Consolidated Edison Co Of New York 10-K 16 Feb 23 2022 FY Annual report Financial data

Cover Page

Cover Page - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2022	Jan. 31, 2023	Jun. 30, 2022
Document Information [Line Items]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2022
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
Entity Shell Company	false
Entity Public Float			$ 33.7
Entity Common Stock, Shares Outstanding		355,045,021
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 15, 2023, to be filed with the Commission pursuant to Regulation 14A, not later than 120 days after December 31, 2022, is incorporated in Part III of this report.
Amendment Flag	false
Document Fiscal Year Focus	2022
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	2022
Document Fiscal Period Focus	FY
Entity Central Index Key	0000023632
Current Fiscal Year End Date	--12-31

Audit Information

Audit Information	12 Months Ended
	Dec. 31, 2022
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, 2022	Dec. 31, 2021	Dec. 31, 2020
OPERATING REVENUES
TOTAL OPERATING REVENUES	$ 15,670	$ 13,676	$ 12,246
OPERATING EXPENSES
Depreciation and amortization	2,056	2,032	1,920
Taxes, other than income taxes	3,005	2,810	2,575
TOTAL OPERATING EXPENSES	13,046	10,850	9,592
OPERATING INCOME	2,624	2,826	2,654
OTHER INCOME (DEDUCTIONS)
Investment income (loss)	20	(420)	(214)
Other income	402	22	23
Allowance for equity funds used during construction	19	21	17
Other deductions	(115)	(161)	(227)
TOTAL OTHER INCOME (DEDUCTIONS)	326	(538)	(401)
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	2,950	2,288	2,253
INTEREST EXPENSE
Interest on long-term debt	987	930	915
Other interest	(99)	(14)	118
Allowance for borrowed funds used during construction	(36)	(11)	(14)
NET INTEREST EXPENSE	852	905	1,019
INCOME BEFORE INCOME TAX EXPENSE	2,098	1,383	1,234
INCOME TAX EXPENSE	498	190	90
NET INCOME	1,600	1,193	1,144
(Loss) Income attributable to non-controlling interest	(60)	(153)	43
NET INCOME	$ 1,660	$ 1,346	$ 1,101
Net income per common share — basic (in dollars per share)	$ 4.68	$ 3.86	$ 3.29
Net income per common share — diluted (in dollars per share)	$ 4.66	$ 3.85	$ 3.28
AVERAGE NUMBER OF SHARES OUTSTANDING — BASIC (in shares)	354.5	348.4	334.8
AVERAGE NUMBER OF SHARES OUTSTANDING — DILUTED (in shares)	355.8	349.4	335.7
Electric
OPERATING REVENUES
TOTAL OPERATING REVENUES	$ 10,522	$ 9,485	$ 8,730
Gas
OPERATING REVENUES
TOTAL OPERATING REVENUES	3,237	2,638	2,269
OPERATING EXPENSES
Operating costs	1,245	690	527
Steam
OPERATING REVENUES
TOTAL OPERATING REVENUES	593	532	508
Non-utility
OPERATING REVENUES
TOTAL OPERATING REVENUES	1,318	1,021	739
Purchased power
OPERATING EXPENSES
Operating costs	2,479	1,835	1,600
Fuel
OPERATING EXPENSES
Operating costs	356	229	156
Other operations and maintenance
OPERATING EXPENSES
Operating costs	$ 3,905	$ 3,254	$ 2,814

Consolidated Statement of Compr

Consolidated Statement of Comprehensive Income - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Statement of Comprehensive Income [Abstract]
Net Income	$ 1,600	$ 1,193	$ 1,144
LOSS (INCOME) ATTRIBUTABLE TO NON-CONTROLLING INTEREST	60	153	(43)
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	16	30	(6)
Other income, net of taxes	1	0	0
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	17	30	(6)
COMPREHENSIVE INCOME	$ 1,677	$ 1,376	$ 1,095

Consolidated Statement of Cash

Consolidated Statement of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
OPERATING ACTIVITIES
Net Income	$ 1,600	$ 1,193	$ 1,144
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	2,056	2,032	1,920
Impairment of assets	0	443	320
Deferred income taxes	435	133	85
Net derivative (gains)/losses	(181)	(53)	57
Other non-cash items, net	163	111	(8)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable - customers	(285)	(411)	(543)
Unbilled revenue and net unbilled revenue deferrals	(96)	(53)	(1)
Reserve adjustments	5	169	78
Materials and supplies, including fuel oil and gas in storage	(111)	(82)	(4)
Prepayments, other receivables and other current assets	31	(234)	(179)
Accounts payable	558	44	170
Pensions and retiree benefits obligations, net	176	266	285
Pensions and retiree benefits contributions	(39)	(472)	(478)
Accrued taxes	7	(46)	74
Distributions from equity investments	20	18	39
System benefit charge	(41)	(34)	(119)
Deferred charges, noncurrent assets, leases, net and other regulatory assets	(870)	(496)	(686)
Deferred credits, noncurrent liabilities and other regulatory liabilities	423	248	(58)
Other current liabilities	84	(43)	102
NET CASH FLOWS FROM OPERATING ACTIVITIES	3,935	2,733	2,198
INVESTING ACTIVITIES
Utility construction expenditures	(3,824)	(3,630)	(3,326)
Cost of removal less salvage	(337)	(323)	(310)
Non-utility construction expenditures	(344)	(323)	(583)
Proceeds from sale of assets	0	629	0
Divestiture of renewable electric projects	0	183	0
Other investing activities	4	10	22
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(4,565)	(3,484)	(4,224)
FINANCING ACTIVITIES
Net (payment)/issuance of short-term debt	1,702	(382)	178
Issuance of long-term debt	800	2,804	2,925
Retirement of long-term debt	(406)	(1,960)	(518)
Debt issuance costs	(13)	(40)	(47)
Common stock dividends	(1,089)	(1,030)	(975)
Issuance of common shares - public offering	0	775	640
Issuance of common shares for stock plans	57	60	58
Distribution to noncontrolling interest	(37)	(23)	(16)
Sale of equity interest	0	257	0
NET CASH FLOWS FROM FINANCING ACTIVITIES	1,014	461	2,245
CASH, TEMPORARY CASH INVESTMENTS AND RESTRICTED CASH:
NET CHANGE FOR THE PERIOD	384	(290)	219
BALANCE AT BEGINNING OF PERIOD	1,146	1,436	1,217
BALANCE AT END OF PERIOD	1,530	1,146	1,436
Total cash, temporary cash investments and restricted cash	1,530	1,146	1,436
LESS: CHANGE IN CASH BALANCES HELD FOR SALE	248	0	0
BALANCE AT END OF PERIOD EXCLUDING HELD FOR SALE	1,282	1,146	1,436
Cash paid/(received) during the period for:
Interest	900	924	920
Income taxes	47	9	38
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	681	457	478
Issuance of common shares for dividend reinvestment	31	49	48
Electric and Gas Transmission Projects
INVESTING ACTIVITIES
Investments in/acquisitions of projects	(64)	(30)	(3)
Renewable Electric Production Projects
INVESTING ACTIVITIES
Investments in/acquisitions of projects	0	0	(24)
Software Licenses
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	2	23	51
Equipment
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	$ 17	$ 22	$ 28

Consolidated Balance Sheet

Consolidated Balance Sheet - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
CURRENT ASSETS
Cash and temporary cash investments	$ 1,282	$ 992
Accounts receivable - customers, less allowance for uncollectible accounts	2,192	1,943
Other receivables, less allowance for uncollectible accounts	164	298
Taxes receivable	10	13
Accrued unbilled revenue	702	662
Fuel oil, gas in storage, materials and supplies, at average cost	492	437
Prepayments	264	295
Regulatory assets	305	206
Restricted cash	0	154
Revenue decoupling mechanism receivable	164	190
Fair value of derivative assets	59	128
Assets held for sale	7,162	0
Other current assets	176	233
TOTAL CURRENT ASSETS	12,972	5,551
INVESTMENTS	841	853
UTILITY PLANT, AT ORIGINAL COST
General	4,205	4,170
TOTAL	57,337	54,239
Less: Accumulated depreciation	13,069	12,177
Net	44,268	42,062
Construction work in progress	2,484	2,152
NET UTILITY PLANT	46,752	44,214
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	13	4,194
Construction work in progress	1	188
NET PLANT	46,766	48,596
OTHER NONCURRENT ASSETS
Goodwill	408	439
Intangible assets, net of accumulated amortization of $297 and $228 in 2021 and 2020, respectively	0	1,293
Operating lease right-of-use-asset	568	809
Regulatory assets	3,974	3,639
Pension and Retiree Benefits	3,269	1,654
Fair value of derivative assets	85	77
Other deferred charges and noncurrent assets	182	205
TOTAL OTHER NONCURRENT ASSETS	8,486	8,116
TOTAL ASSETS	69,065	63,116
CURRENT LIABILITIES
Long-term debt due within one year	649	440
Term Loan	400	0
Notes payable	2,640	1,488
Accounts payable	1,955	1,497
Customer deposits	358	300
Accrued taxes	102	104
Accrued interest	153	151
Accrued wages	116	113
Fair value of derivative liabilities	42	152
Regulatory liabilities	374	185
System benefit charge	390	423
Operating lease liabilities	103	113
Liabilities held for sale	3,610	0
Other current liabilities	444	461
TOTAL CURRENT LIABILITIES	11,336	5,427
NONCURRENT LIABILITIES
Provision for injuries and damages	181	183
Pensions and retiree benefits	577	737
Superfund and other environmental costs	997	940
Asset retirement obligations	500	577
Fair value of derivative liabilities	13	84
Deferred income taxes and unamortized investment tax credits	7,641	6,873
Operating lease liabilities	476	717
Regulatory liabilities	6,027	4,381
Other deferred credits and noncurrent liabilities	281	257
TOTAL NONCURRENT LIABILITIES	16,693	14,749
TOTAL LONG-TERM DEBT EXCLUDING HELD FOR SALE	20,147	22,604
COMMITMENTS, CONTINGENCIES, AND GUARANTEES (Note B, Note G, and Note H)
EQUITY
Common shareholders’ equity	20,687	20,037
Noncontrolling interest	202	299
TOTAL EQUITY (See Statement of Equity)	20,889	20,336
TOTAL LIABILITIES AND EQUITY	69,065	63,116
Electric
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	36,819	34,938
Gas
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	13,378	12,303
Steam
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	$ 2,935	$ 2,828

Consolidated Balance Sheet (Par

Consolidated Balance Sheet (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Accounts receivable - customers, allowance for uncollectible accounts	$ 322	$ 317
Other receivables, allowance for uncollectible accounts	10	22
Non-utility property, accumulated depreciation	23	626
Intangible assets, accumulated amortization		297
CECONY
Accounts receivable - customers, allowance for uncollectible accounts	314	304
Other receivables, allowance for uncollectible accounts	7	19
Non-utility property, accumulated depreciation	$ 25	$ 25

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/(Loss)	Noncontrolling Interest
BALANCE AS OF BEGINNING OF PERIOD (in shares) at Dec. 31, 2019		333,000,000
BALANCE AS OF BEGINNING OF PERIOD at Dec. 31, 2019	$ 18,213	$ 35	$ 8,054	$ 11,100	$ (1,038)	$ (110)	$ (19)	$ 191
TREASURY STOCK, BALANCE AS OF BEGINNING OF PERIOD (in shares) at Dec. 31, 2019					23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	1,144			1,101				43
Common stock dividends	(1,023)			(1,023)
Issuance of common shares - public offering (in shares)		9,000,000
Issuance of common shares - public offering	640	$ 1	641			(2)
Issuance of common shares for stock plans	113		113
Other comprehensive income	(6)						(6)
Distributions to noncontrolling interests	(16)							(16)
BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2020		342,000,000
BALANCE AS OF END OF PERIOD at Dec. 31, 2020	19,065	$ 36	8,808	11,178	$ (1,038)	(112)	(25)	218
TREASURY STOCK, BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2020					23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	1,193			1,346				(153)
Common stock dividends	(1,079)			(1,079)
Issuance of common shares - public offering (in shares)		10,000,000
Issuance of common shares - public offering	766	$ 1	775			(10)
Issuance of common shares for stock plans (in shares)		2,000,000
Issuance of common shares for stock plans	127		127
Other comprehensive income	30						30
Distributions to noncontrolling interests	(23)							(23)
Net proceeds from sale of equity interest	$ 257							257
BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2021	353,983,712	354,000,000
BALANCE AS OF END OF PERIOD at Dec. 31, 2021	$ 20,336	$ 37	9,710	11,445	$ (1,038)	(122)	5	299
TREASURY STOCK, BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2021					23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	1,600			1,660				(60)
Common stock dividends	(1,120)			(1,120)
Issuance of common shares - public offering	0
Issuance of common shares for stock plans (in shares)		1,000,000
Issuance of common shares for stock plans	93		93
Other comprehensive income	17						17
Distributions to noncontrolling interests	$ (37)							(37)
BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2022	354,962,058	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
TREASURY STOCK, BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2022					23,000,000

