021, the NYSPSC issued an order that allowed CECONY to recover $7 million of late payment charges and fees that were not billed for the year ended December 31, 2020. The recalculated return on equity for 2020 which reflects the recovery of these fees is 8.56 percent. (j) Amounts reflect amortization of the TCJA allocable to CECONY’s gas customers ($32 million) over a two-year period ($16 million in Yr. 1 and Yr. 2), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s gas customers ($679 million) over the remaining lives of the related assets ($9 million in Yr. 1, $10 million in Yr. 2, and $10 million in Yr. 3) and the unprotected portion of the net regulatory liability ($42 million) over two years ($21 million annually). In January 2025, CECONY filed a request with the NYSPSC for a gas rate increase of $441 million, effective January 1, 2026. The filing reflects a return on common equity of 10.1 percent and a common equity ratio of 48 percent. The company is requesting provisions pursuant to which expenses for pension and other post-retirement benefits, long-term debt, storm restoration, property taxes, municipal infrastructure support, the impact of new laws, late payment charges, and environmental site investigation and remediation are reconciled to amounts reflected in rates. In addition, the company is proposing a continued reconciliation and current recovery or surcharge mechanism of uncollectible write-offs to the level in rates. The company is proposing the continuation of earnings opportunities from Earnings Adjustment Mechanisms for meeting energy efficiency goals. The filing also reflects continuation of the revenue decoupling mechanism and the provisions pursuant to which the company recovers its purchased gas costs from customers. The filing includes supplemental information regarding gas rate plans for 2027 and 2028, which the company is not requesting, but would consider through settlement discussions. For purposes of illustration, rate increases of $266 million and $166 million effective January 2027 and 2028, respectively, were calculated based upon an assumed return on common equity of 10.1 percent and a common equity ratio of 48 percent. CECONY – Steam Effective period January 2014 – December 2016 (g) November 2023 – October 2026 Base rate changes Yr. 1 – $(22.4) million (h) Yr. 2 –$19.8 million (h) Yr. 3 –$20.3 million(h) Yr. 4 – None Yr. 5 – None Yr. 6 – None Yr. 7 – None Yr. 8 – None Yr. 9 – None Yr.10 – None Yr. 1 – $110 million (a) Yr. 2 – $44 million (a) Yr. 3 – $45 million (a) Amortizations to income of net $37 million over three years Yr. 1 – $15 million (b) Yr. 2 – $3 million (b) Yr. 3 – $3 million (b) Weather Normalization Adjustment Implementation of a weather normalization adjustment to reflect normal weather conditions during the heating season. Recoverable energy costs Current rate recovery of purchased power and fuel costs. Continuation of current rate recovery of purchased power and fuel costs. Negative revenue adjustments Potential charges (up to $1 million annually) if certain performance targets are not met. The company did not record any negative revenue adjustments under this rate plan. Potential charges if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 - $3.7 million Yr. 2 - $3.8 million Yr. 3 - $3.8 million In Yr. 1, the company did not record any negative revenue adjustments. Regulatory reconciliations (i) (j) In 2014, 2015, 2016, 2017, 2018, 2019, 2020, 2021, 2022 and 2023, the company deferred $42 million of net regulatory liabilities, $17 million of net regulatory assets, $8 million and $14 million of net regulatory liabilities, $1 million of net regulatory assets, $8 million of net regulatory liabilities, $35 million of net regulatory assets, $32 million of net regulatory assets, $11 million of net regulatory assets and $18 million net regulatory liabilities, respectively. Reconciliation of uncollectible expenses and late payment charges (c) and expenses for pension and other postretirement benefits, variable-rate debt, property taxes (d), municipal infrastructure support costs (e), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates. (f) In Yr. 1, the company deferred $7 million of net regulatory assets. Net utility plant reconciliations Target levels reflected in rates were: Production: Yr. 1 – $1,752 million Yr. 2 – $1,732 million Yr. 3 – $1,720 million Distribution: Yr. 1 – $6 million Yr. 2 – $11 million Yr. 3 – $25 million The company reduced its regulatory liability by $0.1 in 2014 and immaterial amounts in 2015 and 2016 and no deferrals were recorded in 2017, 2018, 2019. In 2020 and 2021, the company deferred $2 million and $1 million as a regulatory liability, respectively. In 2022, the company deferred $0.1 million as a regulatory asset. No deferral was recorded in 2023. Yr. 1 - $2,025 million Yr. 2 - $2,029 million Yr. 3 - $2,015 million In Yr. 1, the company deferred $2.4 million as a regulatory liability. Average rate base Yr. 1 – $1,511 million Yr. 2 – $1,547 million Yr. 3 – $1,604 million Yr. 1 - $1,799 million Yr. 2 - $1,848 million Yr. 3 - $1,882 million Weighted average cost of capital (after-tax) Yr. 1 – 7.10 percent Yr. 2 – 7.13 percent Yr. 3 – 7.21 percent Yr. 1 - 6.78 percent Yr. 2 - 6.81 percent Yr. 3 - 6.83 percent Authorized return on common equity 9.3 percent 9.25 percent Actual return on common equity (j) Yr. 1 – 9.82 percent Yr. 2 – 10.88 percent Yr. 3 – 10.54 percent Yr. 4 – 9.51 percent Yr. 5 – 11.73 percent Yr. 6 – 10.45 percent Yr. 7 – 7.91 percent Yr. 8 – 5.99 percent Yr. 9 - 5.72 percent Yr. 10 - (0.10) percent . Yr. 1 – 6.55 percent Earnings sharing Weather normalized earnings above an annual earnings threshold of 9.9 percent are to be applied to reduce regulatory assets for environmental remediation and other costs. In 2014, the company had no earnings above the threshold. Actual earnings were $11.5 million and $7.8 million above the threshold in 2015 and 2016, respectively. In 2017, actual earnings were $8.5 million above the threshold, offset in part by a positive adjustment related to 2016 of $4 million. In 2018, actual earnings were $16.5 million above the threshold, and an additional $1.1 million related to 2017 was recorded. In 2019 actual earnings were $5 million above the threshold, offset in part by an adjustment related to 2018 of $2.3 million. In 2020, 2021, 2022 and 2023, the company had no earnings sharing above the threshold. Reserve adjustments of $0.4 million and $0.2 million were recorded in 2021 related to potential adjustment to the excess earnings sharing amounts for 2016 and 2018, respectively. Most earnings above an annual earnings threshold of 9.75 percent are to be applied

Leases

Leases	12 Months Ended
Leases	Dec. 31, 2024
Leases [Abstract]
Leases	Leases The Companies lease land, office buildings, equipment and access rights to support electric transmission facilities. The Companies recognize lease right-of-use assets and lease liabilities on their consolidated balance sheets for virtually all of their leases (other than leases that meet the definition of a short-term lease, the expense for which was immaterial). A lease right-of-use asset represents a right to use an identifiable underlying asset and obtain substantially all of the economic benefits from the use of that asset for the lease term. A lease liability represents an obligation to make lease payments arising from the lease. Leases are classified as either operating leases or finance leases. Operating leases of the Utilities are included in operating lease right-of-use asset and operating lease liabilities on the Companies’ consolidated balance sheets. Finance leases are included in other noncurrent assets, other current liabilities and other noncurrent liabilities. The Utilities, as regulated entities, are permitted to continue to recognize expense for operating leases using the timing that conforms to the regulatory rate treatment as rental payments are recovered from our customers and to account the same way for finance leases. For new operating leases, the Companies recognize operating lease right-of-use assets and operating lease liabilities based on the present value of the future minimum lease payments over the lease term at commencement date. As most of the Companies’ leases do not provide an implicit rate, the Companies used their collateralized incremental borrowing rate based on the information available at the commencement date to determine the present value of future payments. Most of the Companies’ leases have remaining lease terms of one year to 20 years and may include options to renew or extend the leases for up to five years at the fair rental value. The Companies' lease terms include options to renew, extend or terminate the lease when it is reasonably certain that the Companies will exercise that option. There were no leases with material variable lease payments or residual value guarantees. The Companies account for lease and non-lease components as a single lease component. Operating lease cost and cash paid for amounts included in the measurement of lease liabilities for the years ended December 31, 2024, 2023, and 2022 were as follows: Con Edison (a) CECONY (Millions of Dollars) 2024 2023 2022 2024 2023 2022 Operating lease cost $67 $70 $88 $66 $66 $67 Operating lease cash flows $67 $68 $83 $66 $65 $64 (a) Amounts for Con Edison include amounts for the Clean Energy Businesses through February 2023. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W and Note X. As of December 31, 2024 , 2023, and 2022, assets recorded as finance leases for Con Edison were $3 million, $2 million and $2 million, r espectively. The accumulated amortization associated with such finance leases were $2 million, $2 million, and $5 million, respectively. As of December 31, 2024, 2023, and 2022, assets recorded as finance leases for CECONY were $3 million, $1 million and $1 million, respectively. Accumulated amortization associated with such finance leases were $2 million for each year. For the years ended December 31, 2024, 2023, and 2022, finance lease costs and cash flows for Con Edison and CECONY were immaterial. Right-of-use assets obtained in exchange for lease obligations for Con Edison and CECO NY were $3 million for the year ended December 31, 2024 and $11 million for the year ended December 31, 2023. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W and Not e X. Other information related to leases for Con Edison and CECONY at December 31, 2024 and 2023 was as follows: Con Edison CECONY 2024 2023 2024 2023 Weighted Average Remaining Lease Term: Operating leases, (a) (b) 10.8 years 11.4 years 10.6 years 11.4 years Finance leases 6 years 6.6 years 5 years 2.7 years Weighted Average Discount Rate: Operating leases, (a) (b) 3.8% 3.7% 3.8% 3.7% Finance leases 2.0% 3.0% 1.6% 3.1% (a) Amounts for Con Edison in 2023 exclude operating leases of the Clean Energy Businesses, inclusive of Broken Bow II, that were classified as held for sale as of December 31, 2023. Including the operating leases of the Clean Energy Businesses would result in a weighted average remaining lease term of 11.6 years and a weighted average discount rate of 3.8 percent as of December 31, 2023. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W and Note X. (b) Amounts for Con Ediso n in 2024 exclude the operating lease of Broken Bow II, that was classified as held for sale as of December 31, 2024 and was sold and transferred in January 2025. Including the operating lease of Broken Bow II would result in a weighted average remaining lease term of 10.8 years and a weighted average discount rate of 3.8 percent as of December 31, 2024. See Note W and Note X. Future minimum lease payments under non-cancellable leases at December 31, 2024 were as follows: (Millions of Dollars) Con Edison CECONY Year Ending December 31, (b) Operating Leases Finance Leases Operating Leases Finance Leases 2025 $68 $1 $67 $1 2026 67 1 67 1 2027 66 1 66 1 2028 61 — 61 — 2029 61 — 61 — All years thereafter 307 1 307 — Total future minimum lease payments $630 $4 $629 $3 Less: imputed interest (126) — (125) — Total $504 $4 $504 $3 Reported as of December 31, 2024 Operating lease liabilities (current) (a) $118 $— $118 $— Operating lease liabilities held for sale (current) 2 — — — Operating lease liabilities (noncurrent) (a) 386 — 386 — Operating lease liabilities held for sale (noncurrent) 5 — — — Other current liabilities — 1 — 1 Other noncurrent liabilities — 3 — 2 Total $511 $4 $504 $3 (a) Amounts exclude operating lease liabilities of Broken Bow II ($7 million) that are classified as current and noncurrent liabilities held for sale on Con Edison's consolidated balance sheet as of December 31, 2024. See Note X. Broken Bow II was sold and transferred in January 2025. (b) Amounts exclude operating lease future minimum lease payments of Broken Bow II, of $4 million in total for years ended December 31, 2025 through 2029, and $9 million for all years thereafter, and imputed interest of $6 million. Broken Bow II was sold and transferred in January 2025. As of December 31, 2024, CECONY has lease agreements for clean energy facilities that have not yet commenced operation. These clean energy facility leases have lease terms of 15 years and are expected to commence operation within two years, for which the total present value is $262 million. There were no material lease terminations for the year ended December 31, 2024.
Leases	Leases The Companies lease land, office buildings, equipment and access rights to support electric transmission facilities. The Companies recognize lease right-of-use assets and lease liabilities on their consolidated balance sheets for virtually all of their leases (other than leases that meet the definition of a short-term lease, the expense for which was immaterial). A lease right-of-use asset represents a right to use an identifiable underlying asset and obtain substantially all of the economic benefits from the use of that asset for the lease term. A lease liability represents an obligation to make lease payments arising from the lease. Leases are classified as either operating leases or finance leases. Operating leases of the Utilities are included in operating lease right-of-use asset and operating lease liabilities on the Companies’ consolidated balance sheets. Finance leases are included in other noncurrent assets, other current liabilities and other noncurrent liabilities. The Utilities, as regulated entities, are permitted to continue to recognize expense for operating leases using the timing that conforms to the regulatory rate treatment as rental payments are recovered from our customers and to account the same way for finance leases. For new operating leases, the Companies recognize operating lease right-of-use assets and operating lease liabilities based on the present value of the future minimum lease payments over the lease term at commencement date. As most of the Companies’ leases do not provide an implicit rate, the Companies used their collateralized incremental borrowing rate based on the information available at the commencement date to determine the present value of future payments. Most of the Companies’ leases have remaining lease terms of one year to 20 years and may include options to renew or extend the leases for up to five years at the fair rental value. The Companies' lease terms include options to renew, extend or terminate the lease when it is reasonably certain that the Companies will exercise that option. There were no leases with material variable lease payments or residual value guarantees. The Companies account for lease and non-lease components as a single lease component. Operating lease cost and cash paid for amounts included in the measurement of lease liabilities for the years ended December 31, 2024, 2023, and 2022 were as follows: Con Edison (a) CECONY (Millions of Dollars) 2024 2023 2022 2024 2023 2022 Operating lease cost $67 $70 $88 $66 $66 $67 Operating lease cash flows $67 $68 $83 $66 $65 $64 (a) Amounts for Con Edison include amounts for the Clean Energy Businesses through February 2023. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W and Note X. As of December 31, 2024 , 2023, and 2022, assets recorded as finance leases for Con Edison were $3 million, $2 million and $2 million, r espectively. The accumulated amortization associated with such finance leases were $2 million, $2 million, and $5 million, respectively. As of December 31, 2024, 2023, and 2022, assets recorded as finance leases for CECONY were $3 million, $1 million and $1 million, respectively. Accumulated amortization associated with such finance leases were $2 million for each year. For the years ended December 31, 2024, 2023, and 2022, finance lease costs and cash flows for Con Edison and CECONY were immaterial. Right-of-use assets obtained in exchange for lease obligations for Con Edison and CECO NY were $3 million for the year ended December 31, 2024 and $11 million for the year ended December 31, 2023. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W and Not e X. Other information related to leases for Con Edison and CECONY at December 31, 2024 and 2023 was as follows: Con Edison CECONY 2024 2023 2024 2023 Weighted Average Remaining Lease Term: Operating leases, (a) (b) 10.8 years 11.4 years 10.6 years 11.4 years Finance leases 6 years 6.6 years 5 years 2.7 years Weighted Average Discount Rate: Operating leases, (a) (b) 3.8% 3.7% 3.8% 3.7% Finance leases 2.0% 3.0% 1.6% 3.1% (a) Amounts for Con Edison in 2023 exclude operating leases of the Clean Energy Businesses, inclusive of Broken Bow II, that were classified as held for sale as of December 31, 2023. Including the operating leases of the Clean Energy Businesses would result in a weighted average remaining lease term of 11.6 years and a weighted average discount rate of 3.8 percent as of December 31, 2023. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W and Note X. (b) Amounts for Con Ediso n in 2024 exclude the operating lease of Broken Bow II, that was classified as held for sale as of December 31, 2024 and was sold and transferred in January 2025. Including the operating lease of Broken Bow II would result in a weighted average remaining lease term of 10.8 years and a weighted average discount rate of 3.8 percent as of December 31, 2024. See Note W and Note X. Future minimum lease payments under non-cancellable leases at December 31, 2024 were as follows: (Millions of Dollars) Con Edison CECONY Year Ending December 31, (b) Operating Leases Finance Leases Operating Leases Finance Leases 2025 $68 $1 $67 $1 2026 67 1 67 1 2027 66 1 66 1 2028 61 — 61 — 2029 61 — 61 — All years thereafter 307 1 307 — Total future minimum lease payments $630 $4 $629 $3 Less: imputed interest (126) — (125) — Total $504 $4 $504 $3 Reported as of December 31, 2024 Operating lease liabilities (current) (a) $118 $— $118 $— Operating lease liabilities held for sale (current) 2 — — — Operating lease liabilities (noncurrent) (a) 386 — 386 — Operating lease liabilities held for sale (noncurrent) 5 — — — Other current liabilities — 1 — 1 Other noncurrent liabilities — 3 — 2 Total $511 $4 $504 $3 (a) Amounts exclude operating lease liabilities of Broken Bow II ($7 million) that are classified as current and noncurrent liabilities held for sale on Con Edison's consolidated balance sheet as of December 31, 2024. See Note X. Broken Bow II was sold and transferred in January 2025. (b) Amounts exclude operating lease future minimum lease payments of Broken Bow II, of $4 million in total for years ended December 31, 2025 through 2029, and $9 million for all years thereafter, and imputed interest of $6 million. Broken Bow II was sold and transferred in January 2025. As of December 31, 2024, CECONY has lease agreements for clean energy facilities that have not yet commenced operation. These clean energy facility leases have lease terms of 15 years and are expected to commence operation within two years, for which the total present value is $262 million. There were no material lease terminations for the year ended December 31, 2024.

Goodwill

Goodwill	12 Months Ended
Goodwill	Dec. 31, 2024
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill	Goodwill The Companies test goodwill for impairment at least annually or whenever there is a triggering event. There is an option to first make a qualitative assessment of whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount before applying a quantitative goodwill impairment test. The quantitative goodwill impairment test compares the estimated fair value of a reporting unit with its carrying value, including goodwill. If the estimated fair value of a reporting unit exceeds its carrying value, goodwill of the reporting unit is considered not impaired. If the carrying value exceeds the estimated fair value of the reporting unit, an impairment loss shall be recognized in an amount equal to that excess, limited to the total amount of goodwill allocated to that reporting unit. Substantially all of Con Edison's goodwill relates to the O&R merger. In 2024 and 2023, Con Edison completed qualitative and quantitative impairment tests, respectively, for its goodwill of $406 million related to the O&R merger and determined that the fair value of the reporting units significantly exceeded their carrying value, and accordingly the goodwill was not impaired. For the impairment test, $245 million and $161 million of goodwill were allocated to CECONY and O&R, respectively. Con Edison used a weighted combination of a discounted cash flow analysis and a market multiples analysis in its quantitative impairment test. No impairments or triggering events were identified for Con Edison's goodwill for the years ending December 31, 2024, 2023 or 2022.

Income Tax

Income Tax	12 Months Ended
Income Tax	Dec. 31, 2024
Income Tax Disclosure [Abstract]
Income Tax	Income Tax The components of income tax are as follows: Con Edison CECONY (Millions of Dollars) 2024 2023 2022 2024 2023 2022 State Current $(81) $179 $5 $(87) $(102) $— Deferred 223 6 324 219 246 110 Federal Current (17) 176 58 (63) (95) 170 Deferred 198 237 117 246 311 (23) Amortization of investment tax credits (5) (111) (6) (1) (2) (2) Total income tax expense $318 $487 $498 $314 $358 $255 Reconciliation of the difference between income tax expense and the amount computed by applying the prevailing statutory income tax rate to income before income taxes is as follows: Con Edison CECONY (% of Pre-tax income) 2024 2023 2022 2024 2023 2022 STATUTORY TAX RATE Federal 21 % 21 % 21 % 21 % 21 % 21 % Changes in computed taxes resulting from: State income taxes, net of federal income taxes 5 5 6 5 5 5 Cost of removal 1 1 1 1 2 1 Allowance for uncollectible accounts, net of COVID-19 assistance (1) — — (1) (1) — Amortization of excess deferred federal income taxes (10) (6) (9) (10) (8) (10) Other (1) — (1) (1) (1) (1) Impacts from the sale of the Clean Energy Businesses: Changes in state apportionments, net of federal income taxes — (1) 6 — — — Deferred unamortized ITC recognized on sale of subsidiary — (4) — — — — Effective tax rate 15 % 16 % 24 % 15 % 18 % 16 % The tax effects of temporary differences, which gave rise to deferred tax assets and liabilities, are as follows: Con Edison CECONY (Millions of Dollars) 2024 2023 2024 2023 Deferred tax liabilities: Property basis differences $9,222 $8,542 $8,632 $8,001 Regulatory Assets: Energy efficiency and other clean energy programs 464 351 449 344 Environmental remediation costs 291 310 267 287 Legacy meters 116 4 112 — Other regulatory assets 571 574 510 525 Pensions and retiree benefits – asset 1,063 918 1,037 894 Operating lease right-of-use asset 143 154 142 153 Total deferred tax liabilities $11,870 $10,853 $11,149 $10,204 Deferred tax assets: Regulatory liabilities: Unrecognized pension and other postretirement costs 296 265 276 244 Future income tax 343 427 312 394 Other regulatory liabilities 909 844 809 744 Tax credits carryforward 346 270 — — Superfund and other environmental costs 291 314 265 288 Pensions and retiree benefits – liability 154 167 142 153 Corporate alternative minimum tax credit carryforward 139 — 111 — Operating lease liabilities 143 154 142 153 Asset retirement obligations 127 146 127 146 Equity investments 80 98 — — Loss carryforwards 42 7 16 — Valuation allowance (12) (7) — — Other 160 125 140 109 Total deferred tax assets $3,018 $2,810 $2,340 $2,231 Net deferred tax liabilities $8,852 $8,043 $8,809 $7,973 Unamortized investment tax credits 22 26 10 11 Net deferred tax liabilities and unamortized investment tax credits $8,874 $8,069 $8,819 $7,984 At December 31, 2024, Con Edison has $346 million in general business tax credit carryovers (primarily renewable energy tax credits). If unused, these general business tax credit carryovers will begin to expire in 2038. A deferred tax asset for these tax attribute carryforwards was recorded, and no valuation allowance was provided, as it is more likely than not that the deferred tax asset will be realized. At December 31, 2024, Con Edison has a deferred tax asset on its New York state net operating loss carryforward of $36 million that will begin to expire, if unused, in 2040. No valuation allowance was provided, as it is more likely than not that the deferred tax asset will be realized. At December 31, 2024, Con Edison has a deferred tax asset on its New York City net operating loss carryforward of $14 million that will begin to expire, if unused, in 2035. Con Edison increased its valuation allowance by $6 million ($5 million, net of federal tax) resulting in a full valuation allowance against this deferred tax asset as it is not more likely than not that the deferred tax assets will be realized. In April 2023, the IRS released Revenue Procedure 2023-15, which provides a safe harbor method of accounting that taxpayers may use to determine whether certain expenditures to maintain, repair, replace, or improve natural gas transmission and distribution property must be capitalized as improvements by the taxpayer or deducted for federal income tax purposes in the current tax year. This revenue procedure also provides procedures for taxpayers to obtain automatic consent to change their method of accounting to the safe harbor method of accounting. Con Edison adopted the safe harbor rules on its 2023 federal and state returns and recorded a reduction in its current tax payable and an increase in accumulated deferred tax liabilities of $457 million, $418 million of which is for CECONY and $39 million of which is for O&R, to reflect the cumulative impact of this change in accounting method for the Utilities. Corporate Alternative Minimum Tax On August 16, 2022, the Inflation Reduction Act (IRA) was signed into law and implemented a new corporate alternative minimum tax (CAMT) that imposes a 15 percent tax on modified GAAP net income. Pursuant to the IRA, corporations are entitled to a tax credit (minimum tax credit) to the extent the CAMT liability exceeds the regular tax liability. This amount can be carried forward indefinitely and used in future years when regular tax liability exceeds the CAMT liability. Beginning in 2024, based on the existing statute, the Companies are subject to and report the CAMT in their Consolidated Income Statements, Consolidated Statements of Cash Flows and the Consolidated Balance Sheets. The Companies accrued a CAMT liability of $139 million ($111 million of which is for CECONY) before the application of general business credits, with an offsetting deferred tax asset representing the minimum tax credit carryforward, for the year ended December 31, 2024. The deferred tax asset related to the minimum tax credit carryforward will be realized to the extent the Companies’ consolidated deferred tax liabilities exceed the minimum tax credit carryforward. The Companies’ deferred tax liabilities are expected to exceed the minimum tax credit carryforward for the foreseeable future and thus no valuation allowance is required. The Companies are continuing to assess the impacts of the IRA on their financial statements and will update estimates based on future guidance to be issued by the Department of the Treasury. Uncertain Tax Positions Under the accounting rules for income taxes, the Companies are not permitted to recognize the tax benefit attributable to a tax position unless such position is more likely than not to be sustained upon examination by taxing authorities, including resolution of any related appeals and litigation processes, based solely on the technical merits of the position. A reconciliation of the beginning and ending amounts of unrecognized tax benefits for Con Edison and CECONY follows: Con Edison CECONY (Millions of Dollars) 2024 2023 2022 2024 2023 2022 Balance at January 1, $11 $23 $17 $7 $8 $5 Additions based on tax positions related to the current year 4 8 3 4 4 2 Additions based on tax positions of prior years — 3 6 — 1 1 Reductions for tax positions of prior years (6) (11) (1) (6) (6) — Settlements — (12) (2) — — — Balance at December 31, $9 $11 $23 $5 $7 $8 At December 31, 2024, the estimated uncertain tax positions for Con Edison was $9 million ($5 million for CECONY). For the year ended December 31, 2024, Con Edison recognized $4 million of income tax expense related to current year positions and recognized a tax benefit of $3 million related to positions in prior years, both of which were attributed to CECONY. In the fourth quarter of 2024, Con Edison concluded its federal tax examination for its 2022 tax return with no changes and reversed $3 million in uncertain tax positions related to 2022 that reduced its effective tax rate. Con Edison and CECONY reasonably expects to resolve within the next twelve months approximately $1 million of various federal uncertainties due to the expected completion of ongoing tax examinations, of which the entire amount, if recognized, would reduce the Companies’ effective tax rates. The total amount of unrecognized tax benefits, if recognized, that would reduce Con Edison’s effective tax rate is $9 million ($8 million, net of federal taxes) with $5 million attributable to CECONY. The Companies recognize interest on liabilities for uncertain tax positions in interest expense and would recognize penalties, if any, in operating expenses in the Companies’ consolidated income statements. In 2024, 2023 and 2022, the Companies recognized an immaterial amount of interest expense and no penalties for uncertain tax positions in their consolidated income statements. At December 31, 2024 and December 31, 2023, the Companies recognized an immaterial amount of accrued interest on their consolidated balance sheets. In February 2024, New York State completed its examination of the Companies' New York State income and franchise tax returns for tax years 2015 through 2021 with no changes. Con Edison’s federal tax return for 2023 remains under examination. State and local tax returns remain open for examination in New York State for tax years 2022 and 2023, in New Jersey for tax years 2020 through 2023 and in New York City for tax years 2021 through 2023.

Revenue Recognition

Revenue Recognition	12 Months Ended
Revenue Recognition	Dec. 31, 2024
Revenue from Contract with Customer [Abstract]
Revenue Recognition	Revenue Recognition The following table presents, for the years ended December 31, 2024, 2023 and 2022, revenue from contracts with customers as defined in ASC Topic 606, "Revenue from Contracts with Customers," as well as additional revenue from sources other than contracts with customers, disaggregated by major source. 2024 2023 2022 (Millions of Dollars) Revenues from contracts with customers Other revenues (a) Total operating revenues Revenues from contracts with customers Other revenues (a) Total operating revenues Revenues from contracts with customers Other revenues (a) Total operating revenues CECONY Electric $10,868 $(151) $10,717 $9,946 $132 $10,078 $9,917 $(166) $9,751 Gas 2,890 (56) 2,834 2,867 (38) 2,829 2,875 49 2,924 Steam 592 (14) 578 551 18 569 584 9 593 Total CECONY $14,350 ($221) $14,129 $13,364 $112 $13,476 $13,376 $(108) $13,268 O&R Electric 865 (13) 852 740 19 759 771 2 773 Gas 250 23 273 286 11 297 306 6 312 Total O&R $1,115 $10 $1,125 $1,026 $30 $1,056 $1,077 $8 $1,085 Clean Energy Businesses (c) Renewables — — — 68 — 68 637 — 637 Energy services — — — 7 — 7 317 — 317 Develop/Transfer Projects — — — 7 — 7 44 — 44 Other — — — — 47 47 — 321 321 Total Clean Energy Businesses $— $— $— $82 $47 $129 $998 $321 $1,319 Con Edison Transmission 4 — 4 4 — 4 4 — 4 Other (b) — (2) (2) — (2) (2) — (6) (6) Total Con Edison $15,469 $(213) $15,256 $14,476 $187 $14,663 $15,455 $215 $15,670 (a) For the Utilities, this includes primarily revenue from alternative revenue programs, such as the revenue decoupling mechanisms under their New York electric and gas rate plans, and negative revenue adjustments. (b) Other includes the parent company, Con Edison's tax equity investments, consolidation adjustments and Broken Bow II, the deferred project held for sale at December 31, 2024, the sale and transfer of which was completed in January 2025. See Note X. (c) On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W and Note X. Revenues are recorded as energy is delivered, generated or services are provided and billed to customers, except for services under percentage-of-completion contracts. Amounts billed are recorded in accounts receivable - customers, with payment generally due the following month. Con Edison’s and the Utilities’ accounts receivable - customers balance also reflects the Utilities’ purchase of receivables from energy service companies to support retail choice programs. Accrued revenues not yet billed to customers are recorded as accrued unbilled revenues. The Utilities have the obligation to deliver electricity, gas and steam energy to their customers. As the energy is immediately available for use upon delivery to the customer, the energy and its delivery are identifiable as a single performance obligation. The Utilities recognize revenues as this performance obligation is satisfied over time as the Utilities deliver, and the customers simultaneously receive and consume, the energy. The amount of revenues recognized reflects the consideration the Utilities expect to receive in exchange for delivering the energy. Under their tariffs, the transaction price for full-service customers includes the Utilities’ energy cost and for all customers includes delivery charges determined based on customer class and in accordance with established tariffs and guidelines of the NYSPSC or the NJBPU, as applicable. Accordingly, there is no unsatisfied performance obligation associated with these customers. The transaction price is applied to the Utilities’ revenue generating activities through the customer billing process. Because energy is delivered over time, the Utilities use output methods that recognize revenue based on direct measurement of the value transferred, such as units delivered, which provides an accurate measure of value for the energy delivered. The Utilities accrue revenues at the end of each month for estimated energy delivered but not yet billed to customers. The Utilities defer over a 12-month period net interruptible gas revenues, other than those authorized by the NYSPSC to be retained by the Utilities, for refund to firm gas sales and transportation customers. The Clean Energy Businesses recognized revenue for the sale of energy from renewable electric projects as energy was generated and billed to counterparties; accrued revenues at the end of each month for energy generated but not yet billed to counterparties; and recognized revenue as energy was delivered and services were provided for managing energy supply assets leased from others and managing the dispatch, fuel requirements and risk management activities for generating plants and merchant transmission in the northeastern United States. The Clean Energy Businesses also recognized revenue for providing energy-efficiency services to government and commercial customers, and recognized revenue for engineering, procurement and construction services, under the percentage-of-completion method of revenue recognition. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W and Note X. Use of the Percentage-of-Completion Method Sales and profits on each percentage-of-completion contract at the Clean Energy Businesses were recorded each month based on the ratio of actual cumulative costs incurred to the total estimated costs at completion of the contract, multiplied by the total estimated contract revenue, less cumulative revenues recognized in prior periods (the ‘‘cost-to-cost’’ method). The impact of revisions of contract estimates, which may have resulted from contract modifications, performance or other reasons, were recognized on a cumulative catch-up basis in the period in which the revisions were made. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W and Note X. 2024 2023 2022 (Millions of Dollars) Unbilled contract revenue (a) Unearned revenue (b) Unbilled contract revenue (a) Unearned revenue (b) Unbilled contract revenue (a) Unearned revenue (b) Beginning balance as of January 1, $4 $— $80 $3 $35 $7 Additions (c) — — 2 — 324 — Subtractions (c) — — (d) 78 3 (d) 279 4 (d) Ending balance as of December 31, $4 $— $4 (e) $— $80 $3 (a) Unbilled contract revenue represents accumulated incurred costs and earned profits on contracts (revenue arrangements), which have been recorded as revenue, but have not yet been billed to customers, and which represent contract assets as defined in Topic 606. Substantially all accrued unbilled contract revenue is expected to be collected within one year. Unbilled contract revenue arises from the cost-to-cost method of revenue recognition. Unbilled contract revenue from fixed-price type contracts is converted to billed receivables when amounts are invoiced to customers according to contractual billing terms, which generally occur when deliveries or other performance milestones are completed. (b) Unearned revenue represents a liability for billings to customers in excess of earned revenue, which are contract liabilities as defined in Topic 606. (c) Additions for unbilled contract revenue and subtractions for unearned revenue represent additional revenue earned. Additions for unearned revenue and subtractions for unbilled contract revenue represent billings. Activity also includes appropriate balance sheet classification for the period. Of the subtractions in 2023, $21 million and $1 million relate to the sale of all of the stock of the Clean Energy Businesses for unbilled contract revenue and unearned revenue, respectively. See (e) below. (d) Of the subtractions from unearned revenue, $3 million and $4 million were included in the balances as of January 1, 2023, and 2022, respectively. (e)

Current Expected Credit Losses

Current Expected Credit Losses	12 Months Ended
Current Expected Credit Losses	Dec. 31, 2024
Credit Loss [Abstract]
Current Expected Credit Losses	Current Expected Credit Losses Allowance for Uncollectible Accounts The Utilities’ “Account receivable – customers” balance consists of utility bills due (bills are generally due the month following billing) from customers who have energy delivered, generated, or services provided by the Utilities. The balance also reflects the Utilities’ purchase of receivables from energy service companies to support the retail choice programs. The “Other receivables” balance generally reflects costs billed by the Utilities for goods and services provided to external parties, such as accommodation work for private parties and certain governmental entities, real estate rental and pole attachments. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W and Note X. The Clean Energy Businesses’ customer accounts receivable balance generally reflected the management of energy supply assets, energy-efficiency services to government and commercial customers, and the engineering, procurement, and construction services of renewable energy projects. The Clean Energy Businesses calculated an allowance for uncollectible accounts related to their energy services customers based on an aging and customer-specific analysis. The amount of such reserves was not material at December 31, 2022. The Clean Energy Businesses were classified as held for sale as of December 31, 2022. The Companies develop expected loss estimates using past events data and consider current conditions and future reasonable and supportable forecasts. Changes to the Utilities’ reserve balances that result in write-offs of customer accounts receivable balances above existing rate allowances are not reflected in rates during the term of the current rate plans. For the Utilities’ allowance for uncollectible accounts for customer accounts receivable, which includes accrued unbilled revenue, past events considered include write-offs relative to customer accounts receivable; current conditions include macro-and micro-economic conditions related to trends in the local economy, bankruptcy rates and current and aged customer accounts receivable balances, including final balances, among other factors; and forecasts about the future include assumptions related to the level of write-offs and recoveries. During 2024, Con Edison's and CECONY's allowances for uncollectible accounts increased to $620 million and $605 million, respectively. Generally, the Utilities write off customer accounts receivable as uncollectible 90 days after the account is disconnected for non-payment, or the account is closed during the collection process. Other receivables allowance for uncollectible accounts is calculated based on a historical average of collections relative to total other receivables, including current receivables. Current macro- and micro-economic conditions are also considered when calculating the current reserve. Probable outcomes of pending litigation, whether favorable or unfavorable to the Companies, are also included in the consideration. Customer accounts receivable and the associated allowance for uncollectible accounts are included in the line “Accounts receivable – customers” on the Companies’ consolidated balance sheets. Other receivables and the associated allowance for uncollectible accounts are included in “Other receivables” on the consolidated balance sheets. The table below presents a rollforward by major portfolio segment type for the years ended December 31, 2024, 2023 and 2022: For the Year Ended December 31, Con Edison CECONY Accounts receivable - customers Other receivables Accounts receivable - customers Other receivables (Millions of Dollars) 2024 2023 2022 2024 2023 2022 2024 2023 2022 2024 2023 2022 Allowance for credit losses Beginning Balance at January 1, $360 $322 $317 $13 $10 $22 $353 $314 $304 $9 $7 $19 Recoveries 21 14 17 — — — 17 12 16 — — — Write-offs (250) (138) (103) — (5) (6) (239) (131) (94) — (3) (4) Reserve adjustments 489 162 91 28 8 (6) 474 158 88 29 5 (8) Ending Balance December 31, $620 $360 $322 $41 $13 $10 $605 $353 $314 $38 $9 $7

Stock-Based Compensation

Stock-Based Compensation	12 Months Ended
Stock-Based Compensation	Dec. 31, 2024
Share-Based Payment Arrangement [Abstract]
Stock-Based Compensation	Stock-Based Compensation The Companies may compensate employees and directors with, among other things, stock units, restricted stock units, contributions to the stock purchase plan and stock options. Long Term Incentive Plans that were approved by Con Edison’s shareholders in 2003 (2003 LTIP), 2013 (2013 LTIP), and 2023 (2023 LTIP) are collectively referred to herein as the LTIP. The LTIP provides for, among other things, awards to employees of restricted stock units and stock options and, to Con Edison’s non-employee directors, stock units. Existing awards under the 2003 LTIP and the 2013 LTIP continue in effect, however no new awards may be issued under either plan. The 2023 LTIP provides for awards for up to ten million shares of common stock. During the years ended December 31, 2024, 2023, and 2022, equity awards were granted under the 2013 and 2023 LTIP. Shares of Con Edison common stock used to satisfy the Companies’ obligations with respect to stock-based compensation may be new shares (authorized, but unissued) or treasury shares (existing treasury shares or shares purchased in the open market). The shares used during the year ended December 31, 2024 were new shares. The Companies intend to use new shares to fulfill their stock-based compensation obligations for 2025. The Companies recognized stock-based compensation expense using a fair value measurement method. The following table summarizes stock-based compensation expense recognized by the Companies in the years ended December 31, 2024, 2023 and 2022: Con Edison CECONY (Millions of Dollars) 2024 2023 2022 2024 2023 2022 Performance-based restricted stock $23 $41 $52 $20 $36 $43 Time-based restricted stock 2 2 2 2 2 2 Non-employee director deferred stock compensation 3 3 3 3 3 3 Stock purchase plan 7 7 7 7 7 6 Total $35 $53 $64 $32 $48 $54 Income tax benefit $10 $15 $18 $9 $13 $15 Restricted Stock and Stock Units Restricted stock and stock unit awards under the LTIP have been made as follows: (i) awards that provide for adjustment of the number of units (performance-restricted stock units or Performance RSUs) to certain officers and employees; (ii) time-based awards to certain officers and employees; and (iii) awards to non-employee directors. Restricted stock and stock units awarded represent the right to receive, upon vesting, shares of Con Edison common stock, or, except for units awarded under the directors’ plan, the cash value of shares or a combination thereof. The number of units in each annual Performance RSU award is subject to adjustment as follows: (i) 50 percent of the units awarded will be multiplied by a factor that may range from 0 to 200 percent, based on Con Edison’s total shareholder return relative to a specified peer group during a specified performance period (the TSR portion); and (ii) 50 percent of the units awarded will be multiplied by factors that may range from 0 to 200 percent, based on determinations made in connection with the Companies’ annual incentive plans or, with respect to certain executive officers, actual performance as compared to certain performance measures during a specified performance period (the non-TSR portion). Performance RSU awards generally vest upon completion of the performance period. Performance against the established targets is recomputed each reporting period as of the earlier of the reporting date and the vesting date. The TSR portion applies a Monte Carlo simulation model, and the non-TSR portion is the product of the market price at the end of the period and the average non-TSR determination over the vesting period. Performance RSUs are “liability awards” because each Performance RSU represents the right to receive, upon vesting, one share of Con Edison common stock, the cash value of a share or a combination thereof. As such, changes in the fair value of the Performance RSUs are reflected in net income. The assumptions used to calculate the fair value of the awards were as follows: 2024 2023 2022 Risk-free interest rate (a) 4.23% - 4.25% 4.06% - 4.64% 4.41% -4.73% Expected term (b) 3 years 3 years 3 years Expected share price volatility (c) 16.48% - 17.20% 17.88% - 19.92% 19.65% - 21.77% (a) The risk-free rate is based on the U.S. Treasury zero-coupon yield curve. (b) The expected term of the Performance RSUs equals the vesting period. The Companies do not expect significant forfeitures to occur. (c) Based on historical experience. The Companies would reevaluate this assumption if market conditions or business developments would reasonably indicate that future volatility might differ materially from historical experience. A summary of changes in the status of the Performance RSUs’ TSR and non-TSR portions during the year ended December 31, 2024 is as follows: Con Edison CECONY Weighted Average Grant Date Fair Value (a) Weighted Average Grant Date Fair Value (a) Units TSR Non-TSR Units TSR Non-TSR Non-vested at December 31, 2023 838,303 $83.70 $80.40 638,473 $83.94 $80.97 Granted 296,250 88.25 88.03 246,221 87.96 88.17 Vested (365,756) 74.36 71.12 (272,859) 74.10 71.36 Forfeited (47,996) 88.48 85.20 (38,242) 88.78 85.73 Transferred — — — (12,186) $90.81 $86.84 Non-vested at December 31, 2024 720,801 $89.99 $87.93 561,407 $90.01 $88.35 (a) The TSR and non-TSR Portions each account for 50 percent of the awards’ value. (b) Fair value is determined using the Monte Carlo simulation described above. Weighted average grant date fair value does not reflect any accrual or payment of dividends prior to vesting. (c) Fair value is determined using the market price of one share of Con Edison common stock on the grant date. The market price has not been discounted to reflect that dividends do not accrue and are not payable on Performance RSUs until vesting. (d) Represents allocation to another Con Edison subsidiary of a portion of the Performance RSUs that had been awarded to a CECONY officer who transferred to another subsidiary. The total expense to be recognized by Con Edison in future periods for unvested Performance RSUs outstanding at December 31, 2024 is $15 million, including $14 million for CECONY, and is expected to be recognized over a weighted average period of one year for both Con Edison and CECONY. Con Edison and CECONY paid cash of $30 million and $27 million in 2024, $21 million and $19 million in 2023, and $10 million and $9 million in 2022, respectively, to settle vested Performance RSUs. In accordance with the accounting rules for stock compensation, for time-based awards awarded to employees, the Companies accrue a liability and recognize compensation expense based on the market value of a common share throughout the vesting period. The vesting period for awards is three years and is based on the employee’s continuous service to Con Edison. Prior to vesting, the awards are subject to forfeiture in whole or in part under certain circumstances. The awards are “liability awards” because each restricted stock unit represents the right to receive, upon vesting, one share of Con Edison common stock, the cash value of a share or a combination thereof. As such, prior to vesting, changes in the fair value of the units are reflected in net income. The time-based awards awarded to officers are “equity awards” because each restricted stock unit represents the right to receive, upon vesting, one share of Con Edison common stock with no cash value options. As such, in accordance with the accounting rules for stock compensation, the value of the awards is measured at the estimated fair value on the date of grant. The cost is recognized as compensation expense over the vesting period. The vesting period for awards is three years and is based on each officer’s continuous service to Con Edison. A summary of changes in the status of time-based awards during the year ended December 31, 2024 is as follows: Con Edison CECONY Units Weighted Average Grant Date Units Weighted Average Grant Date Non-vested at December 31, 2023 345,201 $89.71 289,063 $90.25 Granted 200,550 88.60 173,755 88.72 Vested (14,915) 74.80 (14,015) 74.80 Forfeited (22,766) 87.67 (18,938) 87.86 Transferred — — (5,210) 86.84 Non-vested at December 31, 2024 508,070 $89.80 424,655 $90.28 The total expense to be recognized by Con Edison in future periods for unvested time-based awards outstanding at December 31, 2024 is $18 million, including $16 million for CECONY, and is expected to be recognized over a weighted average period of two years. Con Edison and CECONY paid cash of $2 million in 2024 and $2 million in 2023 and 2022, to settle vested time-based awards. Under the LTIP, each non-employee director receives stock units, which are deferred until the director’s separation from service or another date specified by the director. Each director may also elect to defer all or a portion of their cash compensation into additional stock units, which are deferred until the director’s termination of service or another date specified by the director. Non-employee directors’ stock units issued under the LTIP are considered “equity awards,” because they may only be settled in shares. Directors immediately vest in units issued to them. The fair value of the units is determined using the closing price of Con Edison’s common stock on the business day immediately preceding the date of issue. In the year ended December 31, 2024, approximately 33,000 units were issued at a weighted average grant date price of $89.23. Stock Purchase Plan The Stock Purchase Plans, which were approved by shareholders in 2014 and 2024 (collectively, the Plan), provide for the Companies to contribute up to $1 for each $9 invested by their directors, officers or employees to purchase Con Edison common stock under the Plan. Eligible participants may invest up to $25,000 during any calendar year (subject to an additional limitation for officers and employees of not more than 20 percent of their pay). Dividends paid on shares held under the Plan are reinvested in additional shares unless otherwise directed by the participant. Participants in the Plan immediately vest in shares purchased by them under the Plan. During 2024, 2023 and 2022, 774,338, 751,702 and 744,932 shares were purchased under the Plan at a weighted average price of $94.71, $91.80 and $91.59 per share, respectively.