Consolidated Statement of Equ_2

Consolidated Statement of Equity (Parenthetical) - $ / shares	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Statement of Stockholders' Equity [Abstract]
Common stock dividends per share (in dollars per share)	$ 3.16	$ 3.10	$ 3.06

Consolidated Statement of Capit

Consolidated Statement of Capitalization - USD ($) shares in Millions, $ in Millions	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Regulated Operations [Abstract]
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE LOSS (in shares)	355	354
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)	$ 20,665	$ 20,032
Pension plan liability adjustments, net of taxes	23	7
Unrealized gains/(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)	(2)
TOTAL ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	22	5
Equity	20,687	20,037
Noncontrolling interest	202	299
TOTAL EQUITY (See Statement of Equity)	$ 20,889	$ 20,336	$ 19,065	$ 18,213

Consolidated Statement of Cap_2

Consolidated Statement of Capitalization - Long-term Debt - USD ($) $ in Millions		Dec. 31, 2022	Dec. 31, 2021
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.94%
Other long-term debt		$ (1)	$ 293
Unamortized debt expense		(172)	(177)
Unamortized debt discount		(51)	(49)
TOTAL		23,441	23,044
Less: Long-term debt due within one year		1,002	440
TOTAL LONG-TERM DEBT		22,439	22,604
Less: Held for sale project debt, net		2,292	0
TOTAL LONG-TERM DEBT EXCLUDING HELD FOR SALE		20,147	22,604
TOTAL CAPITALIZATION		$ 40,834	42,641
Copper Mountain Solar 2
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[1]	6.91%
TOTAL PROJECT DEBT		$ 179	192
Copper Mountain Solar 3
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[1]	6.91%
TOTAL PROJECT DEBT		$ 229	247
CED Southwest
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[1]	5.92%
TOTAL PROJECT DEBT		$ 408	418
Wind Holdings
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[1]	4.41%
TOTAL PROJECT DEBT		$ 87	95
Copper Mountain Solar 1
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[1]	6.48%
TOTAL PROJECT DEBT		$ 41	49
CED California Texas
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[1]	6.42%
TOTAL PROJECT DEBT		$ 236	248
Mesquite Solar 1
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL PROJECT DEBT		$ 149	165
Mesquite Solar 1 | Minimum
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[2]	2.24%
Mesquite Solar 1 | Maximum
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[2]	3.03%
Texas Solar 4
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL PROJECT DEBT		$ 49	52
Texas Solar 4 | Minimum
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[2]	5.25%
Texas Solar 4 | Maximum
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[2]	4.95%
California Solar 2
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.94%
TOTAL PROJECT DEBT		$ 86	88
California Solar 3
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.07%
TOTAL PROJECT DEBT		$ 77	79
California Solar
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.78%
TOTAL PROJECT DEBT		$ 168	171
California Solar 4
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.82%
TOTAL PROJECT DEBT		$ 265	271
Broken Bow II
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.82%
TOTAL PROJECT DEBT		$ 64	65
Texas Solar 5
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.53%
TOTAL PROJECT DEBT		$ 132	135
Texas Solar 7
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.21%
TOTAL PROJECT DEBT		$ 180	184
Upton County Solar
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.45%
TOTAL PROJECT DEBT		$ 81	83
CED Nevada Virginia
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.77%
TOTAL PROJECT DEBT		$ 228	228
Other project debt
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL PROJECT DEBT		6	7
Project Debt
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL PROJECT DEBT		2,665	2,777
Debentures
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL		$ 20,550	19,750
Debentures | Debenture 2020A, 0.65 Percent, Due 2023
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		0.65%
TOTAL		$ 650	650
Debentures | Debenture 2014B, 3.30 Percent, Due 2024
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.30%
TOTAL		$ 250	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 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	0
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 2004B, 5.70% Due 2034
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.70%
TOTAL		$ 200	200
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 2005B, 5.25% Due 2035
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.25%
TOTAL		$ 125	125
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	0
Debentures | Debenture Series 2014C, 4.625% Due 2054
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.63%
TOTAL		$ 750	750
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		$ 450	450
Tax-Exempt Debt | Tax Exempt Debt Series 2010A Due 2036
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[3]	3.61%
TOTAL PROJECT DEBT		$ 225	225
Tax-Exempt Debt | Tax Exempt Debt Series 2004C, 1.663% Due 2039
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[3]	3.68%
TOTAL PROJECT DEBT		$ 99	99
Tax-Exempt Debt | Tax-Exempt Debt Series 2005A, 1.627% Due 2039
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[3]	3.63%
TOTAL PROJECT DEBT		$ 126	$ 126
[1](b) December 31, 2022 effective rates shown, reflecting variable interest rates on the debt that are reset quarterly or semi-annually. Refer to Note Q for the effect of applicable interest rate swaps.[2](c) Range of rates shown reflect multiple tranches associated with the debt.[3]Rates reset weekly; December 31, 2022 rates shown.

Consolidated Income Statement _

Consolidated Income Statement  - CECONY - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
TOTAL OPERATING REVENUES	$ 15,670	$ 13,676	$ 12,246
Depreciation and amortization	2,056	2,032	1,920
Taxes, other than income taxes	3,005	2,810	2,575
TOTAL OPERATING EXPENSES	13,046	10,850	9,592
Operating income	2,624	2,826	2,654
Investment income (loss)	20	(420)	(214)
Allowance for equity funds used during construction	19	21	17
Other deductions	(115)	(161)	(227)
TOTAL OTHER INCOME (DEDUCTIONS)	326	(538)	(401)
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	2,950	2,288	2,253
Interest on long-term debt	987	930	915
Other interest	(99)	(14)	118
Allowance for borrowed funds used during construction	(36)	(11)	(14)
NET INTEREST EXPENSE	852	905	1,019
INCOME BEFORE INCOME TAX EXPENSE	2,098	1,383	1,234
INCOME TAX EXPENSE	498	190	90
NET INCOME	1,660	1,346	1,101
CECONY
TOTAL OPERATING REVENUES	13,268	11,716	10,647
Depreciation and amortization	1,778	1,705	1,598
Taxes, other than income taxes	2,887	2,696	2,456
TOTAL OPERATING EXPENSES	11,133	9,256	8,337
Operating income	2,135	2,460	2,310
Investment income (loss)	376	16	19
Allowance for equity funds used during construction	18	19	14
Other deductions	(62)	(143)	(204)
TOTAL OTHER INCOME (DEDUCTIONS)	332	(108)	(171)
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	2,467	2,352	2,139
Interest on long-term debt	808	759	718
Other interest	47	13	33
Allowance for borrowed funds used during construction	(33)	(10)	(12)
NET INTEREST EXPENSE	822	762	739
INCOME BEFORE INCOME TAX EXPENSE	1,645	1,590	1,400
INCOME TAX EXPENSE	255	246	215
NET INCOME	1,390	1,344	1,185
Electric
TOTAL OPERATING REVENUES	10,522	9,485	8,730
Electric | CECONY
TOTAL OPERATING REVENUES	9,751	8,806	8,103
Gas
TOTAL OPERATING REVENUES	3,237	2,638	2,269
Operating costs	1,245	690	527
Gas | CECONY
TOTAL OPERATING REVENUES	2,924	2,378	2,036
Operating costs	869	541	426
Steam
TOTAL OPERATING REVENUES	593	532	508
Steam | CECONY
TOTAL OPERATING REVENUES	593	532	508
Purchased power
Operating costs	2,479	1,835	1,600
Purchased power | CECONY
Operating costs	2,201	1,633	1,432
Fuel
Operating costs	356	229	156
Fuel | CECONY
Operating costs	356	229	156
Other operations and maintenance
Operating costs	3,905	3,254	2,814
Other operations and maintenance | CECONY
Operating costs	3,042	2,452	2,269
Non-utility
TOTAL OPERATING REVENUES	$ 1,318	$ 1,021	$ 739

Consolidated Statement of Com_2

Consolidated Statement of Comprehensive Income - CECONY - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
NET INCOME	$ 1,660	$ 1,346	$ 1,101
Pension and other postretirement benefit plan liability adjustments, net of taxes	16	30	(6)
Other income, net of taxes	1	0	0
Other comprehensive income	17	30	(6)
COMPREHENSIVE INCOME	1,677	1,376	1,095
CECONY
NET INCOME	1,390	1,344	1,185
Pension and other postretirement benefit plan liability adjustments, net of taxes	3	7	(1)
Other income, net of taxes	1	0	0
Other comprehensive income	4	7	(1)
COMPREHENSIVE INCOME	$ 1,394	$ 1,351	$ 1,184

Consolidated Statement of Cas_2

Consolidated Statement of Cash Flows - CECONY - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
OPERATING ACTIVITIES
Net income	$ 1,660	$ 1,346	$ 1,101
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	2,056	2,032	1,920
Deferred income taxes	435	133	85
Other non-cash items, net	163	111	(8)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable - customers	(285)	(411)	(543)
Reserve adjustments	5	169	78
Prepayments, other receivables and other current assets	31	(234)	(179)
Accounts payable	558	44	170
Pensions and retiree benefits obligations, net	176	266	285
Pensions and retiree benefits contributions	(39)	(472)	(478)
Accrued taxes	7	(46)	74
System benefit charge	(41)	(34)	(119)
Deferred charges, noncurrent assets, leases, net and other regulatory assets	(870)	(496)	(686)
Deferred credits, noncurrent liabilities and other regulatory liabilities	423	248	(58)
Other current liabilities	84	(43)	102
NET CASH FLOWS FROM OPERATING ACTIVITIES	3,935	2,733	2,198
INVESTING ACTIVITIES
Utility construction expenditures	(3,824)	(3,630)	(3,326)
Cost of removal less salvage	(337)	(323)	(310)
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(4,565)	(3,484)	(4,224)
FINANCING ACTIVITIES
Net (payment)/issuance of short-term debt	1,702	(382)	178
Issuance of long-term debt	800	2,804	2,925
Retirement of long-term debt	(406)	(1,960)	(518)
Debt issuance costs	(13)	(40)	(47)
NET CASH FLOWS FROM FINANCING ACTIVITIES	1,014	461	2,245
CASH, TEMPORARY CASH INVESTMENTS AND RESTRICTED CASH:
NET CHANGE FOR THE PERIOD	384	(290)	219
BALANCE AT BEGINNING OF PERIOD	1,146	1,436	1,217
BALANCE AT END OF PERIOD	1,530	1,146	1,436
Cash paid/(received) during the period for:
Interest	900	924	920
Income taxes	47	9	38
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	681	457	478
CECONY
OPERATING ACTIVITIES
Net income	1,390	1,344	1,185
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	1,778	1,705	1,598
Deferred income taxes	85	124	168
Other non-cash items, net	175	(2)	(62)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable - customers	(268)	(412)	(516)
Reserve adjustments	10	166	74
Prepayments, other receivables and other current assets	56	(354)	(98)
Accounts receivables from affiliated companies	(8)	96	(61)
Accounts payable	322	65	145
Accounts payable to affiliated companies	(1)	(4)	9
Pensions and retiree benefits obligations, net	182	283	253
Pensions and retiree benefits contributions	(26)	(433)	(438)
Accrued taxes	15	(54)	61
Accrued taxes to affiliated companies	79	9	1
System benefit charge	(33)	(32)	(112)
Deferred charges, noncurrent assets, leases, net and other regulatory assets	(852)	(484)	(633)
Deferred credits, noncurrent liabilities and other regulatory liabilities	312	192	15
Other current liabilities	47	(23)	104
NET CASH FLOWS FROM OPERATING ACTIVITIES	3,263	2,186	1,693
INVESTING ACTIVITIES
Utility construction expenditures	(3,596)	(3,413)	(3,112)
Cost of removal less salvage	(330)	(316)	(304)
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(3,926)	(3,729)	(3,416)
FINANCING ACTIVITIES
Net (payment)/issuance of short-term debt	939	(299)	523
Issuance of long-term debt	700	2,250	2,200
Retirement of long-term debt	0	(640)	(350)
Debt issuance costs	(12)	(27)	(34)
Capital contribution by parent	150	1,100	500
Dividend to parent	(978)	(988)	(982)
NET CASH FLOWS FROM FINANCING ACTIVITIES	799	1,396	1,857
CASH, TEMPORARY CASH INVESTMENTS AND RESTRICTED CASH:
NET CHANGE FOR THE PERIOD	136	(147)	134
BALANCE AT BEGINNING OF PERIOD	920	1,067	933
BALANCE AT END OF PERIOD	1,056	920	1,067
Cash paid/(received) during the period for:
Interest	755	739	693
Income taxes	87	5	102
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	561	406	417
Software Licenses
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	2	23	51
Software Licenses | CECONY
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	2	22	48
Equipment
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	17	22	28
Equipment | CECONY
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	$ 17	$ 22	$ 28