Financial Information by Busine

Financial Information by Business Segment	12 Months Ended
Financial Information by Business Segment	Dec. 31, 2024
Segment Reporting [Abstract]
Financial Information by Business Segment	Financial Information by Business Segment In December 2024, the Companies adopted ASU 2023-07, “Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures.” The amendments improve the disclosures about a public entity’s reportable segments and address requests from investors for additional, more detailed information about a reportable segment’s expenses. Prior periods presented have been updated to conform to the requirements of the ASU. The business segments of each of the Companies, which are its operating segments, were determined based on management’s reporting and decision-making requirements in accordance with the accounting rules for segment reporting. Con Edison’s chief operating decision maker (CODM) is the Con Edison President and Chief Executive Officer, and CECONY’s CODMs are the CECONY Chief Executive Officer and the CECONY President. Con Edison's CODM is regularly provided with each company’s operating income to assess performance and allocate resources, including drivers of budget variances by regulated utility service for the Utilities, and for the nonregulated entities. CECONY’s CODMs are regularly provided with CECONY’s operating income to assess performance and allocate resources, including drivers of budget variances by CECONY's principal business segments. Con Edison’s principal business segments are CECONY’s regulated utility activities, O&R’s regulated utility activities and Con Edison Transmission. CECONY’s principal business segments are its regulated electric, gas and steam utility activities. All revenues of these business segments are from customers located in the United States of America. Also, all assets of the business segments are located in the United States of America. The accounting policies of the segments are the same as those described in Note A. Common services shared by the business segments are assigned directly or allocated based on various cost factors, depending on the nature of the service provided. The financial data for the business segments are as follows: As of and for the Year Ended December 31, 2024 (Millions of Dollars) Operating revenues Inter- segment revenues Other operations and maintenance(c) Depreciation and amortization Other operating expense (c) Operating income Other Income (deductions) Interest Allowance for borrowed funds used during construction Income Tax Expense Total assets Capital expenditures CECONY Electric $10,717 $20 $2,622 $1,471 $4,792 $1,832 $441 $826 ($41) $193 $46,275 $3,088 Gas 2,834 9 528 458 1,100 748 102 287 (16) 132 16,507 1,154 Steam 578 75 203 108 254 13 35 54 (1) (11) 2,868 132 Consolidation adjustments — (104) — — — — — — — — — — Total CECONY $14,129 $— $3,353 $2,037 $6,146 $2,593 $578 $1,167 ($58) $314 $65,650 $4,374 O&R Electric $852 $— $307 $82 $351 $112 $25 $43 ($5) $24 $2,596 $214 Gas 273 — 80 35 109 49 7 22 — 5 1,464 111 Total O&R $1,125 $— $387 $117 $460 $161 $32 $65 ($5) $29 $4,060 $325 Con Edison Transmission $4 $— $11 $1 $— ($8) $61 $— $— $8 $470 $29 Other (b) (2) — — — 74 (76) (16) 18 — (33) 382 — Total Con Edison $15,256 $— $3,751 $2,155 $6,680 $2,670 $655 $1,250 ($63) $318 $70,562 $4,728 As of and for the Year Ended December 31, 2023 (Millions of Dollars) Operating revenues Inter- segment revenues Other operations and maintenance (c) Depreciation and amortization Other operating expense (c) Operating income Other Income (deductions) Interest Expense Allowance for borrowed funds used during construction Income Tax Expense Total assets Capital expenditures CECONY Electric $10,078 $18 $2,417 $1,395 $4,698 $1,568 $564 $708 ($34) $217 $42,226 $2,909 Gas 2,829 8 528 429 1,190 682 122 240 (13) 159 16,343 1,046 Steam 569 74 231 100 311 (73) 46 46 (2) (18) 3,031 128 Consolidation adjustments — (100) — — — — — — — — — — Total CECONY $13,476 $— $3,176 $1,924 $6,199 $2,177 $732 $994 ($49) $358 $61,600 $4,083 O&R Electric $759 $— $292 $76 $306 $85 $37 $35 ($3) $20 $2,329 $211 Gas 297 — 83 30 143 41 12 19 — 8 1,346 85 Total O&R $1,056 $— $375 $106 $449 $126 $49 $54 ($3) $28 $3,675 $296 Clean Energy Businesses (a) $129 $— $47 $— $45 $37 $1 $16 $— $3 $— $81 Con Edison Transmission 4 — 11 1 1 (9) 62 2 — 14 414 49 Other (b) (2) — (3) — (864) 865 (14) 9 — 84 642 — Total Con Edison $14,663 $— $3,606 $2,031 $5,830 $3,196 $830 $1,075 ($52) $487 $66,331 $4,509 As of and for the Year Ended December 31, 2022 (Millions of Dollars) Operating Inter- Other operations and maintenance (c) Depreciation Other operating expense (c) Operating Other Income (deductions) Interest Allowance for borrowed funds used during construction Income Total Capital CECONY Electric $9,751 $19 $2,373 $1,315 $4,567 $1,496 $259 $609 ($27) $134 $39,153 $2,522 Gas 2,924 8 471 367 1,426 660 52 203 (5) 140 15,361 1,128 Steam 593 76 198 96 320 (21) 21 43 (1) (19) 2,931 108 Consolidation adjustments — (103) — — — — — — — — — — Total CECONY $13,268 $— $3,042 $1,778 $6,313 $2,135 $332 $855 ($33) $255 $57,445 $3,758 O&R Electric $773 $— $275 $71 $333 $94 $17 $32 ($3) $17 $2,247 $167 Gas 312 — 77 27 166 42 6 17 — 8 1,264 76 Total O&R $1,085 $— $352 $98 $499 $136 $23 $49 ($3) $25 $3,511 $243 Clean Energy Businesses (a) $1,319 $— $503 $178 $270 $368 $3 $(35) $— $84 $7,224 $399 Con Edison Transmission 4 — 12 1 1 (10) 19 5 — 5 314 65 Other (b) (6) — (4) 1 2 (5) (51) 14 — 129 571 — Total Con Edison $15,670 $— $3,905 $2,056 $7,085 $2,624 $326 $888 ($36) $498 $69,065 $4,465 (a) The Clean Energy Businesses were classified as held for sale as of December 31, 2022. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. As a result of this sale, the Clean Energy Businesses are no longer a principal segment. See Note W and Note X. (b) Other includes the parent company, Con Edison’s tax equity investments, consolidation adjustments and Broken Bow II, the deferred project held for sale at December 31, 2024, the sale and transfer of which was completed in January 2025. (c) Other operations and maintenance expenses constitute significant segment expenses which are regularly provided to the CODMs. Other operating expense includes other segment items (purchased power, fuel, gas purchased for resale, taxes other than income taxes) and, for 2023, the preliminary gain on the sale of the Clean Energy Businesses. See Note W.

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities	12 Months Ended
Derivative Instruments and Hedging Activities	Dec. 31, 2024
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities	Derivative Instruments and Hedging Activities Con Edison’s subsidiaries hedge market price fluctuations associated with physical purchases and sales of electricity, natural gas, steam and, to a lesser extent, refined fuels by using derivative instruments including futures, forwards, basis swaps, options, transmission congestion contracts and financial transmission rights contracts. These are economic hedges, for which the Utilities do not elect hedge accounting. The Companies use economic hedges to manage commodity price risk in accordance with provisions set by state regulators. The volume of hedging activity at the Utilities depends upon the forecasted volume of physical commodity supply to meet customer needs, and program costs or benefits are recovered from or credited to full-service customers, respectively. Derivatives are recognized on the consolidated balance sheet at fair value (see Note R), unless an exception is available under the accounting rules for derivatives and hedging. Qualifying derivative contracts that have been designated as normal purchases or normal sales contracts are not reported at fair value under the accounting rules. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W and Note X. The fair values of the Companies’ derivatives, including the offsetting of assets and liabilities, on the consolidated balance sheet at December 31, 2024 and 2023 were: (Millions of Dollars) 2024 2023 Balance Sheet Location Gross Amounts of Recognized Assets/ (Liabilities) Gross Amounts Offset Net Amounts of Assets/(Liabilities) (a) Gross Amounts of Recognized Assets/ (Liabilities) Gross Amounts Offset Net Amounts of Assets/(Liabilities) (a) Con Edison Fair value of derivative assets Current $56 $(41) $15 (b) $83 $(38) $45 (b) Noncurrent 39 (12) 27 77 (29) 48 Total fair value of derivative assets $95 $(53) $42 $160 $(67) $93 Fair value of derivative liabilities Current $(92) $44 $(48) (b) $(230) $52 $(178) (b) Noncurrent (108) 12 (96) (154) 33 (121) Total fair value of derivative liabilities $(200) $56 $(144) $(384) $85 $(299) Net fair value derivative assets/(liabilities) $(105) $3 $(102) $(224) $18 $(206) CECONY Fair value of derivative assets Current $51 $(40) $11 (b) $78 $(35) $43 (b) Noncurrent 36 (11) 25 76 (27) 49 Total fair value of derivative assets $87 $(51) $36 $154 $(62) $92 Fair value of derivative liabilities Current $(84) $42 $(42) (b) $(217) $48 $(169) (b) Noncurrent (95) 11 (84) (139) 31 (108) Total fair value of derivative liabilities $(179) $53 $(126) $(356) $79 $(277) Net fair value derivative assets/(liabilities) $(92) $2 $(90) $(202) $17 $(185) (a) Derivative instruments and collateral were offset on the consolidated balance sheet as applicable under the accounting rules. The Companies enter into master agreements for their commodity derivatives. These agreements typically provide offset in the event of contract termination. In such case, generally the non-defaulting party’s payable will be offset by the defaulting party’s payable. The non-defaulting party will customarily notify the defaulting party within a specific time period and come to an agreement on the early termination amount. (b) At December 31, 2024, no margin deposits for Con Edison and CECONY were classified as derivative assets and $(4) million and $(2) million, respectively were classified as derivative liabilities on the consolidated balance sheet, but not included in the table. At December 31, 2023, margin deposits for Con Edison and CECONY of $7 million and $6 million were classified as derivative assets, and $(15) million and $(10) million, respectively were classified as derivative liabilities on the consolidated balance sheets, but not included in the table. Margin is collateral, typically cash, that the holder of a derivative instrument is required to deposit in order to transact on an exchange and to cover its potential losses with its broker or the exchange. The Utilities generally recover their prudently incurred fuel, purchased power and gas costs, including hedging gains and losses, in accordance with rate provisions approved by the applicable state utility regulators. In accordance with the accounting rules for regulated operations, the Utilities record a regulatory asset or regulatory liability to defer recognition of unrealized gains and losses on their electric and gas derivatives. As gains and losses are realized in future periods, they will be recognized as purchased power, gas and fuel costs in the Companies’ consolidated income statements. The Clean Energy Businesses recorded realized and unrealized gains and losses on their derivative contracts in gas purchased for resale and non-utility revenue in the reporting period in which they occurred. The Clean Energy Businesses recorded changes in the fair value of their interest rate swaps in other interest expense at the end of each reporting period. Management believes that these derivative instruments represent economic hedges that mitigate exposure to fluctuations in commodity prices and interest rates. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W and Note X. The following table presents the realized and unrealized gains or losses on derivatives that have been deferred or recognized in earnings for the years ended December 31, 2024 and 2023: Con Edison CECONY (Millions of Dollars) Financial Statement Location 2024 2023 2024 2023 Pre-tax gains (losses) deferred in accordance with accounting rules for regulated operations: Current Regulatory liabilities $(49) $(236) $(49) $(216) Noncurrent Regulatory liabilities (41) (96) (43) (81) Total deferred gains (losses) $(90) $(332) $(92) $(297) Current Regulatory assets $166 $(85) $161 $(76) Current Recoverable energy costs (318) (563) (294) (533) Noncurrent Regulatory assets 57 (132) 54 (122) Total deferred or recognized gains (losses) $(95) $(780) $(79) $(731) Net deferred or recognized gains (losses) (a) $(185) $(1,112) $(171) $(1,028) Financial Statement Location Pre-tax gains (losses) recognized in income Gas purchased for resale (b) $— $4 $— $— Non-utility revenue (b) — 17 — — Other interest expense (b) — 5 — — Total pre-tax gains (losses) recognized in income $— $26 $— $— (a) Unrealized net deferred losses on electric and gas derivatives for the Utilities decreased as a result of higher electric and gas commodity prices during the year ended December 31, 2024. Upon settlement, short-term deferred derivative losses generally increase the recoverable costs of electric and gas purchases. (b) Comprised of realized and unrealized gains and losses on the derivative contracts of the Clean Energy Businesses. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W and Note X. The following table presents the hedged volume of Con Edison’s and CECONY’s commodity derivative transactions at December 31, 2024: Electric Energy Capacity (MW-mos) (a) Natural Gas (Dt) (a)(b) Refined Fuels (gallons) Con Edison 33,303,430 31,500 313,300,000 3,780,000 CECONY 30,466,200 24,000 292,340,000 3,780,000 (a) Volumes are reported net of long and short positions, except natural gas collars where the volumes of long positions are reported. (b) Excludes electric congestion and gas basis swap contracts which are associated with electric and gas contracts and hedged volumes. The Companies are exposed to credit risk related to transactions entered into primarily for the various energy supply and hedging activities by the Utilities. Credit risk relates to the loss that may result from a counterparty’s nonperformance. The Companies use credit policies to manage this risk, including an established credit approval process, monitoring of counterparty limits, netting provisions within agreements, collateral or prepayment arrangements, credit insurance and credit default swaps. The Companies measure credit risk exposure as the replacement cost for open energy commodity and derivative positions plus amounts owed from counterparties for settled transactions. The replacement cost of open positions represents unrealized gains, net of any unrealized losses where the Companies have a legally enforceable right to offset. At December 31, 2024, Con Edison and CECONY had $29 million and $21 million of credit exposure, respectively, in connection with open energy supply net receivables and hedging activities, net of collateral. Con Edison’s net credit exposure consisted of $22 million with investment-grade counterparties and $7 million with commodity exchange brokers. CECONY’s net credit exposure consisted of $15 million with investment-grade counterparties and $6 million with commodity exchange brokers. The collateral requirements associated with, and settlement of, derivative transactions are included in net cash flows from operating activities in the Companies’ consolidated statements of cash flows. Most derivative instrument contracts contain provisions that may require a party to provide collateral on its derivative instruments that are in a net liability position. The amount of collateral to be provided will depend on the fair value of the derivative instruments and the party’s credit ratings. The following table presents the aggregate fair value of the Companies’ derivative instruments with credit-risk-related contingent features that are in a net liability position, the collateral posted for such positions and the additional collateral that would have been required to be posted had the lowest applicable credit rating been reduced one level and to below investment grade at December 31, 2024: (Millions of Dollars) Con Edison (a) CECONY (a) Aggregate fair value – net liabilities $129 $112 Collateral posted 122 120 Additional collateral (b) (downgrade one level from current ratings) 17 8 Additional collateral (b)(c) (downgrade to below investment grade from current ratings) 136 114 (a) Non-derivative transactions for the purchase and sale of electricity and gas and qualifying derivative instruments, that have been designated as normal purchases or normal sales, are excluded from the table. These transactions primarily include purchases of electricity from independent system operators. In the event the Utilities are no longer extended unsecured credit for such purchases, the Companies would be required to post additional collateral of $1 million at December 31, 2024. For certain other such non-derivative transactions, the Companies could be required to post collateral under certain circumstances, including in the event counterparties had reasonable grounds for insecurity. (b) The Companies measure the collateral requirements by taking into consideration the fair value amounts of derivative instruments that contain credit-risk-related contingent features that are in a net liability position plus amounts owed to counterparties for settled transactions and amounts required by counterparties for minimum financial security. The fair value amounts represent unrealized losses, net of any unrealized gains where the Companies have a legally enforceable right to offset. (c) Derivative instruments that are net assets have been excluded from the table. At December 31, 2024, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $8 million.

Fair Value Measurements

Fair Value Measurements	12 Months Ended
Fair Value Measurements	Dec. 31, 2024
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements The accounting rules for fair value measurements and disclosures define fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, that refer broadly to assumptions that market participants use in pricing assets or liabilities. These inputs can be readily observable, market corroborated, or generally unobservable firm inputs. The Companies often make certain assumptions that market participants would use in pricing the asset or liability, including assumptions about risk, and the risks inherent in the inputs to valuation techniques. The Companies use valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs. The accounting rules for fair value measurements and disclosures established a fair value hierarchy, that prioritizes the inputs to valuation techniques used to measure fair value in three broad levels. The rules require that assets and liabilities be classified in their entirety based on the level of input that is significant to the fair value measurement. Assessing the significance of a particular input may require judgment considering factors specific to the asset or liability, and may affect the valuation of the asset or liability and their placement within the fair value hierarchy. The Companies classify fair value balances based on the fair value hierarchy defined by the accounting rules for fair value measurements and disclosures as follows: • Level 1 – Consists of assets or liabilities whose value is based on unadjusted quoted prices in active markets at the measurement date. An active market is one in which transactions for assets or liabilities occur with sufficient frequency and volume to provide pricing information on an ongoing basis. This category includes contracts traded on active exchange markets valued using unadjusted prices quoted directly from the exchange. • Level 2 – Consists of assets or liabilities valued using industry standard models and based on prices, other than quoted prices within Level 1, that are either directly or indirectly observable as of the measurement date. The industry standard models consider observable assumptions including time value, volatility factors and current market and contractual prices for the underlying commodities, in addition to other economic measures. This category includes contracts traded on active exchanges or in over-the-counter markets priced with industry standard models. • Level 3 – Consists of assets or liabilities whose fair value is estimated based on internally developed models or methodologies using inputs that are generally less readily observable and supported by little, if any, market activity at the measurement date. Unobservable inputs are developed based on the best available information and subject to cost benefit constraints. This category includes contracts priced using models that are internally developed and contracts placed in illiquid markets. It also includes contracts that expire after the period of time for which quoted prices are available and internal models are used to determine a significant portion of the value. For information on the measurement of Con Edison's investment in MVP that was measured at fair value on a non-recurring basis, see Note A. Assets and liabilities measured at fair value on a recurring basis for the years ended December 31, 2024 and 2023 are summarized below. 2024 2023 (Millions of Dollars) Level 1 Level 2 Level 3 Netting Total Level 1 Level 2 Level 3 Netting Total Con Edison Derivative assets: Commodity (a)(b)(c) $9 $81 $1 $(49) $42 $6 $146 $2 $(54) $100 Mutual Funds (a)(b) 570 — — — 570 505 — — — 505 Cash Value of Life Insurance — 129 — — 129 — 118 — — 118 Total assets $579 $210 $1 $(49) $741 $511 $264 $2 $(54) $723 Derivative liabilities: Commodity (a)(b)(c) $5 $175 $16 $(48) $148 $22 $347 $10 $(65) $314 CECONY Derivative assets: Commodity (a)(b)(c) $9 $74 $1 $(48) $36 $6 $143 $1 $(52) $98 Mutual Funds (a)(b) 553 — — — 553 488 — — — 488 Cash Value of Life Insurance — 123 — — 123 — 113 — — 113 Total assets $562 $197 $1 $(48) $712 $494 $256 $1 $(52) $699 Derivative liabilities: Commodity (a)(b)(c) $4 $164 $7 $(47) $128 $20 $326 $6 $(65) $287 (a) The Companies’ policy is to review the fair value hierarchy and recognize transfers into and transfers out of the levels at the end of each reporting period. Transfers out of Level 3 represent assets and liabilities that were previously classified as Level 3 for which the inputs became observable for classification in Level 2. The inputs are now observable because of availability of observable market data due to the decrease in the terms of certain contracts from beyond three years to less than three years. (b) Level 2 assets and liabilities include investments held in the deferred compensation plan and/or non-qualified retirement plans, exchange-traded contracts where there is insufficient market liquidity to warrant inclusion in Level 1, and certain over-the-counter derivative instruments for electricity, refined products and natural gas. Derivative instruments classified as Level 2 are valued using industry standard models that incorporate corroborated observable inputs, such as pricing services or prices from similar instruments that trade in liquid markets, time value and volatility factors. (c) The accounting rules for fair value measurements and disclosures require consideration of the impact of nonperformance risk (including credit risk) from a market participant perspective in the measurement of the fair value of assets and liabilities. At December 31, 2024 and 2023, the Companies determined that nonperformance risk would have no material impact on their financial position or results of operations. (d) Amounts represent the impact of legally-enforceable master netting agreements that allow the Companies to net gain and loss positions and cash collateral held or placed with the same counterparties. The employees in the Companies’ risk management group develop and maintain the Companies’ valuation policies and procedures for, and verify pricing and fair value valuation of, commodity derivatives. Under the Companies’ policies and procedures, multiple independent sources of information are obtained for forward price curves used to value commodity derivatives. Fair value and changes in fair value of commodity derivatives are reported monthly to the Companies’ risk committees, comprised of officers and employees of the Companies that oversee energy hedging at the Utilities. The risk management group reports to the Companies’ Vice President and Treasurer. Fair Value of Level 3 at December 31, 2024 Average (Millions of Dollars) Valuation Techniques Unobservable Inputs Range Con Edison — Commodity Electricity $(16) Discounted Cash Flow Forward capacity prices ($/kW-month) (a) $0.73 - $7.14 $3.69 Transmission Congestion Contracts 1 Discounted Cash Flow Inter-zonal forward price curves adjusted for historical zonal losses ($/MWh) (b) $(0.20) - $3.88 $1.85 Total Con Edison - Commodity $(15) CECONY — Commodity Electricity $(7) Discounted Cash Flow Forward capacity prices ($/kW-month) (a) $0.73 - $7.14 $3.75 Transmission Congestion Contracts 1 Discounted Cash Flow Inter-zonal forward price curves adjusted for historical zonal losses ($/MWh) (b) $(0.20) - $3.88 $1.85 Total CECONY — Commodity $(6) (a) Generally, increases/(decreases) in this input in isolation would result in a higher/(lower) fair value measurement. (b) Generally, increases/(decreases) in this input in isolation would result in a lower/(higher) fair value measurement. The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value for the years ended December 31, 2024 and 2023 and classified as Level 3 in the fair value hierarchy: Con Edison CECONY (Millions of Dollars) 2024 2023 2024 2023 Beginning balance as of January 1, $(8) $15 $(5) $(6) Included in earnings (9) (4) (4) (2) Included in regulatory assets and liabilities (7) 33 — 31 Settlements 10 4 4 2 Decrease due to the sale of the Clean Energy Businesses (a) — (29) — — Transfer out of level 3 (1) (27) (1) (30) Ending balance as of December 31, $(15) $(8) $(6) $(5) (a) On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W and Note X. For the Utilities, realized gains and losses on Level 3 commodity derivative assets and liabilities are reported as part of purchased power, gas and fuel costs. The Utilities generally recover these costs in accordance with rate provisions approved by the applicable state public utilities regulators. See Note A. Unrealized gains and losses for commodity derivatives are generally deferred on the consolidated balance sheet in accordance with the accounting rules for regulated operations. For the Clean Energy Businesses, realized and unrealized gains and losses on Level 3 commodity derivative assets and liabilities were reported in non-utility revenues

Variable Interest Entities

Variable Interest Entities	12 Months Ended
Variable Interest Entities	Dec. 31, 2024
Equity Method Investments and Joint Ventures [Abstract]
Variable Interest Entities	Variable Interest Entities The accounting rules for consolidation address the consolidation of a variable interest entity (VIE) by a business enterprise that is the primary beneficiary. A VIE is an entity that does not have a sufficient equity investment at risk to permit it to finance its activities without additional subordinated financial support, or whose equity investors lack the characteristics of a controlling financial interest. The primary beneficiary is the business enterprise that has the power to direct the activities of the VIE that most significantly impact the VIE’s economic performance and either absorbs a significant amount of the VIE’s losses or has the right to receive benefits that could be significant to the VIE. The Companies enter into arrangements including leases, partnerships and electricity purchase agreements, with various entities. As a result of these arrangements, the Companies retain or may retain a variable interest in these entities. CECONY CECONY has an ongoing long-term electricity purchase agreement with Brooklyn Navy Yard Cogeneration Partn ers, LP, a potential VIE. In 2024, a request was made of this counterparty for information necessary to determine whether the entity was a VIE and whether CECONY is the primary beneficiary; however, the information was not made available. See Note I for information on this electricity purchase agreement; the payments for this contract constitute CECONY's maximum exposure to loss with respect to the potential VIE. Clean Energy Businesses Con Edison has determined that the use of Hypothetical Liquidation at Book Value (HLBV) accounting is reasonable and appropriate to attribute income and loss to the tax equity investors for various projects owned by the Clean Energy Businesses. See "Use of Hypothetical Liquidation at Book Value" in Note A. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. In connection with the sale, Con Edison retained a tax equity interest in two renewable electric projects located in Virginia, and in the Crane Solar Project (collectively, the "Retained Projects"). Included in the sale were Con Edison's interests in CED Nevada Virginia and the Tax Equity Projects, defined below (collectively, the "Sold Projects"). The HLBV method of accounting resulted in an immaterial amount of income/(loss) for Con Edison and the tax equity investor for the Sold Projects for the year ended December 31, 2023; information for the year ended December 31, 2022 is presented below. See Note W and X. Retained Projects Con Edison retained a tax equity interest in two renewable electric projects located in Virginia that is accounted for as an equity method investment and represents the maximum exposure to loss for this investment. See Note A and Note W. The earnings of the projects are determined using the HLBV method of accounting and resulted in losses of $3 million ($2.5 million, after tax) and $14 million ($10 million, after tax) for the years ended December 31, 2024 and 2023, respectively. Con Edison also retained its equity interest in the Crane solar project that was valued at $0 as of December 31, 2024 and is accounted for as an equity method investment. See Note W. The earnings of the project are determined using the HLBV method of accounting and were not material for the years ended December 31, 2024, 2023, and 2022. Con Edison is not the primary beneficiary of any Retained Projects since the power to direct the activities that most significantly impact the economics of the renewable electric projects is not held by Con Edison. Sold Projects In 2018, the Clean Energy Businesses completed its acquisition of Sempra Solar Holdings, LLC. Included in the acquisition were certain operating projects (Tax Equity Projects) with a noncontrolling tax equity investor to which a percentage of earnings, tax attributes and cash flows are allocated. Electricity generated by the Tax Equity Projects is sold to utilities and municipalities pursuant to long-term power purchase agreements. In 2021, a subsidiary of the Clean Energy Businesses entered into an agreement relating to certain projects (CED Nevada Virginia) with a noncontrolling tax equity investor to which a percentage of earnings, tax attributes and cash flows are allocated. The Tax Equity Projects and CED Nevada Virginia were consolidated entities in which Con Edison had less than a 100 percent membership interest at December 31, 2022 and in which Con Edison has no interest in subsequent to the sale of the Clean Energy Businesses on March 1, 2023. Con Edison was the primary beneficiary since the power to direct the activities that most significantly impact the economics of the Tax Equity Projects and CED Nevada Virginia was held by Con Edison. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W and Note X. The HLBV method of accounting resulted in income/(loss) for the year ended December 31, 2022 as follows: (Millions of Dollars) CED Nevada Virginia Tax Equity Projects Tax equity investor $(49) $(11) After tax (37) (8) Con Edison 41 51 After tax 31 38

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
Asset Retirement Obligations	Dec. 31, 2024
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations The Companies recognize a liability at fair value for legal obligations associated with the retirement of long-lived assets in the period in which they are incurred, or when sufficient information becomes available to reasonably estimate the fair value of such legal obligations. When the liability is initially recorded, asset retirement costs are capitalized by increasing the carrying amount of the related asset. The liability is accreted to its present value each period and the capitalized cost is depreciated over the useful life of the related asset. The fair value of the asset retirement obligation liability is measured using expected future cash flows discounted at credit-adjusted risk-free rates, historical information, and where available, quoted prices from outside contractors. The Companies evaluate these assumptions underlying the asset retirement obligation liability on an annual basis or as frequently as needed. The Companies recorded asset retirement obligations associated with the removal of asbestos and asbestos-containing material in their buildings (other than the structures enclosing generating stations and substations), electric equipment and steam and gas distribution systems. The Companies also recorded asset retirement obligations relating to gas and oil pipelines abandoned in place and municipal infrastructure support. The Companies did not record an asset retirement obligation for the removal of asbestos associated with the structures enclosing generating stations and substations. For these building structures, the Companies were unable to reasonably estimate their asset retirement obligations because the Companies were unable to estimate the undiscounted retirement costs or the retirement dates and settlement dates. The amount of the undiscounted retirement costs could vary considerably depending on the disposition method for the building structures, and the method has not been determined. The Companies anticipate continuing to use these building structures in their businesses for an indefinite period, and so the retirement dates and settlement dates are not determinable. Con Edison recorded asset retirement obligations for the removal of the Clean Energy Businesses’ solar and wind equipment related to projects located on property that is not owned by them and the term of the arrangement is finite including any renewal options. Con Edison did not record asset retirement obligations for the Clean Energy Businesses’ projects that were located on property that was owned by them because they expect that the equipment will continue to generate electricity at these facilities long past the manufacturer’s warranty at minimal operating expense. Therefore, Con Edison was unable to reasonably estimate the retirement date of this equipment. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W and Note X. The Utilities include in depreciation rates the estimated removal costs, less salvage, for utility plant assets. The amounts related to removal costs that are associated with asset retirement obligations are classified as an asset retirement liability. Pursuant to accounting rules for regulated operations, future removal costs that do not represent legal asset retirement obligations are recorded as regulatory liabilities. Accretion and depreciation expenses related to removal costs that represent legal asset retirement obligations are applied against the Companies’ regulatory liabilities. Asset retirement costs that are recoverable from customers are recorded as regulatory liabilities to reflect the timing difference between costs recovered through the rate-making process and recognition of costs. The following table represents the balance of asset retirement obligations as of December 31, 2024 and 2023, and changes to the obligation for the years then ended: Con Edison CECONY (Millions of Dollars) 2024 (a) 2023 2024 2023 Beginning Balance as of January 1, $522 $500 $520 $499 Changes in estimated cash flows (21) 76 (21) 75 Accretion expense 20 17 20 17 Liabilities settled (68) (71) (67) (71) Ending Balance as of December 31, (b) $453 $522 $452 $520 (a) The asset retirement obligations of Broken Bow II in 2023 and 2024 are reflected in current liabilities held for sale on Con Edison's consolidated balance sheets as of December 31, 2023 and 2024, respectively. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. For 2023 and 2024, $3 million of asset retirement obligations related to Broken Bow II are not shown in the table above, as they are already excluded from the beginning balance as of January 1, 2023 and January 1, 2024 for Con Edison. Broken Bow II was sold and transferred in January 2025. See Note A, Note W, and Note X. (b) At December 31, 2024, Con Edison and CECONY recorded reductions of $85 million and $84 million, respectively, to the regulatory liability associated with cost of removal to reflect depreciation and interest expense. At December 31, 2023, Con Edison and CECONY recorded reductions of $77 million to the regulatory liability associated with cost of removal to reflect depreciation and interest expense.

Related Party Transactions

Related Party Transactions	12 Months Ended
Related Party Transactions	Dec. 31, 2024
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions The NYSPSC generally requires that the Utilities and Con Edison’s other subsidiaries be operated as separate entities. The Utilities and the other subsidiaries are required to have separate operating employees and operating officers of the Utilities may not be operating officers of the other subsidiaries. The Utilities may provide administrative and other services to, and receive such services from, Con Edison and its other subsidiaries only pursuant to cost allocation procedures approved by the NYSPSC. Transfers of assets between the Utilities and Con Edison or its other subsidiaries may be made only as approved by the NYSPSC. The debt of the Utilities is to be raised directly by the Utilities and not derived from Con Edison. Without the prior permission of the NYSPSC, the Utilities may not make loans to, guarantee the obligations of, or pledge assets as security for the indebtedness of Con Edison or its other subsidiaries. The NYSPSC limits the dividends that the Utilities may pay Con Edison. See “Dividends” in Note C. As a result, substantially all of the net assets of CECONY and O&R ($19,971 million and $1,142 million, respectively), at December 31, 2024, are considered restricted net assets. The NYSPSC may impose additional measures to separate, or “ring fence,” the Utilities from Con Edison and its other subsidiaries. See “Rate Plans” in Note B. The costs of administrative and other services provided by CECONY to, and received by it from, Con Edison and its other subsidiaries for the years ended December 31, 2024, 2023 and 2022 were as follows: CECONY (a) (Millions of Dollars) 2024 2023 2022 Cost of services provided $147 $146 $135 Cost of services received 82 82 75 (a) On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W and Note X. In addition, CECONY and O&R have joint gas supply arrangements in connection with which CECONY sold to O&R $77 million, $82 million and $144 million of natural gas for the years ended December 31, 2024, 2023 and 2022, respectively. These amounts are net of the effect of related hedging transactions. At December 31, 2024 and 2023, CECONY's net receivable from Con Edison for income taxes were $344 million and $110 million, respectively. The Utilities perform work and incur expenses on behalf of New York Transco, a company in which Con Edison Transmission owns an interest. The Utilities bill New York Transco for such work and expenses in accordance with established policies. For the years ended December 31, 2024 and 2023, the amounts billed by the Utilities to New York Transco were immaterial and $7.3 million, respectively. CECONY has a 20-year transportation contract with MVP, a company in which Con Edison Transmission owns an interest, for 200,000 Dts per day of capacity. See "Investment in Mountain Valley Pipeline, LLC (MVP) " in Note A. In October 2017, the Environmental Defense Fund and the Natural Resource Defense Council requested the NYSPSC to prohibit CECONY from recovering costs under its contract with MVP unless CECONY can demonstrate that the contract is in the public interest. CECONY advised the NYSPSC that it would respond to the request if the NYSPSC were to open a proceeding to consider this request. For the year ended December 31, 2024, the amounts billed by MVP to CECONY were $28 million. FERC has authorized CECONY to lend funds to O&R for a period of not more than 12 months, in an amount not to exceed $250 million, at prevailing market rates. At December 31, 2024 and 2023 there were no outstanding loans to O&R. The Clean Energy Businesses had financial electric capacity contracts with CECONY and O&R. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. As a result of the sale, the Clean Energy Businesses are no longer recognized as a related party. See Note W and Note X.

New Financial Accounting Standa

New Financial Accounting Standards	12 Months Ended
New Financial Accounting Standards	Dec. 31, 2024
Accounting Changes and Error Corrections [Abstract]
New Financial Accounting Standards	New Financial Accounting Standards In December 2023, the FASB issued amendments to the guidance on accounting for Income Taxes (Topic 740) through ASU 2023-09 to improve disclosures related to income taxes. The amendments focus on three key areas: rate reconciliation, income taxes paid, and income (or loss)/income tax expense (or benefit) from disaggregated continuing operations. For public entities, the amendments are effective for annual reporting periods beginning after December 15, 2024. Early adoption is permitted for annual financial statements. The Companies do not expect the new guidance to have a material impact on their financial position, results of operations and liquidity. In November 2024, the FASB issued ASU 2024-03, Income Statement—Reporting Comprehensive Income—Expense Disaggregation Disclosures (Subtopic 220-40) to improve disclosures about a public business entity's expenses. The ASU addresses requests from investors for more detailed information about the types of expenses (including purchases of inventory, employee compensation, depreciation, amortization, and depletion) in commonly presented expense captions. The amendments require a public business entity to disclose, in the notes to the financial statements, specified information about certain costs and expenses at each interim and annual reporting period. The amendments are effective for annual reporting periods beginning after December 15, 2026, and interim reporting periods beginning after December 15, 2027. Early adoption is permitted. The Companies are in the process of evaluating the potential impact of the ASU on their financial position, results of operations and liquidity.

Dispositions

Dispositions	12 Months Ended
Dispositions	Dec. 31, 2024
Discontinued Operations and Disposal Groups [Abstract]
Dispositions	Dispositions Clean Energy Businesses During the first nine months of 2022, Con Edison considered strategic alternatives with respect to the Clean Energy Businesses. On October 1, 2022, following the conclusion of such review and to allow for continued focus on the Utilities and their clean energy transition, Con Edison entered into a purchase and sale agreement pursuant to which Con Edison agreed to sell all of the stock of the Clean Energy Businesses to RWE Renewables Americas, LLC, a subsidiary of RWE for a total of $6,800 million, subject to closing adjustments. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses to RWE for $3,993 million. The preliminary purchase price at the March 1, 2023 closing was adjusted (i) upward for certain cash and cash equivalents, (ii) downward for certain indebtedness and debt-like items, (iii) downward for certain transaction expenses, (iv) downward to the extent that the net working capital varied from a set target, (v) upward to the extent that capital expenditures incurred prior to the closing of the transaction varied from a set budget, and (vi) downward by the value allocated to Broken Bow II, a project that was not able to be conveyed to RWE upon closing of the transaction. The process to finalize the purchase price was completed during the second quarter of 2024. The final purchase price was subject to customary adjustments for timing differences and a final valuation report, among other factors. The transaction was completed at arm’s length and RWE was not, and will not be, considered a related party to Con Edison. The sale on March 1, 2023 included all assets, operations and projects of the Clean Energy Businesses with the exception of tax equity interests in three projects, described below, that Con Edison continues to retain, and one deferred project, Broken Bow II, a 75 MW nameplate capacity wind power project located in Nebraska. See Note X. In January 2025, Con Edison completed the sale and transfer of Broken Bow II to RWE and the corresponding value of $54 million (net of assumed debt and other final adjustments) was paid to Con Edison. RWE Renewables Americas, LLC operated the facility on behalf of Con Edison until the transfer to RWE pursuant to certain service agreements, for which the fees were not material. For the year ended December 31, 2023, Con Edison's preliminary gain on the sale of all of the stock of the Clean Energy Businesses was $865 million ($767 million, after tax). The portion of the gain attributable to the non-controlling interest retained in certain tax-equity projects was not material. For the year ended December 31, 2024, the gain on the sale of all of the stock of the Clean Energy Businesses was adjusted downward by $62 million ($46 million after-tax) in aggregate due to certain customary closing adjustments, including $33 million ($25 million after-tax) to align with the consideration received upon the sale and transfer of Broken Bow II in January 2025. See Note X. Con Edison retained the Clean Energy Businesses' tax equity investment interest in the Crane solar project and another tax equity investment interest in two solar projects located in Virginia. These tax equity partnerships produced renewable energy tax credits that can be used to reduce Con Edison’s federal income tax. These tax credits are subject to recapture, in whole or in part, if the assets are sold within a five -year period beginning on the date on which the assets are placed in service. Con Edison will continue to employ HLBV accounting for its interests in these tax equity partnerships. The combined carrying value of the retained tax equity interests was $4 million and $13 million at December 31, 2024 and 2023, respectively . Con Edison also retained any post-sale deferred income taxes (federal and state income taxes, including tax attributes), any valuation allowances associated with the deferred tax assets, all current federal taxes and New York State taxes and the estimated liability for uncertain tax positions. The unamortized deferred investment tax credits of the Clean Energy Businesses were recognized in full upon the completion of the sale of all of the stock of the Clean Energy Businesses. Concurrent with entering into the purchase and sale agreement, Con Edison incurred costs in the normal course of the sale process. Transaction costs of $48 million ($35 million after-tax), $12 million ($9 million after-tax) and an immaterial amount were recorded during 2022, 2023, and 2024, respectively. Also, depreciation and amortization expense of approximately $41 million ($28 million after-tax) were not recorded on the assets of the Clean Energy Businesses in 2023 prior to the closing of the transaction. Following the sale of all of the stock of the Clean Energy Businesses and pursuant to a reimbursement and indemnity agreement with RWE, Con Edison remains responsible for certain potential costs related to a battery storage project located in Imperial County, California. Con Edison's exposure under the agreement could range up to approximate ly $172 million. As of December 31, 2024, no material amounts wer e recorded as liabilities on Con Edison's consolidated balance sheet related to this agreement. During 2023, Con Edi son received $24 million of net proceeds from this battery storage project. Con Edison had $4 million of unbilled contract revenue recorded as of December 31, 2023 and 2024. See Note M. The following table shows the pre-tax operating income for the Clean Energy Businesses. The 2023 period shown is through the date of the sale of the Clean Energy Businesses; there is no applicable data for the year ended December 31, 2024. For the Year Ended December 31, (Millions of Dollars) 2023 2022 Pre-tax operating income $25 $466 Pre-tax operating income, excluding non-controlling interest 21 406 On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W. The sale included all assets, operations and projects of the Clean Energy Businesses with the exception of tax equity interests in three projects and one deferred project, Broken Bow II, a 75 MW nameplate capacity wind power project located in Nebraska. In January 2025, Con Edison completed the sale and transfer of Broken Bow II to RWE and the corresponding value of $54 million (net of assumed debt and other final adjustments) was paid to Con Edison. RWE Renewables Americas, LLC operated the facility on behalf of Con Edison until the transfer to RWE pursuant to certain service agreements, for which the fees were not material. Following the sale and transfer of Broken Bow II in January 2025, Con Edison did not have any assets or liabilities recorded on a held-for-sale basis. For the year ended December 31, 2024, the book value of the assets of Broken Bow II were reduced to align with the consideration received upon the transfer of the project in January 2025, resulting in a downward adjustment to the cumulative gain on the sale of all of the stock of the Clean Energy Businesses of $33 million ($25 million after-tax). See Note W. The carrying amounts of the major classes of assets and liabilities of Broken Bow II, that were transferred from Con Edison to RWE in January 2025, were presented on a held-for-sale basis as of December 31, 2023 and 2024 , and accordingly, excluded net deferred tax liability balances, as follows: (Millions of Dollars) December 31, December 31, ASSETS CURRENT ASSETS Cash and temporary cash investments $1 $— Accounts receivable and other receivables - net allowance for uncollectible accounts 2 1 Accrued unbilled revenue — 1 Restricted cash 8 5 Other current assets — 1 TOTAL CURRENT ASSETS 11 8 NON-UTILITY PLANT Non-utility property, net accumulated depreciation 59 76 NET PLANT 59 76 OTHER NONCURRENT ASSETS Intangible assets, less accumulated amortization 56 72 Operating lease right-of-use asset 7 7 TOTAL OTHER NONCURRENT ASSETS 63 79 TOTAL ASSETS $133 $163 (Millions of Dollars) December 31, December 31, LIABILITIES CURRENT LIABILITIES Long-term debt due within one year $2 $2 Operating lease liabilities 2 2 Other current liabilities 10 4 TOTAL CURRENT LIABILITIES 14 8 NONCURRENT LIABILITIES Asset retirement obligations 3 3 Operating lease liabilities 5 5 TOTAL NONCURRENT LIABILITIES 8 8 LONG-TERM DEBT 57 60 TOTAL LIABILITIES $79 $76

Held-for-Sale Treatment of the

Held-for-Sale Treatment of the Clean Energy Businesses	12 Months Ended
Held-for-Sale Treatment of the Clean Energy Businesses	Dec. 31, 2024
Discontinued Operations and Disposal Groups [Abstract]
Held-for-Sale Treatment of the Clean Energy Businesses	Dispositions Clean Energy Businesses During the first nine months of 2022, Con Edison considered strategic alternatives with respect to the Clean Energy Businesses. On October 1, 2022, following the conclusion of such review and to allow for continued focus on the Utilities and their clean energy transition, Con Edison entered into a purchase and sale agreement pursuant to which Con Edison agreed to sell all of the stock of the Clean Energy Businesses to RWE Renewables Americas, LLC, a subsidiary of RWE for a total of $6,800 million, subject to closing adjustments. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses to RWE for $3,993 million. The preliminary purchase price at the March 1, 2023 closing was adjusted (i) upward for certain cash and cash equivalents, (ii) downward for certain indebtedness and debt-like items, (iii) downward for certain transaction expenses, (iv) downward to the extent that the net working capital varied from a set target, (v) upward to the extent that capital expenditures incurred prior to the closing of the transaction varied from a set budget, and (vi) downward by the value allocated to Broken Bow II, a project that was not able to be conveyed to RWE upon closing of the transaction. The process to finalize the purchase price was completed during the second quarter of 2024. The final purchase price was subject to customary adjustments for timing differences and a final valuation report, among other factors. The transaction was completed at arm’s length and RWE was not, and will not be, considered a related party to Con Edison. The sale on March 1, 2023 included all assets, operations and projects of the Clean Energy Businesses with the exception of tax equity interests in three projects, described below, that Con Edison continues to retain, and one deferred project, Broken Bow II, a 75 MW nameplate capacity wind power project located in Nebraska. See Note X. In January 2025, Con Edison completed the sale and transfer of Broken Bow II to RWE and the corresponding value of $54 million (net of assumed debt and other final adjustments) was paid to Con Edison. RWE Renewables Americas, LLC operated the facility on behalf of Con Edison until the transfer to RWE pursuant to certain service agreements, for which the fees were not material. For the year ended December 31, 2023, Con Edison's preliminary gain on the sale of all of the stock of the Clean Energy Businesses was $865 million ($767 million, after tax). The portion of the gain attributable to the non-controlling interest retained in certain tax-equity projects was not material. For the year ended December 31, 2024, the gain on the sale of all of the stock of the Clean Energy Businesses was adjusted downward by $62 million ($46 million after-tax) in aggregate due to certain customary closing adjustments, including $33 million ($25 million after-tax) to align with the consideration received upon the sale and transfer of Broken Bow II in January 2025. See Note X. Con Edison retained the Clean Energy Businesses' tax equity investment interest in the Crane solar project and another tax equity investment interest in two solar projects located in Virginia. These tax equity partnerships produced renewable energy tax credits that can be used to reduce Con Edison’s federal income tax. These tax credits are subject to recapture, in whole or in part, if the assets are sold within a five -year period beginning on the date on which the assets are placed in service. Con Edison will continue to employ HLBV accounting for its interests in these tax equity partnerships. The combined carrying value of the retained tax equity interests was $4 million and $13 million at December 31, 2024 and 2023, respectively . Con Edison also retained any post-sale deferred income taxes (federal and state income taxes, including tax attributes), any valuation allowances associated with the deferred tax assets, all current federal taxes and New York State taxes and the estimated liability for uncertain tax positions. The unamortized deferred investment tax credits of the Clean Energy Businesses were recognized in full upon the completion of the sale of all of the stock of the Clean Energy Businesses. Concurrent with entering into the purchase and sale agreement, Con Edison incurred costs in the normal course of the sale process. Transaction costs of $48 million ($35 million after-tax), $12 million ($9 million after-tax) and an immaterial amount were recorded during 2022, 2023, and 2024, respectively. Also, depreciation and amortization expense of approximately $41 million ($28 million after-tax) were not recorded on the assets of the Clean Energy Businesses in 2023 prior to the closing of the transaction. Following the sale of all of the stock of the Clean Energy Businesses and pursuant to a reimbursement and indemnity agreement with RWE, Con Edison remains responsible for certain potential costs related to a battery storage project located in Imperial County, California. Con Edison's exposure under the agreement could range up to approximate ly $172 million. As of December 31, 2024, no material amounts wer e recorded as liabilities on Con Edison's consolidated balance sheet related to this agreement. During 2023, Con Edi son received $24 million of net proceeds from this battery storage project. Con Edison had $4 million of unbilled contract revenue recorded as of December 31, 2023 and 2024. See Note M. The following table shows the pre-tax operating income for the Clean Energy Businesses. The 2023 period shown is through the date of the sale of the Clean Energy Businesses; there is no applicable data for the year ended December 31, 2024. For the Year Ended December 31, (Millions of Dollars) 2023 2022 Pre-tax operating income $25 $466 Pre-tax operating income, excluding non-controlling interest 21 406 On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W. The sale included all assets, operations and projects of the Clean Energy Businesses with the exception of tax equity interests in three projects and one deferred project, Broken Bow II, a 75 MW nameplate capacity wind power project located in Nebraska. In January 2025, Con Edison completed the sale and transfer of Broken Bow II to RWE and the corresponding value of $54 million (net of assumed debt and other final adjustments) was paid to Con Edison. RWE Renewables Americas, LLC operated the facility on behalf of Con Edison until the transfer to RWE pursuant to certain service agreements, for which the fees were not material. Following the sale and transfer of Broken Bow II in January 2025, Con Edison did not have any assets or liabilities recorded on a held-for-sale basis. For the year ended December 31, 2024, the book value of the assets of Broken Bow II were reduced to align with the consideration received upon the transfer of the project in January 2025, resulting in a downward adjustment to the cumulative gain on the sale of all of the stock of the Clean Energy Businesses of $33 million ($25 million after-tax). See Note W. The carrying amounts of the major classes of assets and liabilities of Broken Bow II, that were transferred from Con Edison to RWE in January 2025, were presented on a held-for-sale basis as of December 31, 2023 and 2024 , and accordingly, excluded net deferred tax liability balances, as follows: (Millions of Dollars) December 31, December 31, ASSETS CURRENT ASSETS Cash and temporary cash investments $1 $— Accounts receivable and other receivables - net allowance for uncollectible accounts 2 1 Accrued unbilled revenue — 1 Restricted cash 8 5 Other current assets — 1 TOTAL CURRENT ASSETS 11 8 NON-UTILITY PLANT Non-utility property, net accumulated depreciation 59 76 NET PLANT 59 76 OTHER NONCURRENT ASSETS Intangible assets, less accumulated amortization 56 72 Operating lease right-of-use asset 7 7 TOTAL OTHER NONCURRENT ASSETS 63 79 TOTAL ASSETS $133 $163 (Millions of Dollars) December 31, December 31, LIABILITIES CURRENT LIABILITIES Long-term debt due within one year $2 $2 Operating lease liabilities 2 2 Other current liabilities 10 4 TOTAL CURRENT LIABILITIES 14 8 NONCURRENT LIABILITIES Asset retirement obligations 3 3 Operating lease liabilities 5 5 TOTAL NONCURRENT LIABILITIES 8 8 LONG-TERM DEBT 57 60 TOTAL LIABILITIES $79 $76

Schedule I - Condensed Financia

Schedule I - Condensed Financial Information	12 Months Ended
Schedule I - Condensed Financial Information	Dec. 31, 2024
Condensed Financial Information Disclosure [Abstract]
Schedule I - Condensed Financial Information	Schedule I Condensed Financial Information of Consolidated Edison, Inc. (a) Condensed Statement of Income and Comprehensive Income (Parent Company Only) For the Years Ended December 31, (Millions of Dollars, except per share amounts) 2024 2023 2022 Equity in earnings of subsidiaries $1,904 $1,759 $1,860 Other operating and maintenance expenses (1) — (1) Taxes other than income taxes (12) (2) (7) Other income (deductions) (14) 7 (31) Interest expense (18) (14) (32) Income tax benefit (expense) 23 (96) (129) Gain (Loss) on the sale of the Clean Energy Businesses (62) 865 — Net Income $1,820 $2,519 $1,660 Comprehensive Income $1,827 $2,520 $1,677 Net Income Per Share – Basic $5.26 $7.25 $4.68 Net Income Per Share – Diluted $5.24 $7.21 $4.66 Dividends Declared Per Share $3.32 $3.24 $3.16 Average Number Of Shares Outstanding—Basic (In Millions) 346.0 347.7 354.5 Average Number Of Shares Outstanding—Diluted (In Millions) 347.3 349.3 355.8 (a) These financial statements, in which Con Edison’s subsidiaries have been included using the equity method, should be read together with its consolidated financial statements and the notes thereto appearing above. Condensed Financial Information of Consolidated Edison, Inc. (a) Condensed Statement of Cash Flows (Parent Company Only) For the Years Ended December 31, (Millions of Dollars) 2024 2023 2022 Net Cash Flows From Operating Activities $1,204 $772 $1,015 Investing Activities Contributions to subsidiaries (175) (1,854) (150) Proceeds from sale of the Clean Energy Businesses, net of cash and cash equivalents sold — 3,927 — Net Cash Flows From (Used in) Investing Activities (175) 2,073 (150) Financing Activities Net issuance (payment) of short-term debt 9 57 232 Issuance of term loan — 200 400 Retirement of term loan — (600) — Retirement of long-term debt — (650) (293) Repurchase of common shares — (1,000) — Issuance of common shares for stock plans 60 56 57 Common stock dividends (1,100) (1,096) (1,089) Net Cash Flows Used in Financing Activities (1,031) (3,033) (693) Net Change for the Period (2) (188) 172 Balance at Beginning of Period 3 191 19 Balance at End of Period $1 $3 $191 (a) These financial statements, in which Con Edison’s subsidiaries have been included using the equity method, should be read together with its consolidated financial statements and the notes thereto appearing above. Condensed Financial Information of Consolidated Edison, Inc. (a) Condensed Balance Sheet (Parent Company Only) December 31, (Millions of Dollars) 2024 2023 Assets Current Assets Cash and temporary cash investments $1 $3 Other receivables, net allowance for uncollectible accounts 64 103 Tax receivable 145 1 Accounts receivable from affiliated companies 300 343 Accrued unbilled revenue 3 4 Prepayments 13 109 Other current assets 1 3 Total Current Assets 527 566 Investments in subsidiaries and others 21,706 20,778 Goodwill 406 406 Pension and retiree benefits - asset 6 5 Other deferred charges and noncurrent assets 356 249 Total Assets $23,001 $22,004 Liabilities and Shareholders’ Equity Current Liabilities Notes payable $348 $339 Accounts payable 17 30 Accounts payable to affiliated companies 14 12 Accrued taxes 2 15 Accrued taxes to affiliated companies 646 437 Other current liabilities 9 8 Total Current Liabilities 1,036 841 Other noncurrent liabilities 4 5 Total Liabilities 1,040 846 Shareholders’ Equity Common stock, including additional paid-in capital 10,024 9,898 Retained earnings 11,937 11,260 Total Shareholders’ Equity 21,961 21,158 Total Liabilities and Shareholders’ Equity $23,001 $22,004 (a) These financial statements, in which Con Edison’s subsidiaries have been included using the equity method, should be read together with its consolidated financial statements and the notes thereto appearing above.