Consolidated Balance Sheet - CE

Consolidated Balance Sheet - CECONY - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
CURRENT ASSETS
Cash and temporary cash investments	$ 1,282	$ 992
Accounts receivable - customers, less allowance for uncollectible accounts	2,192	1,943
Other receivables, less allowance for uncollectible accounts	164	298
Taxes receivable	10	13
Accrued unbilled revenue	702	662
Fuel oil, gas in storage, materials and supplies, at average cost	492	437
Prepayments	264	295
Regulatory assets	305	206
Revenue decoupling mechanism receivable	164	190
Fair value of derivative assets	59	128
Other current assets	176	233
TOTAL CURRENT ASSETS	12,972	5,551
INVESTMENTS	841	853
UTILITY PLANT, AT ORIGINAL COST
General	4,205	4,170
TOTAL	57,337	54,239
Less: Accumulated depreciation	13,069	12,177
Net	44,268	42,062
Construction work in progress	2,484	2,152
NET UTILITY PLANT	46,752	44,214
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	13	4,194
NET PLANT	46,766	48,596
OTHER NONCURRENT ASSETS
Regulatory assets	3,974	3,639
Operating lease right-of-use-asset	568	809
Pension and Retiree Benefits	3,269	1,654
Fair value of derivative assets	85	77
Other deferred charges and noncurrent assets	182	205
TOTAL OTHER NONCURRENT ASSETS	8,486	8,116
TOTAL ASSETS	69,065	63,116
CURRENT LIABILITIES
Notes payable	2,640	1,488
Accounts payable	1,955	1,497
Customer deposits	358	300
Accrued taxes	102	104
Accrued interest	153	151
Accrued wages	116	113
Fair value of derivative liabilities	42	152
Regulatory liabilities	374	185
System benefit charge	390	423
Operating lease liabilities	103	113
Other current liabilities	444	461
TOTAL CURRENT LIABILITIES	11,336	5,427
NONCURRENT LIABILITIES
Provision for injuries and damages	181	183
Pensions and retiree benefits	577	737
Superfund and other environmental costs	997	940
Asset retirement obligations	500	577
Fair value of derivative liabilities	13	84
Deferred income taxes and unamortized investment tax credits	7,641	6,873
Operating lease liabilities	476	717
Regulatory liabilities	6,027	4,381
Other deferred credits and noncurrent liabilities	281	257
TOTAL NONCURRENT LIABILITIES	16,693	14,749
LONG-TERM DEBT	22,439	22,604
COMMITMENTS, CONTINGENCIES, AND GUARANTEES (Note B, Note G, and Note H)
EQUITY
Common shareholders’ equity	20,687	20,037
TOTAL LIABILITIES AND EQUITY	69,065	63,116
Electric
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	36,819	34,938
Gas
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	13,378	12,303
Steam
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	2,935	2,828
CECONY
CURRENT ASSETS
Cash and temporary cash investments	1,056	920
Accounts receivable - customers, less allowance for uncollectible accounts	2,099	1,841
Other receivables, less allowance for uncollectible accounts	147	121
Taxes receivable	5	5
Accrued unbilled revenue	573	549
Accounts receivable from affiliated companies	46	38
Fuel oil, gas in storage, materials and supplies, at average cost	440	369
Prepayments	223	212
Regulatory assets	286	188
Revenue decoupling mechanism receivable	164	191
Fair value of derivative assets	51	71
Other current assets	157	198
TOTAL CURRENT ASSETS	5,247	4,703
INVESTMENTS	539	608
UTILITY PLANT, AT ORIGINAL COST
General	3,879	3,854
TOTAL	53,788	50,849
Less: Accumulated depreciation	12,047	11,223
Net	41,741	39,626
Construction work in progress	2,268	1,985
NET UTILITY PLANT	44,009	41,611
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	2	2
NET PLANT	44,011	41,613
OTHER NONCURRENT ASSETS
Regulatory assets	3,669	3,316
Operating lease right-of-use-asset	567	545
Pension and Retiree Benefits	3,184	1,677
Fair value of derivative assets	80	56
Other deferred charges and noncurrent assets	148	137
TOTAL OTHER NONCURRENT ASSETS	7,648	5,731
TOTAL ASSETS	57,445	52,655
CURRENT LIABILITIES
Notes payable	2,300	1,361
Accounts payable	1,763	1,285
Accounts payable to affiliated companies	17	18
Customer deposits	341	285
Accrued taxes	93	78
Accrued taxes to affiliated companies	89	10
Accrued interest	134	127
Accrued wages	105	103
Fair value of derivative liabilities	35	88
Regulatory liabilities	308	134
System benefit charge	351	372
Operating lease liabilities	103	90
Other current liabilities	397	370
TOTAL CURRENT LIABILITIES	6,036	4,321
NONCURRENT LIABILITIES
Provision for injuries and damages	177	178
Pensions and retiree benefits	526	669
Superfund and other environmental costs	903	850
Asset retirement obligations	499	504
Fair value of derivative liabilities	9	40
Deferred income taxes and unamortized investment tax credits	7,144	6,796
Operating lease liabilities	475	462
Regulatory liabilities	5,481	3,921
Other deferred credits and noncurrent liabilities	237	220
TOTAL NONCURRENT LIABILITIES	15,451	13,640
LONG-TERM DEBT	19,080	18,382
COMMITMENTS, CONTINGENCIES, AND GUARANTEES (Note B, Note G, and Note H)
EQUITY
Common shareholders’ equity	16,878	16,312
TOTAL LIABILITIES AND EQUITY	57,445	52,655
CECONY | Electric
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	34,636	32,846
CECONY | Gas
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	12,338	11,321
CECONY | Steam
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	$ 2,935	$ 2,828

Consolidated Balance Sheet - _2

Consolidated Balance Sheet - CECONY (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Accounts receivable - customers, allowance for uncollectible accounts	$ 322	$ 317
Other receivables, allowance for uncollectible accounts	10	22
Non-utility property, accumulated depreciation	23	626
CECONY
Accounts receivable - customers, allowance for uncollectible accounts	314	304
Other receivables, allowance for uncollectible accounts	7	19
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 CECONY	Retained Earnings	Retained Earnings CECONY	Repurchased Con Edison Stock CECONY	Capital Stock Expense CECONY	Accumulated Other Comprehensive Income/(Loss)	Accumulated Other Comprehensive Income/(Loss) CECONY
BALANCE AS OF BEGINNING OF PERIOD (in shares) at Dec. 31, 2019			333,000,000	235,000,000
BALANCE AS OF BEGINNING OF PERIOD at Dec. 31, 2019		$ 14,147		$ 589	$ 5,669		$ 8,919	$ (962)	$ (62)		$ (6)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
NET INCOME	$ 1,101	1,185					1,185
Common stock dividend to parent	(1,023)	(982)				$ (1,023)	(982)
Capital contribution by parent		500			500
Other comprehensive income	(6)	(1)								$ (6)	(1)
BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2020			342,000,000	235,000,000
BALANCE AS OF END OF PERIOD at Dec. 31, 2020		14,849		$ 589	6,169		9,122	(962)	(62)		(7)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
NET INCOME	1,346	1,344					1,344
Common stock dividend to parent	(1,079)	(988)				(1,079)	(988)
Capital contribution by parent		1,100			1,100
Other comprehensive income	$ 30	$ 7								30	7
BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2021	353,983,712	235,488,094	354,000,000	235,000,000
BALANCE AS OF END OF PERIOD at Dec. 31, 2021	$ 20,037	$ 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 parent	(1,120)	(978)				$ (1,120)	(978)
Capital contribution by parent		150			150
Other comprehensive income	$ 17	$ 4								$ 17	4
BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2022	354,962,058	235,488,094	355,000,000	235,000,000
BALANCE AS OF END OF PERIOD at Dec. 31, 2022	$ 20,687	$ 16,878		$ 589	$ 7,419		$ 9,890	$ (962)	$ (62)		$ 4

Consolidated Statement of Cap_3

Consolidated Statement of Capitalization - CECONY - USD ($) shares in Millions, $ in Millions	Dec. 31, 2022	Dec. 31, 2021
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE LOSS (in shares)	355	354
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)	$ 20,665	$ 20,032
Pension plan liability adjustments, net of taxes	23	7
Unrealized gains/(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)	(2)
TOTAL ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	$ 22	$ 5
CECONY
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE LOSS (in shares)	235	235
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)	$ 16,874	$ 16,312
Pension plan liability adjustments, net of taxes	5	1
Unrealized gains/(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 (LOSS), NET OF TAXES	4	0
TOTAL SHAREHOLDER’S EQUITY (See Statement of Shareholder’s Equity)	$ 16,878	$ 16,312

Consolidated Statement of Cap_4

Consolidated Statement of Capitalization - Long-Term Debt - CECONY - USD ($) $ in Millions		Dec. 31, 2022	Dec. 31, 2021
Interest Rate		4.94%
Long-term debt		$ 23,441	$ 23,044
Unamortized debt expense		(172)	(177)
Unamortized debt discount		(51)	(49)
LONG-TERM DEBT		22,439	22,604
TOTAL CAPITALIZATION		40,834	42,641
CECONY
Unamortized debt expense		(145)	(145)
Unamortized debt discount		(50)	(48)
LONG-TERM DEBT		19,080	18,382
TOTAL CAPITALIZATION		35,958	34,694
Debentures
Long-term debt		20,550	19,750
Debentures | CECONY
Long-term debt		18,825	18,125
Tax-Exempt Debt | CECONY
Long-term debt		$ 450	450
Debenture 2014B, 3.30 Percent, Due 2024 | Debentures
Interest Rate		3.30%
Long-term debt		$ 250	250
Debenture 2014B, 3.30 Percent, Due 2024 | Debentures | CECONY
Interest Rate		3.30%
Long-term debt		$ 250	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 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 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 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
Interest Rate		5.25%
Long-term debt		$ 125	125
Debenture Series 2005B, 5.25% Due 2035 | Debentures | CECONY
Interest Rate		5.25%
Long-term debt		$ 125	125
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	0
Debenture 2022A, 6.15%, Due 2052 | Debentures | CECONY
Interest Rate		6.15%
Long-term debt		$ 700	0
Debenture Series 2014C, 4.625% Due 2054 | Debentures
Interest Rate		4.63%
Long-term debt		$ 750	750
Debenture Series 2014C, 4.625% Due 2054 | Debentures | CECONY
Interest Rate		4.625%
Long-term debt		$ 750	750
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 2036 | Tax-Exempt Debt
Interest Rate	[1]	3.61%
Tax Exempt Debt Series 2010A Due 2036 | Tax-Exempt Debt | CECONY
Interest Rate	[2]	3.61%
Long-term debt	[2]	$ 225	225
Tax Exempt Debt Series 2004C, 1.663% Due 2039 | Tax-Exempt Debt
Interest Rate	[1]	3.68%
Tax Exempt Debt Series 2004C, 1.663% Due 2039 | Tax-Exempt Debt | CECONY
Interest Rate	[2]	3.68%
Long-term debt	[2]	$ 99	99
Tax-Exempt Debt Series 2005A, 1.627% Due 2039 | Tax-Exempt Debt
Interest Rate	[1]	3.63%
Tax-Exempt Debt Series 2005A, 1.627% Due 2039 | Tax-Exempt Debt | CECONY
Interest Rate	[2]	3.63%
Long-term debt	[2]	$ 126	$ 126
[1]Rates reset weekly; December 31, 2022 rates shown.[2]Rates reset weekly; December 31, 2022 rates shown.

General

General	12 Months Ended
	Dec. 31, 2022
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, which 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 Clean Energy Businesses, Inc. (together with its subsidiaries, the Clean Energy Businesses) and Con Edison Transmission, Inc. (together with its subsidiaries, Con Edison Transmission) in Con Edison’s consolidated financial statements. The term “Utilities” is used in these notes to refer to CECONY and O&R. As used in these notes, the term “Companies” refers to Con Edison and CECONY and, except as otherwise noted, the information in these combined notes relates to each of the Companies. However, CECONY makes no representation as to information relating to Con Edison or the subsidiaries of Con Edison other than itself. Con Edison has two regulated utility subsidiaries: CECONY and O&R. CECONY provides electric service and gas service in New York City and Westchester County. The company also provides steam service in parts of Manhattan. O&R, along with its regulated utility subsidiary, provides electric service in southeastern New York, "NY" and northern New Jersey, "NJ" and gas service in southeastern NY. The Clean Energy Businesses, through its subsidiaries, develops, owns and operates renewable and sustainable energy infrastructure projects and provides energy-related products and services to wholesale and retail customers. In October 2022, Con Edison entered into a purchase and sale agreement pursuant to which Con Edison agreed to sell the Clean Energy Businesses to RWE Renewables America, LLC, a subsidiary of RWE Aktiengesellschaft. The Clean Energy Businesses were classified as held for sale as of December 31, 2022. See “Assets and Liabilities Held for Sale” in Note A and Note X. Con Edison Transmission invests in and seeks to develop electric transmission projects through its subsidiary, Consolidated Edison Transmission, LLC (CET), and manages, through joint ventures, investments in gas pipeline and storage facilities through its subsidiary Con Edison Gas Pipeline and Storage, LLC (CET). See "Investments" in Note A and Note W.

Summary of Significant Accounti

Summary of Significant Accounting Policies and Other Matters	12 Months Ended
	Dec. 31, 2022
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, 2022 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 NY 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) 2022 2021 2020 Con Edison $400 $358 $323 CECONY 387 346 312 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 5.2 percent, 4.5 percent and 5.2 percent for 2022, 2021 and 2020, respectively. The AFUDC rates for O&R were 5.0 percent, 4.8 percent and 5.3 percent for 2022, 2021 and 2020, 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 3.5 percent for 2022 and 3.5 percent for 2021 and 3.5 percent for 2020. The average depreciation rates for O&R were 3.0 percent for 2022, 3.1 percent for 2021 and 3.2 percent for 2020. The estimated lives for utility plant for CECONY range from 5 to 80 years for electric, 5 to 90 years for gas, 5 to 80 years for steam and 5 to 55 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. At December 31, 2022 and 2021, the capitalized cost of the Companies’ utility plant, net of accumulated depreciation, was as follows: Con Edison CECONY (Millions of Dollars) 2022 2021 2022 2021 Electric Generation $534 $559 $534 $559 Transmission 4,223 3,955 3,916 3,658 Distribution 23,345 22,418 22,130 21,240 General 113 87 113 87 Gas (a) 11,326 10,473 10,567 9,748 Steam 1,962 1,924 1,962 1,924 General 2,648 2,566 2,410 2,338 Held for future use 117 80 109 72 Construction work in progress 2,484 2,152 2,268 1,985 Net Utility Plant $46,752 $44,214 $44,009 $41,611 (a) Primarily distribution. General utility plant of Con Edison and CECONY included $72 million and $69 million, respectively, at December 31, 2022, and $79 million and $74 million, respectively, at December 31, 2021, 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 $31 million and $29 million, respectively, at December 31, 2022 and $24 million at December 31, 2021. Under the Utilities’ rate plans, the aggregate annual depreciation allowance for the period ended December 31, 2022 was $1,907 million, including $1,808 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. For Con Edison, non-utility plant consists 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, respectively. The Clean Energy Businesses were classified as held for sale as of December 31, 2022, and depreciation on their assets was not recorded for the three months ended December 31, 2022. See "Assets and Liabilities Held for Sale" below, and Note X. 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) 2022 2021 2022 2021 Prepayments (a)(b) $24 $16 $23 $15 Other Deferred Charges and Noncurrent Assets (a)(b) 105 81 103 78 (a) Depreciation on these assets is computed using the straight-line method for financial statement purposes over their estimated useful lives. (b) Depreciation expense related to these assets incurred during the year ended December 31, 2022 for Con Edison and CECONY was $15 million and $14 million, respectively, and for the year ended December 31, 2021 for Con Edison and CECONY was $12 million and $11 million , respectively. Accumulated depreciation related to these assets for Con Edison and CECONY was $37 million and $33 million, respectively at December 31, 2022 and was $22 million and $19 million, respectively at December 31, 2021. 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. Con Edison's intangible assets with definite lives consist primarily of power purchase agreements, which were identified as part of purchase price allocations associated with acquisitions made by the Clean Energy Businesses in 2016 and 2018. At December 31, 2022 and 2021, intangible assets arising from power purchase agreements were $1,219 million and $1,290 million, net of accumulated amortization of $359 million and $288 million, respectively, and were being amortized over the life of each agreement. The Clean Energy Businesses were classified as held for sale as of December 31, 2022, and amortization on their assets was not recorded for the three months ended December 31, 2022. See "Assets and Liabilities Held for Sale" below, and Note X. Excluding power purchase agreements, Con Edison’s other intangible assets were $2 million, net of accumulated amortization of $9 million at December 31, 2022 and 2021. CECONY’s other intangible assets were immaterial at December 31, 2022 and 2021. Con Edison recorded amortization expense related to its intangible assets of $71 million in 2022, $95 million in 2021, and $102 million in 2020. Con Edison expects amortization expense to be immaterial over each of the next five years. No impairment charges were recorded on Con Edison's long-lived assets or intangible assets with definite lives in 2022 or 2021. 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 market 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. 2021 Partial Impairment of Investment in Stagecoach Gas Services LLC (Stagecoach) In May 2021, a subsidiary of Con Edison Gas Pipeline and Storage, LLC (CET) entered into a purchase and sale agreement pursuant to which the subsidiary and its joint venture partner agreed to sell their combined interests in Stagecoach Gas Services LLC (Stagecoach) for a total of $1,225 million, of which $629 million was attributed to CET for its 50 percent interest. The purchase and sale agreement contemplated a two-stage closing, the first of which was completed in July 2021 and the second of which was completed in November 2021. As a result of information made available to Stagecoach as part of the sale process, Stagecoach performed impairment tests that resulted in Stagecoach recording impairment charges of $414 million for the year ended December 31, 2021. Accordingly, Con Edison recorded pre-tax impairment losses on its 50 percent interest in Stagecoach of $212 million ($147 million after-tax), including working capital and transaction cost adjustments, within "Investment income/(loss)" on Con Edison's consolidated income statement for the year ended December 31, 2021. Stagecoach’s impairment charges and information obtained from the sales process constituted triggering events for Con Edison's investment in Stagecoach as of March 31, 2021 and June 30, 2021. Con Edison evaluated the carrying value of its investment in Stagecoach for other-than-temporary declines in value using income and market-based approaches. Con Edison determined that the carrying value of its investment in Stagecoach of $667 million and $630 million as of March 31, 2021 and June 30, 2021, respectively, was not impaired. The carrying value of $630 million at June 30, 2021 reflected the final sales price received in July and the remaining amount received in November 2021, including closing adjustments. CET had no remaining investment in Stagecoach as of December 31, 2021 and 2022. 2020 and 2021 Partial Impairments of Investment in Mountain Valley Pipeline, LLC (MVP) In January 2016, Con Edison Gas Pipeline and Storage, LLC (CET), an indirect subsidiary of Con Edison, acquired a 12.5 percent equity interest in MVP, a company developing a proposed 300-mile gas transmission project (the Project) in WV and VA. During 2019, Con Edison exercised its right to limit, and did limit, its cash contributions to the joint venture to approximately $530 million, which reduced CET's interest in MVP to 11.3 percent and 10.2 percent as of December 31, 2020 and 2021, respectively. As of December 31, 2022 CET's interest in MVP is 9.6 percent and is expected to be reduced to 8.0 percent based on the Project's current cost estimate and CET's previous capping of its cash contributions. As of December 31, 2021 and 2022, the Project was approximately 94 percent complete. During 2020, progress was made on the construction of the Project, and the U.S. Supreme Court issued favorable decisions in cases unrelated to MVP regarding the permitting process for pipeline construction and water crossings. In November 2020, the U.S. Court of Appeals for the Fourth Circuit issued a stay on the Nationwide Permit 12, effectively blocking the Project’s ability to pursue water crossings under that permit. As a result, in November 2020 the Project applied to the FERC for a certificate amendment to bore under water bodies in a portion of the Project in WV, allowing this portion of the pipe to be completed and placed in-service while a plan for the remaining water crossings was pursued. If approved, this certificate amendment would have led to additional Project costs and would have extended the anticipated in-service date. In January 2021, the FERC did not approve the requested certificate amendment. Later in January 2021, the Project indicated its plans to apply for U.S. Army Corps of Engineers individual permits for certain water crossings and a new certificate amendment application to the FERC to bore under other water crossings that, in total, would cover the entire Project length. The uncertainty related to obtaining necessary water crossing permits, the resulting Project costs and the likelihood of the Project not reaching eventual completion increased as a result of actions taken by the U.S. Court of Appeals for the Fourth Circuit. This action and associated delays constituted a triggering event (the "2020 triggering event") that required Con Edison to test its investment in MVP for an other-than-temporary impairment as of December 31, 2020. In December 2021, the VA Department of Environmental Quality and the WV Department of Environmental Protection both issued water quality certification permits which are required in order for the U.S. Army Corps of Engineers to proceed with the permitting process for construction of certain Project water crossings. In January 2022, the U.S. Court of Appeals for the Fourth Circuit rejected permits for crossings through the Jefferson National Forest issued by the U.S. Forest Service and Bureau of Land Management. In February 2022, the U.S. Court of Appeals for the Fourth Circuit vacated a biological opinion from the U.S. Fish and Wildlife Service, applicable to all remaining construction. The biological opinion had been issued and was the subject of litigation prior to December 31, 2021. Con Edison believed that the February 2022 action by the U.S. Court of Appeals for the Fourth Circuit, along with the potential outcome of other matters pending before that Court, may lead to further delays and increased Project costs, which constituted a triggering event (the “2021 triggering event”) that required Con Edison to test its investment in MVP for an other-than-temporary impairment as of December 31, 2021. In response to the 2020 triggering event and 2021 triggering event, Con Edison assessed the value of its equity investment in the Project to determine whether the fair value of its investment in MVP had declined below its carrying value on an other-than-temporary basis as of December 31, 2020 and 2021, respectively. The estimated fair value of the investment was determined using a discounted cash flow analysis, which is a level 3 fair value measurement. The analysis discounted probability-weighted future cash flows, including revenues based on long-term firm transportation contracts, that are secured for the first 20 years following completion of the Project. See Note U. Con Edison has also assumed cash flows extending beyond this period. All cash flows were discounted at a pre-tax discount rate of 8.3 percent and then weighted based on Con Edison’s estimate of the likelihood that the Project will be completed. For the 2020 triggering event, Con Edison estimated that the likelihood of Project completion was in the upper end of a reasonably possible range. For the 2021 triggering event, Con Edison anticipated that the Project faces legal and regulatory challenges that make construction completion increasingly remote. The Project faces additional delays and increased costs that could further reduce CET's interest in MVP to below 8 percent based on CET's previous capping of its cash contributions. The likelihood that the Project will be completed and, for 2020, the discount rate, are the most significant and sensitive assumptions; changes in these assumptions may materially change the results of the impairment calculation. Based on the discounted cash flow analyses, Con Edison concluded as of December 31, 2020 and 2021 that the fair value of its investment in MVP declined below its carrying value and the declines were other-than-temporary. Accordingly, Con Edison recorded a pre-tax impairment loss of $320 million ($223 million, after tax) for the year ended December 31, 2020 that reduced the carrying value of its investment in MVP from $662 million to $342 million, with an associated deferred tax asset of $53 million. Additionally, Con Edison recorded a pre-tax impairment loss of $231 million ($162 million, after tax) for the year ended December 31, 2021 that reduced the carrying value of its investment in MVP from $342 million to $111 million, with an additional $77 million associated deferred tax asset, totaling a deferred tax asset of $130 million at December 31, 2021 and 2022. The impairments were recorded within “Investment income (loss)” on Con Edison’s Consolidated Income Statement. In addition, Con Edison did not record non-cash equity in earnings from allowance for funds used during construction from MVP beginning in January 2021 and will continue to refrain from recording such amounts until such time as substantial construction activities resume, which would be indicative of probable Project completion. There were no impairments or substantial changes in the carrying value of Con Edison's investment in MVP for the year ended December 31, 2022. There is risk that the fair value of Con Edison’s investment in MVP may be further or fully impaired in the future. There are ongoing legal and regulatory matters that must be resolved favorably before the Project can be completed. Assumptions and estimates used to test Con Edison’s investment in MVP for impairment may change if adverse or delayed resolutions to the Project’s pending legal and regulatory challenges were to occur, which could have a material adverse effect on the fair value of Con Edison’s investment in MVP. Summary of Investment Balances The following investment assets are included in the Companies' consolidated balance sheets at December 31, 2022 and 2021: Con Edison CECONY (Millions of Dollars) 2022 2021 2022 2021 CET investment in Mountain Valley Pipeline, LLC (a) $111 $111 $— $— Supplemental retirement income plan assets (b) 459 525 439 499 Deferred income plan assets 93 102 93 102 CET investment in New York Transco, LLC (c) 176 112 — — Other 2 3 7 7 Total investments $841 $853 $539 $608 (a) At December 31, 2022 and 2021, CET's cash investment in MVP was $530 million. In May 2021, the operator of the Mountain Valley Pipeline indicated that, subject to receipt of certain authorizations and resolution of certain challenges, it is targeting an in-service date for the project of the second half of 2023 at an overall project cost of approximately $6,600 million excluding allowance for funds used during construction. See "2020 and 2021 Partial Impairments of Investment in Mountain Valley Pipeline, LLC (MVP)" above. (b) See Note E. (c) CET owns a 45.7 percent interest in New York Transco, LLC. 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. Research and Development Costs Research and development costs are charged to operating expenses as incurred. Research and development costs were as follows: For the Years Ended December 31, (Millions of Dollars) 2022 2021 2020 Con Edison $27 $25 $24 CECONY 25 24 23 Reclassification Certain prior period amounts have been reclassified within the Companies' Consolidated Statements of Cash Flows and Consolidated Balance Sheets to conform with current period presentation. Earnings Per Common 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 exercise price (see Note O) and its common shares that are subject to forward sale agreements (see Note C). Before the issuance of common shares upon settlement of the forward sale agreements, 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 agreements 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) 2022 2021 2020 Net income for common stock $1,660 $1,346 $1,101 Weighted average common shares outstanding – basic 354.5 348.4 334.8 Add: Incremental shares attributable to effect of potentially dilutive securities 1.3 1.0 0.9 Adjusted weighted average common shares outstanding – diluted 355.8 349.4 335.7 Net Income per common share – basic $4.68 $3.86 $3.29 Net Income per common share – diluted $4.66 $3.85 $3.28 The computation of diluted EPS for the years ended December 31, 2021 and 2020 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 mana