Pay vs Performance Disclosure

Pay vs Performance Disclosure - USD ($) $ in Millions	12 Months Ended
Pay vs Performance Disclosure - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Pay vs Performance Disclosure
NET INCOME	$ 1,820	$ 2,519	$ 1,660

Insider Trading Arrangements

Insider Trading Arrangements	3 Months Ended
Insider Trading Arrangements	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
Insider Trading Policies and Procedures	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
Cybersecurity Risk Management and Strategy Disclosure	Dec. 31, 2024
Cybersecurity Risk Management, Strategy, and Governance [Line Items]
Cybersecurity Risk Management Processes for Assessing, Identifying, and Managing Threats [Text Block]	The Companies have identified cybersecurity as a key enterprise risk. As operators of critical energy infrastructure, the Companies require the continuous operation of information systems and network infrastructure. Cybersecurity threats are assessed, identified and managed as part of the Companies’ corporate-wide Enterprise Risk Management (ERM) program. The ERM program establishes processes to identify emerging issues; monitor, assess and mitigate known risks; align risk exposure to organizational priorities; and inform business decisions and resource allocation; and leverages, among others, the National Institute of Standards and Technology framework to help inform the Companies' processes around cybersecurity risk management. In accordance with the Companies’ ERM program, management has established a multidisciplinary cybersecurity team including personnel from the technology, operations, legal, compliance, and risk management departments that identifies, assesses and remediates cybersecurity risks. The Companies employ several processes to manage their cybersecurity risks, including, but not limited to, the following: • Incident Detection and Prevention : The Companies deploy safeguards designed to protect their operational and information systems, the personal information of their customers and employees and other critical information from cybersecurity threats. These safeguards include, among other things, intrusion prevention and detection systems, anti-malware functionality and ongoing vulnerability assessments. • Review and Assessment : The Companies assess the severity, likelihood and controllability of cybersecurity threats and consider risk outlook, recent external and internal cybersecurity events and audit findings to assess their overall cybersecurity risk management process. The Companies then use the findings from these assessments to inform cybersecurity risk mitigation activities, including long-term strategic and short-term tactical efforts, and capital allocation decisions. • Independent Advisors : The Companies engage consultants to assess, identify and manage material risks from cybersecurity threats on a regular basis. The consultants are engaged to, among other things, assess the process by which cybersecurity threats are identified; provide incident response and forensic services; review and analyze cybersecurity controls and infrastructure; and provide threat emulation services. • Third-Party Risk Assessments : The Companies’ vendors and suppliers participate in a third-party risk assessment to periodically validate such party’s profile across multiple risk domains. A cybersecurity risk assessment is performed by the Companies’ Information Technology department to assess the controls of high-risk third parties that, among other things, possess the Companies’ sensitive information and the personal information of their customers and employees. In addition, the Companies typically impose contractual obligations on their vendors and suppliers related to privacy, confidentiality, and data security based on their access to the Companies’ data, operational and information technology systems and sensitive information and the personal information of their customers and employees. • Disclosure Controls and Procedures : Management has developed protocols and procedures to share information regarding cybersecurity incidents with the Chief Information Security Officer, Chief Privacy Officer, the Companies’ Disclosure Committee and the Law Department to enable assessments related to disclosure and reporting obligations in compliance with federal and state cybersecurity and data privacy regulations. • Incident Response : The Companies have established and maintain incident response plans that set forth procedures for their response to cybersecurity incidents and data breaches and test and evaluate such plans on an ongoing basis. • Training and Compliance : The Companies train employees regularly on potential cybersecurity threats; monitor network and computing systems; collaborate with government and industry partners on threat mitigation; collaborate with local, state and federal agencies and utility industry colleagues to identify and employ tools that seek to protect the Companies’ operational and information systems and the personal information of their customers and employees from cybersecurity threats; and regularly conduct and participate in exercises to test and further develop prevention and responses to potential cyber and physical threats, both internally and through sector-level and cross-sector exercises led by industry or the U.S. government.
Cybersecurity Risk Management Processes Integrated [Flag]	true
Cybersecurity Risk Management Processes Integrated [Text Block]	The Companies have identified cybersecurity as a key enterprise risk. As operators of critical energy infrastructure, the Companies require the continuous operation of information systems and network infrastructure. Cybersecurity threats are assessed, identified and managed as part of the Companies’ corporate-wide Enterprise Risk Management (ERM) program. The ERM program establishes processes to identify emerging issues; monitor, assess and mitigate known risks; align risk exposure to organizational priorities; and inform business decisions and resource allocation; and leverages, among others, the National Institute of Standards and Technology framework to help inform the Companies' processes around cybersecurity risk management. In accordance with the Companies’ ERM program, management has established a multidisciplinary cybersecurity team including personnel from the technology, operations, legal, compliance, and risk management departments that identifies, assesses and remediates cybersecurity risks.
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 Board of Directors Oversight [Text Block]	The Companies have established a cybersecurity team that manages the Companies’ cybersecurity risk. The cybersecurity team is led by the Vice President and Chief Information Security Officer, a technology leader with over 15 years of experience in information technology and cybersecurity. The cybersecurity team reports to a multidisciplinary team of executives and senior officers including personnel from the technology and operations departments who are responsible for the review and approval of changes in cybersecurity risk assessment and have oversight of risk mitigation and monitoring strategies. The executive and senior officer team is led by the Senior Vice President and Chief Information Officer, a senior global technology and operations leader with over 30 years of experience in the technology field and who is responsible for the Companies’ information technology and corporate security departments.
Cybersecurity Risk Board Committee or Subcommittee Responsible for Oversight [Text Block]	The Companies have established a cybersecurity team that manages the Companies’ cybersecurity risk. The cybersecurity team is led by the Vice President and Chief Information Security Officer, a technology leader with over 15 years of experience in information technology and cybersecurity. The cybersecurity team reports to a multidisciplinary team of executives and senior officers including personnel from the technology and operations departments who are responsible for the review and approval of changes in cybersecurity risk assessment and have oversight of risk mitigation and monitoring strategies. The executive and senior officer team is led by the Senior Vice President and Chief Information Officer, a senior global technology and operations leader with over 30 years of experience in the technology field and who is responsible for the Companies’ information technology and corporate security departments.
Cybersecurity Risk Process for Informing Board Committee or Subcommittee Responsible for Oversight [Text Block]	Con Edison’s Board of Directors and CECONY’s Board of Trustees (collectively, the Board) and their respective Audit Committees oversee the management of risks from cybersecurity threats, including the policies, processes and practices that management implements to address risks from cybersecurity threats. There is a process in place for the Board and the Audit Committee to receive quarterly updates and information from the Senior Vice President and Chief Information Officer and the Vice President and Chief Information Security Officer, regarding significant and potentially significant cybersecurity incidents and a range of cybersecurity metrics. The Board receives an annual presentation and report on cybersecurity risks from the Senior Vice President and Chief Information Officer and the Vice President and Chief Information Security Officer that addresses various topics, such as recent developments, vulnerability assessments and third-party and independent reviews. The Audit Committee also meets annually with the Senior Vice President and Chief Information Officer in executive session, without management present.
Cybersecurity Risk Role of Management [Text Block]	The Companies have established a cybersecurity team that manages the Companies’ cybersecurity risk. The cybersecurity team is led by the Vice President and Chief Information Security Officer, a technology leader with over 15 years of experience in information technology and cybersecurity. The cybersecurity team reports to a multidisciplinary team of executives and senior officers including personnel from the technology and operations departments who are responsible for the review and approval of changes in cybersecurity risk assessment and have oversight of risk mitigation and monitoring strategies. The executive and senior officer team is led by the Senior Vice President and Chief Information Officer, a senior global technology and operations leader with over 30 years of experience in the technology field and who is responsible for the Companies’ information technology and corporate security departments. The cybersecurity team’s processes to protect the personal information of the Companies’ customers and employees are supported by a privacy compliance team. The privacy compliance team is led by the Chief Privacy Officer, a professional with over 18 years of experience in data privacy risk and compliance and who is a Certified Information Privacy Professional and a Certified Information Privacy Manager and is designated as a Fellow in Privacy. The Chief Privacy Officer reports to the Vice President and Chief Ethics and Compliance Officer, an attorney and executive who has over 25 years of experience in the legal, ethics, and compliance fields and is responsible for the company’s ethics and compliance program and department, including data privacy compliance. The Chief Ethics and Compliance Officer reports to the Senior Vice President and General Counsel, the Companies’ lead attorney and a senior executive with over 20 years of risk management, corporate governance and team leadership experience. Role of Board of Directors and Board of Trustees in Cybersecurity Risk Management Con Edison’s Board of Directors and CECONY’s Board of Trustees (collectively, the Board) and their respective Audit Committees oversee the management of risks from cybersecurity threats, including the policies, processes and practices that management implements to address risks from cybersecurity threats. There is a process in place for the Board and the Audit Committee to receive quarterly updates and information from the Senior Vice President and Chief Information Officer and the Vice President and Chief Information Security Officer, regarding significant and potentially significant cybersecurity incidents and a range of cybersecurity metrics. The Board receives an annual presentation and report on cybersecurity risks from the Senior Vice President and Chief Information Officer and the Vice President and Chief Information Security Officer that addresses various topics, such as recent developments, vulnerability assessments and third-party and independent reviews. The Audit Committee also meets annually with the Senior Vice President and Chief Information Officer in executive session, without management present.
Cybersecurity Risk Management Positions or Committees Responsible [Flag]	true
Cybersecurity Risk Management Positions or Committees Responsible [Text Block]	The Companies have established a cybersecurity team that manages the Companies’ cybersecurity risk. The cybersecurity team is led by the Vice President and Chief Information Security Officer, a technology leader with over 15 years of experience in information technology and cybersecurity. The cybersecurity team reports to a multidisciplinary team of executives and senior officers including personnel from the technology and operations departments who are responsible for the review and approval of changes in cybersecurity risk assessment and have oversight of risk mitigation and monitoring strategies. The executive and senior officer team is led by the Senior Vice President and Chief Information Officer, a senior global technology and operations leader with over 30 years of experience in the technology field and who is responsible for the Companies’ information technology and corporate security departments.
Cybersecurity Risk Management Expertise of Management Responsible [Text Block]	The cybersecurity team’s processes to protect the personal information of the Companies’ customers and employees are supported by a privacy compliance team. The privacy compliance team is led by the Chief Privacy Officer, a professional with over 18 years of experience in data privacy risk and compliance and who is a Certified Information Privacy Professional and a Certified Information Privacy Manager and is designated as a Fellow in Privacy. The Chief Privacy Officer reports to the Vice President and Chief Ethics and Compliance Officer, an attorney and executive who has over 25 years of experience in the legal, ethics, and compliance fields and is responsible for the company’s ethics and compliance program and department, including data privacy compliance. The Chief Ethics and Compliance Officer reports to the Senior Vice President and General Counsel, the Companies’ lead attorney and a senior executive with over 20 years of risk management, corporate governance and team leadership experience.
Cybersecurity Risk Process for Informing Management or Committees Responsible [Text Block]	Con Edison’s Board of Directors and CECONY’s Board of Trustees (collectively, the Board) and their respective Audit Committees oversee the management of risks from cybersecurity threats, including the policies, processes and practices that management implements to address risks from cybersecurity threats. There is a process in place for the Board and the Audit Committee to receive quarterly updates and information from the Senior Vice President and Chief Information Officer and the Vice President and Chief Information Security Officer, regarding significant and potentially significant cybersecurity incidents and a range of cybersecurity metrics. The Board receives an annual presentation and report on cybersecurity risks from the Senior Vice President and Chief Information Officer and the Vice President and Chief Information Security Officer that addresses various topics, such as recent developments, vulnerability assessments and third-party and independent reviews. The Audit Committee also meets annually with the Senior Vice President and Chief Information Officer in executive session, without management present.
Cybersecurity Risk Management Positions or Committees Responsible Report to Board [Flag]	true

Summary of Significant Accoun_2

Summary of Significant Accounting Policies and Other Matters (Policies)	12 Months Ended
	Dec. 31, 2024
Accounting Policies [Abstract]
Principles of Consolidation	Principles of Consolidation The Companies’ consolidated financial statements include the accounts of their respective majority-owned subsidiaries, and variable interest entities (see Note S), as required. All intercompany balances and intercompany transactions have been eliminated.
Accounting Policies	Accounting Policies The accounting policies of Con Edison and its subsidiaries conform to generally accepted accounting principles in the United States of America (GAAP). For the Utilities, these accounting principles include the accounting rules for regulated operations and the accounting requirements of the Federal Energy Regulatory Commission (FERC) and the state regulators having jurisdiction. The accounting rules for regulated operations specify the economic effects that result from the causal relationship of costs and revenues in the rate-regulated environment and how these effects are to be accounted for by a regulated enterprise. Revenues intended to cover some costs may be recorded either before or after the costs are incurred. If regulation provides assurance that incurred costs will be recovered in the future, these costs would be recorded as deferred charges or “regulatory assets” under the accounting rules for regulated operations. If revenues are recorded for costs that are expected to be incurred in the future, these revenues would be recorded as deferred credits or “regulatory liabilities” under the accounting rules for regulated operations. The Utilities’ principal regulatory assets and liabilities are detailed in Note B. In general, the Utilities are receiving or being credited with a return on their regulatory assets for which a cash outflow has been made, and are paying or being charged with a return on their regulatory liabilities for which a cash inflow has been received. The Utilities’ regulatory assets and liabilities at December 31, 2024 are recoverable from customers, or to be applied for customer benefit, in accordance with rate provisions that have been approved by state regulators.
Revenues	Revenues CECONY’s electric and gas rate plans and O&R’s New York electric and gas rate plans each contain a revenue decoupling mechanism, that covers all residential and most commercial customers, under which the company’s actual energy delivery revenues are compared with the authorized delivery revenues and the difference accrued, with interest, for refund to, or recovery from, customers, as applicable. See “Rate Plans” in Note B.
Plant and Depreciation Utility Plant / Non-Utility Plant	Plant and Depreciation Utility Plant Utility plant is stated at original cost. The cost of repairs and maintenance is charged to expense and the cost of betterments is capitalized. The capitalized cost of additions to utility plant includes indirect costs such as engineering, supervision, payroll taxes, pensions, other benefits and an allowance for funds used during construction (AFUDC). The original cost of property is charged to expense over the estimated useful lives of the assets. Upon retirement, the original cost of property is charged to accumulated depreciation. See Note T. Rates used for AFUDC include the cost of borrowed funds and a reasonable rate of return on the Utilities’ own funds when so used, determined in accordance with regulations of the FERC or the state public utility regulatory authority having jurisdiction. The rate is compounded semiannually, and the amounts applicable to borrowed funds are treated as a reduction of interest charges, while the amounts applicable to the Utilities’ own funds are credited to other income (deductions). The AFUDC rates for CECONY were 5.9 percent, 5.9 percent and 5.2 percent for 2024, 2023 and 2022, respectively. The AFUDC rates for O&R were 6.0 percent, 6.2 percent and 5.0 percent for 2024, 2023 and 2022, respectively. The Utilities generally compute annual charges for depreciation using the straight-line method for financial statement purposes, with rates based on average service lives and net salvage factors. The average depreciation rates for CECONY were 3.6 percent for 2024, 3.6 percent for 2023 and 3.5 percent for 2022. The average depreciation rates for O&R were 3.3 percent for 2024, 3.1 percent for 2023 and 3.0 percent for 2022. The estimated lives for utility plant for CECONY range from 5 to 80 years for electric, 5 to 80 years for gas, 5 to 55 years for steam and 5 to 50 years for general plant. For O&R, the estimated lives for utility plant range from 5 to 75 years for electric and gas and 5 to 50 years for general plant. Non–Utility Plant Non-utility plant is stated at original cost. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W and X. For Con Edison, non-utility plant consisted primarily of the Clean Energy Businesses’ renewable electric projects. Property, plant and equipment are stated at cost, less accumulated depreciation and include capitalized interest during construction. Depreciation is computed under the straight-line method over the useful lives of the assets. Solar power generating assets and wind power generating assets have useful lives of 35 years and 30 years, respectively. For the Utilities, non-utility plant consists of land and conduit for telecommunication use. Depreciation on non-utility plant, other than land, is computed using the straight-line method for financial statement purposes over their estimated useful lives, which is 10 years.
Long-Lived and Intangible Assets	Long–Lived and Intangible Assets The Companies test long-lived and intangible assets for recoverability when events or changes in circumstances indicate that the carrying value of long-lived or intangible assets may not be recoverable. The carrying amount of a long-lived asset or intangible asset with a definite life is deemed not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the assets. In the event a test indicates that such cash flows cannot be expected to be sufficient to fully recover the assets, the assets are considered impaired and written down to their estimated fair value.
Recoverable Energy Costs/New York Independent System Operator (NYISO)	Recoverable Energy Costs The Utilities generally recover all of their prudently incurred fuel, purchased power and gas costs, including hedging gains and losses, in accordance with rate provisions approved by the applicable state public utility regulators. If the actual energy supply costs for a given month are more or less than the amounts billed to customers for that month, the difference in most cases is recoverable from or refundable to customers. Differences between actual and billed electric and steam supply costs are generally deferred for charge or refund to customers during the next billing cycle (normally within one New York Independent System Operator (NYISO) The Utilities purchase electricity through the wholesale electricity market administered by the NYISO. The difference between purchased power and related costs initially billed to the Utilities by the NYISO and the actual cost of power subsequently calculated by the NYISO is refunded by the NYISO to the Utilities, or paid to the NYISO by the Utilities. The reconciliation payments or receipts are recoverable from or refundable to the Utilities’ customers. Certain other payments to or receipts from the NYISO are also subject to reconciliation, with shortfalls or amounts in excess of specified rate allowances recoverable from or refundable to customers. These include proceeds from the sale through the NYISO of transmission rights on CECONY’s transmission system (transmission congestion contracts or TCCs).
Temporary Cash Investments	Temporary Cash Investments Temporary cash investments are short-term, highly-liquid investments that generally have maturities of three months or less at the date of purchase. They are stated at cost, which approximates market. The Companies consider temporary cash investments to be cash equivalents.
Investments	Investments Accounting for Investments Con Edison’s investments consist primarily of the investments of Con Edison Transmission that are accounted for under the equity method and the fair value of the Utilities’ supplemental retirement income plan and deferred income plan assets. The accounting rules require Con Edison to evaluate its investments periodically to determine whether they are impaired. The standard for determining whether an impairment exists and must be recorded is whether an other-than-temporary decline in carrying value has occurred. Changes in economic conditions, forecasted cash flows and the regulatory environment, among other factors, could require equity method investments to recognize a decrease in carrying value for an other-than-temporary decline. When management believes such a decline may have occurred, the fair value of the investment is estimated using market inputs, when observable, or a valuation model such as a discounted cash flow analysis. The fair value is compared to the carrying value of the investment in order to determine the amount of impairment to record, if any. The evaluation and measurement of impairments involve uncertainties. The judgments that Con Edison makes to estimate the fair value of its equity method investments are based on assumptions that management believes are reasonable, and variations in these estimates or the underlying assumptions, or the receipt of additional market information, could have a material impact on whether a triggering event is determined to exist or the amount of any such impairment. Additionally, if the projects in which Con Edison holds these investments recognize an impairment, Con Edison may record a share of that impairment loss and would evaluate its investment for an other-than-temporary decline in carrying value as described above. Con Edison Transmission is considering strategic alternatives with respect to its investment in MVP and both Con Edison Transmission and CECONY are considering strategic alternatives with respect to their investments in Honeoye. Investment in Mountain Valley Pipeline, LLC (MVP)
Pension and Other Postretirement Benefits	Pension and Other Postretirement Benefits The accounting rules for retirement benefits require an employer to recognize an asset or liability for the overfunded or underfunded status of its pension and other postretirement benefit plans. For a pension plan, the asset or liability is the difference between the fair value of the plan’s assets and the projected benefit obligation. For any other postretirement benefit plan, the asset or liability is the difference between the fair value of the plan’s assets and the accumulated postretirement benefit obligation. The accounting rules generally require employers to recognize all unrecognized prior service costs and credits and unrecognized actuarial gains and losses in accumulated other comprehensive income/(loss) (OCI), net of tax. Such amounts will be adjusted as they are subsequently recognized as components of total periodic benefit cost or income pursuant to the current recognition and amortization provisions. For the Utilities’ pension and other postretirement benefit plans, regulatory accounting treatment is generally applied in accordance with the accounting rules for regulated operations. Unrecognized prior service costs or credits and unrecognized actuarial gains and losses are recorded to regulatory assets or liabilities, rather than OCI. See Notes E and F. The total periodic benefit costs are recognized in accordance with the accounting rules for retirement benefits. Investment gains and losses are recognized in expense over a 15-year period and other actuarial gains and losses are recognized in expense over a 10-year period, subject to the deferral provisions in the rate plans. In accordance with the Statement of Policy issued by the NYSPSC and its current electric, gas and steam rate plans, CECONY defers for payment to or recovery from customers the difference between such expenses and the amounts for such expenses reflected in rates. O&R also defers such difference pursuant to its NY rate plans. See Note B. The Companies calculate the expected return on pension and other postretirement benefit plan assets by multiplying the expected rate of return on plan assets by the market-related value (MRV) of plan assets at the beginning of the year, taking into consideration anticipated contributions and benefit payments that are to be made during the year. The accounting rules allow the MRV of plan assets to be either fair value or a calculated value that recognizes changes in fair value in a systematic and rational manner over not more than five years. The Companies use a calculated value when determining the MRV of the plan assets that adjusts for 20 percent of the difference between fair value and expected MRV of plan assets. This calculated value has the effect of stabilizing variability in assets to which the Companies apply the expected return.
Federal Income Tax/State Income Tax	Federal Income Tax In accordance with accounting rules for income taxes, the Companies have recorded an accumulated deferred federal income tax liability at current tax rates for temporary differences between the book and tax basis of assets and liabilities. In accordance with rate plans, the Utilities have recovered amounts from customers for a portion of the tax liability they will pay in the future as a result of the reversal or “turn-around” of these temporary differences. As to the remaining deferred tax liability, the Utilities had established regulatory assets for the net revenue requirements to be recovered from customers for the related future tax expense pursuant to the NYSPSC's 1993 Policy Statement approving accounting procedures consistent with accounting rules for income taxes and providing assurances that these future increases in taxes will be recoverable in rates. Accumulated deferred investment tax credits are amortized ratably over the lives of the related properties and applied as a reduction to future federal income tax expense. Con Edison and its subsidiaries file a consolidated federal income tax return. The consolidated income tax liability is allocated to each member of the consolidated group using the separate return method. Each member pays or receives an amount based on its own taxable income or loss in accordance with a consolidated tax allocation agreement. Tax loss and tax credit carryforwards are allocated among members in accordance with consolidated tax return regulations. State Income Tax Con Edison and its subsidiaries file a combined New York State Corporation Business Franchise Tax Return. Similar to a federal consolidated income tax return, the income of all entities in the combined group is subject to New York State taxation, after adjustments for differences between federal and New York law and apportionment of income among the states in which the company does business. Each member’s share of the New York State tax is based on its own New York State taxable income or loss.
Reclassification	Reclassification
Earnings Per Common Share	Earnings Per Share Con Edison presents basic and diluted earnings per share (EPS) on the face of its consolidated income statement. Basic EPS is calculated by dividing earnings available to common shareholders (“Net income for common stock” on Con Edison’s consolidated income statement) by the weighted average number of Con Edison common shares outstanding during the period. In the calculation of diluted EPS, weighted average shares outstanding are increased for additional shares that would be outstanding if potentially dilutive securities were converted to common stock.
Estimates	Estimates The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
New Financial Accounting Standards	New Financial Accounting Standards In December 2023, the FASB issued amendments to the guidance on accounting for Income Taxes (Topic 740) through ASU 2023-09 to improve disclosures related to income taxes. The amendments focus on three key areas: rate reconciliation, income taxes paid, and income (or loss)/income tax expense (or benefit) from disaggregated continuing operations. For public entities, the amendments are effective for annual reporting periods beginning after December 15, 2024. Early adoption is permitted for annual financial statements. The Companies do not expect the new guidance to have a material impact on their financial position, results of operations and liquidity. In November 2024, the FASB issued ASU 2024-03, Income Statement—Reporting Comprehensive Income—Expense Disaggregation Disclosures (Subtopic 220-40) to improve disclosures about a public business entity's expenses. The ASU addresses requests from investors for more detailed information about the types of expenses (including purchases of inventory, employee compensation, depreciation, amortization, and depletion) in commonly presented expense captions. The amendments require a public business entity to disclose, in the notes to the financial statements, specified information about certain costs and expenses at each interim and annual reporting period. The amendments are effective for annual reporting periods beginning after December 15, 2026, and interim reporting periods beginning after December 15, 2027. Early adoption is permitted. The Companies are in the process of evaluating the potential impact of the ASU on their financial position, results of operations and liquidity.

Summary of Significant Accoun_3

Summary of Significant Accounting Policies and Other Matters (Tables)	12 Months Ended
	Dec. 31, 2024
Accounting Policies [Abstract]
Schedule of Total Excise Taxes Recorded in Operating Revenues	Total excise taxes (inclusive of gross receipts taxes) recorded in operating revenues were as follows: For the Years Ended December 31, (Millions of Dollars) 2024 2023 2022 Con Edison $437 $409 $400 CECONY 425 396 387
Capitalized Cost of Utility Plant	December 31, 2024 and 2023, was as follows: Con Edison CECONY (Millions of Dollars) 2024 2023 2024 2023 Electric Generation $577 $580 $577 $580 Transmission 5,072 4,652 4,703 4,333 Distribution 25,129 24,491 23,770 23,238 General 174 141 174 141 Gas (a) 12,703 12,023 11,830 11,226 Steam 2,006 1,990 2,006 1,990 General 3,249 3,158 2,940 2,860 Held for future use 77 118 69 110 Construction work in progress 3,165 2,442 2,912 2,168 Net Utility Plant $52,152 $49,594 $48,981 $46,646 (a) Primarily distribution.
Schedule of Other Deferred Charges and Noncurrent Assets and Prepayments	Other deferred charges and noncurrent assets and prepayments, net of accumulated depreciation, included the following related to implementation costs incurred in cloud computing arrangements: Con Edison CECONY (Millions of Dollars) 2024 2023 2024 2023 Prepayments (a)(b) $57 $50 $54 $49 Other Deferred Charges and Noncurrent Assets (a)(b) 254 179 243 178 (a) Amortization on these assets is computed using the straight-line method for financial statement purposes over their estimated useful lives. (b) Amortization expense related to these assets incurred during the year ended December 31, 2024 for Con Edison and CECONY was $33 million and $32 million, respectively, for the year ended December 31, 2023 for Con Edison and CECONY was $21 million and $20 million, respectively, and for the year ended December 31, 2022 for Con Edison and CECONY was $15 million and $14 million, respectively. Accumulated amortization related to these assets for Con Edison and CECONY was $91 million and $85 million, respectively at December 31, 2024 and was $58 million and $53 million, respectively at December 31, 2023.
Schedule of Investment Assets	The following investment assets are included in the Companies' consolidated balance sheets at December 31, 2024 and 2023: Con Edison CECONY (Millions of Dollars) 2024 2023 2024 2023 Supplemental retirement income plan assets (b) $583 $524 $560 $502 Con Edison Transmission's investment in New York Transco (d) 254 221 — — Con Edison Transmission's investment in MVP (a) (d) 166 144 — — Deferred income plan assets 116 99 116 99 Virginia Tax Equity Projects (c) 4 8 — — Other 3 3 8 7 Total investments $1,126 $999 $684 $608 (a) At December 31, 2024 and 2023, Con Edison Transmission's cash investment in MVP was $530 million. In June 2024, MVP entered service at an overall project cost of approximately $8,100 million excluding allowance for funds used during construction. See "Investment in Mountain Valley Pipeline, LLC (MVP)" above. (b) See Note E. (c) See Note S. (d)
Basic and Diluted EPS	Basic and diluted EPS for Con Edison are calculated as follows: For the Years Ended December 31, (Millions of Dollars, except per share amounts/Shares in Millions) 2024 2023 2022 Net income for common stock $1,820 $2,519 $1,660 Weighted average common shares outstanding – basic 346.0 347.7 354.5 Add: Incremental shares attributable to effect of potentially dilutive securities 1.3 1.6 1.3 Adjusted weighted average common shares outstanding – diluted 347.3 349.3 355.8 Net Income per common share – basic $5.26 $7.25 $4.68 Net Income per common share – diluted $5.24 $7.21 $4.66
Restrictions on Cash and Cash Equivalents	At December 31, 2024 and 2023, cash, temporary cash investments and restricted cash for Con Edison were as follows; CECONY did not have material restricted cash balances as of December 31, 2024 and 2023: At December 31, Con Edison (Millions of Dollars) 2024 2023 Cash and temporary cash investments $1,324 $1,189 Restricted cash (a) 9 6 Total cash, temporary cash investments and restricted cash $1,333 $1,195 (a)
Schedule of Cash and Cash Equivalents	At December 31, 2024 and 2023, cash, temporary cash investments and restricted cash for Con Edison were as follows; CECONY did not have material restricted cash balances as of December 31, 2024 and 2023: At December 31, Con Edison (Millions of Dollars) 2024 2023 Cash and temporary cash investments $1,324 $1,189 Restricted cash (a) 9 6 Total cash, temporary cash investments and restricted cash $1,333 $1,195 (a)

Regulatory Matters (Tables)