Regulatory Matters

Regulatory Matters	12 Months Ended
	Dec. 31, 2022
Regulated Operations [Abstract]
Regulatory Matters	Note B – Regulatory Matters Rate Plans The Utilities provide service to NY customers according to the terms of tariffs approved by the NYSPSC. Tariffs for service to customers of Rockland Electric Company (RECO), O&R’s NJ 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’ NY rate plans include: 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 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. 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. Other revenue adjustments 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. 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. 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”). 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). Current Rate Cases On February 16, 2023, CECONY, the New York State Department of Public Service (NYSDPS) and other parties entered into a Joint Proposal for CECONY electric and gas rate plans for the three-year period January 2023 through December 2025. The Joint Proposal is subject to NYSPSC approval. The Joint Proposal is summarized in the tables below. In November 2022, CECONY filed a request with the NYSPSC for an increase in the rates it charges for steam service rendered in New York, effective November 2023, of $137 million. The filing reflects a return on common equity of 10 percent and a common equity ratio of 50 percent. CECONY is requesting a new mechanism for decoupling revenues from steam consumption and the continuation of provisions with respect to recovery from customers of the cost of fuel and purchased steam and the reconciliation of actual expenses allocable to the steam business to the amounts for such expenses reflected in steam rates for pension and other postretirement benefits, environmental remediation expenses and uncollectible costs. In addition, the company is requesting full reconciliation for property taxes, municipal infrastructure support costs and long-term debt costs. The filing requests symmetrical reconciliation for labor and non-labor inflation rate to the extent that the actual inflation rate deviates from what is assumed in the revenue requirement by 50 basis points up or down. The filing includes supplemental information regarding steam rate plans for November 2024 through October 2025 and November 2025 through October 2026, which the company is not requesting but would consider through settlement discussions. For purposes of illustration, rate increases of $54 million and $49 million effective November 2024 and 2025, respectively, were calculated based upon an assumed return on common equity of 10 percent and a common equity ratio of 50 percent. In February 2023, CECONY updated its November 2022 request to the NYSPSC for a steam rate increase effective November 2023. The company increased its requested November 2023 rate increase by $4 million to $141 million, increased its illustrated November 2024 rate increase by $1 million to $55 million and increased its illustrated November 2025 rate increase by $4 million to $53 million. The following tables contain a summary of the Utilities’ rate plans: CECONY – Electric Effective period January 2020 – December 2022 (a) January 2023 – December 2025 (l) Base rate changes Yr. 1 – $113 million (b) Yr. 2 – $370 million (b) Yr. 3 – $326 million (b) Yr. 1 – $442 million (d) Yr. 2 – $518 million (d) Yr. 3 – $382 million (d) Amortizations to income of net regulatory (assets) and liabilities Yr. 1 – $267 million (c) Yr. 2 – $269 million (c) Yr. 3 – $272 million (c) Yr. 1 – $104 million (k) Yr. 2 – $49 million (k) Yr. 3 – $-205 million (k) 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 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. 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 Regulatory reconciliations Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (g). 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 (j) and expenses for uncollectibles, pension and other postretirement benefits, variable-rate debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (g). 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 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 (i) (j) Yr. 1 – 8.5 percent Yr. 2 – 8.03 percent Yr. 3 – 8.41 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. 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) In January 2020, the NYSPSC approved the October 2019 Joint Proposal for CECONY's electric rate plan for January 2020 through December 2022. If at the end of any semi-annual period ending June 30 and December 31, Con Edison’s investments in its non-utility businesses exceed 15 percent of its total consolidated revenues, assets or cash flow, or if the ratio of holding company debt to total consolidated debt rises above 20 percent, CECONY is required to notify the NYSPSC and submit a ring-fencing plan or a demonstration why additional ring-fencing measures (see Note U) are not necessary. (b) 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. (c) 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). (d) 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 will be effective as of January 1, 2023. CECONY will begin billing customers at the new levelized rate once the Joint Proposal is approved by the NYSPSC. Any shortfall in revenues due to the timing of billing to customers will be collected throu gh a surcharge billed through 2024, includin g 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. (e) 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: reflected in the January 2020 - December 2022 rate plan Yr 1 - 10.0 basis points; Yr 2 - 7.5 basis points; and Yr 3 - 5.0 basis points; reflected in the January 2023 - December 2025 Yr 1 - 10.0 basis points; Yr 2 - 5.0 basis points; and Yr 3 - 5.0 basis points, (f) 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. (g) In addition, the NYSPSC staff continues its focused operations audit to investigate CECONY's income tax accounting. Any NYSPSC ordered adjustment to CECONY’s income tax accounting is expected to be refunded to or collected from customers, as determined by the NYSPSC. See "Other Regulatory Matters," below. (h) Reconciliation of net utility plant for AMI will be done on a combined basis for electric and gas. (i) Calculated in accordance with the earnings calculation method prescribed in the rate order. (j) 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. (k) 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 ($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). (l) The February 2023 Joint Proposal is subject to NYSPSC approval. CECONY forecasts the need to construct a new project in Jamaica, Queens consisting of two substations and associated feeders at an estimated cost of $1,100 million (the Eastern Queens Reliability Project). Pursuant to the Joint Proposal, CECONY may petition the NYSPSC for approval to build and receive cost recovery for the Eastern Queens Reliability Project no sooner than 30 days after the NYSPSC adopts the Joint Proposal. CECONY – Gas Effective period January 2020 – December 2022 (a) January 2023 – December 2025 (l) Base rate changes Yr. 1 – $84 million (b) Yr. 2 – $122 million (b) Yr. 3 – $167 million (b) Yr. 1 – $217 million (d) Yr. 2 – $173 million (d) Yr. 3 – $122 million (d) Amortizations to income of net Yr. 1 – $45 million (c) Yr. 2 – $43 million (c) Yr. 3 – $10 million (c) Yr. 1 – $31 million (k) Yr. 2 – $24 million (k) Yr. 3 – $(11) million (k) 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 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. 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 Regulatory reconciliations Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (g). 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 (j) and expenses for uncollectibles, pension and other postretirement benefits, variable-rate debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (g). 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 (h): 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 (h): Yr. 1 - $234 million CSS: Yr. 1 - $2 million 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 (i) (j) Yr. 1 – 8.4 percent Yr. 2 – 8.48 percent Yr. 3 – 8.93 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. 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) In January 2020, the NYSPSC approved the October 2019 Joint Proposal for CECONY's gas rate plan for January 2020 through December 2022. If at the end of any semi-annual period ending June 30 and December 31, Con Edison’s investments in its non-utility businesses exceed 15 percent of its total consolidated revenues, assets or cash flow, or if the ratio of holding company debt to total consolidated debt rises above 20 percent, CECONY is required to notify the NYSPSC and submit a ring-fencing plan or a demonstration why additional ring-fencing measures (see Note U) are not necessary. (b) 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. (c) 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) (d) 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 will be effective as of January 1, 2023. CECONY will begin billing customers at the new levelized rate once the Joint Proposal is approved by the NYSPSC. Any shortfall in revenues due to the timing of billing to customers will be collected th rough 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. (e)-(i) See footnotes (e) - (i) to the table under “CECONY Electric,” above. (j) 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. (k) Amounts reflect amortization of the 2018 tax savings under the federal Tax Cuts and Jobs Act of 2017 (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). (l) The February 2023 Joint Proposal is subject to NYSPSC approval. CECONY – Steam Effective period January 2014 – December 2016 (a) Base rate changes Yr. 1 – $(22.4) million (b) Yr. 2 – $19.8 million (b) Yr. 3 – $20.3 million (b) Yr. 4 – None Yr. 5 – None Yr. 6 – None Yr. 7 – None Yr. 8 – None Amortizations to income of net $37 million over three years Recoverable energy costs Current rate recovery of purchased power and fuel costs. Negative revenue adjustments Potential charges (up to $1 million annually) if certain steam performance targets are not met. In years 2014 through 2022, the company did not record any negative revenue adjustments. Cost reconciliations (c)(d) In 2014, 2015, 2016, 2017, 2018, 2019, 2020, 2021 and 2022, 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 and $11 million of net regulatory assets, respectively. 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 million 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. Average rate base Yr. 1 – $1,511 million Yr. 2 – $1,547 million Yr. 3 – $1,604 million Weighted average cost of capital (after-tax) Yr. 1 – 7.10 percent Yr. 2 – 7.13 percent Yr. 3 – 7.21 percent Authorized return on common equity 9.3 percent Actual return on common equity (e) 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 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 and 2022, 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. Cost of long-term debt Yr. 1 – 5.17 percent Yr. 2 – 5.23 percent Yr. 3 – 5.39 percent Common equity ratio 48 percent (a) Rates determined pursuant to this rate plan continue in effect until a new rate plan is approved by the NYSPSC. (b) The impact of these base rate changes was deferred which resulted in an $8 million regulatory liability at December 31, 2016. (c) 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. (d) In addition, the NYSPSC staff has commenced a focused operations audit to investigate CECONY’s income tax accounting. Any NYSPSC ordered adjustment to CECONY’s income tax accounting is expected to be refunded to or collected from customers, as determined by the NYSPSC. CECONY’s historical inadvertent understatement of its calculation of total federal income tax expense for ratemaking purposes has not been addressed in the current steam rate plan. See "Other Regulatory Matters," below. (e) Calculated in accordance with the earnings calculation method prescribed in the rate order. O&R New York – Electric Effective period (a) January 2019 – December 2021 January 2022 – December 2024 Base rate changes Yr. 1 – $13.4 million (b) Yr. 2 – $8.0 million (b) Yr. 3 – $5.8 million (b) Yr. 1 – $4.9 million (i) Yr. 2 – $16.2 million (i) Yr. 3 – $23.1 million (i) Amortizations to income of net Yr. 1 – $(1.5) million (c) Yr. 2 – $(1.5) million (c) Yr. 3 – $(1.5) million (c) Yr. 1 – $11.8 million (j) Yr. 2 – $13.5 million (j) Yr. 3 – $15.2 million (j) Other revenue sources Potential earnings adjustment mechanism incentives for peak reduction, energy efficiency, Distributed Energy Resources utilization and other potential incentives of up to: Yr. 1 - $3.6 million Yr. 2 - $4.0 million Yr. 3 - $4.2 million Potential incentive if performance target related to customer service is met: $0.5 million annually. In 2019, 2020 and 2021, the company recorded $2.6 million, $1.9 million and $1.8 million of earnings adjustment mechanism incentives for energy efficiency, respectively. In 2019 and 2020, the company recorded $0.2 million and $0.5 million of incentives for customer service, respectively. In 2021, the company did not record incentives for customer service. In 2021, the company reversed the $0.5 million of incentives recorded in 2020 pursuant to the October 2021 Joint Proposal. 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 2019 and 2020, the company deferred $0.1 million and $6 million regulatory assets, respectively. In 2021, $10 million was deferred as regulatory liabilities. Continuation of reconciliation of actual to authorized electric delivery revenues. In 2022, the company deferred $6.9 million regulatory liabilities. Recoverable energy costs Continuation of current rate recovery of purchased power 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 a