Regulatory Matters (Tables)	12 Months Ended
Regulatory Matters (Tables)	Dec. 31, 2024
Regulated Operations [Abstract]
Summary of Utilities Rate Plans	The following tables contain a summary of the Utilities’ rate plans: CECONY – Electric Effective period January 2020 – December 2022 January 2023 – December 2025 Base rate changes Yr. 1 – $113 million (a) Yr. 2 – $370 million (a) Yr. 3 – $326 million (a) Yr. 1 – $442 million (c) Yr. 2 – $518 million (c) Yr. 3 – $382 million (c) Amortizations to income of net regulatory (assets) and liabilities Yr. 1 – $267 million (b) Yr. 2 – $269 million (b) Yr. 3 – $272 million (b) Yr. 1 – $104 million (j) Yr. 2 – $49 million (j) Yr. 3 – $(205) million (j) Other revenue sources Retention of $75 million of annual transmission congestion revenues. Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $69 million Yr. 2 - $74 million Yr. 3 - $79 million In 2020, 2021 and 2022, the company recorded $34 million, $64 million and $33 million primarily related to earnings adjustment mechanism incentives for energy efficiency, respectively. In 2022, the company recorded a positive incentive of $4 million. Retention of $75 million of annual transmission congestion revenues. Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $70 million Yr. 2 - $75 million Yr. 3 - $79 million In 2023 and 2024, the company recorded $34.4 million and $52.3 million primarily related to earnings adjustment mechanism incentives for energy efficiency, respectively. Revenue decoupling mechanisms Continuation of reconciliation of actual to authorized electric delivery revenues. In 2020, 2021 and 2022, the company deferred for recovery from customers $242 million, $226 million and $90 million of revenues, respectively. Continuation of reconciliation of actual to authorized electric delivery revenues. In 2023 and 2024, the company deferred for recovery from customers $162 million and $164 million of revenues, respectively. Recoverable energy costs Continuation of current rate recovery of purchased power and fuel costs. Continuation of current rate recovery of purchased power and fuel costs. Negative revenue adjustments Potential charges if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 - $450 million Yr. 2 - $461 million Yr. 3 - $476 million In 2020, the company recorded negative revenue adjustments of $5 million. In 2021, the company did not record any negative revenue adjustments. In 2022, the company recorded negative revenue adjustments of $3 million. Potential charges if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 - $516 million Yr. 2 - $557 million Yr. 3 - $597 million In 2023 and 2024, the company did not record any negative revenue adjustments. Regulatory reconciliations Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate debt, major storms, property taxes (d), municipal infrastructure support costs (e), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (f). In 2020 and 2021, the company deferred $288 million and $191 million of net regulatory assets, respectively. In 2022, the company deferred $138 million of net regulatory liabilities. Reconciliation of late payment charges (i) and expenses for uncollectibles, pension and other postretirement benefits, variable-rate debt, major storms, property taxes (d), municipal infrastructure support costs (e), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (f). In 2023 and 2024, the company deferred $140 million and $52 million of net regulatory liabilities, respectively. Net utility plant reconciliations Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 - $24,491 million Yr. 2 - $25,092 million Yr. 3 - $25,708 million AMI (h): Yr. 1 - $572 million Yr. 2 - $740 million Yr. 3 - $806 million In 2020, the company deferred $4.1 million as a regulatory asset. In 2021 and 2022, the company deferred $3.2 million and $1.8 million, as a regulatory liability, respectively. Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI) and Customer Service System (CSS) for Yr. 1: Yr. 1 - $27,847 million Yr. 2 - $29,884 million Yr. 3 - $31,026 million AMI (h): Yr. 1 - $744 million CSS: Yr. 1 - $11 million In 2023 and 2024, the company deferred $1.2 million and $(25.3) million as a regulatory asset and regulatory liability, respectively. Average rate base Yr. 1 - $21,660 million Yr. 2 - $22,783 million Yr. 3 - $23,926 million Yr. 1 - $26,095 million Yr. 2 - $27,925 million Yr. 3 - $29,362 million Weighted average cost of capital (after-tax) Yr. 1 to Yr. 3 – 6.61 percent Yr. 1 - 6.75 percent Yr. 2 - 6.79 percent Yr. 3 - 6.85 percent Authorized return on common equity 8.8 percent 9.25 percent Actual return on common equity (h) (i) Yr. 1 – 8.5 percent Yr. 2 – 8.03 percent Yr. 3 – 8.41 percent Yr. 1 – 9.46 percent Yr. 2 - 9.21 percent Earnings sharing Most earnings above an annual earnings threshold of 9.3 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2020, 2021 and 2022, the company had no earnings sharing above the threshold. A reserve of $4.3 million was recorded in 2021 related to a potential adjustment to the excess earnings sharing amount for 2016. Most earnings above an annual earnings threshold of 9.75 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2023 and 2024, the company had no earnings sharing above the threshold. Cost of long-term debt Yr. 1 to Yr. 3 – 4.63 percent Yr. 1 – 4.46 percent Yr. 2 – 4.54 percent Yr. 3 – 4.64 percent Common equity ratio 48 percent 48 percent (a) Base rates reflect recovery by the company of certain costs of its energy efficiency, demonstration projects, non-wire alternative projects (including the Brooklyn Queens demand management program), and off-peak electric vehicle charging programs (Yr. 1 - $206 million; Yr. 2 - $245 million; and Yr. 3 - $251 million) over a 10-year period, including the overall pre-tax rate of return on such costs. (b) Amounts reflect amortization of the 2018 tax savings under the federal Tax Cuts and Jobs Act of 2017 (TCJA) allocable to CECONY’s electric customers ($377 million) over a three-year period ($126 million annually), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s electric customers ($1,663 million) over the remaining lives of the related assets ($49 million in Yr. 1, $50 million in Yr. 2, and $53 million in Yr. 3) and the unprotected portion of the net regulatory liability ($784 million) over five years ($157 million annually). Amounts also reflect amortization of the regulatory asset for deferred MTA power reliability costs ($238 million) over a five-year period ($48 million annually). (c) The electric base rate increases shown above will be implemented with increases of $457 million in Yr. 1; $457 million in Yr. 2; and $457 million in Yr. 3 in order to levelize the customer bill impact. New rates were effective as of January 1, 2023 and CECONY began billing customers at the new levelized rate in August 2023. The shortfall in revenues due to the timing of billing to customers ($216 million) were collected through a surcharge billed through 2024, including a carrying charge on the outstanding balance. Base rates reflect recovery by the company of certain costs of its energy efficiency, demonstration projects, non-wire alternative projects (including the Brooklyn Queens demand management program), and off-peak electric vehicle charging programs (Yr. 1 - $244 million; Yr. 2 - $237 million; and Yr. 3 - $281 million) over periods varying between seven and fifteen years, including the overall pre-tax rate of return on such costs. (d) Deferrals for property taxes are limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a maximum number of basis points impact on return on common equity of 10.0 basis points, 7.5 basis points and 5.0 basis points for each of Yr. 1, Yr. 2 and Yr. 3, respectively, of the 2020 – 2022 rate plan and 10.0 basis points, 5.0 basis points and 5.0 basis points for each of Yr. 1, Yr. 2 and Yr. 3, respectively, of the 2023 – 2025 rate plan. (e) In general, if actual expenses for municipal infrastructure support (other than company labor) are below the amounts reflected in rates the company will defer the difference for credit to customers, and if the actual expenses are above the amount reflected in rates the company will defer for recovery from customers 80 percent of the difference subject to a maximum deferral, subject to certain conditions, of 15 percent of the amount reflected in the rate plans. (f) In addition, the NYSPSC continues its focused operations audit to investigate CECONY's financial accounting for income taxes. Any NYSPSC ordered adjustment to CECONY’s financial accounting for income taxes is expected to be refunded to or collected from customers, as determined by the NYSPSC. See "Other Regulatory Matters," below. (g) Reconciliation of net utility plant for AMI will be done on a combined basis for electric and gas. (h) Calculated in accordance with the earnings calculation method prescribed in the rate order. (i) In November 2021, the NYSPSC issued an order that allowed CECONY to recover $43 million of late payment charges and fees that were not billed for the year ended December 31, 2020. The recalculated return on equity for 2020 which reflects the recovery of these fees is 8.81 percent. (j) Amounts reflect amortization of the TCJA allocable to CECONY’s electric customers ($256 million) over a two-year period ($128 million in Yr. 1 and Yr. 2), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s electric customers ($1,512 million) over the remaining lives of the related assets ($34 million in Yr. 1, $63 million in Yr. 2, and $34 million in Yr. 3) and the unprotected portion of the net regulatory liability ($306 million) over two years ($153 million annually). Amounts also reflect amortization of the regulatory asset for deferred MTA power reliability costs ($93 million) over a three-year period ($31 million annually). CECONY – Gas Effective period January 2020 – December 2022 January 2023 – December 2025 Base rate changes Yr. 1 – $84 million (a) Yr. 2 – $122 million (a) Yr. 3 – $167 million (a) Yr. 1 – $217 million (c) Yr. 2 – $173 million (c) Yr. 3 – $122 million (c) Amortizations to income of net Yr. 1 – $45 million (b) Yr. 2 – $43 million (b) Yr. 3 – $10 million (b) Yr. 1 – $31 million (j) Yr. 2 – $24 million (j) Yr. 3 – $(11) million (j) Other revenue sources Retention of annual revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. Potential incentives if performance targets related to gas leak backlog, leak prone pipe and service terminations are met: Yr. 1 – $20 million Yr. 2 – $22 million Yr. 3 – $25 million In 2020, 2021 and 2022, the company recorded $3 million, $26 million and $8 million of earnings adjustment mechanism incentives for energy efficiency, respectively. In 2020, 2021 and 2022, the company recorded positive incentives of $13 million, $7 million, and $9 million respectively. In 2021, the company reversed $6 million of positive incentives recorded in 2020 pursuant to an order issued by the NYSPSC in December 2021. Retention of annual revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. Potential earnings adjusted mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $18 million Yr. 2 - $20 million Yr. 3 - $21 million In 2023 and 2024, the company recorded $5 million and $7 million of earnings adjustment mechanism incentives for energy efficiency, respectively. In 2023 and 2024, the company recorded positive incentives of $3 million each year, respectively. Revenue decoupling mechanisms Continuation of reconciliation of actual to authorized gas delivery revenues, modified to be calculated based upon revenue per customer class instead of revenue per customer. In 2020, 2021 and 2022, the company deferred for recovery from customers $27 million, $100 million and $141 million of revenues, respectively. Continuation of reconciliation of actual to authorized gas delivery revenues, modified to be calculated based upon revenue per customer class instead of revenue per customer. In 2023 and 2024, the company deferred for recovery from customers $162 million and $93 million of revenues, respectively. Recoverable energy costs Continuation of current rate recovery of purchased gas costs. Continuation of current rate recovery of purchased gas costs. Negative revenue adjustments Potential charges if performance targets relating to service, safety and other matters are not met: Yr. 1 – $81 million Yr. 2 – $88 million Yr. 3 – $96 million In 2020 and 2021, the company did not record any negative revenue adjustments. In 2022, the company recorded negative revenue adjustments of $8 million. Potential charges if performance targets relating to service, safety and other matters are not met: Yr. 1 - $107 million Yr. 2 - $119 million Yr. 3 - $130 million In 2023 and 2024, the company recorded negative revenue adjustments of $3 million and $2 million, respectively. Regulatory reconciliations Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes (d), municipal infrastructure support costs (e), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (f). In 2020 and 2021, the company deferred $91 million and $14 million of net regulatory assets, respectively. In 2022, the company deferred $70 million of net regulatory liabilities. Reconciliation of late payment charges (i) and expenses for uncollectibles, pension and other postretirement benefits, variable-rate debt, major storms, property taxes (d), municipal infrastructure support costs (e), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (f). In 2023 and 2024, the company deferred $12 million and $29 million of net regulatory liabilities, respectively. Net utility plant reconciliations Target levels reflected in rates: Gas average net plant target excluding AMI: Yr. 1 – $8,108 million Yr. 2 – $8,808 million Yr. 3 – $9,510 million AMI (g): Yr. 1 – $142 million Yr. 2 – $183 million Yr. 3 – $211 million In 2020 and 2021, the company deferred $24.7 million and $26 million, as a regulatory liability, respectively. In 2022, the company deferred $10.8 million as a regulatory asset. Target levels reflected in rates: Gas average net plant target excluding AMI and CSS for Yr. 1: Yr. 1 - $10,466 million Yr. 2 - $11,442 million Yr. 3 - $12,142 million AMI (g): Yr. 1 - $234 million CSS: Yr. 1 - $2 million In 2023 and 2024, the company deferred $15.5 million and $31.5 million as regulatory liabilities, respectively. Average rate base Yr. 1 – $7,171 million Yr. 2 – $7,911 million Yr. 3 – $8,622 million Yr. 1 - $9,647 million Yr. 2 - $10,428 million Yr. 3 - $11,063 million Weighted average cost of capital Yr. 1 – Yr. 3 - 6.61 percent Yr. 1 – 6.75 percent Yr. 2 – 6.79 percent Yr. 3 – 6.85 percent Authorized return on common equity 8.8 percent 9.25 percent Actual return on common equity (h) (i) Yr. 1 – 8.4 percent Yr. 2 – 8.48 percent Yr. 3 – 8.93 percent Yr. 1 – 9.00 percent Yr. 2 - 9.82 percent Earnings sharing Most earnings above an annual earnings threshold of 9.3 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2020, 2021 and 2022, the company had no earnings above the threshold. Most earnings above an annual earnings threshold of 9.75 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2023, the company had no earnings above the threshold. In 2024, the company had $4.3 million above the threshold. Cost of long-term debt Yr. 1 – Yr. 3 - 4.63 percent Yr. 1 – 4.46 percent Yr. 2 – 4.54 percent Yr. 3 – 4.64 percent Common equity ratio 48 percent 48 percent (a) The gas base rate increases shown above will be implemented with increases of $47 million in Yr. 1; $176 million in Yr. 2; and $170 million in Yr. 3 in order to levelize customer bill impacts. Base rates reflect recovery by the company of certain costs of its energy efficiency program (Yr. 1 - $30 million; Yr. 2 - $37 million; and Yr. 3 - $40 million) over a ten-year period, including the overall pre-tax rate of return on such costs. (b) Amounts reflect amortization of t he remaining 2018 TCJA tax savings allocable to CECONY’s gas customers ($63 million) over a two year period ($32 million annually), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s gas customers ($725 million) over the remaining lives of the related assets ($14 million in Yr. 1, $14 million in Yr. 2, and $12 million in Yr. 3) and the unprotected portion of the net regulatory liability ($107 million) over five years ($21 million annually) (c) The gas base rate increases shown above will be implemented with increases of $187 million in Yr. 1; $187 million in Yr. 2; and $187 million in Yr. 3 in order to levelize the customer bill impact. New rates were effective as of January 1, 2023. CECONY began billing customers at the new levelized rate in August 2023. The shortfall in revenues due to the timing of billing to customers ($99 million) are being collected through a surcharge billed through 2025, including a carrying charge on the outstanding balance. Base rates reflect recovery by the company of certain costs of its energy efficiency programs (Yr. 1 - $45 million; Yr. 2 - $78 million; and Yr. 3 - $62 million) over a fifteen-year period, including the overall pre-tax rate of return on such costs. (d)-(h) See footnotes (d) - (h) to the table under “CECONY Electric,” above. (i) In November 2021, the NYSPSC issued an order that allowed CECONY to recover $7 million of late payment charges and fees that were not billed for the year ended December 31, 2020. The recalculated return on equity for 2020 which reflects the recovery of these fees is 8.56 percent. (j) Amounts reflect amortization of the TCJA allocable to CECONY’s gas customers ($32 million) over a two-year period ($16 million in Yr. 1 and Yr. 2), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s gas customers ($679 million) over the remaining lives of the related assets ($9 million in Yr. 1, $10 million in Yr. 2, and $10 million in Yr. 3) and the unprotected portion of the net regulatory liability ($42 million) over two years ($21 million annually). CECONY – Steam Effective period January 2014 – December 2016 (g) November 2023 – October 2026 Base rate changes Yr. 1 – $(22.4) million (h) Yr. 2 –$19.8 million (h) Yr. 3 –$20.3 million(h) Yr. 4 – None Yr. 5 – None Yr. 6 – None Yr. 7 – None Yr. 8 – None Yr. 9 – None Yr.10 – None Yr. 1 – $110 million (a) Yr. 2 – $44 million (a) Yr. 3 – $45 million (a) Amortizations to income of net $37 million over three years Yr. 1 – $15 million (b) Yr. 2 – $3 million (b) Yr. 3 – $3 million (b) Weather Normalization Adjustment Implementation of a weather normalization adjustment to reflect normal weather conditions during the heating season. Recoverable energy costs Current rate recovery of purchased power and fuel costs. Continuation of current rate recovery of purchased power and fuel costs. Negative revenue adjustments Potential charges (up to $1 million annually) if certain performance targets are not met. The company did not record any negative revenue adjustments under this rate plan. Potential charges if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 - $3.7 million Yr. 2 - $3.8 million Yr. 3 - $3.8 million In Yr. 1, the company did not record any negative revenue adjustments. Regulatory reconciliations (i) (j) In 2014, 2015, 2016, 2017, 2018, 2019, 2020, 2021, 2022 and 2023, the company deferred $42 million of net regulatory liabilities, $17 million of net regulatory assets, $8 million and $14 million of net regulatory liabilities, $1 million of net regulatory assets, $8 million of net regulatory liabilities, $35 million of net regulatory assets, $32 million of net regulatory assets, $11 million of net regulatory assets and $18 million net regulatory liabilities, respectively. Reconciliation of uncollectible expenses and late payment charges (c) and expenses for pension and other postretirement benefits, variable-rate debt, property taxes (d), municipal infrastructure support costs (e), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates. (f) In Yr. 1, the company deferred $7 million of net regulatory assets. Net utility plant reconciliations Target levels reflected in rates were: Production: Yr. 1 – $1,752 million Yr. 2 – $1,732 million Yr. 3 – $1,720 million Distribution: Yr. 1 – $6 million Yr. 2 – $11 million Yr. 3 – $25 million The company reduced its regulatory liability by $0.1 in 2014 and immaterial amounts in 2015 and 2016 and no deferrals were recorded in 2017, 2018, 2019. In 2020 and 2021, the company deferred $2 million and $1 million as a regulatory liability, respectively. In 2022, the company deferred $0.1 million as a regulatory asset. No deferral was recorded in 2023. Yr. 1 - $2,025 million Yr. 2 - $2,029 million Yr. 3 - $2,015 million In Yr. 1, the company deferred $2.4 million as a regulatory liability. Average rate base Yr. 1 – $1,511 million Yr. 2 – $1,547 million Yr. 3 – $1,604 million Yr. 1 - $1,799 million Yr. 2 - $1,848 million Yr. 3 - $1,882 million Weighted average cost of capital (after-tax) Yr. 1 – 7.10 percent Yr. 2 – 7.13 percent Yr. 3 – 7.21 percent Yr. 1 - 6.78 percent Yr. 2 - 6.81 percent Yr. 3 - 6.83 percent Authorized return on common equity 9.3 percent 9.25 percent Actual return on common equity (j) Yr. 1 – 9.82 percent Yr. 2 – 10.88 percent Yr. 3 – 10.54 percent Yr. 4 – 9.51 percent Yr. 5 – 11.73 percent Yr. 6 – 10.45 percent Yr. 7 – 7.91 percent Yr. 8 – 5.99 percent Yr. 9 - 5.72 percent Yr. 10 - (0.10) percent . Yr. 1 – 6.55 percent Earnings sharing Weather normalized earnings above an annual earnings threshold of 9.9 percent are to be applied to reduce regulatory assets for environmental remediation and other costs. In 2014, the company had no earnings above the threshold. Actual earnings were $11.5 million and $7.8 million above the threshold in 2015 and 2016, respectively. In 2017, actual earnings were $8.5 million above the threshold, offset in part by a positive adjustment related to 2016 of $4 million. In 2018, actual earnings were $16.5 million above the threshold, and an additional $1.1 million related to 2017 was recorded. In 2019 actual earnings were $5 million above the threshold, offset in part by an adjustment related to 2018 of $2.3 million. In 2020, 2021, 2022 and 2023, the company had no earnings sharing above the threshold. Reserve adjustments of $0.4 million and $0.2 million were recorded in 2021 related to potential adjustment to the excess earnings sharing amounts for 2016 and 2018, respectively. Most earnings above an annual earnings threshold of 9.75 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. There were no earnings above the threshold in Yr. 1. Cost of long-term debt Yr. 1 – 5.17 percent Yr. 2 – 5.23 percent Yr. 3 – 5.39 percent Yr. 1 – 4.51 percent Yr. 2 – 4.58 percent Yr. 3 – 4.62 percent Common equity ratio 48 percent 48 percent (a) The base rate increases will be implemented with increases of $77.8 million in Yr. 1; $77.8 million in Yr. 2; and $77.8 million in Yr. 3 to levelize the customer bill impact. New rates were effective as of November 1, 2023. CECONY began billing customers at the new levelized rate in December 2023. (b) Amounts reflect amortization of the tax savings under the federal Tax Cuts and Jobs Act of 2017 (TCJA) for the unprotected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s steam customers (the entire $24 million in Yr.1), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s steam customers over the remaining lives of the related assets ($3 million in Yr. 1; $5 million in Yr. 2; and $6 million in Yr. 3) and the non-plant portion of the regulatory asset for deficient deferred income taxes allocable to CECONY’s steam customers (the entire $11 million in Yr.1). (c) CECONY will defer the difference between its actual write-offs of uncollectible expenses and late payment fees (from January 1, 2020 through October 31, 2026) to amounts reflected in rates, with recovery/refund from or to customers via surcharge/sur-credit. Surcharge recoveries for write-offs of uncollectible expenses and late payment fees will each be subject to an annual cap that produces no more than a half percent (0.5 percent) total customer bill impact (estimated to be $2.5 million, $3.0 million, $3.5 million for Yr. 1, Yr. 2 and Yr. 3, respectively). Amounts in excess of the annual surcharge cap in a specific year may be rolled forward for recovery and will count towards the following year’s surcharge cap. Amounts in excess of the surcharge cap will be deferred as a regulatory asset for recovery in CECONY’s next steam base rate case. (d) Deferrals for property taxes are limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a maximum number of basis points impact on return on common equity (Yr. 1 – 10.0 basis points; Yr. 2 – 7.5 basis points; and Yr. 3 – 5.0 basis points), with recovery/refund from or to customers via surcharge/sur-credit. Surcharge recoveries will be subject to an annual cap that produces no more than a half percent (0.5 percent) total customer bill impact (estimated to be $2.5 million, $3.0 million, $3.5 million for Yr. 1, Yr. 2 and Yr. 3, respectively). Amounts in excess of the annual surcharge cap in a specific year may be rolled forward for recovery and will count towards the following year’s surcharge cap. Amounts in excess of the surcharge cap will be deferred as a regulatory asset for recovery in CECONY’s next steam base rate case. (e) In general, if actual expenses for municipal infrastructure support (other than company labor) are below the amounts reflected in rates, CECONY will defer the difference for credit to customers, and if the actual expenses are above the amount reflected in rates, CECONY will defer for recovery from customers 80 percent of the difference subject to a maximum deferral, subject to certain conditions, of 30 percent of the amount reflected in the rate plan. (f) In addition, the NYSPSC continues its focused operations audit to investigate CECONY's financial accounting for income taxes. Any NYSPSC ordered adjustment to CECONY’s financial accounting for income taxes is expected to be refunded to or collected from customers, as determined by the NYSPSC. See "Other Regulatory Matters," below. (g) Rates determined pursuant to this rate plan were in effect until October 31, 2023. 2023 or Yr. 10 represents a partial year commencing January 1, 2023 through October 31, 2023. (h) The impact of these base rate changes was deferred which resulted in an $8 million regulatory liability at December 31, 2016. (i) Deferrals for property taxes are limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a 10 basis point impact on return on common equity. (j) Calculated in accordance with the earnings calculation method prescribed in the rate order. O&R New York – Electric Effective period January 2022 – December 2024 January 2025 – December 2027 (a) Base rate changes Yr. 1 – $4.9 million (b) Yr. 2 – $16.2 million (b) Yr. 3 – $23.1 million (b) Yr. 1 – $(13.1) million (c) Yr. 2 – $24.8 million (c) Yr. 3 – $44.1 million (c) Amortizations to income of net Yr. 1 – $11.8 million (d) Yr. 2 – $13.5 million (d) Yr. 3 – $15.2 million (d) Yr. 1 – $(4.5) million Yr. 2 – $(5.4) million Yr. 3 – $(6.4) million Other revenue sources Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Revenue decoupling mechanisms Continuation of reconciliation of actual to authorized electric delivery revenues. In 2022, and 2023, the company deferred $6.9 million, $3.4 million as regulatory assets, respectively. In 2024, the company deferred $18.6 million as regulatory liabilities. Continuation of reconciliation of actual to authorized electric delivery revenues. Recoverable energy costs Continuation of current rate recovery of purchased power and fuel costs. Continuation of current rate recovery of purchased power and fuel costs. Negative revenue adjustments Potential charges if certain performance targets relating to service, reliability and other matters are not met: Yr. 1 - $4.3 million Yr. 2 - $4.4 million Yr. 3 - $5.1 million In 2022, 2023 and 2024, the company did not record any negative revenue adjustments. Potential charges if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 – $7.6 million Yr. 2 – $8.5 million Yr. 3 – $11.5 million Regulatory reconciliations Reconciliation of late payment charges (e) and reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (f), energy efficiency program (g), major storms, uncollectible expenses and certain other costs to amounts reflected in rates (h). In 2022 and 2023, the company deferred $9.4 million and $15.4 million as net regulatory liabilities, respectively. In 2024, the company deferred $10.2 million as net regulatory assets. Reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (f), energy efficiency program (i), major storms, low-income bill credits, uncollectible expenses (j), late payment charges (j), and certain other costs to amounts reflected in rates. Net utility plant reconciliations Target levels reflected in rates: Electric average net plant target Yr. 1 - $1,175 million Yr. 2 - $1,198 million Yr. 3 - $1,304 million The company did not record any regulatory liabilities in 2022, 2023 and 2024. Target levels reflected in rates: Electric average net plant target Yr. 1 – $1,398 million Yr. 2 – $1,471 million Yr. 3 – $1,737 million Average rate base Yr. 1 – $1,021 million Yr. 2 – $1,044 million Yr. 3 – $1,144 million Yr. 1 – $1,293 million Yr. 2 – $1,393 million Yr. 3 – $1,646 million Weighted average cost of capital (after-tax) Yr. 1 – 6.77 percent Yr. 2 – 6.73 percent Yr. 3 – 6.72 percent Yr. 1 – 7.25 percent Yr. 2 – 7.28 percent Yr. 3 – 7.31 percent Authorized return on common equity 9.2 percent 9.75 percent Actual return on common equity (k) Yr. 1 – 8.96 percent Yr. 2 – 8.73 percent Yr. 3 – 9.86 percent Earnings sharing Most earnings above an annual earnings threshold of 9.7 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2022 and 2023, earnings did not exceed the earnings threshold. In 2024, actual earnings were 1.2 million above the threshold. Most earnings above an annual earnings threshold of 10.25 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. Cost of long-term debt Yr. 1 – 4.58 percent Yr. 2 – 4.51 percent Yr. 3 – 4.49 percent Yr. 1 – 4.95 percent Yr. 2 – 5.01 percent Yr. 3 – 5.08 percent Common equity ratio 48 percent 48 percent a. The November 2024 Joint Proposal is subject to NYSPSC approval. b. The base rate changes will be implemented with increases of: Yr.
Schedule of Regulatory Assets	Regulatory assets and liabilities at December 31, 2024 and 2023 were comprised of the following items: Con Edison CECONY (Millions of Dollars) 2024 2023 2024 2023 Regulatory assets Energy efficiency and other clean energy programs (a) $1,656 $1,251 $1,598 $1,223 Customer account deferrals (b) 1,073 789 1,058 782 Environmental remediation costs 1,038 1,105 952 1,022 Revenue taxes 540 476 517 455 Legacy meters (c) 413 17 398 — Deferred storm costs (d) 147 206 53 115 Property tax reconciliation (e) 131 169 131 169 Deferred derivative losses - long term 106 163 94 148 MTA power reliability deferral (f) 31 61 31 61 Gas service line deferred costs 18 43 18 43 Pension and other postretirement benefits deferrals 2 48 2 39 Other 368 279 306 257 Regulatory assets – noncurrent 5,523 4,607 5,158 4,314 Deferred derivative losses - short term 102 269 92 253 Recoverable energy costs 39 12 14 1 Regulatory assets – current 141 281 106 254 Total Regulatory Assets $5,664 $4,888 $5,264 $4,568 Regulatory liabilities Allowance for cost of removal less salvage (g) $1,527 $1,456 $1,322 $1,266 Future income tax* 1,224 1,535 1,112 1,404 Unrecognized pension and other postretirement costs (h) 1,054 943 984 867 Net unbilled revenue deferrals 436 278 436 278 Pension and other postretirement benefit deferrals 368 284 304 233 Late payment charge deferral 231 167 224 161 System benefit charge carrying charge 115 92 110 88 Net proceeds from sale of property 25 48 24 47 Settlement of prudence proceeding (i) 10 11 10 11 Deferred derivative gains - long term 8 49 6 49 Other 446 465 408 414 Regulatory liabilities – noncurrent 5,444 5,328 4,940 4,818 Refundable energy costs 59 71 18 36 Deferred derivative gains - short term 25 74 22 71 Revenue decoupling mechanism 18 — — — Regulatory liabilities—current 102 145 40 107 Total Regulatory Liabilities $5,546 $5,473 $4,980 $4,925 * See "Federal Income Tax" in Note A, "Other Regulatory Matters," above, and Note L. (a) Energy Efficiency and Other Clean Energy Programs represent programs designed to increase energy efficiency achievements and other clean energy transformation efforts. (b) Customer account deferrals include (1) the amount to be collected from customers related to the Emergency Summer Cooling Credits program for CECONY, (2) deferrals under CECONY and O&R's electric and gas rate plans for the reconciliation of write-offs of customer accounts receivable balances to amounts reflected in rates as well as for increases to the allowance for uncollectible accounts receivable and (3) deferral related to the arrears relief programs. Amounts deferred under the arrears relief programs were $323.7 million and $1.4 million for CECONY and O&R at December 31, 2024, respectively, and $398.6 million and $2.1 million at December 31, 2023, respectively, and receive a return at the pre-tax weighted average cost of capital. (c) Pursuant to their rate plans, CECONY and O&R are recovering the costs of legacy meters over a 15-year period beginning January 1, 2024 and a 12-year period beginning January 1, 2022, respectively. (d) Deferred storm costs represent response and restoration costs, other than capital expenditures, in connection with Tropical Storm Isaias and other major storms that were deferred by the Utilities. (e) Property tax reconciliation represents the amount deferred between actual property taxes incurred and the level included in rates subject to the provisions of the respective rate plans. (f) MTA power reliability deferral represents CECONY’s costs in excess of those reflected in its prior electric rate plan to take certain actions relating to the electrical equipment that serves the Metropolitan Transportation Authority (MTA) subway system. The company is recovering this regulatory asset pursuant to its current electric rate plan. See footnote (d) to the CECONY - Electric table under “Rate Plans,” above. (g) Allowance for cost of removal less salvage represents cash previously collected from customers to fund future anticipated removal expenditures. (h) Unrecognized pension and other postretirement costs represent the deferrals associated with the accounting rules for retirement benefits. See "Pension and Other Postretirement Benefits" in Note A. (i) Settlement of prudence proceeding represents the remaining amount to be credited to customers pursuant to a Joint Proposal, approved by the NYSPSC in April 2016, with respect to the prudence of certain CECONY expenditures and related matters.
Schedule of Regulatory Liabilities	Regulatory assets and liabilities at December 31, 2024 and 2023 were comprised of the following items: Con Edison CECONY (Millions of Dollars) 2024 2023 2024 2023 Regulatory assets Energy efficiency and other clean energy programs (a) $1,656 $1,251 $1,598 $1,223 Customer account deferrals (b) 1,073 789 1,058 782 Environmental remediation costs 1,038 1,105 952 1,022 Revenue taxes 540 476 517 455 Legacy meters (c) 413 17 398 — Deferred storm costs (d) 147 206 53 115 Property tax reconciliation (e) 131 169 131 169 Deferred derivative losses - long term 106 163 94 148 MTA power reliability deferral (f) 31 61 31 61 Gas service line deferred costs 18 43 18 43 Pension and other postretirement benefits deferrals 2 48 2 39 Other 368 279 306 257 Regulatory assets – noncurrent 5,523 4,607 5,158 4,314 Deferred derivative losses - short term 102 269 92 253 Recoverable energy costs 39 12 14 1 Regulatory assets – current 141 281 106 254 Total Regulatory Assets $5,664 $4,888 $5,264 $4,568 Regulatory liabilities Allowance for cost of removal less salvage (g) $1,527 $1,456 $1,322 $1,266 Future income tax* 1,224 1,535 1,112 1,404 Unrecognized pension and other postretirement costs (h) 1,054 943 984 867 Net unbilled revenue deferrals 436 278 436 278 Pension and other postretirement benefit deferrals 368 284 304 233 Late payment charge deferral 231 167 224 161 System benefit charge carrying charge 115 92 110 88 Net proceeds from sale of property 25 48 24 47 Settlement of prudence proceeding (i) 10 11 10 11 Deferred derivative gains - long term 8 49 6 49 Other 446 465 408 414 Regulatory liabilities – noncurrent 5,444 5,328 4,940 4,818 Refundable energy costs 59 71 18 36 Deferred derivative gains - short term 25 74 22 71 Revenue decoupling mechanism 18 — — — Regulatory liabilities—current 102 145 40 107 Total Regulatory Liabilities $5,546 $5,473 $4,980 $4,925 * See "Federal Income Tax" in Note A, "Other Regulatory Matters," above, and Note L. (a) Energy Efficiency and Other Clean Energy Programs represent programs designed to increase energy efficiency achievements and other clean energy transformation efforts. (b) Customer account deferrals include (1) the amount to be collected from customers related to the Emergency Summer Cooling Credits program for CECONY, (2) deferrals under CECONY and O&R's electric and gas rate plans for the reconciliation of write-offs of customer accounts receivable balances to amounts reflected in rates as well as for increases to the allowance for uncollectible accounts receivable and (3) deferral related to the arrears relief programs. Amounts deferred under the arrears relief programs were $323.7 million and $1.4 million for CECONY and O&R at December 31, 2024, respectively, and $398.6 million and $2.1 million at December 31, 2023, respectively, and receive a return at the pre-tax weighted average cost of capital. (c) Pursuant to their rate plans, CECONY and O&R are recovering the costs of legacy meters over a 15-year period beginning January 1, 2024 and a 12-year period beginning January 1, 2022, respectively. (d) Deferred storm costs represent response and restoration costs, other than capital expenditures, in connection with Tropical Storm Isaias and other major storms that were deferred by the Utilities. (e) Property tax reconciliation represents the amount deferred between actual property taxes incurred and the level included in rates subject to the provisions of the respective rate plans. (f) MTA power reliability deferral represents CECONY’s costs in excess of those reflected in its prior electric rate plan to take certain actions relating to the electrical equipment that serves the Metropolitan Transportation Authority (MTA) subway system. The company is recovering this regulatory asset pursuant to its current electric rate plan. See footnote (d) to the CECONY - Electric table under “Rate Plans,” above. (g) Allowance for cost of removal less salvage represents cash previously collected from customers to fund future anticipated removal expenditures. (h) Unrecognized pension and other postretirement costs represent the deferrals associated with the accounting rules for retirement benefits. See "Pension and Other Postretirement Benefits" in Note A. (i) Settlement of prudence proceeding represents the remaining amount to be credited to customers pursuant to a Joint Proposal, approved by the NYSPSC in April 2016, with respect to the prudence of certain CECONY expenditures and related matters.
Schedule of Regulatory Assets Not Earning Return	At December 31, 2024 and 2023, regulatory assets for Con Edison and CECONY that did not earn a return consisted of the following items: Regulatory Assets Not Earning a Return* Con Edison CECONY (Millions of Dollars) 2024 2023 2024 2023 Environmental remediation costs $1,037 $1,105 $942 $1,022 Revenue taxes 567 490 543 470 UB deferral for uncollectible accounts receivable 551 291 541 288 Deferred derivative losses - long term 106 163 94 148 Deferred derivative losses - short term 102 269 92 253 Other 39 29 28 28 Total $2,402 $2,347 $2,240 $2,209

Capitalization (Tables)

Capitalization (Tables)	12 Months Ended
Capitalization (Tables)	Dec. 31, 2024
Debt Disclosure [Abstract]
Schedule of Long-Term Debt Maturities	Long-term debt maturing in the period 2025-2029 is as follows: (Millions of Dollars) Con Edison (a) CECONY 2025 $— $— 2026 250 250 2027 780 700 2028 800 800 2029 44 — (a) Amounts shown exclude $59 million of debt for Broken Bow II, a deferred project, which was classified as held for sale as of December 31, 2024 and is shown under “Project Debt Held for Sale" on Con Edison's Consolidated Statement of Capitalization. See "Assets Held for Sale" in Note A and Note X for additional information. The sale and transfer of Broken Bow II, including the related debt, was completed in January 2025.
Carrying Amounts and Fair Values of Long-Term Debt	The carrying amounts and fair values of long-term debt at December 31, 2024 and 2023 are: (Millions of Dollars) 2024 2023 Long-Term Debt (including current portion) (a) Carrying Fair Carrying Fair Con Edison (b) $24,651 $21,997 $22,177 $20,525 CECONY 23,409 20,915 21,060 19,517 (a) Amounts shown are net of unamortized debt expense and unamortized debt discount of $249 million and $241 million for Con Edison and CECONY, respectively, as of December 31, 2024 and $222 million and $215 million for Con Edison and CECONY, respectively, as of December 31, 2023. (b) Amounts shown exclude the debt of Broken Bow II, a deferred project that was classified as held for sale as of December 31, 2024 and as of December 31, 2023 and is shown under “Project Debt Held for Sale" on Con Edison's Consolidated Statement of Capitalization. The carrying value and fair value of Broken Bow II's long-term debt, including the current portion, as of December 31, 2024 was $59 million and $54 million, respectively, and as of December 31, 2023 was $62 million and $58 million, respectively. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W and Note X. The sale and transfer of Broken Bow II, including the related debt, was completed in January 2025. See Note W.

Pension Benefits (Tables)

Pension Benefits (Tables)	12 Months Ended
Pension Benefits (Tables)	Dec. 31, 2024
Retirement Benefits [Abstract]
Total Periodic Benefit Costs	The components of the Companies’ total periodic benefit cost/(credit) for 2024, 2023 and 2022 were as follows: Con Edison CECONY (Millions of Dollars) 2024 2023 2022 2024 2023 2022 Service cost – including administrative expenses $177 $161 $287 $167 $151 $270 Interest cost on projected benefit obligation 642 649 505 604 611 475 Expected return on plan assets (1,129) (1,114) (1,168) (1,076) (1,061) (1,109) Recognition of net actuarial loss/(gain) (5) (232) 377 (7) (219) 358 Recognition of prior service credit (17) (17) (16) (19) (19) (21) TOTAL PERIODIC BENEFIT COST/(CREDIT) $(332) $(553) $(15) $(331) $(537) $(27) Cost capitalized (94) (81) (137) (90) (78) (129) Reconciliation to rate level 55 282 259 43 261 245 Total expense/(benefit) recognized $(371) $(352) $107 $(378) $(354) $89 The components of the Companies’ total periodic postretirement benefit costs/(credit) for 2024, 2023 and 2022 were as follows: Con Edison CECONY (Millions of Dollars) 2024 2023 2022 2024 2023 2022 Service cost $13 $14 $18 $10 $12 $15 Interest cost on accumulated other postretirement benefit obligation 47 57 35 40 49 30 Expected return on plan assets (68) (70) (72) (55) (56) (58) Recognition of net actuarial loss/(gain) (20) (16) (14) (13) (8) (9) Recognition of prior service credit (1) (2) (1) — — — TOTAL PERIODIC POSTRETIREMENT BENEFIT COST/(CREDIT) $(29) $(17) $(34) $(18) $(3) $(22) Cost capitalized (6) (6) (8) (5) (5) (7) Reconciliation to rate level 16 4 29 13 (2) 24 Total credit recognized $(19) $(19) $(13) $(10) $(10) $(5)
Schedule of Funded Status	The funded status at December 31, 2024, 2023 and 2022 was as follows: Con Edison CECONY (Millions of Dollars) 2024 2023 2022 2024 2023 2022 CHANGE IN PROJECTED BENEFIT OBLIGATION Projected benefit obligation at beginning of year $12,712 $12,113 $17,357 $11,977 $11,395 $16,341 Service cost – excluding administrative expenses 172 156 283 162 146 266 Interest cost on projected benefit obligation 642 649 505 604 611 475 Net actuarial loss/(gain) (557) 599 (5,102) (557) 572 (4,845) Plan amendments — 3 — — — — Benefits paid (828) (808) (930) (751) (747) (842) PROJECTED BENEFIT OBLIGATION AT END OF YEAR $12,141 $12,712 $12,113 $11,435 $11,977 $11,395 CHANGE IN PLAN ASSETS Fair value of plan assets at beginning of year $15,404 $14,979 $18,504 $14,674 $14,248 $17,566 Actual return on plan assets 724 1,261 (2,583) 691 1,201 (2,453) Employer contributions 20 21 30 17 18 17 Benefits paid (828) (808) (930) (751) (747) (842) Administrative expenses (42) (49) (42) (40) (46) (40) FAIR VALUE OF PLAN ASSETS AT END OF YEAR $15,278 $15,404 $14,979 $14,591 $14,674 $14,248 FUNDED STATUS $3,137 $2,692 $2,866 $3,156 $2,697 $2,853 Unrecognized net loss/(gain) $(857) ($757) ($1,485) $(825) ($705) ($1,397) Unrecognized prior service credits (88) (105) (124) (104) (124) (143) Accumulated benefit obligation $11,236 $11,739 $11,167 $10,554 $11,031 $10,478 The funded status of the programs at December 31, 2024, 2023 and 2022 were as follows: Con Edison CECONY (Millions of Dollars) 2024 2023 2022 2024 2023 2022 CHANGE IN BENEFIT OBLIGATION Benefit obligation at beginning of year $963 $1,058 $1,398 $825 $921 $1,189 Service cost 13 14 18 10 12 15 Interest cost on accumulated postretirement benefit obligation 47 57 35 40 49 30 Net actuarial gain (57) (93) (311) (38) (94) (239) Benefits paid and administrative expenses, net of subsidies (120) (128) (130) (112) (118) (121) Participant contributions 52 55 48 50 55 47 BENEFIT OBLIGATION AT END OF YEAR $898 $963 $1,058 $775 $825 $921 CHANGE IN PLAN ASSETS Fair value of plan assets at beginning of year $929 $860 $1,150 $750 $708 $955 Actual return on plan assets 56 116 (225) 44 84 (187) Employer contributions 13 22 13 10 17 10 Employer group waiver plan subsidies 66 56 55 60 52 50 Participant contributions 52 55 48 50 55 47 Benefits paid (182) (180) (181) (170) (166) (167) FAIR VALUE OF PLAN ASSETS AT END OF YEAR $934 $929 $860 $744 $750 $708 FUNDED STATUS $36 $(34) $(198) $(31) $(75) $(213) Unrecognized net loss/(gain) ($119) $(90) $37 ($57) $(41) $78 Unrecognized prior service costs (9) (10) (12) — — —
Schedule of Assumptions	The actuarial assumptions were as follows: 2024 2023 2022 Weighted-average assumptions used to determine benefit obligations at December 31: Discount rate 5.70 % 5.15 % 5.45 % Interest crediting rate for cash balance plan 4.30 % 4.20 % 4.00 % Rate of compensation increase CECONY 3.80 % 3.80 % 3.80 % O&R 3.20 % 3.20 % 3.20 % Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31: Discount rate 5.15 % 5.45 % 3.00 % Interest crediting rate for cash balance plan 4.20 % 4.00 % 3.50 % Expected return on plan assets 6.75 % 6.75 % 7.00 % Rate of compensation increase CECONY 3.80 % 3.80 % 3.80 % O&R 3.20 % 3.20 % 3.20 % The actuarial assumptions were as follows: 2024 2023 2022 Weighted-average assumptions used to determine benefit obligations at December 31: Discount Rate CECONY 5.55 % 5.05 % 5.35 % O&R 5.65 % 5.15 % 5.45 % Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31: Discount Rate CECONY 5.05 % 5.35 % 2.75 % O&R 5.15 % 5.45 % 3.00 % Expected Return on Plan Assets 6.45 % 6.80 % 6.80 %
Schedule of Expected Benefit Payments	Based on current assumptions, the Companies expect to make the following benefit payments over the next ten years: (Millions of Dollars) Con Edison CECONY 2025 $840 $781 2026 808 749 2027 820 764 2028 824 766 2029 836 778 2030-2034 $4,227 $3,952 Based on current assumptions, the Companies expect to make the following benefit payments over the next ten years, net of receipt of governmental subsidies and participant contributions: (Millions of Dollars) Con Edison CECONY 2025 $67 $59 2026 68 60 2027 70 61 2028 71 62 2029 71 63 2030-2034 $346 $303
Schedule of Plan Assets Allocations	The asset allocations for the pension plan at the end of 2024, 2023 and 2022, and the target allocation for 2025 are as follows: Target Allocation Range Plan Assets at December 31, Asset Category 2025 2024 2023 2022 Equity Securities 26% - 30% 27 % 26 % 33 % Debt Securities 42% - 60% 51 % 50 % 50 % Real Estate and Other Alternatives 14% - 30% 22 % 24 % 17 % Total 100 % 100 % 100 % The asset allocations for CECONY’s other postretirement benefit plans at the end of 2024, 2023 and 2022, and the target allocation for 2025 are as follows: Target Allocation Range Plan Assets at December 31, Asset Category 2025 2024 2023 2022 Equity Securities 35%-55% 41 % 44 % 49 % Debt Securities 40%-60% 51 % 51 % 51 % Real Estate and Other Alternatives —%-9% 8 % 5 % — % Total 100% 100 % 100 % 100 %
Schedule of Fair Value of Plan Assets	The fair values of the pension plan assets at December 31, 2024 by asset category are as follows: (Millions of Dollars) Level 1 Level 2 Total Investments within the fair value hierarchy U.S. Equity (a) $2,752 $— $2,752 International Equity (b) 1,508 — 1,508 U.S. Government Issued Debt (c) — 619 619 Corporate Bonds Debt (d) — 5,429 5,429 Structured Assets Debt (e) — 159 159 Other Fixed Income Debt (f) — 783 783 Commingled Trust Fund (g) — 478 478 Cash and Cash Equivalents (h) 51 292 343 Futures (i) (4) — (4) Total investments within the fair value hierarchy $4,307 $7,760 $12,067 Investments measured at NAV per share (o) Private Equity (j) 975 Real Estate (k) 1,609 Hedge Funds (l) 788 Total investments valued using NAV per share $3,372 Funds for retiree health benefits (m) (50) (90) (140) Funds for retiree health benefits measured at NAV per share (m)(o) (39) Total funds for retiree health benefits $(179) Investments (excluding funds for retiree health benefits) $4,257 $7,670 $15,260 Pending activities (n) 18 Total fair value of plan net assets $15,278 (a) U.S. Equity is comprised of both actively- and passively-managed investments in domestic equity index funds and actively-managed small-capitalization equities. (b) International Equity is comprised of investments in international equity index funds and actively-managed international equities. (c) U.S. Government Issued Debt is comprised of agency and treasury securities. (d) Corporate Bonds Debt is comprised of debt issued by various corporations. (e) Structured Assets Debt is comprised of commercial-mortgage-backed securities and collateralized mortgage obligations. (f) Other Fixed Income Debt is comprised of municipal bonds, sovereign debt and regional governments. (g) Commingled Trust Fund is comprised of an actively managed commingled trust fund benchmarked to the Bloomberg Aggregate Bond Index. (h) Cash and Cash Equivalents are comprised of short term investments, money markets, foreign currency and cash collateral. (i) Futures are comprised of exchange-traded financial contracts encompassing U.S. Equity, International Equity and U.S. Government indices. (j) Private Equity is comprised of global private market investments. Private equity's investment objective is to generate returns on capital from a diversified portfolio of primary fund investments, secondaries and co-investments. The plan's unfunded commitments to private equity were approximately $180 million at December 31, 2024. However, the managers also expect to make significant cash flow distributions in 2025 and 2026. While the investments in this asset class cannot be redeemed, the plan would be able to receive distributions from selling its limited partnership interests in the secondary market, which would be expected to take three (k) Real Estate investments are open-end real estate funds that invest in a portfolio of real properties that are broadly diversified by geography and property type. The real estate asset class is expected to produce returns from income and capital appreciation. Real estate also provides a hedge against inflation. The funds allow for quarterly redemptions, however the amount and timing of distributions are subject to market conditions and are currently uncertain. (l) Hedge Funds are structured as a custom fund of one and can invest in external hedge fund managers that pursue a wide array of strategies including event driven, fundamental long/short, relative value, directional trading, and direct sourcing. These investments seek to generate positive absolute returns with lower volatility than other investments. The various hedge fund managers can invest in all financial instruments. Substantially all of the investment could be liquidated within 18 months. (m) The Companies set aside funds for retiree health benefits through a separate account within the pension trust, as permitted under Section 401(h) of the Internal Revenue Code of 1986, as amended. In accordance with the Code, the plan’s investments in the 401(h) account may not be used for, or diverted to, any purpose other than providing health benefits for retirees. The net assets held in the 401(h) account are calculated based on a pro-rata percentage allocation of the net assets in the pension plan. The related obligations for health benefits are not included in the pension plan’s obligations and are included in the Companies’ other postretirement benefit obligation. See Note F. (n) Pending activities include security purchases and sales that have not settled, interest and dividends that have not been received and reflects adjustments for available estimates at year end. (o) In accordance with ASU 2015-07, Fair Value Measurements (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or its equivalent), certain investments that are measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy. The fair values of the pension plan assets at December 31, 2023 by asset category are as follows: (Millions of Dollars) Level 1 Level 2 Total Investments within the fair value hierarchy U.S. Equity (a) $2,474 $1 $2,475 International Equity (b) 1,584 — 1,584 U.S. Government Issued Debt (c) — 615 615 Corporate Bonds Debt (d) — 5,526 5,526 Structured Assets Debt (e) — 132 132 Other Fixed Income Debt (f) — 735 735 Commingled Trust Fund (g) — 475 475 Cash and Cash Equivalents (h) 36 302 338 Futures (i) 19 — 19 Total investments within the fair value hierarchy $4,113 $7,786 $11,899 Investments measured at NAV per share (o) Private Equity (j) 1,031 Real Estate (k) 1,876 Hedge Funds (l) 723 Total investments valued using NAV per share $3,630 Funds for retiree health benefits (m) (52) (96) (148) Funds for retiree health benefits measured at NAV per share (m)(o) (45) Total funds for retiree health benefits $(193) Investments (excluding funds for retiree health benefits) $4,061 $7,690 $15,336 Pending activities (n) $68 Total fair value of plan net assets $15,404 (a) - (o) Reference is made to footnotes (a) through (n) in the above table of pension plan assets at December 31, 2024 by asset category. The fair values of the plans' assets at December 31, 2024 by asset category as defined by the accounting rules for fair value measurements (see Note R) are as follows: (Millions of Dollars) Level 1 Level 2 Total Equity (a) $— $302 $302 Other Fixed Income Debt (b) — 323 323 Cash and Cash Equivalents (c) 7 27 34 Commingled Trust Fund (d) — 38 38 Real Estate (e)(f) $39 Total investments $7 $690 $736 Funds for retiree health benefits (g) 50 90 140 Investments (including funds for retiree health benefits) $57 $780 $876 Funds for retiree health benefits measured at net asset value (f)(g) 39 Pending activities (h) 19 Total fair value of plan net assets $934 (a) Equity is comprised of a passively managed commingled index fund benchmarked to the MSCI All Country World Index. (b) Other Fixed Income Debt is comprised of a passively managed commingled index fund benchmarked to the Bloomberg Barclays U.S. Long Credit Index and an active separately managed portfolio indexed to the Bloomberg Barclays U.S. Long Credit Index. (c) Cash and Cash Equivalents is comprised of short-term investments and money markets. (d) Commingled Trust Fund is comprised of an actively managed commingled trust fund benchmarked to the Bloomberg Aggregate Bond Index. (e) Real Estate investments are open-end real estate funds that invest in a portfolio of real properties that are broadly diversified by geography and property type. The real estate asset class is expected to produce returns from income and capital appreciation. Real estate also provides a hedge against inflation. The funds allow for quarterly redemptions, however the amount and timing of distributions are subject to market conditions and are currently uncertain. (f) In accordance with ASU 2015-07, Fair Value Measurements (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or its equivalent), certain investments that are measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy. (g) The Companies set aside funds for retiree health benefits through a separate account within the pension trust, as permitted under Section 401(h) of the Internal Revenue Code of 1986, as amended. In accordance with the Code, the plan’s investments in the 401(h) account may not be used for, or diverted to, any purpose other than providing health benefits for retirees. The net assets held in the 401(h) account are calculated based on a pro-rata percentage allocation of the net assets in the pension plan. The related obligations for health benefits are not included in the pension plan’s obligations and are included in the Companies’ other postretirement benefit obligation. See Note E. (h) Pending activities include security purchases and sales that have not settled, interest and dividends that have not been received, and reflects adjustments for available estimates at year-end. The fair values of the plans' assets at December 31, 2023 by asset category (see Note R) are as follows: (Millions of Dollars) Level 1 Level 2 Total Equity (a) $— $331 $331 Other Fixed Income Debt (b) — 323 323 Cash and Cash Equivalents (c) 7 18 25 Commingled Trust Fund (d) — 38 38 Total investments $7 $710 $717 Funds for retiree health benefits (e) 52 96 148 Investments (including funds for retiree health benefits) $59 $806 $865 Funds for retiree health benefits measured at net asset value (f)(g) 45 Pending activities (h) 19 Total fair value of plan net assets $929 (a) - (h) Reference is made to footnotes (a) through (h) in the above table of other postretirement benefit plan assets at December 31, 2024 by asset category. The fair values of CECONY's portion of the plans' assets at December 31, 2024 by asset category as defined by the accounting rules for fair value measurements (see Note R) are as follows: (Millions of Dollars) Level 1 Level 2 Total Equity (a) $— $205 $205 Other Fixed Income Debt (b) — 233 233 Cash and Cash Equivalents (c) 7 26 33 Commingled Trust Fund (d) — 38 38 Real Estate (e)(f) $39 Total investments $7 $502 $548 Funds for retiree health benefits (g) 50 90 $140 Investments (including funds for retiree health benefits) $57 $592 $688 Funds for retiree health benefits measured at net asset value (f)(g) 39 Pending activities (h) 17 Total fair value of plan net assets $744 (a) - (h) Reference is made to footnotes (a) through (h) in the above table of other postretirement benefit plan assets at December 31, 2024 by asset category. The fair values of CECONY's portion of the plans' assets at December 31, 2023 by asset category (see Note R) are as follows: (Millions of Dollars) Level 1 Level 2 Total Equity (a) $— $241 $241 Other Fixed Income Debt (b) — 237 237 Cash and Cash Equivalents (c) 7 17 24 Commingled Trust Fund (d) — 38 38 Real Estate (e)(f) Total investments $7 $533 $540 Funds for retiree health benefits (g) 52 96 $148 Investments (including funds for retiree health benefits) $59 $629 $688 Funds for retiree health benefits measured at net asset value (e)(g) 45 Pending activities (h) 17 Total fair value of plan net assets $750 (a) - (h) Reference is made to footnotes (a) through (h) in the above table of other postretirement benefit plan assets at December 31, 2024 by asset category.
Schedule of Employer Contribution to Defined Savings Plan	The Companies also offer a defined contribution savings plan that covers substantially all employees and made contributions to the plan as follows: For the Years Ended December 31, (Millions of Dollars) 2024 2023 2022 Con Edison $57 $57 $57 CECONY 52 51 48

Environmental Matters (Tables)

Environmental Matters (Tables)	12 Months Ended
Environmental Matters (Tables)	Dec. 31, 2024
Environmental Remediation Obligations [Abstract]
Accrued Liabilities and Regulatory Assets	The accrued liabilities and regulatory assets related to Superfund Sites at December 31, 2024 and 2023 were as follows: Con Edison CECONY (Millions of Dollars) 2024 2023 2024 2023 Accrued Liabilities: Manufactured gas plant sites $941 $1,016 $846 $924 Other Superfund Sites 96 102 96 102 Total $1,037 $1,118 $942 $1,026 Regulatory assets $1,038 $1,105 $952 $1,022
Environmental Remediation Costs	Environmental remediation costs incurred related to Superfund Sites at December 31, 2024 and 2023 were as follows: Con Edison CECONY (Millions of Dollars) 2024 2023 2024 2023 Remediation costs incurred $44 $13 $44 $12
Accrued Liability for Asbestos Suits and Workers' Compensation Proceedings	The accrued liability for asbestos suits and workers’ compensation proceedings (including those related to asbestos exposure) and the amounts deferred as regulatory assets or liabilities for the Companies at December 31, 2024 and 2023 were as follows: Con Edison CECONY (Millions of Dollars) 2024 2023 2024 2023 Accrued liability – asbestos suits $8 $8 $7 $7 Regulatory assets – asbestos suits 8 8 7 7 Accrued liability – workers’ compensation 53 56 51 54 Regulatory liabilities – workers’ compensation 20 17 20 17

Material Contingencies (Tables)

Material Contingencies (Tables)	12 Months Ended
Material Contingencies (Tables)	Dec. 31, 2024
Commitments and Contingencies Disclosure [Abstract]
Summary of Total Guarantees	A summary, by type and term, of Con Edison’s total guarantees under these other agreements at December 31, 2024 is as follows: Guarantee Type 0 – 3 years > 10 years Total (Millions of Dollars) Con Edison Transmission $49 $— $49 Broken Bow II (a) — 9 9 Total $49 $9 $58 (a) Guarantee amount shown represents a guarantee issued on behalf of Broken Bow II associated with its investment in a wind energy facility. Broken Bow II was held for sale as of December 31, 2024, and was sold and transferred in January 2025. See Note W and Note X.

Electricity and Gas Purchase _2

Electricity and Gas Purchase Agreements (Tables)	12 Months Ended
Electricity and Gas Purchase Agreements (Tables)	Dec. 31, 2024
Regulated Operations [Abstract]
Summary of Estimated Capacity and Other Fixed Payments	The future capacity and other fixed payments under the electricity and gas purchase agreements are estimated to be as follows: (Millions of Dollars) 2025 2026 2027 2028 2029 All Years Thereafter Con Edison Electricity power purchase agreements $234 $131 $60 $49 $44 $302 Natural gas 383 11 8 — — — Gas transportation and storage 510 497 450 376 212 2,390 CECONY Electricity power purchase agreements 230 128 59 49 44 302 Natural gas 331 10 7 — — — Gas transportation and storage 445 434 394 329 185 2,083
Summary of Capacity, Energy and Other Fixed Payments	The company’s payments under the significant terms of the agreements for capacity, energy, gas transportation and storage, and other fixed payments in 2024, 2023 and 2022 were as follows: For the Years Ended December 31, (Millions of Dollars) 2024 2023 2022 Con Edison Astoria Generating Company (a) $75 $40 $45 Brooklyn Navy Yard (b) 139 134 165 Gas Transportation and Storage (c) 422 372 386 Total $636 $546 $596 CECONY Astoria Generating Company (a) $75 $40 $45 Brooklyn Navy Yard (b) 139 134 165 Gas Transportation and Storage (c) 372 327 340 Total $586 $501 $550 (a) Capacity purchase agreements with terms ending in 2024 through 2028. (b) Contract for plant output, which started in 1996 and ends in 2036. (c) Contracts for various counterparties and terms extending through 2046.

Leases (Tables)

Leases (Tables)	12 Months Ended
Leases (Tables)	Dec. 31, 2024
Leases [Abstract]
Lease Costs, Cash Flows and Other Related Information	Operating lease cost and cash paid for amounts included in the measurement of lease liabilities for the years ended December 31, 2024, 2023, and 2022 were as follows: Con Edison (a) CECONY (Millions of Dollars) 2024 2023 2022 2024 2023 2022 Operating lease cost $67 $70 $88 $66 $66 $67 Operating lease cash flows $67 $68 $83 $66 $65 $64 (a) Amounts for Con Edison include amounts for the Clean Energy Businesses through February 2023. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W and Note X. Other information related to leases for Con Edison and CECONY at December 31, 2024 and 2023 was as follows: Con Edison CECONY 2024 2023 2024 2023 Weighted Average Remaining Lease Term: Operating leases, (a) (b) 10.8 years 11.4 years 10.6 years 11.4 years Finance leases 6 years 6.6 years 5 years 2.7 years Weighted Average Discount Rate: Operating leases, (a) (b) 3.8% 3.7% 3.8% 3.7% Finance leases 2.0% 3.0% 1.6% 3.1% (a) Amounts for Con Edison in 2023 exclude operating leases of the Clean Energy Businesses, inclusive of Broken Bow II, that were classified as held for sale as of December 31, 2023. Including the operating leases of the Clean Energy Businesses would result in a weighted average remaining lease term of 11.6 years and a weighted average discount rate of 3.8 percent as of December 31, 2023. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W and Note X. (b) Amounts for Con Ediso n in 2024 exclude the operating lease of Broken Bow II, that was classified as held for sale as of December 31, 2024 and was sold and transferred in January 2025. Including the operating lease of Broken Bow II would result in a weighted average remaining lease term of 10.8 years and a weighted average discount rate of 3.8 percent as of December 31, 2024. See Note W and Note X.
Operating Leases, Future Minimum Lease Payments	Future minimum lease payments under non-cancellable leases at December 31, 2024 were as follows: (Millions of Dollars) Con Edison CECONY Year Ending December 31, (b) Operating Leases Finance Leases Operating Leases Finance Leases 2025 $68 $1 $67 $1 2026 67 1 67 1 2027 66 1 66 1 2028 61 — 61 — 2029 61 — 61 — All years thereafter 307 1 307 — Total future minimum lease payments $630 $4 $629 $3 Less: imputed interest (126) — (125) — Total $504 $4 $504 $3 Reported as of December 31, 2024 Operating lease liabilities (current) (a) $118 $— $118 $— Operating lease liabilities held for sale (current) 2 — — — Operating lease liabilities (noncurrent) (a) 386 — 386 — Operating lease liabilities held for sale (noncurrent) 5 — — — Other current liabilities — 1 — 1 Other noncurrent liabilities — 3 — 2 Total $511 $4 $504 $3 (a) Amounts exclude operating lease liabilities of Broken Bow II ($7 million) that are classified as current and noncurrent liabilities held for sale on Con Edison's consolidated balance sheet as of December 31, 2024. See Note X. Broken Bow II was sold and transferred in January 2025. (b) Amounts exclude operating lease future minimum lease payments of Broken Bow II, of $4 million in total for years ended December 31, 2025 through 2029, and $9 million for all years thereafter, and imputed interest of $6 million. Broken Bow II was sold and transferred in January 2025.
Finance Leases, Future Minimum Lease Payments	Future minimum lease payments under non-cancellable leases at December 31, 2024 were as follows: (Millions of Dollars) Con Edison CECONY Year Ending December 31, (b) Operating Leases Finance Leases Operating Leases Finance Leases 2025 $68 $1 $67 $1 2026 67 1 67 1 2027 66 1 66 1 2028 61 — 61 — 2029 61 — 61 — All years thereafter 307 1 307 — Total future minimum lease payments $630 $4 $629 $3 Less: imputed interest (126) — (125) — Total $504 $4 $504 $3 Reported as of December 31, 2024 Operating lease liabilities (current) (a) $118 $— $118 $— Operating lease liabilities held for sale (current) 2 — — — Operating lease liabilities (noncurrent) (a) 386 — 386 — Operating lease liabilities held for sale (noncurrent) 5 — — — Other current liabilities — 1 — 1 Other noncurrent liabilities — 3 — 2 Total $511 $4 $504 $3 (a) Amounts exclude operating lease liabilities of Broken Bow II ($7 million) that are classified as current and noncurrent liabilities held for sale on Con Edison's consolidated balance sheet as of December 31, 2024. See Note X. Broken Bow II was sold and transferred in January 2025. (b) Amounts exclude operating lease future minimum lease payments of Broken Bow II, of $4 million in total for years ended December 31, 2025 through 2029, and $9 million for all years thereafter, and imputed interest of $6 million. Broken Bow II was sold and transferred in January 2025.