Capitalization

Capitalization	12 Months Ended
	Dec. 31, 2022
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, 2022 and 2021, 354,962,058 and 353,983,712 shares, respectively, of Con Edison common stock were outstanding. At December 31, 2022 and 2021, 235,488,094 million shares of CECONY common stock were outstanding, all of which were owned by Con Edison. At December 31, 2022 and 2021, Con Edison had 23,210,700 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. CECONY presents in the financial statements the cost of the Con Edison stock it owns as a reduction of common shareholder’s equity. Capitalization of Con Edison 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 and the Clean Energy Businesses. 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 2023-2027 is as follows: (Millions of Dollars) Con Edison (a) CECONY 2023 $650 $— 2024 250 250 2025 — — 2026 250 250 2027 430 350 (a) Amounts shown exclude the debt of the Clean Energy Businesses, which were classified as held for sale as of December 31, 2022 and are shown under "Project Debt Held for Sale" on Con Edison's Consolidated Statement of Capitalization. See "Assets and Liabilities Held for Sale" in Note A and Note X for additional information. CECONY has issued $450 million of tax–exempt debt through the New York State Energy Research and Development Authority (NYSERDA) that currently bears interest at a rate determined weekly and is subject to tender by bondholders for purchase by the company. The carrying amounts and fair values of long-term debt at December 31, 2022 and 2021 are: (Millions of Dollars) 2022 2021 Long-Term Debt (including current portion) (a) Carrying Fair Carrying Amount Fair Value Con Edison $20,796 (b) $18,234 (b) $23,044 $26,287 CECONY 19,080 16,699 18,382 21,382 (a) Amounts shown are net of unamortized debt expense and unamortized debt discount of $202 million and $195 million for Con Edison and CECONY, respectively, as of December 31, 2022 and $226 million and $193 million for Con Edison and CECONY, respectively, as of December 31, 2021. (b) Amounts shown exclude the debt of the Clean Energy Businesses, which were classified as held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A, and Note X for additional information. The carrying value and fair value of the Clean Energy Businesses’ long-term debt, including the current portion, as of December 31, 2022 was $2,645 million and $2,489 million, respectively. The fair values of the Companies' long-term debt have been estimated primarily using available market information and at December 31, 2022 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, 2022 . 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 specified levels ($150 million or $100 million, depending on the facility).

Short-Term Borrowing

Short-Term Borrowing	12 Months Ended
	Dec. 31, 2022
Debt Disclosure [Abstract]
Short-Term Borrowing	Short-Term Borrowing In December 2016, Con Edison and the Utilities entered into a credit agreement (Credit Agreement), under which banks are committed to provide loans and letters of credit on a revolving credit basis. The Credit Agreement, as amended in 2019, expires in December 2023. There was a maximum of $2,250 million of credit available through December 2022 and $2,200 million of credit available from then through December 2023. The full amount is available to CECONY and $1,000 million (subject to increase up to $1,500 million) is available to Con Edison, including up to $1,200 million of letters of credit. The Credit Agreement supports the Companies’ commercial paper programs. The Companies have not borrowed under the Credit Agreement. In March 2022, CECONY entered into a 364-Day Revolving Credit Agreement (the CECONY Credit Agreement) under which banks are committed to provide loans up to $750 million on a revolving credit basis. The CECONY Credit Agreement expires on March 30, 2023 and supports CECONY’s commercial paper program. CECONY has not borrowed under the CECONY Credit Agreement. At December 31, 2022, Con Edison had $2,640 million of commercial paper outstanding, of which $2,300 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, 2022 was 4.8 percent for both Con Edison and CECONY. At December 31, 2021, Con Edison had $1,488 million of commercial paper outstanding of which $1,361 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, 2021 was 0.3 percent for both Con Edison and CECONY. At December 31, 2022 and 2021, no loans were outstanding under the Credit Agreement or the CECONY Credit Agreement. An immaterial amount of letters of credit were outstanding under the Credit Agreement as of December 31, 2022 and 2021. 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 under the Credit Agreement or the CECONY Credit Agreement, respectively, 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, 2022 this ratio was 0.54 to 1 for Con Edison and 0.56 to 1 for CECONY); that company having liens on its assets in an aggregate amount exceeding five percent of its consolidated total capital, 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, 2022. In June 2022 and January 2023, Con Edison borrowed $400 million and $200 million, respectively, at a variable rate under a 364-Day Senior Unsecured Term Loan Credit Agreement entered into by the company in June 2022, as amended in November 2022 (the June 2022 Term Loan Credit Agreement). The interest rate at December 31, 2022 was 4.94 percent. Upon a change of control of, or upon an event of default by Con Edison, the bank may declare the loans, accrued interest and any other amounts due by Con Edison immediately due and payable. Events of default include Con Edison exceeding at any time a ratio of consolidated debt to consolidated total capital of 0.65 to 1; Con Edison or its subsidiaries having liens on its or their assets in an aggregate amount exceeding 5.0 percent of Con Edison’s consolidated total capital, subject to certain exceptions; Con Edison or 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); 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) or enables the holders of such debt to accelerate the maturity thereof; and other customary events of default. Subject to certain exceptions, the term loans issued under the June 2022 Term Loan Credit Agreement are subject to mandatory termination and prepayment with the net cash proceeds of certain equity issuances or asset sales by Con Edison. The term loans mature in June 2023. In August 2022, the Clean Energy Businesses entered into and borrowed $150 million at a variable rate under a 364-Day Senior Unsecured Term Loan Credit Agreement, which is guaranteed by Con Edison (see Note H) and includes customary terms and conditions. The interest rate at December 31, 2022 was 5.06 percent. Upon a change of control of the Clean Energy Businesses, the bank may declare the loan, accrued interest and any other amounts due by the Clean Energy Businesses immediately due and payable if the bank does not consent to a guarantee from the successor company, which consent may not be unreasonably withheld. Upon an event of default of the Clean Energy Businesses, the bank may declare the loan, accrued interest and any other amounts due by the Clean Energy Businesses immediately due and payable. This loan is classified within liabilities held for sale on Con Edison's balance sheet as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X for additional information. See Note U for information about short-term borrowing between related parties.

Pension Benefits

Pension Benefits	12 Months Ended
	Dec. 31, 2022
Retirement Benefits [Abstract]
Pension Benefits	Pension Benefits Con Edison maintains a tax-qualified, non-contributory pension plan that covers substantially all employees of CECONY, O&R and Con Edison Transmission and certain employees of the Clean Energy Businesses. 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 The components of the Companies’ total periodic benefit costs for 2022, 2021 and 2020 were as follows: Con Edison CECONY (Millions of Dollars) 2022 2021 2020 2022 2021 2020 Service cost – including administrative expenses $287 $343 $293 $270 $321 $274 Interest cost on projected benefit obligation 505 471 549 475 443 515 Expected return on plan assets (1,168) (1,096) (1,034) (1,109) (1,040) (980) Recognition of net actuarial loss 377 787 699 358 746 661 Recognition of prior service credit (16) (17) (16) (21) (19) (19) TOTAL PERIODIC BENEFIT COST $(15) $488 $491 $(27) $451 $451 Cost capitalized (137) (154) (130) (129) (146) (123) Reconciliation to rate level 259 (226) (250) 245 (216) (239) Total expense recognized $107 $108 $111 $89 $89 $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 line “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, 2022, 2021 and 2020 was as follows: Con Edison CECONY (Millions of Dollars) 2022 2021 2020 2022 2021 2020 CHANGE IN PROJECTED BENEFIT OBLIGATION Projected benefit obligation at beginning of year $17,357 $18,965 $16,792 $16,341 $17,821 $15,750 Service cost – excluding administrative expenses 283 337 288 266 317 269 Interest cost on projected benefit obligation 505 471 549 475 443 515 Net actuarial loss/(gain) (5,102) (1,547) 2,281 (4,845) (1,441) 2,154 Benefits paid (930) (869) (945) (842) (799) (867) PROJECTED BENEFIT OBLIGATION AT END OF YEAR $12,113 $17,357 $18,965 $11,395 $16,341 $17,821 CHANGE IN PLAN ASSETS Fair value of plan assets at beginning of year $18,504 $17,022 $15,608 $17,566 $16,147 $14,790 Actual return on plan assets (2,583) 1,935 1,927 (2,453) 1,838 1,830 Employer contributions 30 469 475 17 432 435 Benefits paid (930) (869) (945) (842) (799) (867) Administrative expenses (42) (53) (43) (40) (52) (41) FAIR VALUE OF PLAN ASSETS AT END OF YEAR $14,979 $18,504 $17,022 $14,248 $17,566 $16,147 FUNDED STATUS $2,866 $1,147 $(1,943) $2,853 $1,225 $(1,674) Unrecognized net loss/(gain) $(1,485) $205 $3,330 $(1,397) $207 $3,145 Unrecognized prior service costs/(credits) (124) (140) (156) (143) (163) (183) Accumulated benefit obligation $11,167 $15,469 $16,768 $10,478 $14,504 $15,676 The increase in the pension funded status at December 31, 2022 for Con Edison and CECONY of $1,719 million and $1,628 million, respectively, compared with December 31, 2021, was primarily due to a decrease in the plan's projected benefit obligation as a result of an increase in the discount rate. The increase in the pension funded status liability at December 31, 2021 for Con Edison and CECONY of $3,090 million and $2,899 million, respectively, compared with December 31, 2020, was primarily due to a decrease in the plan's projected benefit obligation as a result of an increase in the discount rate and actuarial gains on plan assets exceeding the expected rate of return. See below for further information on the change in the discount rate and determination of the discount rate assumption. For Con Edison, the 2022 increase in pension funded status asset corresponds with a decrease to regulatory assets of $1,655 million for unrecognized net losses and unrecognized prior service costs associated with the Utilities consistent with the accounting rules for regulated operations, a credit to OCI of $15 million (net of taxes) for the unrecognized net losses, and an immaterial change to OCI (net of taxes) for the unrecognized prior service costs associated with certain employees of the Clean Energy Businesses, Con Edison Transmission, and RECO who previously worked for the Utilities. For 2022, included within the funded status are noncurrent liabilities of $311 million and $287 million for Con Edison and CECONY, respectively. For 2021, included within the funded status are noncurrent liabilities of $459 million and $381 million for Con Edison and CECONY, respectively. For CECONY, the increase in pension funded status asset at December 31, 2022 corresponds with a decrease to regulatory assets of $1,579 million for unrecognized net losses and unrecognized prior service costs consistent with the accounting rules for regulated operations, and also a credit to OCI of $3 million (net of taxes) for unrecognized net losses, and an immaterial change to OCI (net of taxes) for the unrecognized prior service costs associated with certain employees of the Clean Energy Businesses and Con Edison Transmission who previously worked for CECONY. At December 31, 2022 and 2021, Con Edison’s investments included $459 million and $525 million, respectively, held in external trust accounts for benefit payments pursuant to the supplemental retirement plans. Included in these amounts for CECONY were $439 million and $499 million, respectively. See Note R. The accumulated benefit obligations for the supplemental retirement plans for Con Edison and CECONY were $306 million and $280 million as of December 31, 2022, respectively, and $386 million and $352 million as of December 31, 2021, respectively. Assumptions The actuarial assumptions were as follows: 2022 2021 2020 Weighted-average assumptions used to determine benefit obligations at December 31: Discount rate 5.45 % 3.00 % 2.55 % Interest crediting rate for cash balance plan 4.00 % 3.50 % 3.00 % 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 3.00 % 2.55 % 3.35 % Interest crediting rate for cash balance plan 3.50 % 3.00 % 3.30 % Expected return on plan assets 7.00 % 7.00 % 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) 2023 2024 2025 2026 2027 2028-2032 Con Edison $748 $759 $809 $780 $792 $4,095 CECONY 692 703 754 725 738 3,824 Expected Contributions Based on estimates as of December 31, 2022, the Companies expect to make contributions to the pension plans during 2023 of $10 million (of which $8 million 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 2022, 2021 and 2020, and the target allocation for 2023 are as follows: Target Allocation Range Plan Assets at December 31, Asset Category 2023 2022 2021 2020 Equity Securities 28% - 38% 33 % 50 % 51 % Debt Securities 42% - 60% 50 % 38 % 38 % Real Estate and Other Alternatives 12% - 22% 17 % 12 % 11 % 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 2023 reflects the results of such a study conducted in 2022. Individual fund managers operate under written guidelines provided by Con Edison, which 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. 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, 2022 by asset category are as follows: (Millions of Dollars) Level 1 Level 2 Total Investments within the fair value hierarchy U.S. Equity (a) $2,150 $3 $2,153 International Equity (b) 1,534 — 1,534 U.S. Government Issued Debt (c) — 823 823 Corporate Bonds Debt (d) — 4,961 4,961 Structured Assets Debt (e) — 183 183 Other Fixed Income Debt (f) — 1,088 1,088 Cash and Cash Equivalents (g) 71 274 345 Futures (h) (1) — (1) Total investments within the fair value hierarchy $3,754 $7,332 $11,086 Investments measured at NAV per share (n) Private Equity (i) 1,018 Real Estate (j) 2,366 Hedge Funds (k) 657 Total investments valued using NAV per share $4,041 Funds for retiree health benefits (l) (48) (91) (139) Funds for retiree health benefits measured at NAV per share (l)(n) (51) Total funds for retiree health benefits $(190) Investments (excluding funds for retiree health benefits) $3,706 $7,241 $14,937 Pending activities (m) 42 Total fair value of plan net assets $14,979 (a) U.S. Equity includes both actively- and passively-managed assets with investments in domestic equity index funds and actively-managed small-capitalization equities. (b) International Equity includes international equity index funds and actively-managed international equities. (c) U.S. Government Issued Debt includes agency and treasury securities. (d) Corporate Bonds Debt consists of debt issued by various corporations. (e) Structured Assets Debt includes commercial-mortgage-backed securities and collateralized mortgage obligations. (f) Other Fixed Income Debt includes municipal bonds, sovereign debt and regional governments. (g) Cash and Cash Equivalents include short term investments, money markets, foreign currency and cash collateral. (h) Futures consist of exchange-traded financial contracts encompassing U.S. Equity, International Equity and U.S. Government indices. (i) Private Equity consists 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 $260 million at December 31, 2022. However, the managers also expect to make significant cash flow distributions in 2023 and 2024. 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 (j) Real Estate investments include 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. (k) Hedge Funds are structured as a custom fund of one and that strategy can invest in external hedge fund managers that can pursue a wide array of strategies including event driven, fundamental long/short, relative value, directional trading, and direct sourcing. This asset class seeks to generate positive absolute returns with lower volatility than other asset classes. It invests in various hedge fund managers who can invest in all financial instruments. If desired, substantially all of the investment could be liquidated within 18 months. (l) 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. (m) 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. (n) 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, 2021 by asset category are as follows: (Millions of Dollars) Level 1 Level 2 Total Investments within the fair value hierarchy U.S. Equity (a) $4,381 $— $4,381 International Equity (b) 3,536 — 3,536 U.S. Government Issued Debt (c) — 1,500 1,500 Corporate Bonds Debt (d) — 3,936 3,936 Structured Assets Debt (e) — 262 262 Other Fixed Income Debt (f) — 1,186 1,186 Cash and Cash Equivalents (g) 80 425 505 Futures (h) 2 — 2 Total investments within the fair value hierarchy $7,999 $7,309 $15,308 Investments measured at NAV per share (n) Private Equity (i) 913 Real Estate (j) 2,306 Hedge Funds (k) 315 Total investments valued using NAV per share $3,534 Funds for retiree health benefits (l) (110) (100) (210) Funds for retiree health benefits measured at NAV per share (l)(n) (48) Total funds for retiree health benefits $(258) Investments (excluding funds for retiree health benefits) $7,889 $7,209 $18,584 Pending activities (m) (80) Total fair value of plan net assets $18,504 (a) - (n) Reference is made to footnotes (a) through (n) in the above table of pension plan assets at December 31, 2022 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) 2022 2021 2020 Con Edison $57 $55 $52 CECONY 48 46 43

Other Postretirement Benefits

Other Postretirement Benefits	12 Months Ended
	Dec. 31, 2022
Retirement Benefits [Abstract]
Other Postretirement Benefits	Other Postretirement Benefits The Utilities and Con Edison Transmission currently have contributory comprehensive hospital, medical and prescription drug programs for eligible retirees, their dependents and surviving spouses. CECONY also has a contributory life insurance program for bargaining unit employees and provides basic life insurance benefits up to a specified maximum at no cost to certain retired management employees. O&R has a non-contributory life insurance program for retirees. Certain employees of the Clean Energy Businesses and Con Edison Transmission are eligible to receive benefits under these programs. Total Periodic Benefit Cost The components of the Companies’ total periodic postretirement benefit costs for 2022, 2021 and 2020 were as follows: Con Edison CECONY (Millions of Dollars) 2022 2021 2020 2022 2021 2020 Service cost $18 $22 $21 $15 $16 $16 Interest cost on accumulated other postretirement benefit obligation 35 33 37 30 28 31 Expected return on plan assets (72) (68) (66) (58) (56) (54) Recognition of net actuarial loss/(gain) (14) 31 37 (9) 27 36 Recognition of prior service credit (1) (3) (3) — (1) (2) TOTAL PERIODIC POSTRETIREMENT BENEFIT COST/(CREDIT) $(34) $15 $26 $(22) $14 $27 Cost capitalized (8) (9) (9) (7) (7) (7) Reconciliation to rate level 29 (7) (17) 24 (12) (25) Total credit recognized $(13) ($1) $— $(5) $(5) $(5) For information about the presentation of the components of net periodic benefit cost and disclosure requirements, see Note E. Funded Status The funded status of the programs at December 31, 2022, 2021 and 2020 were as follows: Con Edison CECONY (Millions of Dollars) 2022 2021 2020 2022 2021 2020 CHANGE IN BENEFIT OBLIGATION Benefit obligation at beginning of year $1,398 $1,425 $1,357 $1,189 $1,209 $1,154 Service cost 18 22 21 15 16 16 Interest cost on accumulated postretirement benefit obligation 35 33 37 30 28 31 Net actuarial loss/(gain) (311) (13) 74 (239) (3) 63 Benefits paid and administrative expenses, net of subsidies (130) (117) (117) (121) (107) (107) Participant contributions 48 48 53 47 46 52 BENEFIT OBLIGATION AT END OF YEAR $1,058 $1,398 $1,425 $921 $1,189 $1,209 CHANGE IN PLAN ASSETS Fair value of plan assets at beginning of year $1,150 $1,115 $1,026 $955 $940 $872 Actual return on plan assets (225) 92 142 (187) 67 117 Employer contributions 13 6 7 10 3 4 Employer group waiver plan subsidies 55 21 20 50 19 19 Participant contributions 48 48 53 47 46 51 Benefits paid (181) (132) (133) (167) (120) (123) FAIR VALUE OF PLAN ASSETS AT END OF YEAR $860 $1,150 $1,115 $708 $955 $940 FUNDED STATUS $(198) $(248) $(310) $(213) $(234) $(269) Unrecognized net loss/(gain) $37 $41 $115 $78 $67 $114 Unrecognized prior service costs (12) (13) (16) — — (1) The decrease in the other postretirement benefits funded status liability at December 31, 2022 for Con Edison and CECONY of $50 million and $21 million, respectively, compared with December 31, 2021, was primarily due to a decrease in the plans' projected benefit obligation as a result of an increase in the discount rate, which more than offset the decrease in the fair value of plan assets as a result of the actual return on plan assets. See below for further information on the change in the discount rate and see Note E for determination of the discount rate assumption. The decrease in the other postretirement benefits funded status liability at December 31, 2021 for Con Edison and CECONY of $62 million and $35 million, respectively, compared with December 31, 2020, was primarily due to an increase in the fair value of plan assets as a result of the actual return on plan assets, along with a decrease in the plans' projected benefit obligation as a result of an increase in the discount rate. For 2022, included within the funded status are noncurrent assets of $72 million and $27 million for Con Edison and CECONY, respectively. For 2021, included within the funded status are noncurrent assets of $79 million and $55 million for Con Edison and CECONY, respectively. For Con Edison, the decrease in funded status liability at December 31, 2022 corresponds with a net decrease to regulatory assets of $2 million for unrecognized net losses and unrecognized prior service costs associated with the Utilities consistent with the accounting rules for regulated operations, a credit to OCI of $2 million (net of taxes) for the unrecognized net losses and an immaterial change to OCI for the unrecognized prior service costs associated with the Clean Energy Businesses, Con Edison Transmission, and RECO. For CECONY, the decrease in funded status liability at December 31, 2022 corresponds with an increase to regulatory assets of $11 million for unrecognized net losses and the unrecognized prior service costs associated with the company consistent with the accounting rules for regulated operations, a credit to OCI of $1 million (net of taxes) for the unrecognized net losses and an immaterial change to OCI for the unrecognized prior service costs associated with eligible employees of the Clean Energy Businesses and Con Edison Transmission who previously worked for CECONY. Assumptions The actuarial assumptions were as follows: 2022 2021 2020 Weighted-average assumptions used to determine benefit obligations at December 31: Discount Rate CECONY 5.35 % 2.75 % 2.25 % O&R 5.45 % 3.00 % 2.55 % Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31: Discount Rate CECONY 2.75 % 2.25 % 3.10 % O&R 3.00 % 2.55 % 3.35 % Expected Return on Plan Assets 6.80 % 6.80 % 6.80 % Refer to Note E for descriptions of the basis for determining the expected return on assets, investment policies and strategies and the assumed discount rate. The health care cost trend rates for covered medical and prescription medication expenses used to determine the accumulated other postretirement benefit obligations (APBO) at December 31, 2022 were assumed to increase each year, with the initial rate gradually decreasing to the ultimate rate as follows: Initial Cost Trend Rate Ultimate Cost Trend Rate Year That Ultimate Rate is Reached Pre-65 Medical 7.00% 4.50% 2036 Post-65 Medical 4.50% 4.50% — Prescription Medications 7.50% 4.50% 2035 Expected Benefit Payments 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) 2023 2024 2025 2026 2027 2028-2032 Con Edison $79 $80 $85 $86 $87 $430 CECONY 71 71 76 77 78 384 Expected Contributions Based on estimates as of December 31, 2022, Con Edison expects to make a contribution of $1 million (all of which is expected to be made by CECONY) to the other postretirement benefit plans in 2023. The Companies’ policy is to fund the total periodic benefit cost of the plans to the extent tax deductible. Plan Assets The asset allocations for CECONY’s other postretirement benefit plans at the end of 2022, 2021 and 2020, and the target allocation for 2023 are as follows: Target Allocation Range Plan Assets at December 31, Asset Category 2023 2022 2021 2020 Equity Securities 42%-80% 49 % 55 % 54 % Debt Securities 20%-58% 51 % 45 % 46 % Total 100% 100 % 100 % 100 % Con Edison has established postretirement health and life insurance benefit plan trusts for the investment of assets to be used for the exclusive purpose of providing other postretirement benefits to participants and beneficiaries. Refer to Note E for a discussion of Con Edison’s investment policy for its benefit plans. The fair values of the plans' assets at December 31, 2022 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) $— $339 $339 Other Fixed Income Debt (b) 10 275 285 Cash and Cash Equivalents (c) — 25 25 Total investments $10 $639 $649 Funds for retiree health benefits (d) 48 91 139 Investments (including funds for retiree health benefits) $58 $730 $788 Funds for retiree health benefits measured at net asset value (d)(e) 51 Pending activities (f) 21 Total fair value of plan net assets $860 (a) Equity includes a passively managed commingled index fund benchmarked to the MSCI All Country World Index. (b) Other Fixed Income Debt includes a passively managed commingled index fund benchmarked to the Bloomberg Barclays U.S. Long Credit Index and an active separately managed fund indexed to the Bloomberg Barclays U.S. Long Credit Index. (c) Cash and Cash Equivalents include short-term investments and money markets. (d) 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. (e) 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. (f) 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, 2021 by asset category (see Note R) are as follows: (Millions of Dollars) Level 1 Level 2 Total Equity (a) $— $474 $474 Other Fixed Income Debt (b) — 379 379 Cash and Cash Equivalents (c) — 22 22 Total investments $— $875 $875 Funds for retiree health benefits (d) 110 100 210 Investments (including funds for retiree health benefits) $110 $975 $1,085 Funds for retiree health benefits measured at net asset value (d)(e) 48 Pending activities (f) 17 Total fair value of plan net assets $1,150