Income Tax (Tables)

Income Tax (Tables)	12 Months Ended
Income Tax (Tables)	Dec. 31, 2024
Income Tax Disclosure [Abstract]
Schedule of Components of Income Tax	The components of income tax are as follows: Con Edison CECONY (Millions of Dollars) 2024 2023 2022 2024 2023 2022 State Current $(81) $179 $5 $(87) $(102) $— Deferred 223 6 324 219 246 110 Federal Current (17) 176 58 (63) (95) 170 Deferred 198 237 117 246 311 (23) Amortization of investment tax credits (5) (111) (6) (1) (2) (2) Total income tax expense $318 $487 $498 $314 $358 $255
Schedule of Income Tax Reconciliation	Reconciliation of the difference between income tax expense and the amount computed by applying the prevailing statutory income tax rate to income before income taxes is as follows: Con Edison CECONY (% of Pre-tax income) 2024 2023 2022 2024 2023 2022 STATUTORY TAX RATE Federal 21 % 21 % 21 % 21 % 21 % 21 % Changes in computed taxes resulting from: State income taxes, net of federal income taxes 5 5 6 5 5 5 Cost of removal 1 1 1 1 2 1 Allowance for uncollectible accounts, net of COVID-19 assistance (1) — — (1) (1) — Amortization of excess deferred federal income taxes (10) (6) (9) (10) (8) (10) Other (1) — (1) (1) (1) (1) Impacts from the sale of the Clean Energy Businesses: Changes in state apportionments, net of federal income taxes — (1) 6 — — — Deferred unamortized ITC recognized on sale of subsidiary — (4) — — — — Effective tax rate 15 % 16 % 24 % 15 % 18 % 16 %
Schedule of Differences on Deferred Tax Assets and Liabilities	The tax effects of temporary differences, which gave rise to deferred tax assets and liabilities, are as follows: Con Edison CECONY (Millions of Dollars) 2024 2023 2024 2023 Deferred tax liabilities: Property basis differences $9,222 $8,542 $8,632 $8,001 Regulatory Assets: Energy efficiency and other clean energy programs 464 351 449 344 Environmental remediation costs 291 310 267 287 Legacy meters 116 4 112 — Other regulatory assets 571 574 510 525 Pensions and retiree benefits – asset 1,063 918 1,037 894 Operating lease right-of-use asset 143 154 142 153 Total deferred tax liabilities $11,870 $10,853 $11,149 $10,204 Deferred tax assets: Regulatory liabilities: Unrecognized pension and other postretirement costs 296 265 276 244 Future income tax 343 427 312 394 Other regulatory liabilities 909 844 809 744 Tax credits carryforward 346 270 — — Superfund and other environmental costs 291 314 265 288 Pensions and retiree benefits – liability 154 167 142 153 Corporate alternative minimum tax credit carryforward 139 — 111 — Operating lease liabilities 143 154 142 153 Asset retirement obligations 127 146 127 146 Equity investments 80 98 — — Loss carryforwards 42 7 16 — Valuation allowance (12) (7) — — Other 160 125 140 109 Total deferred tax assets $3,018 $2,810 $2,340 $2,231 Net deferred tax liabilities $8,852 $8,043 $8,809 $7,973 Unamortized investment tax credits 22 26 10 11 Net deferred tax liabilities and unamortized investment tax credits $8,874 $8,069 $8,819 $7,984
Summary of Unrecognized Tax Benefits	A reconciliation of the beginning and ending amounts of unrecognized tax benefits for Con Edison and CECONY follows: Con Edison CECONY (Millions of Dollars) 2024 2023 2022 2024 2023 2022 Balance at January 1, $11 $23 $17 $7 $8 $5 Additions based on tax positions related to the current year 4 8 3 4 4 2 Additions based on tax positions of prior years — 3 6 — 1 1 Reductions for tax positions of prior years (6) (11) (1) (6) (6) — Settlements — (12) (2) — — — Balance at December 31, $9 $11 $23 $5 $7 $8

Revenue Recognition (Tables)

Revenue Recognition (Tables)	12 Months Ended
Revenue Recognition (Tables)	Dec. 31, 2024
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	The following table presents, for the years ended December 31, 2024, 2023 and 2022, revenue from contracts with customers as defined in ASC Topic 606, "Revenue from Contracts with Customers," as well as additional revenue from sources other than contracts with customers, disaggregated by major source. 2024 2023 2022 (Millions of Dollars) Revenues from contracts with customers Other revenues (a) Total operating revenues Revenues from contracts with customers Other revenues (a) Total operating revenues Revenues from contracts with customers Other revenues (a) Total operating revenues CECONY Electric $10,868 $(151) $10,717 $9,946 $132 $10,078 $9,917 $(166) $9,751 Gas 2,890 (56) 2,834 2,867 (38) 2,829 2,875 49 2,924 Steam 592 (14) 578 551 18 569 584 9 593 Total CECONY $14,350 ($221) $14,129 $13,364 $112 $13,476 $13,376 $(108) $13,268 O&R Electric 865 (13) 852 740 19 759 771 2 773 Gas 250 23 273 286 11 297 306 6 312 Total O&R $1,115 $10 $1,125 $1,026 $30 $1,056 $1,077 $8 $1,085 Clean Energy Businesses (c) Renewables — — — 68 — 68 637 — 637 Energy services — — — 7 — 7 317 — 317 Develop/Transfer Projects — — — 7 — 7 44 — 44 Other — — — — 47 47 — 321 321 Total Clean Energy Businesses $— $— $— $82 $47 $129 $998 $321 $1,319 Con Edison Transmission 4 — 4 4 — 4 4 — 4 Other (b) — (2) (2) — (2) (2) — (6) (6) Total Con Edison $15,469 $(213) $15,256 $14,476 $187 $14,663 $15,455 $215 $15,670 (a) For the Utilities, this includes primarily revenue from alternative revenue programs, such as the revenue decoupling mechanisms under their New York electric and gas rate plans, and negative revenue adjustments. (b) Other includes the parent company, Con Edison's tax equity investments, consolidation adjustments and Broken Bow II, the deferred project held for sale at December 31, 2024, the sale and transfer of which was completed in January 2025. See Note X. (c) On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W and Note X.
Change in Unbilled Contract and Unearned Revenues	2024 2023 2022 (Millions of Dollars) Unbilled contract revenue (a) Unearned revenue (b) Unbilled contract revenue (a) Unearned revenue (b) Unbilled contract revenue (a) Unearned revenue (b) Beginning balance as of January 1, $4 $— $80 $3 $35 $7 Additions (c) — — 2 — 324 — Subtractions (c) — — (d) 78 3 (d) 279 4 (d) Ending balance as of December 31, $4 $— $4 (e) $— $80 $3 (a) Unbilled contract revenue represents accumulated incurred costs and earned profits on contracts (revenue arrangements), which have been recorded as revenue, but have not yet been billed to customers, and which represent contract assets as defined in Topic 606. Substantially all accrued unbilled contract revenue is expected to be collected within one year. Unbilled contract revenue arises from the cost-to-cost method of revenue recognition. Unbilled contract revenue from fixed-price type contracts is converted to billed receivables when amounts are invoiced to customers according to contractual billing terms, which generally occur when deliveries or other performance milestones are completed. (b) Unearned revenue represents a liability for billings to customers in excess of earned revenue, which are contract liabilities as defined in Topic 606. (c) Additions for unbilled contract revenue and subtractions for unearned revenue represent additional revenue earned. Additions for unearned revenue and subtractions for unbilled contract revenue represent billings. Activity also includes appropriate balance sheet classification for the period. Of the subtractions in 2023, $21 million and $1 million relate to the sale of all of the stock of the Clean Energy Businesses for unbilled contract revenue and unearned revenue, respectively. See (e) below. (d) Of the subtractions from unearned revenue, $3 million and $4 million were included in the balances as of January 1, 2023, and 2022, respectively. (e)

Current Expected Credit Losses

Current Expected Credit Losses (Tables)	12 Months Ended
Current Expected Credit Losses (Tables)	Dec. 31, 2024
Credit Loss [Abstract]
Rollforward of Allowance for Credit Losses	The table below presents a rollforward by major portfolio segment type for the years ended December 31, 2024, 2023 and 2022: For the Year Ended December 31, Con Edison CECONY Accounts receivable - customers Other receivables Accounts receivable - customers Other receivables (Millions of Dollars) 2024 2023 2022 2024 2023 2022 2024 2023 2022 2024 2023 2022 Allowance for credit losses Beginning Balance at January 1, $360 $322 $317 $13 $10 $22 $353 $314 $304 $9 $7 $19 Recoveries 21 14 17 — — — 17 12 16 — — — Write-offs (250) (138) (103) — (5) (6) (239) (131) (94) — (3) (4) Reserve adjustments 489 162 91 28 8 (6) 474 158 88 29 5 (8) Ending Balance December 31, $620 $360 $322 $41 $13 $10 $605 $353 $314 $38 $9 $7

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	12 Months Ended
Stock-Based Compensation (Tables)	Dec. 31, 2024
Share-Based Payment Arrangement [Abstract]
Summary of Stock-Based Compensation Expense	The following table summarizes stock-based compensation expense recognized by the Companies in the years ended December 31, 2024, 2023 and 2022: Con Edison CECONY (Millions of Dollars) 2024 2023 2022 2024 2023 2022 Performance-based restricted stock $23 $41 $52 $20 $36 $43 Time-based restricted stock 2 2 2 2 2 2 Non-employee director deferred stock compensation 3 3 3 3 3 3 Stock purchase plan 7 7 7 7 7 6 Total $35 $53 $64 $32 $48 $54 Income tax benefit $10 $15 $18 $9 $13 $15
Assumptions Used to Calculate Fair Value of Awards	The assumptions used to calculate the fair value of the awards were as follows: 2024 2023 2022 Risk-free interest rate (a) 4.23% - 4.25% 4.06% - 4.64% 4.41% -4.73% Expected term (b) 3 years 3 years 3 years Expected share price volatility (c) 16.48% - 17.20% 17.88% - 19.92% 19.65% - 21.77% (a) The risk-free rate is based on the U.S. Treasury zero-coupon yield curve. (b) The expected term of the Performance RSUs equals the vesting period. The Companies do not expect significant forfeitures to occur. (c) Based on historical experience. The Companies would reevaluate this assumption if market conditions or business developments would reasonably indicate that future volatility might differ materially from historical experience.
Summary of Changes in Status of Performance RSUs	A summary of changes in the status of the Performance RSUs’ TSR and non-TSR portions during the year ended December 31, 2024 is as follows: Con Edison CECONY Weighted Average Grant Date Fair Value (a) Weighted Average Grant Date Fair Value (a) Units TSR Non-TSR Units TSR Non-TSR Non-vested at December 31, 2023 838,303 $83.70 $80.40 638,473 $83.94 $80.97 Granted 296,250 88.25 88.03 246,221 87.96 88.17 Vested (365,756) 74.36 71.12 (272,859) 74.10 71.36 Forfeited (47,996) 88.48 85.20 (38,242) 88.78 85.73 Transferred — — — (12,186) $90.81 $86.84 Non-vested at December 31, 2024 720,801 $89.99 $87.93 561,407 $90.01 $88.35 (a) The TSR and non-TSR Portions each account for 50 percent of the awards’ value. (b) Fair value is determined using the Monte Carlo simulation described above. Weighted average grant date fair value does not reflect any accrual or payment of dividends prior to vesting. (c) Fair value is determined using the market price of one share of Con Edison common stock on the grant date. The market price has not been discounted to reflect that dividends do not accrue and are not payable on Performance RSUs until vesting. (d)
Summary of Changes in Status of Time-Based Awards	A summary of changes in the status of time-based awards during the year ended December 31, 2024 is as follows: Con Edison CECONY Units Weighted Average Grant Date Units Weighted Average Grant Date Non-vested at December 31, 2023 345,201 $89.71 289,063 $90.25 Granted 200,550 88.60 173,755 88.72 Vested (14,915) 74.80 (14,015) 74.80 Forfeited (22,766) 87.67 (18,938) 87.86 Transferred — — (5,210) 86.84 Non-vested at December 31, 2024 508,070 $89.80 424,655 $90.28

Financial Information by Busi_2

Financial Information by Business Segment (Tables)	12 Months Ended
Financial Information by Business Segment (Tables)	Dec. 31, 2024
Segment Reporting [Abstract]
Financial Data for Business Segments	The financial data for the business segments are as follows: As of and for the Year Ended December 31, 2024 (Millions of Dollars) Operating revenues Inter- segment revenues Other operations and maintenance(c) Depreciation and amortization Other operating expense (c) Operating income Other Income (deductions) Interest Allowance for borrowed funds used during construction Income Tax Expense Total assets Capital expenditures CECONY Electric $10,717 $20 $2,622 $1,471 $4,792 $1,832 $441 $826 ($41) $193 $46,275 $3,088 Gas 2,834 9 528 458 1,100 748 102 287 (16) 132 16,507 1,154 Steam 578 75 203 108 254 13 35 54 (1) (11) 2,868 132 Consolidation adjustments — (104) — — — — — — — — — — Total CECONY $14,129 $— $3,353 $2,037 $6,146 $2,593 $578 $1,167 ($58) $314 $65,650 $4,374 O&R Electric $852 $— $307 $82 $351 $112 $25 $43 ($5) $24 $2,596 $214 Gas 273 — 80 35 109 49 7 22 — 5 1,464 111 Total O&R $1,125 $— $387 $117 $460 $161 $32 $65 ($5) $29 $4,060 $325 Con Edison Transmission $4 $— $11 $1 $— ($8) $61 $— $— $8 $470 $29 Other (b) (2) — — — 74 (76) (16) 18 — (33) 382 — Total Con Edison $15,256 $— $3,751 $2,155 $6,680 $2,670 $655 $1,250 ($63) $318 $70,562 $4,728 As of and for the Year Ended December 31, 2023 (Millions of Dollars) Operating revenues Inter- segment revenues Other operations and maintenance (c) Depreciation and amortization Other operating expense (c) Operating income Other Income (deductions) Interest Expense Allowance for borrowed funds used during construction Income Tax Expense Total assets Capital expenditures CECONY Electric $10,078 $18 $2,417 $1,395 $4,698 $1,568 $564 $708 ($34) $217 $42,226 $2,909 Gas 2,829 8 528 429 1,190 682 122 240 (13) 159 16,343 1,046 Steam 569 74 231 100 311 (73) 46 46 (2) (18) 3,031 128 Consolidation adjustments — (100) — — — — — — — — — — Total CECONY $13,476 $— $3,176 $1,924 $6,199 $2,177 $732 $994 ($49) $358 $61,600 $4,083 O&R Electric $759 $— $292 $76 $306 $85 $37 $35 ($3) $20 $2,329 $211 Gas 297 — 83 30 143 41 12 19 — 8 1,346 85 Total O&R $1,056 $— $375 $106 $449 $126 $49 $54 ($3) $28 $3,675 $296 Clean Energy Businesses (a) $129 $— $47 $— $45 $37 $1 $16 $— $3 $— $81 Con Edison Transmission 4 — 11 1 1 (9) 62 2 — 14 414 49 Other (b) (2) — (3) — (864) 865 (14) 9 — 84 642 — Total Con Edison $14,663 $— $3,606 $2,031 $5,830 $3,196 $830 $1,075 ($52) $487 $66,331 $4,509 As of and for the Year Ended December 31, 2022 (Millions of Dollars) Operating Inter- Other operations and maintenance (c) Depreciation Other operating expense (c) Operating Other Income (deductions) Interest Allowance for borrowed funds used during construction Income Total Capital CECONY Electric $9,751 $19 $2,373 $1,315 $4,567 $1,496 $259 $609 ($27) $134 $39,153 $2,522 Gas 2,924 8 471 367 1,426 660 52 203 (5) 140 15,361 1,128 Steam 593 76 198 96 320 (21) 21 43 (1) (19) 2,931 108 Consolidation adjustments — (103) — — — — — — — — — — Total CECONY $13,268 $— $3,042 $1,778 $6,313 $2,135 $332 $855 ($33) $255 $57,445 $3,758 O&R Electric $773 $— $275 $71 $333 $94 $17 $32 ($3) $17 $2,247 $167 Gas 312 — 77 27 166 42 6 17 — 8 1,264 76 Total O&R $1,085 $— $352 $98 $499 $136 $23 $49 ($3) $25 $3,511 $243 Clean Energy Businesses (a) $1,319 $— $503 $178 $270 $368 $3 $(35) $— $84 $7,224 $399 Con Edison Transmission 4 — 12 1 1 (10) 19 5 — 5 314 65 Other (b) (6) — (4) 1 2 (5) (51) 14 — 129 571 — Total Con Edison $15,670 $— $3,905 $2,056 $7,085 $2,624 $326 $888 ($36) $498 $69,065 $4,465 (a) The Clean Energy Businesses were classified as held for sale as of December 31, 2022. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. As a result of this sale, the Clean Energy Businesses are no longer a principal segment. See Note W and Note X. (b) Other includes the parent company, Con Edison’s tax equity investments, consolidation adjustments and Broken Bow II, the deferred project held for sale at December 31, 2024, the sale and transfer of which was completed in January 2025. (c) Other operations and maintenance expenses constitute significant segment expenses which are regularly provided to the CODMs. Other operating expense includes other segment items (purchased power, fuel, gas purchased for resale, taxes other than income taxes) and, for 2023, the preliminary gain on the sale of the Clean Energy Businesses. See Note W.

Derivative Instruments and He_2

Derivative Instruments and Hedging Activities (Tables)	12 Months Ended
Derivative Instruments and Hedging Activities (Tables)	Dec. 31, 2024
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Offsetting of Assets	The fair values of the Companies’ derivatives, including the offsetting of assets and liabilities, on the consolidated balance sheet at December 31, 2024 and 2023 were: (Millions of Dollars) 2024 2023 Balance Sheet Location Gross Amounts of Recognized Assets/ (Liabilities) Gross Amounts Offset Net Amounts of Assets/(Liabilities) (a) Gross Amounts of Recognized Assets/ (Liabilities) Gross Amounts Offset Net Amounts of Assets/(Liabilities) (a) Con Edison Fair value of derivative assets Current $56 $(41) $15 (b) $83 $(38) $45 (b) Noncurrent 39 (12) 27 77 (29) 48 Total fair value of derivative assets $95 $(53) $42 $160 $(67) $93 Fair value of derivative liabilities Current $(92) $44 $(48) (b) $(230) $52 $(178) (b) Noncurrent (108) 12 (96) (154) 33 (121) Total fair value of derivative liabilities $(200) $56 $(144) $(384) $85 $(299) Net fair value derivative assets/(liabilities) $(105) $3 $(102) $(224) $18 $(206) CECONY Fair value of derivative assets Current $51 $(40) $11 (b) $78 $(35) $43 (b) Noncurrent 36 (11) 25 76 (27) 49 Total fair value of derivative assets $87 $(51) $36 $154 $(62) $92 Fair value of derivative liabilities Current $(84) $42 $(42) (b) $(217) $48 $(169) (b) Noncurrent (95) 11 (84) (139) 31 (108) Total fair value of derivative liabilities $(179) $53 $(126) $(356) $79 $(277) Net fair value derivative assets/(liabilities) $(92) $2 $(90) $(202) $17 $(185) (a) Derivative instruments and collateral were offset on the consolidated balance sheet as applicable under the accounting rules. The Companies enter into master agreements for their commodity derivatives. These agreements typically provide offset in the event of contract termination. In such case, generally the non-defaulting party’s payable will be offset by the defaulting party’s payable. The non-defaulting party will customarily notify the defaulting party within a specific time period and come to an agreement on the early termination amount. (b) At December 31, 2024, no margin deposits for Con Edison and CECONY were classified as derivative assets and $(4) million and $(2) million, respectively were classified as derivative liabilities on the consolidated balance sheet, but not included in the table. At December 31, 2023, margin deposits for Con Edison and CECONY of $7 million and $6 million were classified as derivative assets, and $(15) million and $(10) million, respectively were classified as derivative liabilities on the consolidated balance sheets, but not included in the table. Margin is collateral, typically cash, that the holder of a derivative instrument is required to deposit in order to transact on an exchange and to cover its potential losses with its broker or the exchange.
Offsetting of Liabilities	The fair values of the Companies’ derivatives, including the offsetting of assets and liabilities, on the consolidated balance sheet at December 31, 2024 and 2023 were: (Millions of Dollars) 2024 2023 Balance Sheet Location Gross Amounts of Recognized Assets/ (Liabilities) Gross Amounts Offset Net Amounts of Assets/(Liabilities) (a) Gross Amounts of Recognized Assets/ (Liabilities) Gross Amounts Offset Net Amounts of Assets/(Liabilities) (a) Con Edison Fair value of derivative assets Current $56 $(41) $15 (b) $83 $(38) $45 (b) Noncurrent 39 (12) 27 77 (29) 48 Total fair value of derivative assets $95 $(53) $42 $160 $(67) $93 Fair value of derivative liabilities Current $(92) $44 $(48) (b) $(230) $52 $(178) (b) Noncurrent (108) 12 (96) (154) 33 (121) Total fair value of derivative liabilities $(200) $56 $(144) $(384) $85 $(299) Net fair value derivative assets/(liabilities) $(105) $3 $(102) $(224) $18 $(206) CECONY Fair value of derivative assets Current $51 $(40) $11 (b) $78 $(35) $43 (b) Noncurrent 36 (11) 25 76 (27) 49 Total fair value of derivative assets $87 $(51) $36 $154 $(62) $92 Fair value of derivative liabilities Current $(84) $42 $(42) (b) $(217) $48 $(169) (b) Noncurrent (95) 11 (84) (139) 31 (108) Total fair value of derivative liabilities $(179) $53 $(126) $(356) $79 $(277) Net fair value derivative assets/(liabilities) $(92) $2 $(90) $(202) $17 $(185) (a) Derivative instruments and collateral were offset on the consolidated balance sheet as applicable under the accounting rules. The Companies enter into master agreements for their commodity derivatives. These agreements typically provide offset in the event of contract termination. In such case, generally the non-defaulting party’s payable will be offset by the defaulting party’s payable. The non-defaulting party will customarily notify the defaulting party within a specific time period and come to an agreement on the early termination amount. (b) At December 31, 2024, no margin deposits for Con Edison and CECONY were classified as derivative assets and $(4) million and $(2) million, respectively were classified as derivative liabilities on the consolidated balance sheet, but not included in the table. At December 31, 2023, margin deposits for Con Edison and CECONY of $7 million and $6 million were classified as derivative assets, and $(15) million and $(10) million, respectively were classified as derivative liabilities on the consolidated balance sheets, but not included in the table. Margin is collateral, typically cash, that the holder of a derivative instrument is required to deposit in order to transact on an exchange and to cover its potential losses with its broker or the exchange.
Realized and Unrealized Gains or Losses on Commodity Derivatives	The following table presents the realized and unrealized gains or losses on derivatives that have been deferred or recognized in earnings for the years ended December 31, 2024 and 2023: Con Edison CECONY (Millions of Dollars) Financial Statement Location 2024 2023 2024 2023 Pre-tax gains (losses) deferred in accordance with accounting rules for regulated operations: Current Regulatory liabilities $(49) $(236) $(49) $(216) Noncurrent Regulatory liabilities (41) (96) (43) (81) Total deferred gains (losses) $(90) $(332) $(92) $(297) Current Regulatory assets $166 $(85) $161 $(76) Current Recoverable energy costs (318) (563) (294) (533) Noncurrent Regulatory assets 57 (132) 54 (122) Total deferred or recognized gains (losses) $(95) $(780) $(79) $(731) Net deferred or recognized gains (losses) (a) $(185) $(1,112) $(171) $(1,028) Financial Statement Location Pre-tax gains (losses) recognized in income Gas purchased for resale (b) $— $4 $— $— Non-utility revenue (b) — 17 — — Other interest expense (b) — 5 — — Total pre-tax gains (losses) recognized in income $— $26 $— $— (a) Unrealized net deferred losses on electric and gas derivatives for the Utilities decreased as a result of higher electric and gas commodity prices during the year ended December 31, 2024. Upon settlement, short-term deferred derivative losses generally increase the recoverable costs of electric and gas purchases.
Hedged Volume of Derivative Transactions	The following table presents the hedged volume of Con Edison’s and CECONY’s commodity derivative transactions at December 31, 2024: Electric Energy Capacity (MW-mos) (a) Natural Gas (Dt) (a)(b) Refined Fuels (gallons) Con Edison 33,303,430 31,500 313,300,000 3,780,000 CECONY 30,466,200 24,000 292,340,000 3,780,000 (a) Volumes are reported net of long and short positions, except natural gas collars where the volumes of long positions are reported. (b) Excludes electric congestion and gas basis swap contracts which are associated with electric and gas contracts and hedged volumes.
Aggregate Fair Value of Companies' Derivative Instruments with Credit-Risk-Related Contingent Features	The following table presents the aggregate fair value of the Companies’ derivative instruments with credit-risk-related contingent features that are in a net liability position, the collateral posted for such positions and the additional collateral that would have been required to be posted had the lowest applicable credit rating been reduced one level and to below investment grade at December 31, 2024: (Millions of Dollars) Con Edison (a) CECONY (a) Aggregate fair value – net liabilities $129 $112 Collateral posted 122 120 Additional collateral (b) (downgrade one level from current ratings) 17 8 Additional collateral (b)(c) (downgrade to below investment grade from current ratings) 136 114 (a) Non-derivative transactions for the purchase and sale of electricity and gas and qualifying derivative instruments, that have been designated as normal purchases or normal sales, are excluded from the table. These transactions primarily include purchases of electricity from independent system operators. In the event the Utilities are no longer extended unsecured credit for such purchases, the Companies would be required to post additional collateral of $1 million at December 31, 2024. For certain other such non-derivative transactions, the Companies could be required to post collateral under certain circumstances, including in the event counterparties had reasonable grounds for insecurity. (b) The Companies measure the collateral requirements by taking into consideration the fair value amounts of derivative instruments that contain credit-risk-related contingent features that are in a net liability position plus amounts owed to counterparties for settled transactions and amounts required by counterparties for minimum financial security. The fair value amounts represent unrealized losses, net of any unrealized gains where the Companies have a legally enforceable right to offset. (c) Derivative instruments that are net assets have been excluded from the table. At December 31, 2024, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $8 million.

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
Fair Value Measurements (Tables)	Dec. 31, 2024
Fair Value Disclosures [Abstract]
Assets and Liabilities Measured at Fair Value on Recurring Basis	For information on the measurement of Con Edison's investment in MVP that was measured at fair value on a non-recurring basis, see Note A. Assets and liabilities measured at fair value on a recurring basis for the years ended December 31, 2024 and 2023 are summarized below. 2024 2023 (Millions of Dollars) Level 1 Level 2 Level 3 Netting Total Level 1 Level 2 Level 3 Netting Total Con Edison Derivative assets: Commodity (a)(b)(c) $9 $81 $1 $(49) $42 $6 $146 $2 $(54) $100 Mutual Funds (a)(b) 570 — — — 570 505 — — — 505 Cash Value of Life Insurance — 129 — — 129 — 118 — — 118 Total assets $579 $210 $1 $(49) $741 $511 $264 $2 $(54) $723 Derivative liabilities: Commodity (a)(b)(c) $5 $175 $16 $(48) $148 $22 $347 $10 $(65) $314 CECONY Derivative assets: Commodity (a)(b)(c) $9 $74 $1 $(48) $36 $6 $143 $1 $(52) $98 Mutual Funds (a)(b) 553 — — — 553 488 — — — 488 Cash Value of Life Insurance — 123 — — 123 — 113 — — 113 Total assets $562 $197 $1 $(48) $712 $494 $256 $1 $(52) $699 Derivative liabilities: Commodity (a)(b)(c) $4 $164 $7 $(47) $128 $20 $326 $6 $(65) $287 (a) The Companies’ policy is to review the fair value hierarchy and recognize transfers into and transfers out of the levels at the end of each reporting period. Transfers out of Level 3 represent assets and liabilities that were previously classified as Level 3 for which the inputs became observable for classification in Level 2. The inputs are now observable because of availability of observable market data due to the decrease in the terms of certain contracts from beyond three years to less than three years. (b) Level 2 assets and liabilities include investments held in the deferred compensation plan and/or non-qualified retirement plans, exchange-traded contracts where there is insufficient market liquidity to warrant inclusion in Level 1, and certain over-the-counter derivative instruments for electricity, refined products and natural gas. Derivative instruments classified as Level 2 are valued using industry standard models that incorporate corroborated observable inputs, such as pricing services or prices from similar instruments that trade in liquid markets, time value and volatility factors. (c) The accounting rules for fair value measurements and disclosures require consideration of the impact of nonperformance risk (including credit risk) from a market participant perspective in the measurement of the fair value of assets and liabilities. At December 31, 2024 and 2023, the Companies determined that nonperformance risk would have no material impact on their financial position or results of operations. (d) Amounts represent the impact of legally-enforceable master netting agreements that allow the Companies to net gain and loss positions and cash collateral held or placed with the same counterparties.
Schedule of Commodity Derivatives	Fair Value of Level 3 at December 31, 2024 Average (Millions of Dollars) Valuation Techniques Unobservable Inputs Range Con Edison — Commodity Electricity $(16) Discounted Cash Flow Forward capacity prices ($/kW-month) (a) $0.73 - $7.14 $3.69 Transmission Congestion Contracts 1 Discounted Cash Flow Inter-zonal forward price curves adjusted for historical zonal losses ($/MWh) (b) $(0.20) - $3.88 $1.85 Total Con Edison - Commodity $(15) CECONY — Commodity Electricity $(7) Discounted Cash Flow Forward capacity prices ($/kW-month) (a) $0.73 - $7.14 $3.75 Transmission Congestion Contracts 1 Discounted Cash Flow Inter-zonal forward price curves adjusted for historical zonal losses ($/MWh) (b) $(0.20) - $3.88 $1.85 Total CECONY — Commodity $(6) (a) Generally, increases/(decreases) in this input in isolation would result in a higher/(lower) fair value measurement. (b) Generally, increases/(decreases) in this input in isolation would result in a lower/(higher) fair value measurement.
Reconciliation of Beginning and Ending Net Balances for Assets and Liabilities Measured at Level 3 Fair Value	The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value for the years ended December 31, 2024 and 2023 and classified as Level 3 in the fair value hierarchy: Con Edison CECONY (Millions of Dollars) 2024 2023 2024 2023 Beginning balance as of January 1, $(8) $15 $(5) $(6) Included in earnings (9) (4) (4) (2) Included in regulatory assets and liabilities (7) 33 — 31 Settlements 10 4 4 2 Decrease due to the sale of the Clean Energy Businesses (a) — (29) — — Transfer out of level 3 (1) (27) (1) (30) Ending balance as of December 31, $(15) $(8) $(6) $(5) (a)

Variable Interest Entities (Tab

Variable Interest Entities (Tables)	12 Months Ended
Variable Interest Entities (Tables)	Dec. 31, 2024
Equity Method Investments and Joint Ventures [Abstract]
Schedule Of Income (Loss), Hypothetical Liquidation At Book Value	The HLBV method of accounting resulted in income/(loss) for the year ended December 31, 2022 as follows: (Millions of Dollars) CED Nevada Virginia Tax Equity Projects Tax equity investor $(49) $(11) After tax (37) (8) Con Edison 41 51 After tax 31 38

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
Asset Retirement Obligations (Tables)	Dec. 31, 2024
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Change in Asset Retirement Obligation	The following table represents the balance of asset retirement obligations as of December 31, 2024 and 2023, and changes to the obligation for the years then ended: Con Edison CECONY (Millions of Dollars) 2024 (a) 2023 2024 2023 Beginning Balance as of January 1, $522 $500 $520 $499 Changes in estimated cash flows (21) 76 (21) 75 Accretion expense 20 17 20 17 Liabilities settled (68) (71) (67) (71) Ending Balance as of December 31, (b) $453 $522 $452 $520 (a) The asset retirement obligations of Broken Bow II in 2023 and 2024 are reflected in current liabilities held for sale on Con Edison's consolidated balance sheets as of December 31, 2023 and 2024, respectively. On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. For 2023 and 2024, $3 million of asset retirement obligations related to Broken Bow II are not shown in the table above, as they are already excluded from the beginning balance as of January 1, 2023 and January 1, 2024 for Con Edison. Broken Bow II was sold and transferred in January 2025. See Note A, Note W, and Note X. (b) At December 31, 2024, Con Edison and CECONY recorded reductions of $85 million and $84 million, respectively, to the regulatory liability associated with cost of removal to reflect depreciation and interest expense. At December 31, 2023, Con Edison and CECONY recorded reductions of $77 million to the regulatory liability associated with cost of removal to reflect depreciation and interest expense.

Related Party Transactions (Tab

Related Party Transactions (Tables)	12 Months Ended
Related Party Transactions (Tables)	Dec. 31, 2024
Related Party Transactions [Abstract]
Summary of Costs of Administrative and Other Services Provided and Received	The costs of administrative and other services provided by CECONY to, and received by it from, Con Edison and its other subsidiaries for the years ended December 31, 2024, 2023 and 2022 were as follows: CECONY (a) (Millions of Dollars) 2024 2023 2022 Cost of services provided $147 $146 $135 Cost of services received 82 82 75 (a) On March 1, 2023, Con Edison completed the sale of all of the stock of the Clean Energy Businesses. See Note W and Note X.

Dispositions (Tables)

Dispositions (Tables)	12 Months Ended
Dispositions (Tables)	Dec. 31, 2024
Discontinued Operations and Disposal Groups [Abstract]
Disposal Groups, Including Discontinued Operations	The following table shows the pre-tax operating income for the Clean Energy Businesses. The 2023 period shown is through the date of the sale of the Clean Energy Businesses; there is no applicable data for the year ended December 31, 2024. For the Year Ended December 31, (Millions of Dollars) 2023 2022 Pre-tax operating income $25 $466 Pre-tax operating income, excluding non-controlling interest 21 406 The carrying amounts of the major classes of assets and liabilities of Broken Bow II, that were transferred from Con Edison to RWE in January 2025, were presented on a held-for-sale basis as of December 31, 2023 and 2024 , and accordingly, excluded net deferred tax liability balances, as follows: (Millions of Dollars) December 31, December 31, ASSETS CURRENT ASSETS Cash and temporary cash investments $1 $— Accounts receivable and other receivables - net allowance for uncollectible accounts 2 1 Accrued unbilled revenue — 1 Restricted cash 8 5 Other current assets — 1 TOTAL CURRENT ASSETS 11 8 NON-UTILITY PLANT Non-utility property, net accumulated depreciation 59 76 NET PLANT 59 76 OTHER NONCURRENT ASSETS Intangible assets, less accumulated amortization 56 72 Operating lease right-of-use asset 7 7 TOTAL OTHER NONCURRENT ASSETS 63 79 TOTAL ASSETS $133 $163 (Millions of Dollars) December 31, December 31, LIABILITIES CURRENT LIABILITIES Long-term debt due within one year $2 $2 Operating lease liabilities 2 2 Other current liabilities 10 4 TOTAL CURRENT LIABILITIES 14 8 NONCURRENT LIABILITIES Asset retirement obligations 3 3 Operating lease liabilities 5 5 TOTAL NONCURRENT LIABILITIES 8 8 LONG-TERM DEBT 57 60 TOTAL LIABILITIES $79 $76

Held-for-Sale Treatment of th_2

Held-for-Sale Treatment of the Clean Energy Businesses (Tables)	12 Months Ended
	Dec. 31, 2024
Discontinued Operations and Disposal Groups [Abstract]
Disposal Groups, Including Discontinued Operations	The following table shows the pre-tax operating income for the Clean Energy Businesses. The 2023 period shown is through the date of the sale of the Clean Energy Businesses; there is no applicable data for the year ended December 31, 2024. For the Year Ended December 31, (Millions of Dollars) 2023 2022 Pre-tax operating income $25 $466 Pre-tax operating income, excluding non-controlling interest 21 406 The carrying amounts of the major classes of assets and liabilities of Broken Bow II, that were transferred from Con Edison to RWE in January 2025, were presented on a held-for-sale basis as of December 31, 2023 and 2024 , and accordingly, excluded net deferred tax liability balances, as follows: (Millions of Dollars) December 31, December 31, ASSETS CURRENT ASSETS Cash and temporary cash investments $1 $— Accounts receivable and other receivables - net allowance for uncollectible accounts 2 1 Accrued unbilled revenue — 1 Restricted cash 8 5 Other current assets — 1 TOTAL CURRENT ASSETS 11 8 NON-UTILITY PLANT Non-utility property, net accumulated depreciation 59 76 NET PLANT 59 76 OTHER NONCURRENT ASSETS Intangible assets, less accumulated amortization 56 72 Operating lease right-of-use asset 7 7 TOTAL OTHER NONCURRENT ASSETS 63 79 TOTAL ASSETS $133 $163 (Millions of Dollars) December 31, December 31, LIABILITIES CURRENT LIABILITIES Long-term debt due within one year $2 $2 Operating lease liabilities 2 2 Other current liabilities 10 4 TOTAL CURRENT LIABILITIES 14 8 NONCURRENT LIABILITIES Asset retirement obligations 3 3 Operating lease liabilities 5 5 TOTAL NONCURRENT LIABILITIES 8 8 LONG-TERM DEBT 57 60 TOTAL LIABILITIES $79 $76

General (Details)

General (Details)	12 Months Ended
General (Details)	Dec. 31, 2024 registrant subsidiary
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of registrants \| registrant	2
Number of regulated subsidiaries \| subsidiary	2

Summary of Significant Accoun_4

Summary of Significant Accounting Policies and Other Matters - Revenues (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Revenue from External Customer [Line Items]
Excise taxes	$ 437	$ 409	$ 400
CECONY
Revenue from External Customer [Line Items]
Excise taxes	$ 425	$ 396	$ 387

Summary of Significant Accoun_5

Summary of Significant Accounting Policies and Other Matters - Plant and Depreciation Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Public Utility, Property, Plant and Equipment [Line Items]
Annual aggregate depreciation allowance	$ 2,228
Software Licenses
Public Utility, Property, Plant and Equipment [Line Items]
Gross asset	59	$ 65
Estimated aggregate annual amortization expense	7
Accumulated amortization	$ 45	$ 38
Non-Utility Plant \| Maximum \| Solar Powered Generating Assets
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	35 years
Non-Utility Plant \| Maximum \| Wind Power Generating Assets
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	30 years
Non-Utility Plant \| Maximum \| Land And Conduit
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	10 years
CECONY
Public Utility, Property, Plant and Equipment [Line Items]
AFUDC rates (percent)	5.90%	5.90%	5.20%
Average depreciation rates (percent)	3.60%	3.60%	3.50%
Annual aggregate depreciation allowance	$ 2,109
CECONY \| Software Licenses
Public Utility, Property, Plant and Equipment [Line Items]
Gross asset	56	$ 62
Estimated aggregate annual amortization expense	7
Accumulated amortization	$ 43	$ 36
CECONY \| Electric \| Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	5 years
CECONY \| Electric \| Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	80 years
CECONY \| Gas \| Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	5 years
CECONY \| Gas \| Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	80 years
CECONY \| Steam \| Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	5 years
CECONY \| Steam \| Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	55 years
CECONY \| General Plant \| Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	5 years
CECONY \| General Plant \| Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	50 years
O&R
Public Utility, Property, Plant and Equipment [Line Items]
AFUDC rates (percent)	6%	6.20%	5%
Average depreciation rates (percent)	3.30%	3.10%	3%
O&R \| Electric \| Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	5 years
O&R \| Electric \| Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	75 years
O&R \| General Plant \| Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	5 years
O&R \| General Plant \| Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	50 years

Summary of Significant Accoun_6

Summary of Significant Accounting Policies and Other Matters - Capitalized Cost of Utility Plant (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Public Utility, Property, Plant and Equipment [Line Items]
General	$ 4,851	$ 4,835
Held for future use	77	118
Construction work in progress	3,165	2,442
NET UTILITY PLANT	52,152	49,594
Electric Generation
Public Utility, Property, Plant and Equipment [Line Items]
Generation	577	580
Electric Transmission
Public Utility, Property, Plant and Equipment [Line Items]
Transmission	5,072	4,652
Electric Distribution
Public Utility, Property, Plant and Equipment [Line Items]
Distribution	25,129	24,491
General
Public Utility, Property, Plant and Equipment [Line Items]
General	174	141
Gas
Public Utility, Property, Plant and Equipment [Line Items]
Gas	12,703	12,023
Steam
Public Utility, Property, Plant and Equipment [Line Items]
Steam	2,006	1,990
General
Public Utility, Property, Plant and Equipment [Line Items]
General	3,249	3,158
CECONY
Public Utility, Property, Plant and Equipment [Line Items]
General	4,520	4,530
Held for future use	69	110
Construction work in progress	2,912	2,168
NET UTILITY PLANT	48,981	46,646
CECONY \| Electric Generation
Public Utility, Property, Plant and Equipment [Line Items]
Generation	577	580
CECONY \| Electric Transmission
Public Utility, Property, Plant and Equipment [Line Items]
Transmission	4,703	4,333
CECONY \| Electric Distribution
Public Utility, Property, Plant and Equipment [Line Items]
Distribution	23,770	23,238
CECONY \| General
Public Utility, Property, Plant and Equipment [Line Items]
General	174	141
CECONY \| Gas
Public Utility, Property, Plant and Equipment [Line Items]
Gas	11,830	11,226
CECONY \| Steam
Public Utility, Property, Plant and Equipment [Line Items]
Steam	2,006	1,990
CECONY \| General
Public Utility, Property, Plant and Equipment [Line Items]
General	$ 2,940	$ 2,860

Summary of Significant Accoun_7

Summary of Significant Accounting Policies and Other Matters - Other Deferred Charges (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Public Utility, Property, Plant and Equipment [Line Items]
Prepayments	$ 57	$ 50
Other deferred charges and noncurrent assets	254	179
Depreciation expense, other deferred charges and noncurrent assets and prepayments	33	21	$ 15
Accumulated depreciation, other deferred charges and noncurrent assets and prepayments	91	58
CECONY
Public Utility, Property, Plant and Equipment [Line Items]
Prepayments	54	49
Other deferred charges and noncurrent assets	243	178
Depreciation expense, other deferred charges and noncurrent assets and prepayments	32	20	$ 14
Accumulated depreciation, other deferred charges and noncurrent assets and prepayments	$ 85	$ 53

Summary of Significant Accoun_8

Summary of Significant Accounting Policies and Other Matters - Long-Lived and Intangible Assets (Details) - USD ($)	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible assets			$ 71,000,000
Amortization expense, year 1	$ 0
Amortization expense, year 2	0
Amortization expense, year 3	0
Amortization expense, year 4	0
Amortization expense, year 5	0
Impairment charges	0	$ 0	$ 0
Other Intangible Assets
Finite-Lived Intangible Assets [Line Items]
Intangible assets, net	0	0
Other Intangible Assets \| CECONY
Finite-Lived Intangible Assets [Line Items]
Intangible assets, net	$ 0	$ 0

Summary of Significant Accoun_9

Summary of Significant Accounting Policies and Other Matters - Recoverable Energy Costs (Details)	12 Months Ended
	Dec. 31, 2024
Minimum
Public Utilities, General Disclosures [Line Items]
Recovery or refund of energy costs, deferral period (in months)	1 month
Maximum
Public Utilities, General Disclosures [Line Items]
Recovery or refund of energy costs, deferral period (in months)	2 months

Summary of Significant Accou_10

Summary of Significant Accounting Policies and Other Matters - Investments (Details) - Mountain Valley Pipeline $ in Millions	1 Months Ended	12 Months Ended
	Jun. 30, 2024 mi	Dec. 31, 2024 USD ($)	Dec. 31, 2016 mi	Dec. 31, 2023 USD ($)	Dec. 31, 2021 USD ($)	May 31, 2021 USD ($)	Dec. 31, 2019 USD ($)	Jan. 31, 2016
Schedule of Equity Method Investments [Line Items]
Equity method investments		$ 530		$ 530
CET Gas
Schedule of Equity Method Investments [Line Items]
Equity method investment, ownership percent (in percent)		6.70%
Number of miles in pipeline construction \| mi	303		300
Equity method investments					$ 166		$ 530
Aggregate project cost		$ 8,100				$ 8,100
Payments to acquire equity method investments		530
Income (loss) from equity method investments		29
Income (loss) from equity method Investments, after tax		$ 21
Expected reduction in equity interest		6.60%
CET Gas \| Mountain Valley Pipeline
Schedule of Equity Method Investments [Line Items]
Equity method investment, ownership percent (in percent)								12.50%

Summary of Significant Accou_11

Summary of Significant Accounting Policies and Other Matters - Schedule of Investments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2021	May 31, 2021	Dec. 31, 2019
Schedule of Equity Method Investments [Line Items]
Supplemental retirement income plan assets	$ 583	$ 524
Deferred income plan assets	116	99
Other	3	3
Total investments	1,126	999
New York Transco, LLC
Schedule of Equity Method Investments [Line Items]
Undistributed Earnings, Basic	16	13
CECONY
Schedule of Equity Method Investments [Line Items]
Supplemental retirement income plan assets	560	502
Deferred income plan assets	116	99
Other	8	7
Total investments	684	608
New York Transco, LLC \| Con Edison Transmission
Schedule of Equity Method Investments [Line Items]
Equity method investment	254	221
New York Transco, LLC \| Con Edison Transmission \| CECONY
Schedule of Equity Method Investments [Line Items]
Equity method investment	0	0
Mountain Valley Pipeline
Schedule of Equity Method Investments [Line Items]
Equity method investment	530	530
Undistributed Earnings, Basic	127	114
Mountain Valley Pipeline \| CET Gas
Schedule of Equity Method Investments [Line Items]
Equity method investment			$ 166		$ 530
Aggregate project cost	8,100			$ 8,100
Mountain Valley Pipeline \| Con Edison Transmission
Schedule of Equity Method Investments [Line Items]
Equity method investment	166	144
Mountain Valley Pipeline \| Con Edison Transmission \| CECONY
Schedule of Equity Method Investments [Line Items]
Equity method investment	0	0
Virginia Tax Equity Project
Schedule of Equity Method Investments [Line Items]
Equity method investment	4	8
Virginia Tax Equity Project \| CECONY
Schedule of Equity Method Investments [Line Items]
Equity method investment	$ 0	$ 0

Summary of Significant Accou_12

Summary of Significant Accounting Policies and Other Matters - Pension and Other Postretirement Benefits (Details)	12 Months Ended
	Dec. 31, 2024
Accounting Policies [Abstract]
Investment gains and losses recognized, time period (years)	15 years
Other actuarial gains and losses recognized, time period (years)	10 years
Difference between fair value and expected market related value of plan assets (percent)	20%

Summary of Significant Accou_13

Summary of Significant Accounting Policies and Other Matters - Earnings Per Common Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Accounting Policies [Abstract]
Net income for common stock	$ 1,820	$ 2,519	$ 1,660
Weighted average common shares outstanding – basic (in shares)	346	347.7	354.5
Add: Incremental shares attributable to effect of potentially dilutive securities (in shares)	1.3	1.6	1.3
Adjusted weighted average common shares outstanding – diluted (in shares)	347.3	349.3	355.8
Net income per common share — basic (in dollars per share)	$ 5.26	$ 7.25	$ 4.68
Net income per common share — diluted (in dollars per share)	$ 5.24	$ 7.21	$ 4.66

Summary of Significant Accou_14

Summary of Significant Accounting Policies and Other Matters - Reconciliation of Cash, Temporary Investments and Restricted Cash (Details) $ in Millions	Dec. 31, 2024 USD ($) MWh	Dec. 31, 2023 USD ($)	Mar. 01, 2023 MWh
Cash and Cash Equivalents [Line Items]
Cash and temporary cash investments	$ 1,324	$ 1,189
Restricted cash	9	6
Total cash, temporary cash investments and restricted cash	$ 1,333	1,195
Electric Energy
Cash and Cash Equivalents [Line Items]
Notional amount \| MWh	33,303,430
CECONY
Cash and Cash Equivalents [Line Items]
Cash and temporary cash investments	$ 1,254	$ 1,138
CECONY \| Electric Energy
Cash and Cash Equivalents [Line Items]
Notional amount \| MWh	30,466,200
Clean Energy Businesses \| Broken Bow II \| Electric Energy
Cash and Cash Equivalents [Line Items]
Notional amount \| MWh	75		75

Summary of Significant Accou_15

Summary of Significant Accounting Policies and Other Matters - Assets Held For Sale (Details)	Mar. 01, 2023 project
Broken Bow II \| Electric Energy \| Clean Energy Businesses
Schedule of Equity Method Investments [Line Items]
Number of deferred projects	1
Disposal Group, Held-for-sale, Not Discontinued Operations \| Clean Energy Businesses
Schedule of Equity Method Investments [Line Items]
Number of tax equity projects	2

Regulatory Matters - Summary of

Regulatory Matters - Summary of Utilities Rate Plans (CECONY-Electric) (Details) - USD ($)	1 Months Ended	12 Months Ended					36 Months Ended
	Nov. 30, 2021	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2025	Dec. 31, 2022
Public Utilities, General Disclosures [Line Items]
Deferred regulatory liabilities		$ 0	$ 0	$ 3,000,000	$ 7,000,000			$ 3,000,000
TOTAL OPERATING REVENUES		15,256,000,000	14,663,000,000	15,670,000,000
CECONY
Public Utilities, General Disclosures [Line Items]
Cost reconciliation, deferred net regulatory liabilities		2,400,000
TOTAL OPERATING REVENUES		14,129,000,000	13,476,000,000	13,268,000,000
CECONY \| Electric
Public Utilities, General Disclosures [Line Items]
Retention of annual transmission congestion revenues								75,000,000
Actual earnings adjustment mechanism incentives		34,400,000	52,300,000	33,000,000	34,000,000	$ 64,000,000
Deferred regulatory liabilities		164,000,000	162,000,000	90,000,000	226,000,000	242,000,000		90,000,000
Negative revenue adjustments		0	3,000,000		0	5,000,000
Cost reconciliation, deferred net regulatory liabilities		52,000,000	140,000,000	138,000,000	191,000,000	288,000,000		138,000,000
Deferred regulatory asset (liability)		$ (25,300,000)	1,200,000	$ 1,800,000	3,200,000	4,100,000		$ 1,800,000
Authorized return on common equity (percent)								8.80%
Earnings sharing (percent)		9.30%
Earnings sharing, threshold limit		$ 0	0		0	$ 0
Earnings sharing, positive adjustment					$ 4,300,000
Common equity ratio (percent)								48%
Recovery or refund of energy costs, deferral period								10 years
Deferrals for property taxes limitation from rates (percent)								90%
Recovery deferral (percent)		80%
Maximum deferral (percent)		15%
CECONY \| Electric \| Gas Leak Backlog, Leak Prone Pipe and Service Terminations
Public Utilities, General Disclosures [Line Items]
TOTAL OPERATING REVENUES			4,000,000
CECONY \| Electric \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Retention of annual transmission congestion revenues							$ 75,000,000
Authorized return on common equity (percent)							925%
Earnings sharing (percent)							9.75%
Common equity ratio (percent)							48%
CECONY \| Electric \| NYSPSC
Public Utilities, General Disclosures [Line Items]
Actual return on common equity (percent)					8.81%
Amount of cost recovery	$ 43,000,000
CECONY \| Electric \| Rate Plan for Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes			113,000,000
Amortizations to income of net regulatory (assets) and liabilities								$ 267,000,000
Potential earnings adjustment mechanism incentives								69,000,000
Potential penalties (annually)								450,000,000
Weighted average cost of capital (after-tax)								$ 21,660,000,000
Weighted average cost of capital (after-tax) (percent)								6.61%
Actual return on common equity (percent)								8.50%
Cost of long-term debt rate		4.63%
Recovery of energy efficiency and savings program costs								$ 206,000,000
Deferral, annual maximum (not more than) (percent)								0.10%
CECONY \| Electric \| Rate Plan for Year 1 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes							$ 442,000,000
Amortizations to income of net regulatory (assets) and liabilities							104,000,000
Potential earnings adjustment mechanism incentives							70,000,000
Potential penalties (annually)							516,000,000
Weighted average cost of capital (after-tax)							$ 26,095,000,000
Weighted average cost of capital (after-tax) (percent)							6.75%
Actual return on common equity (percent)							9.46%
Cost of long-term debt rate							4.46%
Deferral, annual maximum (not more than) (percent)							0.10%
CECONY \| Electric \| Rate Plan for Year 1 \| Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations								$ 24,491,000,000
CECONY \| Electric \| Rate Plan for Year 1 \| Electric average excluding AMI \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							$ 27,847,000,000
CECONY \| Electric \| Rate Plan for Year 1 \| Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations								572,000,000
CECONY \| Electric \| Rate Plan for Year 1 \| Advanced metering infrastructure (AMI) \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							744,000,000
CECONY \| Electric \| Rate Plan for Year 1 \| Customer Service Systems (CSS) \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							11,000,000
CECONY \| Electric \| Rate Plan for Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes			370,000,000
Amortizations to income of net regulatory (assets) and liabilities								269,000,000
Potential earnings adjustment mechanism incentives								74,000,000
Potential penalties (annually)								461,000,000
Weighted average cost of capital (after-tax)								$ 22,783,000,000
Weighted average cost of capital (after-tax) (percent)								6.61%
Actual return on common equity (percent)								8.03%
Cost of long-term debt rate		4.63%
Recovery of energy efficiency and savings program costs								$ 245,000,000
Deferral, annual maximum (not more than) (percent)								0.075%
CECONY \| Electric \| Rate Plan for Year 2 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes							518,000,000
Amortizations to income of net regulatory (assets) and liabilities							49,000,000
Potential earnings adjustment mechanism incentives							75,000,000
Potential penalties (annually)							557,000,000
Weighted average cost of capital (after-tax)							$ 27,925,000,000
Weighted average cost of capital (after-tax) (percent)							6.79%
Actual return on common equity (percent)							9.21%
Cost of long-term debt rate							4.54%
Deferral, annual maximum (not more than) (percent)							0.05%
CECONY \| Electric \| Rate Plan for Year 2 \| Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations								$ 25,092,000,000
CECONY \| Electric \| Rate Plan for Year 2 \| Electric average excluding AMI \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							$ 29,884,000,000
CECONY \| Electric \| Rate Plan for Year 2 \| Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations								740,000,000
CECONY \| Electric \| Rate Plan for Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes			$ 326,000,000
Amortizations to income of net regulatory (assets) and liabilities								272,000,000
Potential earnings adjustment mechanism incentives								79,000,000
Potential penalties (annually)								476,000,000
Weighted average cost of capital (after-tax)								$ 23,926,000,000
Weighted average cost of capital (after-tax) (percent)								6.61%
Actual return on common equity (percent)								8.41%
Cost of long-term debt rate		4.63%
Recovery of energy efficiency and savings program costs								$ 251,000,000
Deferral, annual maximum (not more than) (percent)								0.05%
CECONY \| Electric \| Rate Plan for Year 3 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes							382,000,000
Amortizations to income of net regulatory (assets) and liabilities							(205,000,000)
Potential earnings adjustment mechanism incentives							79,000,000
Potential penalties (annually)							597,000,000
Weighted average cost of capital (after-tax)							$ 29,362,000,000
Weighted average cost of capital (after-tax) (percent)							6.85%
Cost of long-term debt rate							4.64%
Deferral, annual maximum (not more than) (percent)							0.05%
CECONY \| Electric \| Rate Plan for Year 3 \| Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations								$ 25,708,000,000
CECONY \| Electric \| Rate Plan for Year 3 \| Electric average excluding AMI \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							$ 31,026,000,000
CECONY \| Electric \| Rate Plan for Year 3 \| Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations								806,000,000
Annually \| CECONY \| Electric
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA								126,000,000
Annually \| CECONY \| Electric \| Deferred Project Costs
Public Utilities, General Disclosures [Line Items]
Amortizations to income of net regulatory (assets) and liabilities								48,000,000
Annually \| CECONY \| Electric \| Deferred Project Costs \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Amortizations to income of net regulatory (assets) and liabilities							31,000,000
Annually \| CECONY \| Electric \| Rate Plan for Year 1 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA							128,000,000
Annually \| CECONY \| Electric \| Rate Plan for Year 2 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA							128,000,000
Over Five Years \| CECONY \| Electric \| Deferred Project Costs
Public Utilities, General Disclosures [Line Items]
Amortizations to income of net regulatory (assets) and liabilities								238,000,000
Over Three Years \| CECONY \| Electric
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA								377,000,000
Over Three Years \| CECONY \| Electric \| Deferred Project Costs \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Amortizations to income of net regulatory (assets) and liabilities							93,000,000
Over Two Years \| CECONY \| Electric \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA							256,000,000
Over Seven To Fifteen Years \| CECONY \| Electric \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Shortfall in revenue							216,000,000
Over Seven To Fifteen Years \| CECONY \| Electric \| Rate Plan for Year 1 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount							457,000,000
Amount of cost recovery							244,000,000
Over Seven To Fifteen Years \| CECONY \| Electric \| Rate Plan for Year 2 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount							457,000,000
Amount of cost recovery							237,000,000
Over Seven To Fifteen Years \| CECONY \| Electric \| Rate Plan for Year 3 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount							457,000,000
Amount of cost recovery							281,000,000
Protected Portion \| CECONY \| Electric
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA								1,663,000,000
Protected Portion \| CECONY \| Electric \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA							1,512,000,000
Protected Portion \| CECONY \| Electric \| Rate Plan for Year 1
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA								49,000,000
Protected Portion \| CECONY \| Electric \| Rate Plan for Year 1 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA							34,000,000
Protected Portion \| CECONY \| Electric \| Rate Plan for Year 2
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA								50,000,000
Protected Portion \| CECONY \| Electric \| Rate Plan for Year 2 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA							63,000,000
Protected Portion \| CECONY \| Electric \| Rate Plan for Year 3
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA								53,000,000
Protected Portion \| CECONY \| Electric \| Rate Plan for Year 3 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA							34,000,000
Unprotected Portion \| CECONY \| Electric
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA								$ 784,000,000
TCJA of 2017 regulatory liabilities, income tax benefit, amortization period								5 years
Unprotected Portion \| Annually \| CECONY \| Electric
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA								$ 157,000,000
Unprotected Portion \| Annually \| CECONY \| Electric \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA							153,000,000
Unprotected Portion \| Over Two Years \| CECONY \| Electric \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA							$ 306,000,000

Regulatory Matters - Utility Ra

Regulatory Matters - Utility Rate Narrative and RECO Narrative (Details) $ in Thousands

1 Months Ended

12 Months Ended

36 Months Ended

Jan. 01, 2024 USD ($)

Aug. 30, 2022 USD ($)

Jan. 01, 2022 USD ($)

Dec. 31, 2021 USD ($)

Jan. 31, 2025 USD ($)

Mar. 31, 2024 USD ($)

Jan. 31, 2024

Aug. 31, 2023 USD ($) substation

Dec. 31, 2022 USD ($)

Jan. 31, 2022

Dec. 31, 2028 USD ($)

Dec. 31, 2027 USD ($)

Dec. 31, 2027

Dec. 31, 2025

Dec. 31, 2024 USD ($)

Dec. 31, 2022

Nov. 24, 2024 USD ($)

May 31, 2024 USD ($)

Dec. 31, 2023 USD ($)

Eastern Queens Reliability Project

Public Utilities, General Disclosures [Line Items]

Estimated cost of substations

$ 1,200,000

CECONY

Public Utilities, General Disclosures [Line Items]

Deferred costs

$ 3,000

Bill relief program, amount received

$ 91,000

Public utilities, billing system costs

510,000

Public utilities, requested capitalization of billing system costs

89,000

Public Utilities, Incremental Costs

$ 51,000

Net regulatory assets

1,078,000

$ 1,113,000

Number of substations | substation

CECONY | Maximum

Public Utilities, General Disclosures [Line Items]

Public utilities, limit for capitalization

421,000

$ 421,000

38,000

CECONY | Electric

Public Utilities, General Disclosures [Line Items]

Authorized return on common equity (percent)

8.80%

Common equity ratio (percent)

48%

CECONY | Electric | Scenario, Forecast

Public Utilities, General Disclosures [Line Items]

Authorized return on common equity (percent)

925%

Common equity ratio (percent)

48%

RECO

Public Utilities, General Disclosures [Line Items]

Authorized return on common equity (percent)

9.60%

Common equity ratio (percent)

48.51%

RECO | New Jersey Board of Public Utilities

Public Utilities, General Disclosures [Line Items]

Investment plan

$ 47,800

Investment plan, term (in years)

5 years

Defer incremental preparation costs

$ 5,000

RECO | Electric

Public Utilities, General Disclosures [Line Items]

Requested rate increase (decrease), amount

$ 20,700

$ 18,200

$ 16,900

RECO | Electric | New Jersey Board of Public Utilities

Public Utilities, General Disclosures [Line Items]

Requested rate increase (decrease), amount

$ 9,650

O&R

Public Utilities, General Disclosures [Line Items]

Bill relief program, amount received

$ 9,000

Net regulatory assets

$ 14,000

$ 18,000

O&R | Electric

Public Utilities, General Disclosures [Line Items]

Authorized return on common equity (percent)

10.10%

Common equity ratio (percent)

48%

O&R | Electric | Subsequent Event

Public Utilities, General Disclosures [Line Items]

Requested rate increase (decrease), amount

$ 1,612,000

Authorized return on common equity (percent)

10.10%

Common equity ratio (percent)

4,800%

O&R | Electric | Scenario, Forecast

Public Utilities, General Disclosures [Line Items]

Requested rate increase (decrease), amount

$ 880,000

$ 932,000

Common equity ratio (percent)

48%

Regulatory Matters - Summary _2

Regulatory Matters - Summary of Utilities Rate Plans (CECONY-Gas) (Details) - USD ($)	1 Months Ended	12 Months Ended					36 Months Ended
	Nov. 30, 2021	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2025	Dec. 31, 2022	Dec. 31, 2021
Public Utilities, General Disclosures [Line Items]
TOTAL OPERATING REVENUES		$ 15,256,000,000	$ 14,663,000,000	$ 15,670,000,000
Deferred regulatory liabilities		0	0	3,000,000	$ 7,000,000			$ 3,000,000	$ 7,000,000
CECONY
Public Utilities, General Disclosures [Line Items]
TOTAL OPERATING REVENUES		14,129,000,000	13,476,000,000	13,268,000,000
Cost reconciliation, deferred net regulatory liabilities		2,400,000
CECONY \| Gas
Public Utilities, General Disclosures [Line Items]
Percentage of revenue reserve								15%
Other earnings incentives		7,000,000	5,000,000	8,000,000	26,000,000	$ 3,000,000
Deferred regulatory liabilities		93,000,000	162,000,000	141,000,000	100,000,000	27,000,000		$ 141,000,000	100,000,000
Negative revenue adjustments		2,000,000	3,000,000	8,000,000
Cost reconciliation, deferred net regulatory liabilities		29,000,000	12,000,000	70,000,000	14,000,000	91,000,000		70,000,000	14,000,000
Deferred regulatory asset (liability)		(31,500,000)	(15,500,000)	$ 10,800,000	(26,000,000)	$ (24,700,000)		$ 10,800,000	(26,000,000)
Authorized return on common equity (percent)								8.80%
Earnings sharing (percent)				9.30%				9.30%
Earnings sharing, threshold limit		4,300,000	0	$ 0
CECONY \| Gas \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Percentage of revenue reserve							15%
Earnings sharing (percent)							9.75%
Common equity ratio (percent)							48%
CECONY \| Gas \| Maximum
Public Utilities, General Disclosures [Line Items]
Amount of revenues retained				65,000,000				$ 65,000,000
CECONY \| Gas \| Maximum \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Amount of revenues retained							$ 65,000,000
CECONY \| Gas \| Gas Leak Backlog, Leak Prone Pipe and Service Terminations
Public Utilities, General Disclosures [Line Items]
TOTAL OPERATING REVENUES		$ 3,000,000	$ 9,000,000	7,000,000	$ 13,000,000
CECONY \| Gas \| Service Termination
Public Utilities, General Disclosures [Line Items]
Incentives reversed				$ 6,000,000
CECONY \| Gas \| Rate Plan for Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes								84,000,000
Amortizations to income of net regulatory (assets) and liabilities								45,000,000
Potential incentives if performance targets are met								20,000,000
Potential penalties (annually)								81,000,000
Weighted average cost of capital (after-tax)								$ 7,171,000,000
Weighted average cost of capital (after-tax) (percent)								6.61%
Actual return on common equity (percent)								8.40%
Cost of long-term debt rate				4.63%				4.63%
Requested rate increase (decrease), amount									10,400,000
CECONY \| Gas \| Rate Plan for Year 1 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes							217,000,000
Amortizations to income of net regulatory (assets) and liabilities							31,000,000
Potential incentives if performance targets are met							18,000,000
Potential penalties (annually)							107,000,000
Weighted average cost of capital (after-tax)							$ 9,647,000,000
Weighted average cost of capital (after-tax) (percent)							6.75%
Authorized return on common equity (percent)							9.25%
Actual return on common equity (percent)							9%
Cost of long-term debt rate							4.46%
CECONY \| Gas \| Rate Plan for Year 1 \| Gas average excluding AMI
Public Utilities, General Disclosures [Line Items]
Average rate base								$ 8,108,000,000
CECONY \| Gas \| Rate Plan for Year 1 \| Gas average excluding AMI \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Average rate base							$ 10,466,000,000
CECONY \| Gas \| Rate Plan for Year 1 \| AMI
Public Utilities, General Disclosures [Line Items]
Average rate base								142,000,000
CECONY \| Gas \| Rate Plan for Year 1 \| AMI \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Average rate base							234,000,000
CECONY \| Gas \| Rate Plan for Year 1 \| Customer Service Systems (CSS) \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Average rate base							2,000,000
CECONY \| Gas \| Rate Plan for Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes								122,000,000
Amortizations to income of net regulatory (assets) and liabilities								43,000,000
Potential incentives if performance targets are met								22,000,000
Potential penalties (annually)								88,000,000
Weighted average cost of capital (after-tax)								$ 7,911,000,000
Weighted average cost of capital (after-tax) (percent)								6.61%
Actual return on common equity (percent)								8.48%
Cost of long-term debt rate				4.63%				4.63%
Requested rate increase (decrease), amount									10,400,000
CECONY \| Gas \| Rate Plan for Year 2 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes							173,000,000
Amortizations to income of net regulatory (assets) and liabilities							24,000,000
Potential incentives if performance targets are met							20,000,000
Potential penalties (annually)							119,000,000
Weighted average cost of capital (after-tax)							$ 10,428,000,000
Weighted average cost of capital (after-tax) (percent)							6.79%
Actual return on common equity (percent)							9.82%
Cost of long-term debt rate							4.54%
CECONY \| Gas \| Rate Plan for Year 2 \| Gas average excluding AMI
Public Utilities, General Disclosures [Line Items]
Average rate base								$ 8,808,000,000
CECONY \| Gas \| Rate Plan for Year 2 \| Gas average excluding AMI \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Average rate base							$ 11,442,000,000
CECONY \| Gas \| Rate Plan for Year 2 \| AMI
Public Utilities, General Disclosures [Line Items]
Average rate base								183,000,000
CECONY \| Gas \| Rate Plan for Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes								167,000,000
Amortizations to income of net regulatory (assets) and liabilities								10,000,000
Potential incentives if performance targets are met								25,000,000
Potential penalties (annually)								96,000,000
Weighted average cost of capital (after-tax)								$ 8,622,000,000
Weighted average cost of capital (after-tax) (percent)								6.61%
Actual return on common equity (percent)								8.93%
Cost of long-term debt rate				4.63%				4.63%
Requested rate increase (decrease), amount									$ 10,400,000
CECONY \| Gas \| Rate Plan for Year 3 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes							122,000,000
Amortizations to income of net regulatory (assets) and liabilities							(11,000,000)
Potential incentives if performance targets are met							21,000,000
Potential penalties (annually)							130,000,000
Weighted average cost of capital (after-tax)							$ 11,063,000,000
Weighted average cost of capital (after-tax) (percent)							6.85%
Cost of long-term debt rate							4.64%
CECONY \| Gas \| Rate Plan for Year 3 \| Gas average excluding AMI
Public Utilities, General Disclosures [Line Items]
Average rate base								$ 9,510,000,000
CECONY \| Gas \| Rate Plan for Year 3 \| Gas average excluding AMI \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Average rate base							$ 12,142,000,000
CECONY \| Gas \| Rate Plan for Year 3 \| AMI
Public Utilities, General Disclosures [Line Items]
Average rate base								211,000,000
NYSPSC \| CECONY \| Gas
Public Utilities, General Disclosures [Line Items]
Actual return on common equity (percent)						8.56%
Amount of cost recovery	$ 7,000,000
Annually \| CECONY \| Gas
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA								32,000,000
Annually \| CECONY \| Gas \| Rate Plan for Year 1 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA							16,000,000
Annually \| CECONY \| Gas \| Rate Plan for Year 2 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA							16,000,000
Over Ten Years \| CECONY \| Gas \| Rate Plan for Year 1
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount								47,000,000
Amount of cost recovery								30,000,000
Over Ten Years \| CECONY \| Gas \| Rate Plan for Year 2
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount								176,000,000
Amount of cost recovery								37,000,000
Over Ten Years \| CECONY \| Gas \| Rate Plan for Year 3
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount								170,000,000
Amount of cost recovery								40,000,000
Over Two Years \| CECONY \| Gas
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA								63,000,000
Over Two Years \| CECONY \| Gas \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA							32,000,000
Over Fifteen Years \| CECONY \| Gas \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Shortfall in revenue							99,000,000
Over Fifteen Years \| CECONY \| Gas \| Rate Plan for Year 1 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount							187,000,000
Amount of cost recovery							45,000,000
Over Fifteen Years \| CECONY \| Gas \| Rate Plan for Year 2 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount							187,000,000
Amount of cost recovery							78,000,000
Over Fifteen Years \| CECONY \| Gas \| Rate Plan for Year 3 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount							187,000,000
Amount of cost recovery							62,000,000
Protected Portion \| CECONY \| Gas
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA								725,000,000
Protected Portion \| CECONY \| Gas \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA							679,000,000
Protected Portion \| CECONY \| Gas \| Rate Plan for Year 1
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA								14,000,000
Protected Portion \| CECONY \| Gas \| Rate Plan for Year 1 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA							9,000,000
Protected Portion \| CECONY \| Gas \| Rate Plan for Year 2
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA								14,000,000
Protected Portion \| CECONY \| Gas \| Rate Plan for Year 2 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA							10,000,000
Protected Portion \| CECONY \| Gas \| Rate Plan for Year 3
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA								12,000,000
Protected Portion \| CECONY \| Gas \| Rate Plan for Year 3 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA							10,000,000
Unprotected Portion \| Annually \| CECONY \| Gas
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA								21,000,000
Unprotected Portion \| Annually \| CECONY \| Gas \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA							21,000,000
Unprotected Portion \| Over Two Years \| CECONY \| Gas \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA							$ 42,000,000
Unprotected Portion \| Over Five Years \| CECONY \| Gas
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA								$ 107,000,000

Regulatory Matters - Summary _3

Regulatory Matters - Summary of Utilities Rate Plans (CECONY-Steam) (Details)	12 Months Ended														36 Months Ended							108 Months Ended
	Dec. 31, 2028 USD ($)	Dec. 31, 2027 USD ($)	Dec. 31, 2026 USD ($)	Dec. 31, 2024 USD ($)	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)	Dec. 31, 2018 USD ($)	Dec. 31, 2017 USD ($)	Dec. 31, 2016 USD ($)	Dec. 31, 2015 USD ($)	Dec. 31, 2014 USD ($)	Dec. 31, 2027 USD ($)	Oct. 31, 2026 USD ($)	Dec. 31, 2025 USD ($)	Dec. 31, 2024 USD ($)	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)	Dec. 31, 2016 USD ($)	Dec. 31, 2022 USD ($)
CECONY
Public Utilities, General Disclosures [Line Items]
Cost reconciliation, deferred net regulatory liabilities				$ 2,400,000														$ 2,400,000
CECONY \| Steam
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities, amortization period												3 years									3 years
Amortizations to income of net regulatory (assets) and liabilities																					$ 37,000,000
Negative revenue adjustments																						$ 0
Cost reconciliation, deferred net regulatory liabilities				7,000,000	$ 18,000,000		$ 8,000,000		$ 14,000,000	$ 8,000,000		$ 42,000,000						7,000,000		$ 8,000,000	$ 42,000,000
Cost reconciliation, deferred net regulatory assets				11,000,000	32,000,000	$ 35,000,000		$ 1,000,000			$ 17,000,000							11,000,000	$ 35,000,000			35,000,000
Deferred regulatory asset (liability)				0			(1,000,000)	(2,000,000)										$ 0		(1,000,000)
Increase (decrease) in regulatory liabilities				100,000			0	$ 0	0		0	0	$ 0	$ 100,000
Authorized return on common equity (percent)																					9.30%
Earnings sharing, positive adjustment										2,300,000	1,100,000	4,000,000
Earnings sharing, threshold limit				$ 0	0	0			$ 5,000,000	$ 16,500,000	$ 8,500,000	7,800,000	$ 11,500,000	$ 0
Earnings sharing (percent)								9.90%
Earnings sharing, additional adjustment					200,000							400,000
Common equity ratio (percent)																					48%
Revenue from contracts with customer, late payment charges, annual cap, percent (in percent)				0.005														0.005
Difference in property taxes (percent)				90%																	90%
Deferral, annual maximum (not more than) (percent)																					0.10%
Recovery deferral (percent)				80%														80%
Maximum deferral (percent)				30%														30%
Other regulatory liabilities												$ 8,000,000									$ 8,000,000
CECONY \| Steam \| Unprotected Portion
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA				$ 24,000,000
CECONY \| Steam \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Authorized return on common equity (percent)																9.25%
Earnings sharing (percent)																9.75%
Common equity ratio (percent)																48%
CECONY \| Steam \| Rate Plan for Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes																					(22,400,000)
Weighted average cost of capital (after-tax)																					$ 1,511,000,000
Weighted average cost of capital (after-tax) (percent)																					7.10%
Actual return on common equity (percent)																					9.82%
Cost of long-term debt rate										5.17%
Requested rate increase (decrease), amount				77,800,000
Late payment charges and fees				$ 2,500,000
Deferral, annual maximum (not more than) (percent)				0.10%
CECONY \| Steam \| Rate Plan for Year 1 \| Protected Portion
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA				$ 3,000,000
Tax cuts and jobs act of 2017, change in tax rate, regulatory asset, income tax benefit				11,000,000
CECONY \| Steam \| Rate Plan for Year 1 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes																$ 110,000,000
Amortizations to income of net regulatory (assets) and liabilities																15,000,000
Potential Penalty Expense																3,700,000
Net utility plant reconciliations																2,025,000,000
Weighted average cost of capital (after-tax)																$ 1,799,000,000
Weighted average cost of capital (after-tax) (percent)																6.78%
Cost of long-term debt rate																4.51%
CECONY \| Steam \| Rate Plan for Year 1 \| Production
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations																					$ 1,752,000,000
CECONY \| Steam \| Rate Plan for Year 1 \| Distribution
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations																					6,000,000
CECONY \| Steam \| Rate Plan for Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes																					19,800,000
Weighted average cost of capital (after-tax)																					$ 1,547,000,000
Weighted average cost of capital (after-tax) (percent)																					7.13%
Actual return on common equity (percent)																					10.88%
Cost of long-term debt rate										5.23%
Requested rate increase (decrease), amount				77,800,000
Late payment charges and fees				$ 3,000,000
Deferral, annual maximum (not more than) (percent)				0.075%
CECONY \| Steam \| Rate Plan for Year 2 \| Protected Portion
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA				$ 5,000,000
CECONY \| Steam \| Rate Plan for Year 2 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes																$ 44,000,000
Amortizations to income of net regulatory (assets) and liabilities																3,000,000
Potential Penalty Expense																3,800,000
Net utility plant reconciliations																2,029,000,000
Weighted average cost of capital (after-tax)																$ 1,848,000,000
Weighted average cost of capital (after-tax) (percent)																6.81%
Cost of long-term debt rate																4.58%
CECONY \| Steam \| Rate Plan for Year 2 \| Production
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations																					$ 1,732,000,000
CECONY \| Steam \| Rate Plan for Year 2 \| Distribution
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations																					11,000,000
CECONY \| Steam \| Rate Plan for Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes																					20,300,000
Weighted average cost of capital (after-tax)																					$ 1,604,000,000
Weighted average cost of capital (after-tax) (percent)																					7.21%
Actual return on common equity (percent)																					10.54%
Cost of long-term debt rate										5.39%
Requested rate increase (decrease), amount				77,800,000
Late payment charges and fees				$ 3,500,000
Deferral, annual maximum (not more than) (percent)				0.05%
CECONY \| Steam \| Rate Plan for Year 3 \| Protected Portion
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA				$ 6,000,000
CECONY \| Steam \| Rate Plan for Year 3 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes																$ 45,000,000
Amortizations to income of net regulatory (assets) and liabilities																3,000,000
Potential Penalty Expense																3,800,000
Net utility plant reconciliations																2,015,000,000
Weighted average cost of capital (after-tax)																$ 1,882,000,000
Weighted average cost of capital (after-tax) (percent)																6.83%
Cost of long-term debt rate																4.62%
CECONY \| Steam \| Rate Plan for Year 3 \| Production
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations																					$ 1,720,000,000
CECONY \| Steam \| Rate Plan for Year 3 \| Distribution
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations																					25,000,000
CECONY \| Steam \| Rate Plan for Year 3 \| Maximum
Public Utilities, General Disclosures [Line Items]
Potential Penalty Expense																					1,000,000
CECONY \| Steam \| Rate Plan for Year 4
Public Utilities, General Disclosures [Line Items]
Base rate changes																					$ 0
Actual return on common equity (percent)																					9.51%
CECONY \| Steam \| Rate Plan for Year 5
Public Utilities, General Disclosures [Line Items]
Base rate changes																					$ 0
Actual return on common equity (percent)																					11.73%
CECONY \| Steam \| Rate Plan For Year 6
Public Utilities, General Disclosures [Line Items]
Base rate changes																					$ 0
Actual return on common equity (percent)																					10.45%
CECONY \| Steam \| Rate Plan For Year 7
Public Utilities, General Disclosures [Line Items]
Base rate changes																					$ 0
Actual return on common equity (percent)																					7.91%
CECONY \| Steam \| Rate Plan For Year 8
Public Utilities, General Disclosures [Line Items]
Base rate changes																					$ 0
Actual return on common equity (percent)																					5.99%
CECONY \| Steam \| Rate Plan For Year 9
Public Utilities, General Disclosures [Line Items]
Base rate changes																					$ 0
Actual return on common equity (percent)																					5.72%
CECONY \| Steam \| Rate Plan For Year 10
Public Utilities, General Disclosures [Line Items]
Base rate changes																					$ 0
Actual return on common equity (percent)																					(0.10%)
CECONY \| Gas
Public Utilities, General Disclosures [Line Items]
Negative revenue adjustments				2,000,000	3,000,000	8,000,000
Cost reconciliation, deferred net regulatory liabilities				29,000,000	12,000,000	70,000,000	14,000,000	$ 91,000,000										$ 29,000,000	70,000,000	14,000,000		70,000,000
Deferred regulatory asset (liability)				(31,500,000)	(15,500,000)	10,800,000	$ (26,000,000)	$ (24,700,000)										(31,500,000)	$ 10,800,000	(26,000,000)		$ 10,800,000
Authorized return on common equity (percent)																			8.80%
Earnings sharing, threshold limit				$ 4,300,000	$ 0	$ 0
Earnings sharing (percent)						9.30%													9.30%			9.30%
CECONY \| Gas \| Protected Portion
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA																			$ 725,000,000
CECONY \| Gas \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Earnings sharing (percent)																	9.75%
Common equity ratio (percent)																	48%
CECONY \| Gas \| Scenario, Forecast \| Protected Portion
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA																	$ 679,000,000
CECONY \| Gas \| Rate Plan for Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes																			84,000,000
Amortizations to income of net regulatory (assets) and liabilities																			45,000,000
Potential Penalty Expense																			81,000,000
Weighted average cost of capital (after-tax)																			$ 7,171,000,000
Weighted average cost of capital (after-tax) (percent)																			6.61%
Actual return on common equity (percent)																			8.40%
Cost of long-term debt rate						4.63%													4.63%			4.63%
Requested rate increase (decrease), amount																				10,400,000
CECONY \| Gas \| Rate Plan for Year 1 \| Protected Portion
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA																			$ 14,000,000
CECONY \| Gas \| Rate Plan for Year 1 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes																	217,000,000
Amortizations to income of net regulatory (assets) and liabilities																	31,000,000
Potential Penalty Expense																	107,000,000
Weighted average cost of capital (after-tax)																	$ 9,647,000,000
Weighted average cost of capital (after-tax) (percent)																	6.75%
Authorized return on common equity (percent)																	9.25%
Actual return on common equity (percent)																	9%
Cost of long-term debt rate																	4.46%
CECONY \| Gas \| Rate Plan for Year 1 \| Scenario, Forecast \| Protected Portion
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA																	$ 9,000,000
CECONY \| Gas \| Rate Plan for Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes																			122,000,000
Amortizations to income of net regulatory (assets) and liabilities																			43,000,000
Potential Penalty Expense																			88,000,000
Weighted average cost of capital (after-tax)																			$ 7,911,000,000
Weighted average cost of capital (after-tax) (percent)																			6.61%
Actual return on common equity (percent)																			8.48%
Cost of long-term debt rate						4.63%													4.63%			4.63%
Requested rate increase (decrease), amount																				10,400,000
CECONY \| Gas \| Rate Plan for Year 2 \| Protected Portion
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA																			$ 14,000,000
CECONY \| Gas \| Rate Plan for Year 2 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes																	173,000,000
Amortizations to income of net regulatory (assets) and liabilities																	24,000,000
Potential Penalty Expense																	119,000,000
Weighted average cost of capital (after-tax)																	$ 10,428,000,000
Weighted average cost of capital (after-tax) (percent)																	6.79%
Actual return on common equity (percent)																	9.82%
Cost of long-term debt rate																	4.54%
CECONY \| Gas \| Rate Plan for Year 2 \| Scenario, Forecast \| Protected Portion
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA																	$ 10,000,000
CECONY \| Gas \| Rate Plan for Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes																			167,000,000
Amortizations to income of net regulatory (assets) and liabilities																			10,000,000
Potential Penalty Expense																			96,000,000
Weighted average cost of capital (after-tax)																			$ 8,622,000,000
Weighted average cost of capital (after-tax) (percent)																			6.61%
Actual return on common equity (percent)																			8.93%
Cost of long-term debt rate						4.63%													4.63%			4.63%
Requested rate increase (decrease), amount																				10,400,000
CECONY \| Gas \| Rate Plan for Year 3 \| Protected Portion
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA																			$ 12,000,000
CECONY \| Gas \| Rate Plan for Year 3 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes																	122,000,000
Amortizations to income of net regulatory (assets) and liabilities																	(11,000,000)
Potential Penalty Expense																	130,000,000
Weighted average cost of capital (after-tax)																	$ 11,063,000,000
Weighted average cost of capital (after-tax) (percent)																	6.85%
Cost of long-term debt rate																	4.64%
CECONY \| Gas \| Rate Plan for Year 3 \| Scenario, Forecast \| Protected Portion
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA																	$ 10,000,000
O&R \| Gas \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Authorized return on common equity (percent)		10.10%	10.10%
Common equity ratio (percent)	48%	48%	48%												48%
Requested rate increase (decrease), amount	$ 166,000,000	$ 266,000,000	$ 441,000,000
O&R \| Gas \| Rate Plan for Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes																		$ 700,000
Authorized return on common equity (percent)				9.20%
Requested rate increase (decrease), amount																				4,400,000
Deferral, annual maximum (not more than) (percent)																		0.10%
O&R \| Gas \| Rate Plan for Year 1 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes															$ 3,600,000
Authorized return on common equity (percent)															9.75%
O&R \| Gas \| Rate Plan for Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes																		$ 7,400,000
Requested rate increase (decrease), amount																				4,400,000
Deferral, annual maximum (not more than) (percent)																		0.075%
O&R \| Gas \| Rate Plan for Year 2 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes															$ 18,000,000
O&R \| Gas \| Rate Plan for Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes																		$ 9,900,000
Requested rate increase (decrease), amount																				$ 4,400,000
Deferral, annual maximum (not more than) (percent)																		0.05%
O&R \| Gas \| Rate Plan for Year 3 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes															$ 16,500,000

Regulatory Matters - Summary _4

Regulatory Matters - Summary of Utilities Rate Plans (O&R New York-Electric) (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended						36 Months Ended
	Jan. 31, 2024	Dec. 31, 2028	Dec. 31, 2027	Dec. 31, 2026	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2027	Dec. 31, 2024	Dec. 31, 2021
Public Utilities, General Disclosures [Line Items]
Deferred regulatory assets					$ 848	$ 722			$ 848
Deferred regulatory liabilities					$ 0	0	$ 3		$ 0	$ 7
O&R \| Electric
Public Utilities, General Disclosures [Line Items]
Deferred regulatory assets						3.4	6.9
Deferral of net increase (decrease) to regulatory assets						15.4	9.4
Authorized return on common equity (percent)	10.10%
Earnings sharing (percent)					9.70%				9.70%
Common equity ratio (percent)	48%								48%
Recovery of late payment charges, period (in years)					3 years
Recovery of late payment charges, amount					$ 2.2
Recovery of late payment charges, return on equity threshold rate					500%
Regulatory assets usefull life					15 years
Uncollecetible expenses, threshold amount					$ 0.9
Surcharge recovery threshold percentage					50%
O&R \| Electric \| Rate Plan for Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes									$ 4.9
Amortization to income of net regulatory assets									11.8
Potential earnings adjustment mechanism incentives									3.3
Weighted average cost of capital (after-tax)									$ 1,021
Weighted average cost of capital (after-tax) (percent)									6.77%
Authorized return on common equity (percent)									9.20%
Actual return on common equity (percent)									8.96%
Cost of long-term debt (percent)									4.58%
Requested rate increase (decrease), amount									$ 11.7
Regulatory assets, amortization period (in years)					5 years				5 years
Deferral, annual maximum (not more than) (percent)									1,000%
O&R \| Electric \| Rate Plan for Year 1 \| Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Average rate base									$ 1,175
O&R \| Electric \| Rate Plan for Year 1 \| Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)									4.3
O&R \| Electric \| Rate Plan for Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes									16.2
Amortization to income of net regulatory assets									13.5
Potential earnings adjustment mechanism incentives									2.3
Weighted average cost of capital (after-tax)									$ 1,044
Weighted average cost of capital (after-tax) (percent)									6.73%
Actual return on common equity (percent)									8.73%
Cost of long-term debt (percent)									4.51%
Requested rate increase (decrease), amount									$ 11.7
Deferral, annual maximum (not more than) (percent)									750%
O&R \| Electric \| Rate Plan for Year 2 \| Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Average rate base									$ 1,198
O&R \| Electric \| Rate Plan for Year 2 \| Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)									4.4
O&R \| Electric \| Rate Plan for Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes									23.1
Amortization to income of net regulatory assets									15.2
Potential earnings adjustment mechanism incentives									4
Potential incentive if target is met, related to service terminations						1.5	$ 2.7
Weighted average cost of capital (after-tax)									$ 1,144
Weighted average cost of capital (after-tax) (percent)									6.72%
Actual return on common equity (percent)									9.86%
Cost of long-term debt (percent)									4.49%
Requested rate increase (decrease), amount									$ 11.7
Deferral, annual maximum (not more than) (percent)									500%
O&R \| Electric \| Rate Plan for Year 3 \| Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Average rate base									$ 1,304
O&R \| Electric \| Rate Plan for Year 3 \| Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)									5.1
O&R \| Electric \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Earnings sharing (percent)			10.25%					10.25%
Common equity ratio (percent)								48%
Requested rate increase (decrease), amount		$ 880	$ 932
O&R \| Electric \| Scenario, Forecast \| Rate Plan for Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes								$ (13.1)
Amortization to income of net regulatory assets								4.5
Potential earnings adjustment mechanism incentives								3.9
Weighted average cost of capital (after-tax)								$ 1,293
Weighted average cost of capital (after-tax) (percent)								7.25%
Authorized return on common equity (percent)								9.75%
Cost of long-term debt (percent)								4.95%
O&R \| Electric \| Scenario, Forecast \| Rate Plan for Year 1 \| Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Average rate base								$ 1,398
O&R \| Electric \| Scenario, Forecast \| Rate Plan for Year 1 \| Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)								7.6
O&R \| Electric \| Scenario, Forecast \| Rate Plan for Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes								24.8
Amortization to income of net regulatory assets								5.4
Potential earnings adjustment mechanism incentives								4.7
Weighted average cost of capital (after-tax)								$ 1,393
Weighted average cost of capital (after-tax) (percent)								7.28%
Cost of long-term debt (percent)								5.01%
O&R \| Electric \| Scenario, Forecast \| Rate Plan for Year 2 \| Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Average rate base								$ 1,471
O&R \| Electric \| Scenario, Forecast \| Rate Plan for Year 2 \| Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)								8.5
O&R \| Electric \| Scenario, Forecast \| Rate Plan for Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes								44.1
Amortization to income of net regulatory assets								6.4
Potential earnings adjustment mechanism incentives								5.8
Weighted average cost of capital (after-tax)								$ 1,646
Weighted average cost of capital (after-tax) (percent)								7.31%
Cost of long-term debt (percent)								5.08%
O&R \| Electric \| Scenario, Forecast \| Rate Plan for Year 3 \| Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Average rate base								$ 1,737
O&R \| Electric \| Scenario, Forecast \| Rate Plan for Year 3 \| Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)								$ 11.5
O&R \| Gas
Public Utilities, General Disclosures [Line Items]
Deferred regulatory assets					$ 2	$ 7.6			$ 2
Deferrals for property taxes limitation from rates (percent)									90%
Recovery of late payment charges, amount					$ 0.6
Regulatory assets usefull life					15 years
Uncollecetible expenses, threshold amount					$ 0.5
Surcharge recovery threshold percentage					50%
O&R \| Gas \| Rate Plan for Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes									$ 0.7
Amortization to income of net regulatory assets									0.8
Potential earnings adjustment mechanism incentives									$ 0.2
Authorized return on common equity (percent)					9.20%
Requested rate increase (decrease), amount										4.4
Deferral, annual maximum (not more than) (percent)									0.10%
O&R \| Gas \| Rate Plan for Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes									$ 7.4
Amortization to income of net regulatory assets									0.7
Potential earnings adjustment mechanism incentives									$ 0.2
Requested rate increase (decrease), amount										4.4
Deferral, annual maximum (not more than) (percent)									0.075%
O&R \| Gas \| Rate Plan for Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes									$ 9.9
Amortization to income of net regulatory assets									0.3
Potential earnings adjustment mechanism incentives									$ 0.4
Requested rate increase (decrease), amount										$ 4.4
Deferral, annual maximum (not more than) (percent)									0.05%
O&R \| Gas \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Authorized return on common equity (percent)			10.10%	10.10%
Common equity ratio (percent)		48%	48%	48%				48%
Requested rate increase (decrease), amount		$ 166	$ 266	$ 441
O&R \| Gas \| Scenario, Forecast \| Rate Plan for Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes								$ 3.6
Amortization to income of net regulatory assets								$ 8.4
Authorized return on common equity (percent)								9.75%
O&R \| Gas \| Scenario, Forecast \| Rate Plan for Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes								$ 18
Amortization to income of net regulatory assets								8.2
O&R \| Gas \| Scenario, Forecast \| Rate Plan for Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes								16.5
Amortization to income of net regulatory assets								$ 8

Regulatory Matters - Summary _5

Regulatory Matters - Summary of Utilities Rate Plans (O&R New York-Gas) (Details) - USD ($) $ in Millions	12 Months Ended				36 Months Ended
	Dec. 31, 2028	Dec. 31, 2027	Dec. 31, 2026	Dec. 31, 2024	Dec. 31, 2027	Dec. 31, 2024	Dec. 31, 2021	Dec. 31, 2023
Public Utilities, General Disclosures [Line Items]
Deferred regulatory assets				$ 848		$ 848		$ 722
O&R \| Gas
Public Utilities, General Disclosures [Line Items]
Deferred regulatory assets				2		$ 2		$ 7.6
Deferrals for property taxes limitation from rates (percent)						90%
Recovery of late payment charges, amount				$ 0.6
Regulatory assets usefull life				15 years
Uncollecetible expenses, threshold amount				$ 0.5
Surcharge recovery threshold percentage				50%
O&R \| Gas \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Authorized return on common equity (percent)		10.10%	10.10%
Common equity ratio (percent)	48%	48%	48%		48%
Requested rate increase (decrease), amount	$ 166	$ 266	$ 441
O&R \| Gas \| Rate Plan for Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes						$ 0.7
Amortization to income of net regulatory assets						0.8
Potential positive rate adjustment for gas safety and performance						1.2
Potential earnings adjustment mechanism incentives						$ 0.2
Authorized return on common equity (percent)				9.20%
Requested rate increase (decrease), amount							$ 4.4
Deferral, annual maximum (not more than) (percent)						0.10%
O&R \| Gas \| Rate Plan for Year 1 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes					$ 3.6
Amortization to income of net regulatory assets					$ 8.4
Authorized return on common equity (percent)					9.75%
O&R \| Gas \| Rate Plan for Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes						$ 7.4
Amortization to income of net regulatory assets						0.7
Potential positive rate adjustment for gas safety and performance						1.3
Potential earnings adjustment mechanism incentives						$ 0.2
Requested rate increase (decrease), amount							4.4
Deferral, annual maximum (not more than) (percent)						0.075%
O&R \| Gas \| Rate Plan for Year 2 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes					$ 18
Amortization to income of net regulatory assets					8.2
O&R \| Gas \| Rate Plan for Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes						$ 9.9
Amortization to income of net regulatory assets						0.3
Potential positive rate adjustment for gas safety and performance						1.4
Potential earnings adjustment mechanism incentives						$ 0.4
Requested rate increase (decrease), amount							$ 4.4
Deferral, annual maximum (not more than) (percent)						0.05%
O&R \| Gas \| Rate Plan for Year 3 \| Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes					16.5
Amortization to income of net regulatory assets					$ 8
Energy Efficiency \| O&R \| Gas
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives						$ 0.2

Regulatory Matters - Summary _6

Regulatory Matters - Summary of Utilities Rate Plans (RECO) (Details) - RECO - USD ($) $ in Thousands		1 Months Ended
	Jan. 01, 2022	Jan. 31, 2022
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities, amortization period	3 years
Amortization to income of net regulatory assets	$ 9,200
Regulatory assets, amortization period (in years)	3 years
Weighted average cost of capital (after-tax)	$ 262,800
Weighted average cost of capital (after-tax) (percent)		7.08%
Authorized return on common equity (percent)		9.60%
Cost of long-term debt (percent)		4.74%
Common equity ratio (percent)		48.51%
Tropical Storm Henri
Public Utilities, General Disclosures [Line Items]
Amortization to income of net regulatory assets	$ 2,400
Regulatory assets, amortization period (in years)	3 years
Rate Plan for Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes		$ 9,650
Actual return on common equity (percent)	9.60%
Rate Plan for Year 2
Public Utilities, General Disclosures [Line Items]
Actual return on common equity (percent)	9.70%
Period 1
Public Utilities, General Disclosures [Line Items]
Amortizations to income of net regulatory (assets) and liabilities	$ 200
Regulatory liabilities, amortization period	3 years
Period 2
Public Utilities, General Disclosures [Line Items]
Amortizations to income of net regulatory (assets) and liabilities	$ 10,000

Regulatory Matters - RECO Narra

Regulatory Matters - RECO Narrative (Details) - USD ($) $ in Thousands					1 Months Ended
	Jan. 01, 2024	Aug. 30, 2022	Jan. 01, 2022	Dec. 31, 2021	Dec. 31, 2022	Dec. 31, 2024
RECO \| New Jersey Board of Public Utilities
Public Utilities, General Disclosures [Line Items]
Investment plan					$ 47,800
Investment plan, term (in years)					5 years
CECONY
Public Utilities, General Disclosures [Line Items]
Deferred costs						$ 3,000
Electric \| RECO
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount	$ 20,700	$ 18,200		$ 16,900
Electric \| RECO \| New Jersey Board of Public Utilities
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount			$ 9,650

Regulatory Matters - Other Regu

Regulatory Matters - Other Regulatory Matters (Details) - USD ($) $ in Millions	Dec. 31, 2024	May 31, 2024	Dec. 31, 2023
CECONY
Public Utilities, General Disclosures [Line Items]
Public utilities, requested capitalization of billing system costs	$ 89
Public utilities, billing system costs	510
Net regulatory assets	1,078		$ 1,113
CECONY \| Maximum
Public Utilities, General Disclosures [Line Items]
Public utilities, limit for capitalization	421	$ 421	38
O&R
Public Utilities, General Disclosures [Line Items]
Net regulatory assets	$ 14		$ 18

Regulatory Matters - Regulatory

Regulatory Matters - Regulatory Assets (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	$ 5,523	$ 4,607
Regulatory assets – current	141	281
Total Regulatory Assets	5,664	4,888
Environmental remediation costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	1,038	1,105
System peak reduction and energy efficiency programs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	1,656	1,251
COVID-19 pandemic deferrals
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	1,073	789
Revenue taxes
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	540	476
Deferred storm costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	147	206
Property tax reconciliation
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	131	169
Deferred derivative losses - long term
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	106	163
MTA power reliability deferral
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	31	61
Pension and other postretirement benefits deferrals
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	2	48
Gas service line deferred costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	18	43
Legacy meters (c)
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	413	17
Other
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	368	279
Deferred derivative losses - short term
Regulatory Assets [Line Items]
Regulatory assets – current	102	269
Recoverable energy costs
Regulatory Assets [Line Items]
Regulatory assets – current	39	12
CECONY
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	5,158	4,314
Regulatory assets – current	106	254
CECONY \| Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	5,158	4,314
Regulatory assets – current	106	254
Total Regulatory Assets	5,264	4,568
CECONY \| Environmental remediation costs \| Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	952	1,022
CECONY \| System peak reduction and energy efficiency programs \| Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	1,598	1,223
CECONY \| COVID-19 pandemic deferrals \| Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	1,058	782
CECONY \| Revenue taxes \| Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	517	455
CECONY \| Deferred storm costs \| Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	53	115
CECONY \| Property tax reconciliation \| Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	131	169
CECONY \| Deferred derivative losses - long term \| Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	94	148
CECONY \| MTA power reliability deferral \| Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	31	61
CECONY \| Pension and other postretirement benefits deferrals \| Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	2	39
CECONY \| Gas service line deferred costs \| Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	18	43
CECONY \| Legacy meters (c) \| Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	398	0
CECONY \| Other \| Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	306	257
CECONY \| Deferred derivative losses - short term \| Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – current	92	253
CECONY \| Recoverable energy costs \| Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – current	$ 14	$ 1

Regulatory Matters - Regulato_2

Regulatory Matters - Regulatory Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	$ 5,444	$ 5,328
Regulatory liabilities—current	102	145
Total Regulatory Liabilities	5,546	5,473
Regulatory assets	5,523	4,607
Future income tax
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	1,224	1,535
Allowance for cost of removal less salvage
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	1,527	1,456
Unrecognized pension and other postretirement costs
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	1,054	943
Pension and other postretirement benefit deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	368	284
Net unbilled revenue deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	436	278
Late payment charge deferral
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	231	167
System benefit charge carrying charge
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	115	92
Deferred derivative gains - long term
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	8	49
Net proceeds from sale of property
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	25	48
Settlement of prudence proceeding
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	10	11
Other
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	446	465
Deferred derivative gains - short term
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	25	74
Refundable energy costs
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	59	71
Revenue decoupling mechanism
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	18	0
CECONY
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	4,940	4,818
Regulatory liabilities—current	40	107
Regulatory assets	5,158	4,314
CECONY \| Arrears Relief Program Deferral [Member]
Regulatory Liabilities [Line Items]
Regulatory assets	323.7	398.6
CECONY \| Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	4,940	4,818
Regulatory liabilities—current	40	107
Total Regulatory Liabilities	4,980	4,925
Regulatory assets	5,158	4,314
CECONY \| Future income tax \| Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	1,112	1,404
CECONY \| Allowance for cost of removal less salvage \| Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	1,322	1,266
CECONY \| Unrecognized pension and other postretirement costs \| Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	984	867
CECONY \| Pension and other postretirement benefit deferrals \| Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	304	233
CECONY \| Net unbilled revenue deferrals \| Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	436	278
CECONY \| Late payment charge deferral \| Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	224	161
CECONY \| System benefit charge carrying charge \| Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	110	88
CECONY \| Deferred derivative gains - long term \| Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	6	49
CECONY \| Net proceeds from sale of property \| Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	24	47
CECONY \| Settlement of prudence proceeding \| Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	10	11
CECONY \| Other \| Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	408	414
CECONY \| Deferred derivative gains - short term \| Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	22	71
CECONY \| Refundable energy costs \| Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	18	36
CECONY \| Revenue decoupling mechanism \| Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	0	0
O&R \| Arrears Relief Program Deferral [Member]
Regulatory Liabilities [Line Items]
Regulatory assets	$ 1.4	$ 2.1

Regulatory Matters - Regulato_3

Regulatory Matters - Regulatory Assets and Liabilities Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Regulatory Assets [Line Items]
Regulatory liabilities	$ 5,444	$ 5,328
Other customer-provided capital rate	5.95%	5.20%
Return on regulatory assets	$ 3,262	$ 2,541
Deferred derivative losses, current, recovery period (in years)	1 year
Deferred derivative losses, noncurrent, recovery period (in years)	3 years
CECONY
Regulatory Assets [Line Items]
Regulatory liabilities	$ 4,940	4,818
Return on regulatory assets	$ 3,024	2,359
CECONY \| Commodity
Regulatory Assets [Line Items]
Regulatory assets, recovery period	4 years
RECO
Regulatory Assets [Line Items]
Return on regulatory assets	$ 28	24
Net unbilled revenue deferrals
Regulatory Assets [Line Items]
Regulatory liabilities	$ 436	$ 278

Regulatory Matters - Schedule o

Regulatory Matters - Schedule of Regulatory Assets Not Earning a Return (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Regulatory Assets [Line Items]
Regulatory assets not earning return	$ 2,402	$ 2,347
CECONY
Regulatory Assets [Line Items]
Regulatory assets not earning return	2,240	2,209
Environmental remediation costs
Regulatory Assets [Line Items]
Regulatory assets not earning return	1,037	1,105
Environmental remediation costs \| CECONY
Regulatory Assets [Line Items]
Regulatory assets not earning return	942	1,022
Revenue taxes
Regulatory Assets [Line Items]
Regulatory assets not earning return	567	490
Revenue taxes \| CECONY
Regulatory Assets [Line Items]
Regulatory assets not earning return	543	470
Deferred derivative losses - long term
Regulatory Assets [Line Items]
Regulatory assets not earning return	106	163
Deferred derivative losses - long term \| CECONY
Regulatory Assets [Line Items]
Regulatory assets not earning return	94	148
UB deferral for uncollectible accounts receivable
Regulatory Assets [Line Items]
Regulatory assets not earning return	551	291
UB deferral for uncollectible accounts receivable \| CECONY
Regulatory Assets [Line Items]
Regulatory assets not earning return	541	288
Other
Regulatory Assets [Line Items]
Regulatory assets not earning return	39	29
Other \| CECONY
Regulatory Assets [Line Items]
Regulatory assets not earning return	28	28
Deferred derivative losses - short term
Regulatory Assets [Line Items]
Regulatory assets not earning return	102	269
Deferred derivative losses - short term \| CECONY
Regulatory Assets [Line Items]
Regulatory assets not earning return	$ 92	$ 253

Capitalization - Common Stock (

Capitalization - Common Stock (Details) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2024 USD ($) dealer $ / shares shares	Dec. 31, 2023 USD ($) shares	Dec. 31, 2022 USD ($)
Schedule of Capitalization [Line Items]
Common stock, shares authorized (in shares)	500,000,000
Common stock, shares outstanding (in shares)	346,597,693	345,415,772
Treasury shares (in shares)	33,753,963
Issuance of common shares - public offering (in shares)	7,000,000
Capitalization, Forward Sale Price \| $ / shares	$ 96.66
Stock repurchases (in shares)		10,543,263
Number of dealers \| dealer	2
Stock repurchase program, authorized amount \| $	$ 1
Preferred stock, par or stated value per share (in usd per share) \| $ / shares	$ 0.10
Repurchase of common shares \| $	$ 0	$ 1,000	$ 0
Treasury stock, shares, acquired	10,543,263
CECONY
Schedule of Capitalization [Line Items]
Common stock, shares authorized (in shares)	340,000,000
Common stock, shares outstanding (in shares)	235,488,094	235,488,094
Treasury shares (in shares)	21,976,200	21,976,200

Capitalization - Dividends (Det

Capitalization - Dividends (Details)	12 Months Ended
Capitalization - Dividends (Details)	Dec. 31, 2024
Debt Disclosure [Abstract]
Percentage limitation for income available for dividends (not more than)	100%
Rolling average calculation of income available for dividends (years)	2 years

Capitalization - Schedule of Lo

Capitalization - Schedule of Long-Term Debt Maturities (Details) $ in Millions	Dec. 31, 2024 USD ($)
Debt Instrument [Line Items]
2025	$ 0
2026	250
2027	780
2028	800
2029	44
Broken Bow II \| Disposal Group, Held-for-sale, Not Discontinued Operations \| Clean Energy Businesses
Debt Instrument [Line Items]
Disposal group, including discontinued operation. Long-term debt, including current maturities	59
CECONY
Debt Instrument [Line Items]
2025	0
2026	250
2027	700
2028	800
2029	$ 0

Capitalization - Long-term Debt

Capitalization - Long-term Debt, Additional Information (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
CECONY \| Tax-Exempt Debt
Debt Instrument [Line Items]
Debt instrument, face amount	$ 225	$ 450

Capitalization - Carrying Amoun

Capitalization - Carrying Amounts and Fair Values of Long-Term Debt (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	$ 24,651
Unamortized debt expense	249	$ 222
Carrying Amount
Debt Instrument [Line Items]
Long-Term Debt (including current portion)		22,177
Fair Value
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	21,997	20,525
CECONY
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	23,409
Unamortized debt discount	241	215
CECONY \| Carrying Amount
Debt Instrument [Line Items]
Long-Term Debt (including current portion)		21,060
CECONY \| Fair Value
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	20,915	19,517
Broken Bow II \| Carrying Amount
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	59	62
Broken Bow II \| Fair Value
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	$ 54	$ 58

Capitalization - Significant De

Capitalization - Significant Debt Covenants (Details) $ in Millions	12 Months Ended
	Dec. 31, 2024 USD ($)
Debt Instrument [Line Items]
Maximum ratio of consolidated debt to consolidated total capital	0.56
CECONY
Debt Instrument [Line Items]
Maximum ratio of consolidated debt to consolidated total capital	0.57
Tax-Exempt Debt \| CECONY
Debt Instrument [Line Items]
Maximum ratio of consolidated debt to consolidated total capital	0.65
Notes \| CECONY
Debt Instrument [Line Items]
Covenant principal balance amount limit	$ 100

Short-Term Borrowing (Details)

Short-Term Borrowing (Details)	1 Months Ended				12 Months Ended
Short-Term Borrowing (Details)	Jan. 31, 2025 USD ($)	Nov. 30, 2024 USD ($)	Mar. 31, 2023 USD ($)	Mar. 31, 2022 USD ($)	Dec. 31, 2024 USD ($)	Dec. 31, 2023 USD ($)
Short-term Debt [Line Items]
Debt term (in years)		364 days
Commercial paper, outstanding					$ 2,170,000,000	$ 2,288,000,000
Weighted average interest rate (percent)					4.70%	5.60%
Loans outstanding under credit agreement					$ 0	$ 0
Maximum ratio of consolidated debt to consolidated total capital					0.56
Failure to pay, maximum aggregate limit		$ 150,000,000			$ 150,000,000	150,000,000
Short-term borrowings		$ 500,000,000
Ratio of consolidated debt to consolidated total capital		0.65
Subsequent Event
Short-term Debt [Line Items]
Short-term borrowings	$ 200,000,000
Maximum
Short-term Debt [Line Items]
Maximum ratio of consolidated debt to consolidated total capital					0.65
Revolving Credit
Short-term Debt [Line Items]
Maximum borrowing capacity			$ 1,000,000,000
Letters of Credit
Short-term Debt [Line Items]
Maximum borrowing capacity			900,000,000
CECONY
Short-term Debt [Line Items]
Commercial paper, outstanding					$ 1,694,000,000	$ 1,903,000,000
Weighted average interest rate (percent)					4.70%	5.60%
Maximum ratio of consolidated debt to consolidated total capital					0.57
March 2022 Credit Agreement Variable Rate 364 Day Revolving Credit Agreement \| Revolving Credit \| Subsidiaries
Short-term Debt [Line Items]
Debt term (in years)				364 days
Credit Availability Through March 2028 \| Revolving Credit
Short-term Debt [Line Items]
Maximum borrowing capacity			800,000,000
Credit Availability Through March 2028 \| CECONY \| Revolving Credit
Short-term Debt [Line Items]
Maximum borrowing capacity			$ 2,500,000,000
Debt term (in years)			1 year
March 2023 Credit Agreement Variable Rate 364 Day Revolving Credit Agreement \| Revolving Credit \| Subsidiaries
Short-term Debt [Line Items]
Maximum borrowing capacity				$ 500,000,000
Debt term (in years)			364 days

Pension Benefits - Total Period

Pension Benefits - Total Periodic Benefit Costs (Details) - Pension Benefits - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Defined Benefit Plan Disclosure [Line Items]
Service cost – including administrative expenses	$ 177	$ 161	$ 287
Interest cost on projected benefit obligation	642	649	505
Expected return on plan assets	(1,129)	(1,114)	(1,168)
Recognition of net actuarial loss/(gain)	(5)	(232)	377
Recognition of prior service credit	(17)	(17)	(16)
TOTAL PERIODIC BENEFIT COST/(CREDIT)	(332)	(553)	(15)
Cost capitalized	(94)	(81)	(137)
Reconciliation to rate level	55	282	259
Total credit recognized	(371)	(352)	107
CECONY
Defined Benefit Plan Disclosure [Line Items]
Service cost – including administrative expenses	167	151	270
Interest cost on projected benefit obligation	604	611	475
Expected return on plan assets	(1,076)	(1,061)	(1,109)
Recognition of net actuarial loss/(gain)	(7)	(219)	358
Recognition of prior service credit	(19)	(19)	(21)
TOTAL PERIODIC BENEFIT COST/(CREDIT)	(331)	(537)	(27)
Cost capitalized	(90)	(78)	(129)
Reconciliation to rate level	43	261	245
Total credit recognized	$ (378)	$ (354)	$ 89

Pension Benefits - Schedule of

Pension Benefits - Schedule of Funded Status (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	$ 524
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	583	$ 524
Pension Benefits
CHANGE IN PROJECTED BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	12,712	12,113	$ 17,357
Service cost – excluding administrative expenses	172	156	283
Interest cost on projected benefit obligation	642	649	505
Net actuarial loss/(gain)	(557)	599	(5,102)
Plan amendments	0	3	0
Benefits paid	(828)	(808)	(930)
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	12,141	12,712	12,113
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	15,404	14,979	18,504
Actual return on plan assets	724	1,261	(2,583)
Employer contributions	20	21	30
Benefits paid	(828)	(808)	(930)
Administrative expenses	(42)	(49)	(42)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	15,278	15,404	14,979
FUNDED STATUS	3,137	2,692	2,866
Unrecognized net loss/(gain)	(857)	(757)	(1,485)
Unrecognized prior service credits	(88)	(105)	(124)
Accumulated benefit obligation	11,236	11,739	11,167
CECONY
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	502
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	560	502
CECONY \| Pension Benefits
CHANGE IN PROJECTED BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	11,977	11,395	16,341
Service cost – excluding administrative expenses	162	146	266
Interest cost on projected benefit obligation	604	611	475
Net actuarial loss/(gain)	(557)	572	(4,845)
Plan amendments	0	0	0
Benefits paid	(751)	(747)	(842)
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	11,435	11,977	11,395
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	14,674	14,248	17,566
Actual return on plan assets	691	1,201	(2,453)
Employer contributions	17	18	17
Benefits paid	(751)	(747)	(842)
Administrative expenses	(40)	(46)	(40)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	14,591	14,674	14,248
FUNDED STATUS	3,156	2,697	2,853
Unrecognized net loss/(gain)	(825)	(705)	(1,397)
Unrecognized prior service credits	(104)	(124)	(143)
Accumulated benefit obligation	$ 10,554	$ 11,031	$ 10,478

Pension Benefits - Additional I

Pension Benefits - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Defined Benefit Plan Disclosure [Line Items]
Pension liability	$ 445	$ 174
Current liabilities	6,433	6,462
Investments value	583	524
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Increase (decrease) in regulatory liabilities	(86)
Charge to OCI	5
Current liabilities	63
Noncurrent liabilities	319	337	$ 311
Investments value	15,278	15,404	14,979	$ 18,504
Accumulated benefit obligation	11,236	11,739	11,167
Estimated future employer contributions	3
Other Nonqualified Supplemental Defined Benefit Pension
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	380	349
CECONY
Defined Benefit Plan Disclosure [Line Items]
Pension liability	459	156
Current liabilities	5,559	5,694
Investments value	560	502
CECONY \| Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Increase (decrease) in regulatory liabilities	(101)
Charge to OCI	7
Current liabilities	60
Noncurrent liabilities	296	313	287
Investments value	14,591	14,674	14,248	$ 17,566
Accumulated benefit obligation	10,554	11,031	$ 10,478
CECONY \| Other Nonqualified Supplemental Defined Benefit Pension
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	$ 354	$ 323

Pension Benefits - Schedule o_2

Pension Benefits - Schedule of Assumptions (Details)	12 Months Ended
Pension Benefits - Schedule of Assumptions (Details)	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
CECONY
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase (in percent)	3.80%	3.80%	3.80%
Rate of compensation increase (percent)	3.80%	3.80%	3.80%
O&R
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase (in percent)	3.20%	3.20%	3.20%
Rate of compensation increase (percent)	3.20%	3.20%	3.20%
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Discount rate, benefit obligations (percent)	5.70%	5.15%	5.45%
Interest crediting rate for cash balance plan (percent)	4.30%	4.20%	4%
Discount rate, net periodic benefit cost (percent)	5.15%	5.45%	3%
Interest crediting rate for cash balance plan (percent)	4.20%	4%	3.50%
Expected return on plan assets (percent)	6.75%	6.75%	7%

Pension Benefits - Schedule o_3

Pension Benefits - Schedule of Expected Benefit Payments (Details) - Pension Benefits $ in Millions	Dec. 31, 2024 USD ($)
Defined Benefit Plan Disclosure [Line Items]
2025	$ 840
2026	808
2027	820
2028	824
2029	836
2030-2034	4,227
CECONY
Defined Benefit Plan Disclosure [Line Items]
2025	781
2026	749
2027	764
2028	766
2029	778
2030-2034	$ 3,952

Pension Benefits - Schedule o_4

Pension Benefits - Schedule of Plan Assets Allocations (Details) - Pension Benefits	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Defined Benefit Plan Disclosure [Line Items]
Plan Assets Percentage (percent)	100%	100%	100%
Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Plan Assets Percentage (percent)	27%	26%	33%
Equity Securities \| Minimum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range (percent)	26%
Equity Securities \| Maximum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range (percent)	30%
Debt Securities
Defined Benefit Plan Disclosure [Line Items]
Plan Assets Percentage (percent)	51%	50%	50%
Debt Securities \| Minimum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range (percent)	42%
Debt Securities \| Maximum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range (percent)	60%
Real Estate and Other Alternatives
Defined Benefit Plan Disclosure [Line Items]
Plan Assets Percentage (percent)	22%	24%	17%
Real Estate and Other Alternatives \| Minimum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range (percent)	14%
Real Estate and Other Alternatives \| Maximum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range (percent)	30%

Pension Benefits - Schedule o_5

Pension Benefits - Schedule of Fair Value of Plan Assets (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	$ 583	$ 524
Defined benefit plan, funded (unfunded) status of plan related to private equity	$ 180
Private Equity
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Fair Value by Hierarchy and NAV [Extensible List]	Fair Value Measured at Net Asset Value Per Share	Fair Value Measured at Net Asset Value Per Share
Private Equity \| Minimum
Defined Benefit Plan Disclosure [Line Items]
Period of sale of limited partnership interests in secondary market (in years)	3 months
Private Equity \| Maximum
Defined Benefit Plan Disclosure [Line Items]
Period of sale of limited partnership interests in secondary market (in years)	6 months
Real Estate and Other Alternatives
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Fair Value by Hierarchy and NAV [Extensible List]	Fair Value Measured at Net Asset Value Per Share	Fair Value Measured at Net Asset Value Per Share
Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Fair Value by Hierarchy and NAV [Extensible List]	Fair Value Measured at Net Asset Value Per Share	Fair Value Measured at Net Asset Value Per Share
Period of liquidation (in years)	18 months
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	$ 15,278	$ 15,404	$ 14,979	$ 18,504
Pension Benefits \| U.S. Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	2,752	2,475
Pension Benefits \| International Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,508	1,584
Pension Benefits \| U.S. Government Issued Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	619	615
Pension Benefits \| Corporate Bonds Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	5,429	5,526
Pension Benefits \| Structured Assets Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	159	132
Pension Benefits \| Other Fixed Income Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	783	735
Pension Benefits \| Commingled Trust Fund
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	478	475
Pension Benefits \| Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	343	338
Pension Benefits \| Futures
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	(4)	19
Pension Benefits \| Private Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	975	1,031
Pension Benefits \| Real Estate and Other Alternatives
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,609	1,876
Pension Benefits \| Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	788	723
Pension Benefits \| Total Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	(179)	(193)
Pension Benefits \| Pending Activities
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	18	68
Pension Benefits \| Fair Value, Inputs, Level 1 and 2 \| Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	12,067	11,899
Pension Benefits \| Fair Value, Inputs, Level 1 and 2 \| Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	(140)	(148)
Pension Benefits \| Fair Value, Inputs, Level 1 and 2 \| Investments Excluding Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	15,260	15,336
Pension Benefits \| Level 1 \| Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	4,307	4,113
Pension Benefits \| Level 1 \| U.S. Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	2,752	2,474
Pension Benefits \| Level 1 \| International Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,508	1,584
Pension Benefits \| Level 1 \| U.S. Government Issued Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	0
Pension Benefits \| Level 1 \| Corporate Bonds Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	0
Pension Benefits \| Level 1 \| Structured Assets Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	0
Pension Benefits \| Level 1 \| Other Fixed Income Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	0
Pension Benefits \| Level 1 \| Commingled Trust Fund
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	0
Pension Benefits \| Level 1 \| Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	51	36
Pension Benefits \| Level 1 \| Futures
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	(4)	19
Pension Benefits \| Level 1 \| Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	(50)	(52)
Pension Benefits \| Level 1 \| Investments Excluding Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	4,257	4,061
Pension Benefits \| Level 2 \| Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	7,760	7,786
Pension Benefits \| Level 2 \| U.S. Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	1
Pension Benefits \| Level 2 \| U.S. Government Issued Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	619	615
Pension Benefits \| Level 2 \| Corporate Bonds Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	5,429	5,526
Pension Benefits \| Level 2 \| Structured Assets Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	159	132
Pension Benefits \| Level 2 \| Other Fixed Income Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	783	735
Pension Benefits \| Level 2 \| Commingled Trust Fund
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	478	475
Pension Benefits \| Level 2 \| Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	292	302
Pension Benefits \| Level 2 \| Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	(90)	(96)
Pension Benefits \| Level 2 \| Investments Excluding Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	7,670	7,690
Pension Benefits \| Fair Value Measured at Net Asset Value Per Share \| Investments Valued Using NAV Per Share
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	3,372	3,630
Pension Benefits \| Fair Value Measured at Net Asset Value Per Share \| Funds For Retiree Health Benefits Measured At Net Asset Value
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	$ (39)	$ (45)

Pension Benefits - Schedule o_6

Pension Benefits - Schedule of Employer Contribution to Defined Savings Plan (Details) - Defined Contribution Savings Plan - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Defined Benefit Plan Disclosure [Line Items]
Employer contribution to the defined savings plan	$ 57	$ 57	$ 57
CECONY
Defined Benefit Plan Disclosure [Line Items]
Employer contribution to the defined savings plan	$ 52	$ 51	$ 48

Environmental Matters - Accrued

Environmental Matters - Accrued Liabilities and Regulatory Assets (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Site Contingency [Line Items]
Accrued Liabilities	$ 1,037	$ 1,118
Regulatory assets	5,664	4,888
Manufactured gas plant sites
Site Contingency [Line Items]
Accrued Liabilities	941	1,016
Other Superfund Sites
Site Contingency [Line Items]
Accrued Liabilities	96	102
Superfund Sites
Site Contingency [Line Items]
Accrued Liabilities	1,037	1,118
Regulatory assets	1,038	1,105
CECONY
Site Contingency [Line Items]
Accrued Liabilities	942	1,026
CECONY \| Manufactured gas plant sites
Site Contingency [Line Items]
Accrued Liabilities	846	924
CECONY \| Other Superfund Sites
Site Contingency [Line Items]
Accrued Liabilities	96	102
CECONY \| Superfund Sites
Site Contingency [Line Items]
Accrued Liabilities	942	1,026
Regulatory assets	$ 952	$ 1,022

Environmental Matters - Environ

Environmental Matters - Environmental Remediation Costs (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Environmental Exit Cost [Line Items]
Remediation costs incurred	$ 44	$ 13
Environmental Remediation Expense, Statement of Income or Comprehensive Income [Extensible Enumeration]	Other Nonoperating Expense	Other Nonoperating Expense
CECONY
Environmental Exit Cost [Line Items]
Remediation costs incurred	$ 44	$ 12
Environmental Remediation Expense, Statement of Income or Comprehensive Income [Extensible Enumeration]	Other Nonoperating Expense	Other Nonoperating Expense

Environmental Matters - Additio

Environmental Matters - Additional Information (Details) - Superfund Sites $ in Millions	12 Months Ended
	Dec. 31, 2024 USD ($)
Site Contingency [Line Items]
Remediation cost estimate	$ 39
Manufactured Gas Plant Sites \| Maximum
Site Contingency [Line Items]
Estimated aggregate undiscounted potential liability related environmental contaminants (up to)	3,237
CECONY
Site Contingency [Line Items]
Remediation cost estimate	38
CECONY \| Manufactured Gas Plant Sites \| Maximum
Site Contingency [Line Items]
Estimated aggregate undiscounted potential liability related environmental contaminants (up to)	$ 3,391

Environmental Matters - Accru_2

Environmental Matters - Accrued Liability for Asbestos Suits and Workers' Compensation Proceedings (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Site Contingency [Line Items]
Regulatory assets	$ 5,664	$ 4,888
Regulatory liabilities	5,546	5,473
Asbestos Suits
Site Contingency [Line Items]
Accrued liability	8	8
Regulatory assets	8	8
Workers' Compensation
Site Contingency [Line Items]
Accrued liability	53	56
Regulatory liabilities	$ 20	$ 17
Environmental Loss Contingency, Statement of Financial Position [Extensible Enumeration]	Accrued Liabilities	Accrued Liabilities
CECONY \| Asbestos Suits
Site Contingency [Line Items]
Accrued liability	$ 7	$ 7
Regulatory assets	7	7
CECONY \| Workers' Compensation
Site Contingency [Line Items]
Accrued liability	51	54
Regulatory liabilities	$ 20	$ 17
Environmental Loss Contingency, Statement of Financial Position [Extensible Enumeration]	Accrued Liabilities	Accrued Liabilities

Material Contingencies - Manhat

Material Contingencies - Manhattan Explosion and Fire (Details) $ in Millions		1 Months Ended
	Mar. 12, 2014 building people	Feb. 28, 2017 USD ($)	Dec. 31, 2024 USD ($)	Dec. 31, 2023 USD ($)	Dec. 31, 2020 USD ($)
Loss Contingencies [Line Items]
Accrued regulatory liability			$ 5,444	$ 5,328
Manhattan Explosion and Fire
Loss Contingencies [Line Items]
Number of buildings destroyed by fire \| building	2
Number of people died in explosion and fire incident \| people	8
Number of people injured in explosion and fire incident (more than) \| people	50
Amount of costs that will not recover from customers		$ 126
Loss contingency accrual			40		$ 40
Insurance receivable			$ 40		$ 40
Manhattan Explosion and Fire \| Settlement of gas proceedings
Loss Contingencies [Line Items]
Accrued regulatory liability		$ 27

Material Contingencies - Guaran

Material Contingencies - Guarantees (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Commitments and Contingencies Disclosure [Abstract]
Guarantee obligations maximum exposure	$ 58	$ 175

Material Contingencies - Total

Material Contingencies - Total Guarantees (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Guarantor Obligations [Line Items]
Total guarantees, by type and term	$ 58	$ 175
Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	49
Broken Bow II (a)
Guarantor Obligations [Line Items]
Total guarantees, by type and term	9
0 – 3 years
Guarantor Obligations [Line Items]
Total guarantees, by type and term	49
0 – 3 years \| Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	49
0 – 3 years \| Broken Bow II (a)
Guarantor Obligations [Line Items]
Total guarantees, by type and term	0
> 10 years
Guarantor Obligations [Line Items]
Total guarantees, by type and term	9
> 10 years \| Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	0
> 10 years \| Broken Bow II (a)
Guarantor Obligations [Line Items]
Total guarantees, by type and term	$ 9

Material Contingencies - Con Ed

Material Contingencies - Con Edison Transmission (Details) - Payment Guarantee by CET Electric of Contributions to New York Transco LLC	12 Months Ended
	Dec. 31, 2024
Guarantor Obligations [Line Items]
Estimated project cost percentage	175%
NY Transco
Guarantor Obligations [Line Items]
Ownership interest, percentage	45.70%

Electricity and Gas Purchase _3

Electricity and Gas Purchase Agreements - Summary of Estimated Capacity and Other Fixed Payments (Details) $ in Millions	Dec. 31, 2024 USD ($)
Long-term Contract for Purchase of Electric Power [Line Items]
2025
2026
2027
2028
2029
All Years Thereafter
Electricity power purchase agreements
Long-term Contract for Purchase of Electric Power [Line Items]
2025	234
2026	131
2027	60
2028	49
2029	44
All Years Thereafter	302
Natural gas
Long-term Contract for Purchase of Electric Power [Line Items]
2025	383
2026	11
2027	8
2028	0
2029	0
All Years Thereafter	0
Gas transportation and storage
Long-term Contract for Purchase of Electric Power [Line Items]
2025	510
2026	497
2027	450
2028	376
2029	212
All Years Thereafter	2,390
CECONY
Long-term Contract for Purchase of Electric Power [Line Items]
2025
2026
2027
2028
2029
All Years Thereafter
CECONY \| Electricity power purchase agreements
Long-term Contract for Purchase of Electric Power [Line Items]
2025	230
2026	128
2027	59
2028	49
2029	44
All Years Thereafter	302
CECONY \| Natural gas
Long-term Contract for Purchase of Electric Power [Line Items]
2025	331
2026	10
2027	7
2028	0
2029	0
All Years Thereafter	0
CECONY \| Gas transportation and storage
Long-term Contract for Purchase of Electric Power [Line Items]
2025	445
2026	434
2027	394
2028	329
2029	185
All Years Thereafter	$ 2,083

Electricity and Gas Purchase _4

Electricity and Gas Purchase Agreements - Summary of Capacity, Energy and Other Fixed Payments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	$ 636	$ 546	$ 596
Astoria Generating Company
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	75	40	45
Brooklyn Navy Yard
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	139	134	165
Gas transportation and storage
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	422	372	386
CECONY
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	586	501	550
CECONY \| Astoria Generating Company
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	75	40	45
CECONY \| Brooklyn Navy Yard
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	139	134	165
CECONY \| Gas transportation and storage
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	$ 372	$ 327	$ 340

Leases - Additional Information

Leases - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Lessee, Lease, Description [Line Items]
Lease, renewal term (in years)	5 years
Assets under finance leases	$ 3	$ 2	$ 2
Finance leases, accumulated amortization	2	2	5
Right-of-use asset obtained in exchange for operating lease liability	3	11
Unrecorded unconditional purchase obligation	262
CECONY
Lessee, Lease, Description [Line Items]
Assets under finance leases	3	1	1
Finance leases, accumulated amortization	2	$ 2	$ 2
Right-of-use asset obtained in exchange for operating lease liability	$ 3
CECONY \| Subsidiaries \| Lease Expected To Commence In 3 Years With 15 Year Lease Term
Lessee, Lease, Description [Line Items]
Lease not yet commenced, term (in years)	15 years
Operating lease, lease not yet commenced, expected period to commence (in years)	2 years
Minimum
Lessee, Lease, Description [Line Items]
Lease, term (in years)	1 year
Maximum
Lessee, Lease, Description [Line Items]
Lease, term (in years)	20 years

Leases - Lease Cost and Cash Fl

Leases - Lease Cost and Cash Flows (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Lessee, Lease, Description [Line Items]
Operating lease cost	$ 67	$ 70	$ 88
Operating lease cash flows	67	68	83
CECONY
Lessee, Lease, Description [Line Items]
Operating lease cost	66	66	67
Operating lease cash flows	$ 66	$ 65	$ 64

Leases - Other Related Informat

Leases - Other Related Information (Details)	Dec. 31, 2024	Dec. 31, 2023
Lessee, Lease, Description [Line Items]
Weighted Average Remaining Lease Term, Operating leases (in years)	10 years 9 months 18 days	11 years 4 months 24 days
Weighted Average Remaining Lease Term, Finance leases (in years)	6 years	6 years 7 months 6 days
Weighted Average Discount Rate, Operating leases (percent)	3.80%	3.70%
Weighted Average Discount Rate, Finance leases (percent)	2%	3%
Clean Energy Businesses
Lessee, Lease, Description [Line Items]
Weighted Average Remaining Lease Term, Operating leases (in years)	11 years 7 months 6 days
Weighted Average Discount Rate, Operating leases (percent)	3.80%
Broken Bow II
Lessee, Lease, Description [Line Items]
Weighted Average Remaining Lease Term, Operating leases (in years)	10 years 9 months 18 days
Weighted Average Discount Rate, Operating leases (percent)	3.80%
CECONY
Lessee, Lease, Description [Line Items]
Weighted Average Remaining Lease Term, Operating leases (in years)	10 years 7 months 6 days	11 years 4 months 24 days
Weighted Average Remaining Lease Term, Finance leases (in years)	5 years	2 years 8 months 12 days
Weighted Average Discount Rate, Operating leases (percent)	3.80%	3.70%
Weighted Average Discount Rate, Finance leases (percent)	1.60%	3.10%

Leases - Future Minimum Lease P

Leases - Future Minimum Lease Payments (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Operating Leases
2025	$ 68
2026	67
2027	66
2028	61
2029	61
All years thereafter	307
Total future minimum lease payments	630
Less: imputed interest	(126)
Total	504
Operating lease liabilities (current)	118	$ 116
Operating lease liabilities held for sale (current)	2
Operating lease liabilities (noncurrent)	386	$ 429
Operating lease liabilities held for sale (noncurrent)	5
Total	511
Finance Leases
2025	1
2026	1
2027	1
2028	0
2029	0
All years thereafter	1
Total future minimum lease payments	4
Less: imputed interest	0
Total	4
Other current liabilities	1
Other noncurrent liabilities	3
Total	$ 4
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	TOTAL CURRENT LIABILITIES	TOTAL CURRENT LIABILITIES
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Liabilities, Other than Long-Term Debt, Noncurrent	Liabilities, Other than Long-Term Debt, Noncurrent
Finance Lease, Liability, Statement of Financial Position [Extensible Enumeration]	Liabilities, Other than Long-Term Debt, Noncurrent, Other Liabilities	Liabilities, Other than Long-Term Debt, Noncurrent, Other Liabilities
Broken Bow II
Operating Leases
2025	$ 4
2026	4
2027	4
2028	4
2029	4
All years thereafter	9
Less: imputed interest	(6)
Operating lease liabilities (current)	7
CECONY
Operating Leases
2025	67
2026	67
2027	66
2028	61
2029	61
All years thereafter	307
Total future minimum lease payments	629
Less: imputed interest	(125)
Total	504
Operating lease liabilities (current)	118	$ 116
Operating lease liabilities held for sale (current)	0
Operating lease liabilities (noncurrent)	386	$ 429
Operating lease liabilities held for sale (noncurrent)	0
Total	504
Finance Leases
2025	1
2026	1
2027	1
2028	0
2029	0
All years thereafter	0
Total future minimum lease payments	3
Less: imputed interest	0
Total	3
Other current liabilities	1
Other noncurrent liabilities	2
Total	$ 3

Goodwill (Details)

Goodwill (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Goodwill [Line Items]
Goodwill	$ 408	$ 408
CECONY
Goodwill [Line Items]
Goodwill	245	245
O&R
Goodwill [Line Items]
Goodwill	161	161
O&R Merger
Goodwill [Line Items]
Goodwill	$ 406	$ 406

Income Tax - Schedule of Compon

Income Tax - Schedule of Components of Income Tax (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
State
Current	$ (81)	$ 179	$ 5
Deferred	223	6	324
Federal
Current	(17)	176	58
Deferred	198	237	117
Amortization of investment tax credits	(5)	(111)	(6)
Total income tax expense	318	487	498
CECONY
State
Current	(87)	(102)	0
Deferred	219	246	110
Federal
Current	(63)	(95)	170
Deferred	246	311	(23)
Amortization of investment tax credits	(1)	(2)	(2)
Total income tax expense	$ 314	$ 358	$ 255

Income Tax - Schedule of Income

Income Tax - Schedule of Income Tax Reconciliation (Details)	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
STATUTORY TAX RATE
Federal	21%	21%	21%
Changes in computed taxes resulting from:
State income taxes, net of federal income taxes	5%	5%	6%
Cost of removal	1%	1%	1%
Allowance for uncollectible accounts, net of COVID-19 assistance	(1.00%)	0%	0%
Amortization of excess deferred federal income taxes	(10.00%)	(6.00%)	(9.00%)
Other	(1.00%)	0%	(1.00%)
Changes in state apportionments, net of federal income taxes	0	(0.01)	0.06
Deferred unamortized ITC recognized on sale of subsidiary	0	(0.04)	0
Effective tax rate	15%	16%	24%
CECONY
STATUTORY TAX RATE
Federal	21%	21%	21%
Changes in computed taxes resulting from:
State income taxes, net of federal income taxes	5%	5%	5%
Cost of removal	1%	2%	1%
Allowance for uncollectible accounts, net of COVID-19 assistance	(1.00%)	(1.00%)	0%
Amortization of excess deferred federal income taxes	(10.00%)	(8.00%)	(10.00%)
Other	(1.00%)	(1.00%)	(1.00%)
Changes in state apportionments, net of federal income taxes	0	0	0
Deferred unamortized ITC recognized on sale of subsidiary	0	0	0
Effective tax rate	15%	18%	16%

Income Tax - Additional Informa

Income Tax - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Operating Loss Carryforwards [Line Items]
Increase to net deferred income tax liabilities		$ 457
Deferred tax asset, valuation allowance	$ 12	7
Increase (decrease) in income taxes payable		$ (457)
State income tax rate (in percent)	5%	5%	6%
Accrued income taxes	$ 139
Unrecognized tax benefits	9	$ 11	$ 23	$ 17
Additions based on tax positions related to the current year	4	8	$ 3
Unrecognized tax benefits, increase (decrease) resulting from prior period tax positions	(3)
Effective income tax rate reconciliation, uncertainty of taxes	1
Unrecognized tax benefits, period increase (decrease)	(3)
Unrecognized tax benefits, net	8
Clean Energy Businesses
Operating Loss Carryforwards [Line Items]
Deferred tax assets, operating loss carryforwards, state and local	5
General Business Tax Credit
Operating Loss Carryforwards [Line Items]
Tax credit carryovers	346
State \| New York State
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards	14
Deferred tax asset, valuation allowance	6
State \| New York City
Operating Loss Carryforwards [Line Items]
Deferred tax assets	36
CECONY
Operating Loss Carryforwards [Line Items]
Increase to net deferred income tax liabilities		418
Deferred tax asset, valuation allowance	$ 0	0
Increase (decrease) in income taxes payable		$ (418)
State income tax rate (in percent)	5%	5%	5%
Accrued income taxes	$ 111
Unrecognized tax benefits	5	$ 7	$ 8	$ 5
Additions based on tax positions related to the current year	4	4	$ 2
CECONY \| Subsidiaries
Operating Loss Carryforwards [Line Items]
Unrecognized tax benefits	$ 5
O&R
Operating Loss Carryforwards [Line Items]
Increase to net deferred income tax liabilities		39
Increase (decrease) in income taxes payable		$ (39)

Income Tax - Schedule of Differ

Income Tax - Schedule of Differences on Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Deferred tax liabilities:
Property basis differences	$ 9,222	$ 8,542
Regulatory Assets:
Energy efficiency and other clean energy programs	464	351
Environmental remediation costs	291	310
Legacy meters	116	4
Other regulatory assets	571	574
Pensions and retiree benefits – asset	1,063	918
Operating lease right-of-use asset	143	154
Total deferred tax liabilities	11,870	10,853
Deferred tax assets:
Unrecognized pension and other postretirement costs	296	265
Future income tax	343	427
Other regulatory liabilities	909	844
Tax credits carryforward	346	270
Superfund and other environmental costs	291	314
Pensions and retiree benefits – liability	154	167
Corporate alternative minimum tax credit carryforward	139	0
Operating lease liabilities	143	154
Asset retirement obligations	127	146
Equity investments	80	98
Loss carryforwards	42	7
Valuation allowance	(12)	(7)
Other	160	125
Total deferred tax assets	3,018	2,810
Net deferred tax liabilities	8,852	8,043
Unamortized investment tax credits	22	26
Net deferred tax liabilities and unamortized investment tax credits	8,874	8,069
CECONY
Deferred tax liabilities:
Property basis differences	8,632	8,001
Regulatory Assets:
Energy efficiency and other clean energy programs	449	344
Environmental remediation costs	267	287
Legacy meters	112	0
Other regulatory assets	510	525
Pensions and retiree benefits – asset	1,037	894
Operating lease right-of-use asset	142	153
Total deferred tax liabilities	11,149	10,204
Deferred tax assets:
Unrecognized pension and other postretirement costs	276	244
Future income tax	312	394
Other regulatory liabilities	809	744
Tax credits carryforward	0	0
Superfund and other environmental costs	265	288
Pensions and retiree benefits – liability	142	153
Corporate alternative minimum tax credit carryforward	111	0
Operating lease liabilities	142	153
Asset retirement obligations	127	146
Equity investments	0	0
Loss carryforwards	16	0
Valuation allowance	0	0
Other	140	109
Total deferred tax assets	2,340	2,231
Net deferred tax liabilities	8,809	7,973
Unamortized investment tax credits	10	11
Net deferred tax liabilities and unamortized investment tax credits	$ 8,819	$ 7,984

Income Tax - Summary of Unrecog

Income Tax - Summary of Unrecognized Tax Benefits (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Unrecognized Tax Benefits [Roll Forward]
Balance at beginning of period	$ 11	$ 23	$ 17
Additions based on tax positions related to the current year	4	8	3
Additions based on tax positions of prior years		3	6
Reductions for tax positions of prior years	(6)	(11)	(1)
Settlements	0	(12)	(2)
Balance at end of period	9	11	23
CECONY
Unrecognized Tax Benefits [Roll Forward]
Balance at beginning of period	7	8	5
Additions based on tax positions related to the current year	4	4	2
Additions based on tax positions of prior years	0	1	1
Reductions for tax positions of prior years	(6)	(6)	0
Settlements	0	0	0
Balance at end of period	$ 5	$ 7	$ 8

Revenue Recognition - Disaggreg

Revenue Recognition - Disaggregation of Revenue (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 15,469	$ 14,476	$ 15,455
TOTAL OPERATING REVENUES	15,256	14,663	15,670
Other
Disaggregation of Revenue [Line Items]
TOTAL OPERATING REVENUES	(213)	187	215
CECONY
Disaggregation of Revenue [Line Items]
TOTAL OPERATING REVENUES	14,129	13,476	13,268
Operating Segments \| Clean Energy Businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	82	998
TOTAL OPERATING REVENUES	0	129	1,319
Operating Segments \| Clean Energy Businesses \| Other
Disaggregation of Revenue [Line Items]
TOTAL OPERATING REVENUES	0	47	321
Operating Segments \| Clean Energy Businesses \| Renewables
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	68	637
TOTAL OPERATING REVENUES	0	68	637
Operating Segments \| Clean Energy Businesses \| Renewables \| Other
Disaggregation of Revenue [Line Items]
TOTAL OPERATING REVENUES	0	0	0
Operating Segments \| Clean Energy Businesses \| Energy services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	7	317
TOTAL OPERATING REVENUES	0	7	317
Operating Segments \| Clean Energy Businesses \| Energy services \| Other
Disaggregation of Revenue [Line Items]
TOTAL OPERATING REVENUES	0	0	0
Operating Segments \| Clean Energy Businesses \| Develop/Transfer Projects
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	7	44
TOTAL OPERATING REVENUES	0	7	44
Operating Segments \| Clean Energy Businesses \| Develop/Transfer Projects \| Other
Disaggregation of Revenue [Line Items]
TOTAL OPERATING REVENUES	0	0	0
Operating Segments \| Clean Energy Businesses \| Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0
TOTAL OPERATING REVENUES	0	47	321
Operating Segments \| Clean Energy Businesses \| Other \| Other
Disaggregation of Revenue [Line Items]
TOTAL OPERATING REVENUES	0	47	321
Operating Segments \| Con Edison Transmission
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	4	4	4
TOTAL OPERATING REVENUES	4	4	4
Operating Segments \| Con Edison Transmission \| Other
Disaggregation of Revenue [Line Items]
TOTAL OPERATING REVENUES	0	0	0
Operating Segments \| CECONY
Disaggregation of Revenue [Line Items]
TOTAL OPERATING REVENUES	14,129	13,476	13,268
Operating Segments \| CECONY \| Subsidiaries
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	14,350	13,364	13,376
TOTAL OPERATING REVENUES	14,129	13,476	13,268
Operating Segments \| CECONY \| Other \| Subsidiaries
Disaggregation of Revenue [Line Items]
TOTAL OPERATING REVENUES	(221)	112	(108)
Operating Segments \| CECONY \| Electric
Disaggregation of Revenue [Line Items]
TOTAL OPERATING REVENUES		10,078	9,751
Operating Segments \| CECONY \| Electric \| Subsidiaries
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	10,868	9,946	9,917
TOTAL OPERATING REVENUES	10,717	10,078	9,751
Operating Segments \| CECONY \| Electric \| Other \| Subsidiaries
Disaggregation of Revenue [Line Items]
TOTAL OPERATING REVENUES	(151)	132	(166)
Operating Segments \| CECONY \| Gas
Disaggregation of Revenue [Line Items]
TOTAL OPERATING REVENUES		2,829	2,924
Operating Segments \| CECONY \| Gas \| Subsidiaries
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2,890	2,867	2,875
TOTAL OPERATING REVENUES	2,834	2,829	2,924
Operating Segments \| CECONY \| Gas \| Other \| Subsidiaries
Disaggregation of Revenue [Line Items]
TOTAL OPERATING REVENUES	(56)	(38)	49
Operating Segments \| CECONY \| Steam
Disaggregation of Revenue [Line Items]
TOTAL OPERATING REVENUES		569	593
Operating Segments \| CECONY \| Steam \| Subsidiaries
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	592	551	584
TOTAL OPERATING REVENUES	578	569	593
Operating Segments \| CECONY \| Steam \| Other \| Subsidiaries
Disaggregation of Revenue [Line Items]
TOTAL OPERATING REVENUES	(14)	18	9
Operating Segments \| O&R
Disaggregation of Revenue [Line Items]
TOTAL OPERATING REVENUES	1,125	1,056	1,085
Operating Segments \| O&R \| Subsidiaries
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,115	1,026	1,077
TOTAL OPERATING REVENUES	1,125	1,056	1,085
Operating Segments \| O&R \| Other \| Subsidiaries
Disaggregation of Revenue [Line Items]
TOTAL OPERATING REVENUES	10	30	8
Operating Segments \| O&R \| Electric
Disaggregation of Revenue [Line Items]
TOTAL OPERATING REVENUES		759	773
Operating Segments \| O&R \| Electric \| Subsidiaries
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	865	740	771
TOTAL OPERATING REVENUES	852	759	773
Operating Segments \| O&R \| Electric \| Other \| Subsidiaries
Disaggregation of Revenue [Line Items]
TOTAL OPERATING REVENUES	(13)	19	2
Operating Segments \| O&R \| Gas
Disaggregation of Revenue [Line Items]
TOTAL OPERATING REVENUES		297	312
Operating Segments \| O&R \| Gas \| Subsidiaries
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	250	286	306
TOTAL OPERATING REVENUES	273	297	312
Operating Segments \| O&R \| Gas \| Other \| Subsidiaries
Disaggregation of Revenue [Line Items]
TOTAL OPERATING REVENUES	23	11	6
Other (b)
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0
TOTAL OPERATING REVENUES	(2)	(2)	(6)
Other (b) \| Other
Disaggregation of Revenue [Line Items]
TOTAL OPERATING REVENUES	$ (2)	$ (2)	$ (6)

Revenue Recognition - Change in

Revenue Recognition - Change in Unbilled Contract and Unearned Revenues (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Unbilled contract revenue
Beginning balance	$ 4	$ 80	$ 35
Additions	0	2	324
Subtractions	0	78	279
Ending balance	4	4	80
Unearned revenue
Beginning balance	0	3	7
Additions	0	0	0
Subtractions	0	3	4
Ending balance	$ 0	0	3
Contracts with customer, revenue recognized, amount outstanding end of last period		$ 3	$ 4

Current Expected Credit Losse_2

Current Expected Credit Losses - Schedule of Major Portfolio Segment Type (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Accounts receivable - customers
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance at January 1,	$ 360	$ 322	$ 317
Recoveries	21	14	17
Write-offs	(250)	(138)	(103)
Reserve adjustments	489	162	91
Ending Balance December 31,	620	360	322
Other receivables
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance at January 1,	13	10	22
Recoveries	0	0	0
Write-offs	0	(5)	(6)
Reserve adjustments	28	8	(6)
Ending Balance December 31,	41	13	10
CECONY \| Accounts receivable - customers \| Subsidiaries
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance at January 1,	353	314	304
Recoveries	17	12	16
Write-offs	(239)	(131)	(94)
Reserve adjustments	474	158	88
Ending Balance December 31,	605	353	314
CECONY \| Other receivables \| Subsidiaries
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance at January 1,	9	7	19
Recoveries	0	0	0
Write-offs	0	(3)	(4)
Reserve adjustments	29	5	(8)
Ending Balance December 31,	$ 38	$ 9	$ 7

Current Expected Credit Losse_3

Current Expected Credit Losses - Additional Information (Details) $ in Millions	12 Months Ended
	Dec. 31, 2024 USD ($)
Accounts, Notes, Loans and Financing Receivable [Line Items]
Increasein allowance for uncollectible accounts	$ 620
Threshold period past due, trade accounts receivable, writeoff	90 days
Subsidiaries \| CECONY
Accounts, Notes, Loans and Financing Receivable [Line Items]
Increasein allowance for uncollectible accounts	$ 605

Stock-Based Compensation - Addi

Stock-Based Compensation - Additional Information (Details) - USD ($)	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Maximum employer contribution match (up to)	$ 1
Amount employee contribution for employer match	9
Maximum employee investment per year (up to)	$ 25,000
Maximum percentage allowed to invest (not more than)	20%
Performance RSUs
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common stock received upon vesting (in shares)	1
Compensation expense to be recognized	$ 15,000,000
Nonvested awards, compensation cost not yet recognized, period for recognition (years)	1 year
Payment for settlement of vested units	$ 30,000,000	$ 21,000,000	$ 10,000,000
Performance RSUs \| CECONY
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense to be recognized	$ 14,000,000
Nonvested awards, compensation cost not yet recognized, period for recognition (years)	1 year
Payment for settlement of vested units	$ 27,000,000	19,000,000	9,000,000
Restricted Stock Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period (years)	3 years
Time-based Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense to be recognized	$ 18,000,000
Nonvested awards, compensation cost not yet recognized, period for recognition (years)	2 years
Payment for settlement of vested units	$ 2,000,000	2,000,000	2,000,000
Weighted average grant date price per share (in dollars per share)	$ 88.60
Time-based Awards \| CECONY
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense to be recognized	$ 16,000,000
Nonvested awards, compensation cost not yet recognized, period for recognition (years)	2 years
Payment for settlement of vested units	$ 2,000,000	$ 2,000,000	$ 2,000,000
Weighted average grant date price per share (in dollars per share)	$ 88.72
2013 LTIP
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares of common stock that can be awarded under the plan	10,000,000
TSR Portion \| Performance RSUs
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Adjustment percentage used for Performance awards	50%
Factor used for adjustment of Performance awards, low end (percent)	0%
Factor used for adjustment of Performance awards, high end (percent)	200%
Weighted average grant date price per share (in dollars per share)	$ 88.25
TSR Portion \| Performance RSUs \| CECONY
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted average grant date price per share (in dollars per share)	$ 87.96
Non-TSR Portion \| Performance RSUs
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Adjustment percentage used for Performance awards	50%
Factor used for adjustment of Performance awards, low end (percent)	0%
Factor used for adjustment of Performance awards, high end (percent)	200%
Weighted average grant date price per share (in dollars per share)	$ 88.03
Non-TSR Portion \| Performance RSUs \| CECONY
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted average grant date price per share (in dollars per share)	$ 88.17
LTIP
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of units issued (in shares)	33,000
Weighted average grant date price per share (in dollars per share)	$ 89.23
Stock Purchase Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares purchased on the open market	774,338	751,702	744,932
Weighted average share price per share, on shares purchased on open market (in dollars per share)	$ 94.71	$ 91.80	$ 91.59

Stock-Based Compensation - Stoc

Stock-Based Compensation - Stock-Based Compensation Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	$ 35	$ 53	$ 64
Income tax benefit	10	15	18
Performance-based restricted stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	23	41	52
Time-based restricted stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	2	2	2
Non-employee director deferred stock compensation
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	3	3	3
Stock purchase plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	7	7	7
CECONY
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	32	48	54
Income tax benefit	9	13	15
CECONY \| Performance-based restricted stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	20	36	43
CECONY \| Time-based restricted stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	2	2	2
CECONY \| Non-employee director deferred stock compensation
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	3	3	3
CECONY \| Stock purchase plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	$ 7	$ 7	$ 6

Stock-Based Compensation - Assu

Stock-Based Compensation - Assumptions Used to Calculate Fair Value (Details) - Performance RSUs	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Risk-free interest rate, minimum (percent)	4.23%	4.06%	4.41%
Risk-free interest rate, maximum (percent)	4.25%	4.64%	4.73%
Expected term (years)	3 years	3 years	3 years
Expected share price volatility, minimum (percent)	16.48%	17.88%	19.65%
Expected share price volatility, maximum (percent)	17.20%	19.92%	21.77%

Stock-Based Compensation - Summ

Stock-Based Compensation - Summary of Changes in Status of Performance RSUs' (Details) - Performance RSUs	12 Months Ended
	Dec. 31, 2024 $ / shares shares
Units
Non-vested at beginning of period (in shares) \| shares	838,303
Granted (in shares) \| shares	296,250
Vested (in shares) \| shares	(365,756)
Forfeited (in shares) \| shares	(47,996)
Transferred (in shares) \| shares	0
Non-vested at end of period (in shares) \| shares	720,801
CECONY
Units
Non-vested at beginning of period (in shares) \| shares	638,473
Granted (in shares) \| shares	246,221
Vested (in shares) \| shares	(272,859)
Forfeited (in shares) \| shares	(38,242)
Transferred (in shares) \| shares	(12,186)
Non-vested at end of period (in shares) \| shares	561,407
TSR Portion
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share)	$ 83.70
Granted (in dollars per share)	88.25
Vested (in dollars per share)	74.36
Forfeited (in dollars per share)	88.48
Transferred (in dollars per share)	0
Non-vested at end of period (in dollars per share)	$ 89.99
Adjustment percentage used for Performance awards	50%
TSR Portion \| CECONY
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share)	$ 83.94
Granted (in dollars per share)	87.96
Vested (in dollars per share)	74.10
Forfeited (in dollars per share)	88.78
Transferred (in dollars per share)	90.81
Non-vested at end of period (in dollars per share)	90.01
Non-TSR Portion
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share)	80.40
Granted (in dollars per share)	88.03
Vested (in dollars per share)	71.12
Forfeited (in dollars per share)	85.20
Transferred (in dollars per share)	0
Non-vested at end of period (in dollars per share)	$ 87.93
Adjustment percentage used for Performance awards	50%
Non-TSR Portion \| CECONY
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share)	$ 80.97
Granted (in dollars per share)	88.17
Vested (in dollars per share)	71.36
Forfeited (in dollars per share)	85.73
Transferred (in dollars per share)	86.84
Non-vested at end of period (in dollars per share)	$ 88.35

Stock-Based Compensation - Su_2

Stock-Based Compensation - Summary of Changes in Status of Time-Based Awards (Details) - Time-based Awards	12 Months Ended
	Dec. 31, 2024 $ / shares shares
Units
Non-vested at beginning of period (in shares) \| shares	345,201
Granted (in shares) \| shares	200,550
Vested (in shares) \| shares	(14,915)
Forfeited (in shares) \| shares	(22,766)
Transferred (in shares) \| shares	0
Non-vested at end of period (in shares) \| shares	508,070
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share) \| $ / shares	$ 89.71
Granted (in dollars per share) \| $ / shares	88.60
Vested (in dollars per share) \| $ / shares	74.80
Forfeited (in dollars per share) \| $ / shares	87.67
Transferred (in dollars per share) \| $ / shares	0
Non-vested at end of period (in dollars per share) \| $ / shares	$ 89.80
CECONY
Units
Non-vested at beginning of period (in shares) \| shares	289,063
Granted (in shares) \| shares	173,755
Vested (in shares) \| shares	(14,015)
Forfeited (in shares) \| shares	(18,938)
Transferred (in shares) \| shares	(5,210)
Non-vested at end of period (in shares) \| shares	424,655
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share) \| $ / shares	$ 90.25
Granted (in dollars per share) \| $ / shares	88.72
Vested (in dollars per share) \| $ / shares	74.80
Forfeited (in dollars per share) \| $ / shares	87.86
Transferred (in dollars per share) \| $ / shares	86.84
Non-vested at end of period (in dollars per share) \| $ / shares	$ 90.28

Financial Information by Busi_3

Financial Information by Business Segment (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Segment Reporting Information [Line Items]
TOTAL OPERATING REVENUES	$ 15,256	$ 14,663	$ 15,670
Other operations and maintenance	3,751	3,606	3,905
Depreciation and amortization	2,155	2,031	2,056
Other operating expense	6,680	5,830	7,085
Operating income	2,670	3,196	2,624
Other Income (deductions)	655	830	326
Interest Expense	1,250	1,075	888
Allowance for borrowed funds used during construction	(63)	(52)	(36)
Income Tax Expense	318	487	498
Total assets	70,562	66,331	69,065
Capital expenditures	4,728	4,509	4,465
Con Edison Transmission
Segment Reporting Information [Line Items]
Other operations and maintenance	11	11
CECONY
Segment Reporting Information [Line Items]
TOTAL OPERATING REVENUES	14,129	13,476	13,268
Depreciation and amortization	2,037	1,924	1,778
Operating income	2,593	2,177	2,135
Other Income (deductions)	578	732	332
Allowance for borrowed funds used during construction	(58)	(49)	(33)
Total assets	65,650	61,600
Operating segment
Segment Reporting Information [Line Items]
Other operations and maintenance	0	(3)
Operating segment \| Clean Energy Businesses
Segment Reporting Information [Line Items]
TOTAL OPERATING REVENUES	0	129	1,319
Other operations and maintenance			503
Depreciation and amortization		0	178
Other operating expense		45	270
Operating income		37	368
Other Income (deductions)		1	3
Interest Expense		16	(35)
Income Tax Expense		3	84
Total assets		0	7,224
Capital expenditures		81	399
Operating segment \| Con Edison Transmission
Segment Reporting Information [Line Items]
TOTAL OPERATING REVENUES	4	4	4
Other operations and maintenance			12
Depreciation and amortization	1	1	1
Other operating expense	0	1	1
Operating income	(8)	(9)	(10)
Other Income (deductions)	61	62	19
Interest Expense	0	2	5
Income Tax Expense	8	14	5
Total assets	470	414	314
Capital expenditures	29	49	65
Operating segment \| CECONY
Segment Reporting Information [Line Items]
TOTAL OPERATING REVENUES	14,129	13,476	13,268
Other operations and maintenance	3,353	3,176	3,042
Depreciation and amortization	2,037	1,924	1,778
Other operating expense	6,146	6,199	6,313
Operating income	2,593	2,177	2,135
Other Income (deductions)	578	732	332
Interest Expense	1,167	994	855
Allowance for borrowed funds used during construction	(58)	(49)	(33)
Income Tax Expense	314	358	255
Total assets	65,650	61,600	57,445
Capital expenditures	4,374	4,083	3,758
Operating segment \| CECONY \| Electric
Segment Reporting Information [Line Items]
TOTAL OPERATING REVENUES		10,078	9,751
Other operations and maintenance	2,622	2,417	2,373
Depreciation and amortization	1,471	1,395	1,315
Other operating expense	4,792	4,698	4,567
Operating income	1,832	1,568	1,496
Other Income (deductions)	441	564	259
Interest Expense	826	708	609
Allowance for borrowed funds used during construction	(41)	(34)	(27)
Income Tax Expense	193	217	134
Total assets	46,275	42,226	39,153
Capital expenditures	3,088	2,909	2,522
Operating segment \| CECONY \| Gas
Segment Reporting Information [Line Items]
TOTAL OPERATING REVENUES		2,829	2,924
Other operations and maintenance	528	528	471
Depreciation and amortization	458	429	367
Other operating expense	1,100	1,190	1,426
Operating income	748	682	660
Other Income (deductions)	102	122	52
Interest Expense	287	240	203
Allowance for borrowed funds used during construction	(16)	(13)	(5)
Income Tax Expense	132	159	140
Total assets	16,507	16,343	15,361
Capital expenditures	1,154	1,046	1,128
Operating segment \| CECONY \| Steam
Segment Reporting Information [Line Items]
TOTAL OPERATING REVENUES		569	593
Other operations and maintenance	203	231	198
Depreciation and amortization	108	100	96
Other operating expense	254	311	320
Operating income	13	(73)	(21)
Other Income (deductions)	35	46	21
Interest Expense	54	46	43
Allowance for borrowed funds used during construction	(1)	(2)	(1)
Income Tax Expense	(11)	(18)	(19)
Total assets	2,868	3,031	2,931
Capital expenditures	132	128	108
Operating segment \| O&R
Segment Reporting Information [Line Items]
TOTAL OPERATING REVENUES	1,125	1,056	1,085
Other operations and maintenance	387	375	352
Depreciation and amortization	117	106	98
Other operating expense	460	449	499
Operating income	161	126	136
Other Income (deductions)	32	49	23
Interest Expense	65	54	49
Allowance for borrowed funds used during construction	(5)	(3)	(3)
Income Tax Expense	29	28	25
Total assets	4,060	3,675	3,511
Capital expenditures	325	296	243
Operating segment \| O&R \| Electric
Segment Reporting Information [Line Items]
TOTAL OPERATING REVENUES		759	773
Other operations and maintenance	307	292	275
Depreciation and amortization	82	76	71
Other operating expense	351	306	333
Operating income	112	85	94
Other Income (deductions)	25	37	17
Interest Expense	43	35	32
Allowance for borrowed funds used during construction	(5)	(3)	(3)
Income Tax Expense	24	20	17
Total assets	2,596	2,329	2,247
Capital expenditures	214	211	167
Operating segment \| O&R \| Gas
Segment Reporting Information [Line Items]
TOTAL OPERATING REVENUES		297	312
Other operations and maintenance	80	83	77
Depreciation and amortization	35	30	27
Other operating expense	109	143	166
Operating income	49	41	42
Other Income (deductions)	7	12	6
Interest Expense	22	19	17
Income Tax Expense	5	8	8
Total assets	1,464	1,346	1,264
Capital expenditures	111	85	76
Other
Segment Reporting Information [Line Items]
TOTAL OPERATING REVENUES	(2)	(2)	(6)
Other operations and maintenance			(4)
Depreciation and amortization	0	0	1
Other operating expense	74	(864)	2
Operating income	(76)	865	(5)
Other Income (deductions)	(16)	(14)	(51)
Interest Expense	18	9	14
Income Tax Expense	(33)	84	129
Total assets	382	642	571
Capital expenditures	0	0	0
Other \| Clean Energy Businesses
Segment Reporting Information [Line Items]
Other operations and maintenance		47
Inter- segment revenues \| CECONY
Segment Reporting Information [Line Items]
TOTAL OPERATING REVENUES	(104)	(100)	(103)
Inter- segment revenues \| CECONY \| Electric
Segment Reporting Information [Line Items]
TOTAL OPERATING REVENUES	20	18	19
Inter- segment revenues \| CECONY \| Gas
Segment Reporting Information [Line Items]
TOTAL OPERATING REVENUES	9	8	8
Inter- segment revenues \| CECONY \| Steam
Segment Reporting Information [Line Items]
TOTAL OPERATING REVENUES	$ 75	$ 74	$ 76

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities - Fair Values of Commodity Derivatives Including Offsetting of Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Net fair value derivative assets/(liabilities)
Gross Amounts of Recognized Assets/ (Liabilities)	$ (105)	$ (224)
Gross Amounts Offset	3	18
Net Amounts of Assets/ (Liabilities)	(102)	(206)
CECONY
Net fair value derivative assets/(liabilities)
Gross Amounts of Recognized Assets/ (Liabilities)	(92)	(202)
Gross Amounts Offset	2	17
Net Amounts of Assets/ (Liabilities)	(90)	(185)
Fair Value of Derivative Liabilities, Current
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(92)	(230)
Gross Amounts Offset	44	52
Net Amounts of Assets/ (Liabilities)	(48)	(178)
Fair Value of Derivative Liabilities, Current \| CECONY
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(84)	(217)
Gross Amounts Offset	42	48
Net Amounts of Assets/ (Liabilities)	(42)	(169)
Fair Value of Derivative Liabilities, Non-current
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(108)	(154)
Gross Amounts Offset	12	33
Net Amounts of Assets/ (Liabilities)	(96)	(121)
Fair Value of Derivative Liabilities, Non-current \| CECONY
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(95)	(139)
Gross Amounts Offset	11	31
Net Amounts of Assets/ (Liabilities)	(84)	(108)
Fair Value of Derivative Liabilities
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(200)	(384)
Gross Amounts Offset	56	85
Net Amounts of Assets/ (Liabilities)	(144)	(299)
Net fair value derivative assets/(liabilities)
Margin deposit liability	(4)	(15)
Fair Value of Derivative Liabilities \| CECONY
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(179)	(356)
Gross Amounts Offset	53	79
Net Amounts of Assets/ (Liabilities)	(126)	(277)
Net fair value derivative assets/(liabilities)
Margin deposit liability	(2)	(10)
Fair Value of Derivative Assets, Current
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	56	83
Gross Amounts Offset	(41)	(38)
Net Amounts of Assets/ (Liabilities)	15	45
Fair Value of Derivative Assets, Current \| CECONY
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	51	78
Gross Amounts Offset	(40)	(35)
Net Amounts of Assets/ (Liabilities)	11	43
Fair Value of Derivative Assets, Non-current
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	39	77
Gross Amounts Offset	(12)	(29)
Net Amounts of Assets/ (Liabilities)	27	48
Fair Value of Derivative Assets, Non-current \| CECONY
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	36	76
Gross Amounts Offset	(11)	(27)
Net Amounts of Assets/ (Liabilities)	25	49
Fair Value of Derivative Assets
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	95	160
Gross Amounts Offset	(53)	(67)
Net Amounts of Assets/ (Liabilities)	42	93
Net fair value derivative assets/(liabilities)
Margin deposits		7
Fair Value of Derivative Assets \| CECONY
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	87	154
Gross Amounts Offset	(51)	(62)
Net Amounts of Assets/ (Liabilities)	$ 36	92
Net fair value derivative assets/(liabilities)
Margin deposits		$ 6

Derivative Instruments and He_4

Derivative Instruments and Hedging Activities - Realized and Unrealized Gains or Losses on Commodity Derivatives (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Pre-tax gains (losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains (losses)	$ (90)	$ (332)
Total deferred or recognized gains (losses)		(780)
Net deferred gains/(losses)	(185)	(1,112)
Pre-tax gains (losses) recognized in income
Total pre-tax gains (losses) recognized in income	$ 0	$ 26
Gas purchased for resale (b)
Pre-tax gains (losses) deferred in accordance with accounting rules for regulated operations:
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	Operating costs	Operating costs
Pre-tax gains (losses) recognized in income
Total pre-tax gains (losses) recognized in income	$ 0	$ 4
Non-utility
Pre-tax gains (losses) deferred in accordance with accounting rules for regulated operations:
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	TOTAL OPERATING REVENUES	TOTAL OPERATING REVENUES
Pre-tax gains (losses) recognized in income
Total pre-tax gains (losses) recognized in income	$ 0	$ 17
Other interest expense (b)
Pre-tax gains (losses) deferred in accordance with accounting rules for regulated operations:
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	Other interest expense (income)	Other interest expense (income)
Pre-tax gains (losses) recognized in income
Total pre-tax gains (losses) recognized in income		$ 5
Interest Expense
Pre-tax gains (losses) recognized in income
Total pre-tax gains (losses) recognized in income	$ 0
Regulatory Liabilities Current
Pre-tax gains (losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains (losses)	(49)	(236)
Total deferred or recognized gains (losses)	(95)
Regulatory Liabilities Non Current
Pre-tax gains (losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains (losses)	(41)	(96)
Regulatory Assets Current
Pre-tax gains (losses) deferred in accordance with accounting rules for regulated operations:
Total deferred or recognized gains (losses)	166	(85)
Recoverable energy costs
Pre-tax gains (losses) deferred in accordance with accounting rules for regulated operations:
Total deferred or recognized gains (losses)	(318)	(563)
Deferred Derivative Losses, Noncurrent
Pre-tax gains (losses) deferred in accordance with accounting rules for regulated operations:
Total deferred or recognized gains (losses)	57	(132)
CECONY
Pre-tax gains (losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains (losses)		(297)
Net deferred gains/(losses)	(171)	(1,028)
Pre-tax gains (losses) recognized in income
Total pre-tax gains (losses) recognized in income	$ 0	$ 0
CECONY \| Gas purchased for resale (b)
Pre-tax gains (losses) deferred in accordance with accounting rules for regulated operations:
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	Operating costs	Operating costs
Pre-tax gains (losses) recognized in income
Total pre-tax gains (losses) recognized in income		$ 0
CECONY \| Non-utility
Pre-tax gains (losses) deferred in accordance with accounting rules for regulated operations:
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	TOTAL OPERATING REVENUES	TOTAL OPERATING REVENUES
Pre-tax gains (losses) recognized in income
Total pre-tax gains (losses) recognized in income		$ 0
CECONY \| Other interest expense (b)
Pre-tax gains (losses) deferred in accordance with accounting rules for regulated operations:
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	Other interest expense (income)	Other interest expense (income)
CECONY \| Interest Expense
Pre-tax gains (losses) recognized in income
Total pre-tax gains (losses) recognized in income		$ 0
CECONY \| Subsidiaries
Pre-tax gains (losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains (losses)	$ (92)
CECONY \| Subsidiaries \| Gas purchased for resale (b)
Pre-tax gains (losses) recognized in income
Total pre-tax gains (losses) recognized in income	0
CECONY \| Subsidiaries \| Non-utility
Pre-tax gains (losses) recognized in income
Total pre-tax gains (losses) recognized in income	0
CECONY \| Subsidiaries \| Interest Expense
Pre-tax gains (losses) recognized in income
Total pre-tax gains (losses) recognized in income	0
CECONY \| Regulatory Liabilities Current
Pre-tax gains (losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains (losses)		(216)
Total deferred or recognized gains (losses)		(731)
CECONY \| Regulatory Liabilities Current \| Subsidiaries
Pre-tax gains (losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains (losses)	(49)
Total deferred or recognized gains (losses)	(79)
CECONY \| Regulatory Liabilities Non Current
Pre-tax gains (losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains (losses)		(81)
CECONY \| Regulatory Liabilities Non Current \| Subsidiaries
Pre-tax gains (losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains (losses)	(43)
CECONY \| Regulatory Assets Current
Pre-tax gains (losses) deferred in accordance with accounting rules for regulated operations:
Total deferred or recognized gains (losses)		(76)
CECONY \| Regulatory Assets Current \| Subsidiaries
Pre-tax gains (losses) deferred in accordance with accounting rules for regulated operations:
Total deferred or recognized gains (losses)	161
CECONY \| Recoverable energy costs
Pre-tax gains (losses) deferred in accordance with accounting rules for regulated operations:
Total deferred or recognized gains (losses)		(533)
CECONY \| Recoverable energy costs \| Subsidiaries
Pre-tax gains (losses) deferred in accordance with accounting rules for regulated operations:
Total deferred or recognized gains (losses)	(294)
CECONY \| Deferred Derivative Losses, Noncurrent
Pre-tax gains (losses) deferred in accordance with accounting rules for regulated operations:
Total deferred or recognized gains (losses)		$ (122)
CECONY \| Deferred Derivative Losses, Noncurrent \| Subsidiaries
Pre-tax gains (losses) deferred in accordance with accounting rules for regulated operations:
Total deferred or recognized gains (losses)	$ 54

Derivative Instruments and He_5

Derivative Instruments and Hedging Activities - Hedged Volume of Derivative Transactions (Details)	Dec. 31, 2024 MWh gal MW MMBTU
Electric Energy
Derivatives, Fair Value [Line Items]
Notional amount \| MWh	33,303,430
Capacity
Derivatives, Fair Value [Line Items]
Notional amount \| MW	31,500
Natural Gas
Derivatives, Fair Value [Line Items]
Notional amount \| MMBTU	313,300,000
Refined Fuels
Derivatives, Fair Value [Line Items]
Notional amount \| gal	3,780,000
CECONY \| Electric Energy
Derivatives, Fair Value [Line Items]
Notional amount \| MWh	30,466,200
CECONY \| Capacity
Derivatives, Fair Value [Line Items]
Notional amount \| MW	24,000
CECONY \| Natural Gas
Derivatives, Fair Value [Line Items]
Notional amount \| MMBTU	292,340,000
CECONY \| Refined Fuels
Derivatives, Fair Value [Line Items]
Notional amount \| gal	3,780,000

Derivative Instruments and He_6

Derivative Instruments and Hedging Activities - Additional Information (Details) - USD ($) $ in Millions	Dec. 31, 2024	Mar. 01, 2023
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	$ 29
Makeup of net credit exposure with investment-grade counterparties	22
Makeup of net credit exposure with commodity exchange brokers	7
CECONY
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	$ 21
Makeup of net credit exposure with investment-grade counterparties		$ 15
Makeup of net credit exposure with commodity exchange brokers		$ 6

Derivative Instruments and He_7

Derivative Instruments and Hedging Activities - Aggregate Fair Value of Companies' Derivative Instruments with Credit-Risk-Related Contingent Features (Details) $ in Millions	Dec. 31, 2024 USD ($)
Derivatives, Fair Value [Line Items]
Aggregate fair value – net liabilities	$ 129
Collateral posted	122
Downgrade One Level from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	17
Downgrade to Below Investment Grade from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	136
Derivatives in net asset position additional collateral	1
Additional Collateral Required Due To Loss Of Unsecured Credit
Derivatives, Fair Value [Line Items]
Collateral posted	8
CECONY
Derivatives, Fair Value [Line Items]
Aggregate fair value – net liabilities	112
Collateral posted	120
CECONY \| Downgrade One Level from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	8
CECONY \| Downgrade to Below Investment Grade from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	$ 114

Fair Value Measurements - Asset

Fair Value Measurements - Assets and Liabilities Measured at Fair Value on Recurring Basis (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset, statement of financial position [Extensible Enumeration]	TOTAL ASSETS	TOTAL ASSETS
Level 3 \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	$ (6)
Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	741	$ 723
Recurring \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	712	699
Recurring \| Netting Adjustment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(49)	(54)
Recurring \| Netting Adjustment \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(48)	(52)
Recurring \| Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	579	511
Recurring \| Level 1 \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	562	494
Recurring \| Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	210	264
Recurring \| Level 2 \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	197	256
Recurring \| Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1	2
Recurring \| Level 3 \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1	1
Recurring \| Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	42	100
Derivative liabilities	148	314
Recurring \| Commodity \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	36	98
Derivative liabilities	128	287
Recurring \| Commodity \| Netting Adjustment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(49)	(54)
Derivative liabilities	(48)	(65)
Recurring \| Commodity \| Netting Adjustment \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(48)	(52)
Derivative liabilities	(47)	(65)
Recurring \| Commodity \| Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	9	6
Derivative liabilities	5	22
Recurring \| Commodity \| Level 1 \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	9	6
Derivative liabilities	4	20
Recurring \| Commodity \| Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	81	146
Derivative liabilities	175	347
Recurring \| Commodity \| Level 2 \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	74	143
Derivative liabilities	164	326
Recurring \| Commodity \| Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1	2
Derivative liabilities	16	10
Recurring \| Commodity \| Level 3 \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1	1
Derivative liabilities	7	6
Recurring \| Mutual Fund
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	570	505
Recurring \| Mutual Fund \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	553	488
Recurring \| Mutual Fund \| Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	570	505
Recurring \| Mutual Fund \| Level 1 \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	553	488
Recurring \| Other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	129	118
Recurring \| Other \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	123	113
Recurring \| Other \| Netting Adjustment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Recurring \| Other \| Netting Adjustment \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Recurring \| Other \| Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	129	118
Recurring \| Other \| Level 2 \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	123	113
Recurring \| Other \| Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Recurring \| Other \| Level 3 \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	$ 0	$ 0

Fair Value Measurements - Sched

Fair Value Measurements - Schedule of Commodity Derivatives (Details) - Level 3 $ in Millions	Dec. 31, 2024 USD ($) $ / MWh $ / kW-month
CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives \| $	$ (6)
Electricity \| Forward Capacity Prices
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives \| $	(16)
Electricity \| Forward Capacity Prices \| CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives \| $	$ (7)
Electricity \| Forward Capacity Prices \| Minimum \| CECONY \| Subsidiaries
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) \| $ / kW-month	0.73
Electricity \| Forward Energy Prices \| Minimum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit)	0.73
Electricity \| Forward Energy Prices \| Maximum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit)	7.14
Electricity \| Forward Energy Prices \| Maximum \| CECONY \| Subsidiaries
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit)	7.14
Electricity \| Forward Energy Prices \| Weighted Average
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit)	3.69
Electricity \| Forward Energy Prices \| Weighted Average \| CECONY \| Subsidiaries
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit)	3.75
Transmission Congestion Contracts \| Inter-Zonal Forward Price Curves
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives \| $	$ 1
Transmission Congestion Contracts \| Inter-Zonal Forward Price Curves \| CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives \| $	$ 1
Transmission Congestion Contracts \| Inter-Zonal Forward Price Curves \| Minimum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit)	(0.20)
Transmission Congestion Contracts \| Inter-Zonal Forward Price Curves \| Minimum \| CECONY \| Subsidiaries
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit)	(0.20)
Transmission Congestion Contracts \| Inter-Zonal Forward Price Curves \| Maximum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit)	3.88
Transmission Congestion Contracts \| Inter-Zonal Forward Price Curves \| Maximum \| CECONY \| Subsidiaries
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit)	3.88
Transmission Congestion Contracts \| Inter-Zonal Forward Price Curves \| Weighted Average
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit)	1.85
Transmission Congestion Contracts \| Inter-Zonal Forward Price Curves \| Weighted Average \| CECONY \| Subsidiaries
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit)	1.85
Total Con Edison - Commodity
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives \| $	$ (15)

Fair Value Measurements - Recon

Fair Value Measurements - Reconciliation of Beginning and Ending Net Balances for Assets and Liabilities Measured at Level 3 Fair Value (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning Balance	$ (8)	$ 15
Included in earnings	(9)	(4)
Included in regulatory assets and liabilities	(7)	33
Settlements	10	4
Decrease due to the sale of the Clean Energy Businesses	0	(29)
Transfer out of level 3	(1)	(27)
Ending Balance	(15)	(8)
CECONY
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning Balance	(5)	(6)
Included in earnings	(4)	(2)
Included in regulatory assets and liabilities	0	31
Settlements	4	2
Decrease due to the sale of the Clean Energy Businesses	0	0
Transfer out of level 3	(1)	(30)
Ending Balance	$ (6)	$ (5)

Fair Value Measurements - Addit

Fair Value Measurements - Additional Information (Details) - Clean Energy Businesses - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Gain (loss) on Level 3 energy derivative assets and liabilities		$ 17	$ 26
Fair Value, Liability, Recurring Basis, Unobservable Input Reconciliation, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	TOTAL OPERATING REVENUES	TOTAL OPERATING REVENUES

Variable Interest Entities - Ad

Variable Interest Entities - Additional Information (Details)	12 Months Ended
	Dec. 31, 2024 USD ($) project	Dec. 31, 2023 USD ($)	Dec. 31, 2018	Mar. 01, 2023 solarProject
Variable Interest Entity [Line Items]
Number of solar projects	2			2
Clean Energy Businesses
Variable Interest Entity [Line Items]
Equity method investment	$ 0
Loss from the project, pre-tax	3,000,000	$ 14,000,000
Loss from the project, after-tax	$ 2,500,000	$ 10,000,000
Variable Interest Entity, Primary Beneficiary \| Clean Energy Businesses \| Tax Equity Projects \| Consolidated Edison Development
Variable Interest Entity [Line Items]
Percentage of variable interests (less than)			100%

Variable Interest Entities - HL

Variable Interest Entities - HLVB Method of Accounting (Details) - Variable Interest Entity, Primary Beneficiary - Clean Energy Businesses $ in Millions	12 Months Ended
	Dec. 31, 2022 USD ($)
CED Nevada Virginia \| Tax equity investor
Schedule of Equity Method Investments [Line Items]
Income (loss)	$ (49)
Net income (loss)	(37)
CED Nevada Virginia \| Consolidated Edison Development
Schedule of Equity Method Investments [Line Items]
Income (loss)	41
Net income (loss)	31
Tax Equity Projects \| Tax equity investor
Schedule of Equity Method Investments [Line Items]
Income (loss)	(11)
Net income (loss)	(8)
Tax Equity Projects \| Consolidated Edison Development
Schedule of Equity Method Investments [Line Items]
Income (loss)	51
Net income (loss)	$ 38

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance as of January 1,	$ 522	$ 500
Changes in estimated cash flows	(21)	76
Accretion expense	20	17
Liabilities settled	(68)	(71)
Ending Balance as of December 31,	453	522
Asset retirement obligation, period increase (decrease)	(85)	(77)
Disposal Group, Held-for-sale, Not Discontinued Operations \| Clean Energy Businesses
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Disposal group, including discontinued operation, asset retirement obligations	3	3
CECONY
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance as of January 1,	520	499
Changes in estimated cash flows	(21)	75
Accretion expense	20	17
Liabilities settled	(67)	(71)
Ending Balance as of December 31,	452	$ 520
Asset retirement obligation, period increase (decrease)	$ (84)

Related Party Transactions - Ad

Related Party Transactions - Additional Information (Details) MMBTU in Thousands	1 Months Ended		12 Months Ended
	Dec. 31, 2024 USD ($)	Apr. 30, 2024 USD ($)	Dec. 31, 2024 USD ($) MMBTU	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)
Related Party Transaction [Line Items]
Other income			$ 635,000,000	$ 834,000,000	$ 402,000,000
Unconditional charitable contribution, accrued amount	$ 12,000,000	$ 12,000,000
CECONY
Related Party Transaction [Line Items]
Net assets	19,971,000,000		19,971,000,000	19,146,000,000	16,878,000,000	$ 16,312,000,000
Sale of natural gas			77,000,000	82,000,000	$ 144,000,000
Tax expense due to affiliates			344,000,000	110,000,000
Funding limit of CECONY to O&R (not to exceed)			$ 250,000,000
CECONY \| Related Party, Lending of Funds
Related Party Transaction [Line Items]
Lending period (not more than) (months)			12 months
CECONY \| Equity Method Investee \| Mountain Valley Pipeline
Related Party Transaction [Line Items]
Other income			$ 28,000,000
Contract term (years)			20 years
Generating capacity per day (in dekatherms) \| MMBTU			200
O&R
Related Party Transaction [Line Items]
Net assets	1,142,000,000		$ 1,142,000,000
Outstanding loans	$ 0		0	0
CET Electric \| NY Transco \| Related Party
Related Party Transaction [Line Items]
Other income			$ 0	$ 7,300,000

Related Party Transactions - Su

Related Party Transactions - Summary of Costs of Administrative and Other Services Provided and Received (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Related Party Transaction [Line Items]
TOTAL OPERATING REVENUES	$ 15,256	$ 14,663	$ 15,670
Cost of services received	12,524	12,332	13,046
CECONY
Related Party Transaction [Line Items]
TOTAL OPERATING REVENUES	14,129	13,476	13,268
Cost of services received	11,536	11,299	11,133
CECONY \| Related Party
Related Party Transaction [Line Items]
TOTAL OPERATING REVENUES	147	146	135
Cost of services received	$ 82	$ 82	$ 75

Dispositions - Narrative (Detai

Dispositions - Narrative (Details) $ in Millions	1 Months Ended	12 Months Ended
Dispositions - Narrative (Details) $ in Millions	Jan. 31, 2025 USD ($)	Dec. 31, 2024 USD ($) MWh project	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)	Mar. 01, 2023 USD ($) MWh solarProject	Oct. 01, 2022 USD ($)	Dec. 31, 2021 USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Number of solar projects		2			2
Unbilled contracts receivable		$ 4	$ 4	$ 80			$ 35
Electric Energy
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Notional amount \| MWh		33,303,430
Clean Energy Businesses \| Renewables Americas, LLC
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Estimate of possible loss		$ 24
Unbilled contracts receivable		4
Clean Energy Businesses \| Renewables Americas, LLC \| Maximum
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Estimate of possible loss		172
Disposal Group, Held-for-sale, Not Discontinued Operations \| Clean Energy Businesses
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Consideration the project is sold					$ 3,993	$ 6,800
Gain (loss) on disposition of stock in subsidiary		62	865
Gain (loss) on disposition of stock in subsidiary, after tax		46	767
Downward price adjustment		33
Downward price adjustment, after tax		25
Disposal group, including discontinue operation, transaction costs		0	12	48
Disposal group, including discontinue operation, transaction costs, after tax		0	9	$ 35
Depreciation and amortization, before tax		41
Depreciation and amortization, after tax		$ 28
Disposal Group, Held-for-sale, Not Discontinued Operations \| Clean Energy Businesses \| Subsequent Event
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Consideration the project is sold	$ 54
Downward price adjustment	33
Downward price adjustment, after tax	25
Disposal Group, Held-for-sale, Not Discontinued Operations \| Clean Energy Businesses \| Broken Bow II \| Subsequent Event
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Consideration the project is sold	$ 54
Disposal Group, Disposed of by Sale, Not Discontinued Operations \| Crane Project
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Holding period (in years)		5 years
Carrying value of tax equity interest		$ 4	$ 13
Clean Energy Businesses \| Electric Energy \| Broken Bow II
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Notional amount \| MWh		75			75
CECONY \| Electric Energy
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Notional amount \| MWh		30,466,200

Dispositions - Pre-Tax Operatin

Dispositions - Pre-Tax Operating Income (Details) - Clean Energy Businesses - Disposal Group, Held-for-sale, Not Discontinued Operations - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Pre-tax operating income	$ 25	$ 466
Pre-tax operating income, excluding non-controlling interest	$ 21	$ 406

Held-for-Sale Treatment of th_3

Held-for-Sale Treatment of the Clean Energy Businesses - Additional Information (Details) $ in Millions	1 Months Ended	12 Months Ended
	Jan. 31, 2025 USD ($)	Dec. 31, 2024 USD ($) MWh	Mar. 01, 2023 USD ($) MWh	Oct. 01, 2022 USD ($)
Disposal Group, Held-for-sale, Not Discontinued Operations \| Clean Energy Businesses
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Consideration the project is sold			$ 3,993	$ 6,800
Downward price adjustment		$ 33
Downward price adjustment, after tax		$ 25
Disposal Group, Held-for-sale, Not Discontinued Operations \| Clean Energy Businesses \| Subsequent Event
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Consideration the project is sold	$ 54
Downward price adjustment	33
Downward price adjustment, after tax	25
Electric Energy
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Notional amount \| MWh		33,303,430
Broken Bow II \| Disposal Group, Held-for-sale, Not Discontinued Operations \| Clean Energy Businesses \| Subsequent Event
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Consideration the project is sold	$ 54
Broken Bow II \| Electric Energy \| Clean Energy Businesses
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Notional amount \| MWh		75	75

Held-for-Sale Treatment of th_4

Held-for-Sale Treatment of the Clean Energy Businesses - Schedule of Carrying Amounts (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
CURRENT ASSETS
TOTAL CURRENT ASSETS	$ 133	$ 163
Non-utility property, net accumulated depreciation	12	13
CURRENT LIABILITIES
TOTAL CURRENT LIABILITIES	79	76
Disposal Group, Held-for-sale, Not Discontinued Operations \| Clean Energy Businesses
CURRENT ASSETS
Cash and temporary cash investments	1	0
Accounts receivable and other receivables - net allowance for uncollectible accounts	2	1
Accrued unbilled revenue	0	1
Restricted cash	8	5
Other current assets	0	1
TOTAL CURRENT ASSETS	11	8
Non-utility property, net accumulated depreciation	59	76
NET PLANT	59	76
OTHER NONCURRENT ASSETS
Intangible assets, less accumulated amortization	56	72
Operating lease right-of-use asset	7	7
TOTAL OTHER NONCURRENT ASSETS	63	79
TOTAL ASSETS	133	163
CURRENT LIABILITIES
Long-term debt due within one year	2	2
Operating lease liabilities	2	2
Other current liabilities	10	4
TOTAL CURRENT LIABILITIES	14	8
NONCURRENT LIABILITIES
Asset retirement obligations	3	3
Operating lease liabilities	5	5
TOTAL NONCURRENT LIABILITIES	8	8
LONG-TERM DEBT	57	60
TOTAL LIABILITIES	$ 79	$ 76

Schedule I - Condensed Financ_2

Schedule I - Condensed Financial Information - Income and Comprehensive Income (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Condensed Income Statements,Captions [Line Items]
Taxes, other than income taxes	$ (3,280)	$ (3,043)	$ (3,005)
Interest expense	(1,187)	(1,023)	(852)
Income tax benefit (expense)	(318)	(487)	(498)
Gain (Loss) on the sale of the Clean Energy Businesses	(62)	865	0
NET INCOME FOR COMMON STOCK	1,820	2,519	1,660
Comprehensive Income	$ 1,827	$ 2,519	$ 1,677
Net Income Per Share – Basic (in dollars per share)	$ 5.26	$ 7.25	$ 4.68
Net Income Per Share – Diluted (in dollars per share)	5.24	7.21	4.66
Dividends Declared Per Share (in dollars per share)	$ 3.32	$ 3.24	$ 3.16
Average Number Of Shares Outstanding—Basic (in shares)	346	347.7	354.5
Average Number Of Shares Outstanding—Diluted (in shares)	347.3	349.3	355.8
Parent Company
Condensed Income Statements,Captions [Line Items]
Equity in earnings of subsidiaries	$ 1,904	$ 1,759	$ 1,860
Other operating and maintenance expenses	(1)	0	(1)
Taxes, other than income taxes	(12)	(2)	(7)
Other income (deductions)	(14)	7	(31)
Interest expense	(18)	(14)	(32)
Income tax benefit (expense)	23	(96)	(129)
Gain (Loss) on the sale of the Clean Energy Businesses	(62)	865	0
NET INCOME FOR COMMON STOCK	1,820	2,519	1,660
Comprehensive Income	$ 1,827	$ 2,520	$ 1,677
Net Income Per Share – Basic (in dollars per share)	$ 5.26	$ 7.25	$ 4.68
Net Income Per Share – Diluted (in dollars per share)	5.24	7.21	4.66
Dividends Declared Per Share (in dollars per share)	$ 3.32	$ 3.24	$ 3.16
Average Number Of Shares Outstanding—Basic (in shares)	346	347.7	354.5
Average Number Of Shares Outstanding—Diluted (in shares)	347.3	349.3	355.8

Schedule I - Condensed Financ_3

Schedule I - Condensed Financial Information - Cash Flows (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Condensed Cash Flow Statements, Captions [Line Items]
NET CASH FLOWS FROM OPERATING ACTIVITIES	$ 3,614	$ 2,156	$ 3,935
INVESTING ACTIVITIES
Proceeds from sale of the Clean Energy Businesses, net of cash and cash equivalents sold	0	3,927	0
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(5,273)	(1,003)	(4,565)
FINANCING ACTIVITIES
Net issuance (payment) of short-term debt	(118)	(202)	1,152
Retirement of long-term debt	(477)	(710)	(406)
Repurchase of common shares	0	(1,000)	0
Issuance of common shares for stock plans	60	56	57
Common stock dividends	(1,100)	(1,096)	(1,089)
NET CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES	1,797	(1,488)	1,014
NET CHANGE FOR THE PERIOD	138	(335)	384
BALANCE AT BEGINNING OF PERIOD	1,195	1,530	1,146
BALANCE AT END OF PERIOD	1,333	1,195	1,530
CECONY
Condensed Cash Flow Statements, Captions [Line Items]
NET CASH FLOWS FROM OPERATING ACTIVITIES	3,358	2,285	3,263
INVESTING ACTIVITIES
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(4,923)	(4,439)	(3,926)
FINANCING ACTIVITIES
Net issuance (payment) of short-term debt	(209)	(397)	939
Issuance of term loan	500	0	0
Retirement of long-term debt	(475)	0	0
NET CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES	1,681	2,236	799
NET CHANGE FOR THE PERIOD	116	82	136
BALANCE AT BEGINNING OF PERIOD	1,138	1,056	920
BALANCE AT END OF PERIOD	1,254	1,138	1,056
Parent Company
Condensed Cash Flow Statements, Captions [Line Items]
NET CASH FLOWS FROM OPERATING ACTIVITIES	1,204	772	1,015
INVESTING ACTIVITIES
Contributions to subsidiaries	(175)	(1,854)	(150)
Proceeds from sale of the Clean Energy Businesses, net of cash and cash equivalents sold	0	3,927	0
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(175)	2,073	(150)
FINANCING ACTIVITIES
Net issuance (payment) of short-term debt	9	57	232
Issuance of term loan	0	200	400
Retirement of term loan	0	(600)	0
Retirement of long-term debt	0	(650)	(293)
Repurchase of common shares	0	(1,000)	0
Issuance of common shares for stock plans	60	56	57
Common stock dividends	(1,100)	(1,096)	(1,089)
NET CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES	(1,031)	(3,033)	(693)
NET CHANGE FOR THE PERIOD	(2)	(188)	172
BALANCE AT BEGINNING OF PERIOD	3	191	19
BALANCE AT END OF PERIOD	$ 1	$ 3	$ 191

Schedule I - Condensed Financ_4

Schedule I - Condensed Financial Information - Balance Sheet (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Current Assets
Cash and temporary cash investments	$ 1,324	$ 1,189
Tax receivable	145	1
Accounts receivable from affiliated companies	2,440	2,418
Accrued unbilled revenue	848	722
Prepayments	445	470
Other current assets	194	125
TOTAL CURRENT ASSETS	6,664	6,537
Investments in subsidiaries and others	1,126	999
Goodwill	408	408
Pension and retiree benefits - asset	3,791	3,275
Other deferred charges and noncurrent assets	10,607	9,187
TOTAL ASSETS	70,562	66,331	$ 69,065
Current Liabilities
Notes payable	2,170	2,288
Accounts payable	1,676	1,775
Accrued taxes	70	73
Other current liabilities	481	411
TOTAL CURRENT LIABILITIES	6,433	6,462
Shareholders’ Equity
TOTAL LIABILITIES AND EQUITY	70,562	66,331
Parent Company
Current Assets
Cash and temporary cash investments	1	3
Other receivables, net allowance for uncollectible accounts	64	103
Tax receivable	145	1
Accounts receivable from affiliated companies	300	343
Accrued unbilled revenue	3	4
Prepayments	13	109
Other current assets	1	3
TOTAL CURRENT ASSETS	527	566
Investments in subsidiaries and others	21,706	20,778
Goodwill	406	406
Pension and retiree benefits - asset	6	5
Other deferred charges and noncurrent assets	356	249
TOTAL ASSETS	23,001	22,004
Current Liabilities
Notes payable	348	339
Other current liabilities	9	8
TOTAL CURRENT LIABILITIES	1,036	841
Other noncurrent liabilities	4	5
Total Liabilities	1,040	846
Shareholders’ Equity
Common stock, including additional paid-in capital	10,024	9,898
Retained earnings	11,937	11,260
Equity	21,961	21,158
TOTAL LIABILITIES AND EQUITY	23,001	22,004
Parent Company \| Nonrelated Party
Current Liabilities
Accounts payable	17	30
Accrued taxes	2	15
Parent Company \| Related Party
Current Liabilities
Accounts payable	14	12
Accrued taxes	$ 646	$ 437

Consolidated Edison (ED) 10-K20 Feb 252024 FY Annual reportFinancial data

Cover Page

Audit Information

Consolidated Income Statement

Consolidated Statement of Compr

Consolidated Statement of Cash

Consolidated Balance Sheet

Consolidated Balance Sheet (Par

Consolidated Statement of Equit

Consolidated Statement of Equ_2

Consolidated Statement of Capit

Consolidated Statement of Cap_2

Consolidated Statement of Cap_3

Consolidated Income Statement _

Consolidated Statement of Com_2

Consolidated Statement of Cas_2

Consolidated Balance Sheet - CE

Consolidated Balance Sheet - _2

Consolidated Statement of Share

Consolidated Statement of Cap_4

Consolidated Statement of Cap_5

Consolidated Statement of Cap_6

General

Summary of Significant Accounti

Regulatory Matters

Capitalization

Short-Term Borrowing

Pension Benefits

Other Postretirement Benefits

Environmental Matters

Material Contingencies

Electricity and Gas Purchase Ag

Leases

Goodwill

Income Tax

Revenue Recognition

Current Expected Credit Losses

Stock-Based Compensation

Financial Information by Busine

Derivative Instruments and Hedg

Fair Value Measurements

Variable Interest Entities

Asset Retirement Obligations

Related Party Transactions

New Financial Accounting Standa

Dispositions

Held-for-Sale Treatment of the

Schedule I - Condensed Financia

Pay vs Performance Disclosure

Insider Trading Arrangements

Insider Trading Policies and Pr

Cybersecurity Risk Management a

Summary of Significant Accoun_2

Summary of Significant Accoun_3

Regulatory Matters (Tables)

Capitalization (Tables)

Pension Benefits (Tables)

Other Postretirement Benefits (

Environmental Matters (Tables)

Material Contingencies (Tables)

Electricity and Gas Purchase _2

Leases (Tables)

Income Tax (Tables)

Revenue Recognition (Tables)

Current Expected Credit Losses

Stock-Based Compensation (Table

Financial Information by Busi_2

Derivative Instruments and He_2

Fair Value Measurements (Tables

Variable Interest Entities (Tab

Asset Retirement Obligations (T

Related Party Transactions (Tab

Dispositions (Tables)

Held-for-Sale Treatment of th_2

General (Details)

Summary of Significant Accoun_4

Summary of Significant Accoun_5

Summary of Significant Accoun_6

Summary of Significant Accoun_7

Summary of Significant Accoun_8