Environmental Matters

Environmental Matters	12 Months Ended
	Dec. 31, 2022
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, 2022 and 2021 were as follows: Con Edison CECONY (Millions of Dollars) 2022 2021 2022 2021 Accrued Liabilities: Manufactured gas plant sites $876 $845 $782 $755 Other Superfund Sites 121 95 121 95 Total $997 $940 $903 $850 Regulatory assets $991 $938 $906 $860 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 material. The Utilities are permitted to recover or defer as regulatory assets (for subsequent recovery through rates) prudently incurred site investigation and remediation costs. Environmental remediation costs incurred related to Superfund Sites at December 31, 2022 and 2021 were as follows: Con Edison CECONY (Millions of Dollars) 2022 2021 2022 2021 Remediation costs incurred $21 $25 $20 $24 Insurance and other third party recoveries received by Con Edison or CECONY were immaterial in 2022 and 2021. Con Edison and CECONY estimate that in 2023 they will incur costs for remediation of approxi mately $63 million and $61 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 2022, 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 $3,140 million and $2,990 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 NY 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, which 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, 2022, Con Edison and CECONY have accrued their estimated aggregate undiscounted potential liabilities for these suits and additional suits that may be brought over the next 15 years as shown in the following table. These estimates were based upon a combination of modeling, historical data analysis and risk factor assessment. Courts have begun, and unless otherwise determined on appeal 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, 2022 and 2021 were as follows: Con Edison CECONY (Millions of Dollars) 2022 2021 2022 2021 Accrued liability – asbestos suits $8 $8 $7 $7 Regulatory assets – asbestos suits 8 8 7 7 Accrued liability – workers’ compensation 61 65 59 62 Regulatory liabilities – workers’ compensation 11 8 11 8

Material Contingencies

Material Contingencies	12 Months Ended
	Dec. 31, 2022
Commitments and Contingencies Disclosure [Abstract]
Material Contingencies	10 years Total (Millions of Dollars) Con Edison Transmission $407 $— $— $407 Energy transactions (a) 489 22 294 805 Renewable electric projects (a) 354 69 555 978 Other (a) 222 — — 222 Total $1,472 $91 $849 $2,412 (a) These represent guarantees of subsidiaries of the Clean Energy Businesses. The Clean Energy Businesses were classified as held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A, and Note X. Con Edison Transmission – Con Edison has guaranteed payment by CET of the contributions CET agreed to make to New York Transco LLC (NY Transco). CET owns a 45.7 percent interest in NY Transco. In April 2019, the New York Independent System Operator (NYISO) selected a transmission project that was jointly proposed by National Grid and NY Transco. The siting, construction and operation of the project will require approvals and permits from appropriate governmental agencies and authorities, including the NYSPSC. The NYISO indicated it will work with the developers to enter into agreements for the development and operation of the projects, including a schedule for entry into service by December 2023. Guarantee amount shown includes the maximum possible required amount of CET’s contributions for this project as calculated based on the assumptions that the project is completed at 175 percent of its estimated costs and NY Transco does not use any debt financing for the project. Energy Transactions — Con Edison and the Clean Energy Businesses guarantee payments on behalf of their subsidiaries in order to facilitate physical and financial transactions in electricity, gas, pipeline capacity, transportation, oil, renewable energy credits and energy services. To the extent that liabilities exist under the contracts subject to these guarantees, such liabilities are included in Con Edison’s consolidated balance sheet. Renewable Electric Projects – Con Edison and the Clean Energy Businesses guarantee payments on behalf of their wholly-owned subsidiaries associated with their investment in, or development for others of, solar and wind energy facilities." 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 the company, 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 the company 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, which caused it to sag and overstressed the defective fusion joint. The NTSB also made safety recommendations, including recommendations to the company 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 the company related to the NYSPSC's investigations of the incident and the practices of qualifying persons to perform plastic fusions. Pursuant to the agreement, the company is providing $27 million of future benefits to customers (for which it has accrued a regulatory liability) and will not recover from customers $126 million of costs for gas emergency response activities that it had previously incurred and expensed. Approximately eighty suits are pending against the company seeking generally unspecified damages and, in some cases, punitive damages, for wrongful death, personal injury, property damage and business interruption. The company notified its insurers of the incident and believes that the policies in force at the time of the incident will cover the company’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, the company accrued its estimated liability for the suits of $40 million and an insurance receivable in the same amount, which estimated liability did not change as of December 31, 2022. Other Contingencies For additional contingencies, see “COVID-19 Regulatory Matters" and "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. Maximum amounts guaranteed by Con Edison and its subsidiaries under these agreements totaled $2,412 million and $2,157 million at December 31, 2022 and 2021, respectively. A summary, by type and term, of Con Edison’s total guarantees under these other agreements at December 31, 2022 is as follows: Guarantee Type 0 – 3 years 4 – 10 years > 10 years Total (Millions of Dollars) Con Edison Transmission $407 $— $— $407 Energy transactions (a) 489 22 294 805 Renewable electric projects (a) 354 69 555 978 Other (a) 222 — — 222 Total $1,472 $91 $849 $2,412 (a) These represent guarantees of subsidiaries of the Clean Energy Businesses. The Clean Energy Businesses were classified as held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A, and Note X. Con Edison Transmission – Con Edison has guaranteed payment by CET of the contributions CET agreed to make to New York Transco LLC (NY Transco). CET owns a 45.7 percent interest in NY Transco. In April 2019, the New York Independent System Operator (NYISO) selected a transmission project that was jointly proposed by National Grid and NY Transco. The siting, construction and operation of the project will require approvals and permits from appropriate governmental agencies and authorities, including the NYSPSC. The NYISO indicated it will work with the developers to enter into agreements for the development and operation of the projects, including a schedule for entry into service by December 2023. Guarantee amount shown includes the maximum possible required amount of CET’s contributions for this project as calculated based on the assumptions that the project is completed at 175 percent of its estimated costs and NY Transco does not use any debt financing for the project. Energy Transactions — Con Edison and the Clean Energy Businesses guarantee payments on behalf of their subsidiaries in order to facilitate physical and financial transactions in electricity, gas, pipeline capacity, transportation, oil, renewable energy credits and energy services. To the extent that liabilities exist under the contracts subject to these guarantees, such liabilities are included in Con Edison’s consolidated balance sheet. Renewable Electric Projects – Con Edison and the Clean Energy Businesses guarantee payments on behalf of their wholly-owned subsidiaries associated with their investment in, or development for others of, solar and wind energy facilities.

Electricity and Gas Purchase Ag

Electricity and Gas Purchase Agreements	12 Months Ended
	Dec. 31, 2022
Regulated Operations [Abstract]
Electricity and Gas Purchase Agreements	Note B – Regulatory Matters Rate Plans The Utilities provide service to NY customers according to the terms of tariffs approved by the NYSPSC. Tariffs for service to customers of Rockland Electric Company (RECO), O&R’s NJ 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’ NY rate plans include: 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 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. 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. Other revenue adjustments 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. 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. 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”). 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). Current Rate Cases On February 16, 2023, CECONY, the New York State Department of Public Service (NYSDPS) and other parties entered into a Joint Proposal for CECONY electric and gas rate plans for the three-year period January 2023 through December 2025. The Joint Proposal is subject to NYSPSC approval. The Joint Proposal is summarized in the tables below. In November 2022, CECONY filed a request with the NYSPSC for an increase in the rates it charges for steam service rendered in New York, effective November 2023, of $137 million. The filing reflects a return on common equity of 10 percent and a common equity ratio of 50 percent. CECONY is requesting a new mechanism for decoupling revenues from steam consumption and the continuation of provisions with respect to recovery from customers of the cost of fuel and purchased steam and the reconciliation of actual expenses allocable to the steam business to the amounts for such expenses reflected in steam rates for pension and other postretirement benefits, environmental remediation expenses and uncollectible costs. In addition, the company is requesting full reconciliation for property taxes, municipal infrastructure support costs and long-term debt costs. The filing requests symmetrical reconciliation for labor and non-labor inflation rate to the extent that the actual inflation rate deviates from what is assumed in the revenue requirement by 50 basis points up or down. The filing includes supplemental information regarding steam rate plans for November 2024 through October 2025 and November 2025 through October 2026, which the company is not requesting but would consider through settlement discussions. For purposes of illustration, rate increases of $54 million and $49 million effective November 2024 and 2025, respectively, were calculated based upon an assumed return on common equity of 10 percent and a common equity ratio of 50 percent. In February 2023, CECONY updated its November 2022 request to the NYSPSC for a steam rate increase effective November 2023. The company increased its requested November 2023 rate increase by $4 million to $141 million, increased its illustrated November 2024 rate increase by $1 million to $55 million and increased its illustrated November 2025 rate increase by $4 million to $53 million. The following tables contain a summary of the Utilities’ rate plans: CECONY – Electric Effective period January 2020 – December 2022 (a) January 2023 – December 2025 (l) Base rate changes Yr. 1 – $113 million (b) Yr. 2 – $370 million (b) Yr. 3 – $326 million (b) Yr. 1 – $442 million (d) Yr. 2 – $518 million (d) Yr. 3 – $382 million (d) Amortizations to income of net regulatory (assets) and liabilities Yr. 1 – $267 million (c) Yr. 2 – $269 million (c) Yr. 3 – $272 million (c) Yr. 1 – $104 million (k) Yr. 2 – $49 million (k) Yr. 3 – $-205 million (k) 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 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. 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 Regulatory reconciliations Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (g). 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 (j) and expenses for uncollectibles, pension and other postretirement benefits, variable-rate debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (g). 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 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 (i) (j) Yr. 1 – 8.5 percent Yr. 2 – 8.03 percent Yr. 3 – 8.41 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. 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) In January 2020, the NYSPSC approved the October 2019 Joint Proposal for CECONY's electric rate plan for January 2020 through December 2022. If at the end of any semi-annual period ending June 30 and December 31, Con Edison’s investments in its non-utility businesses exceed 15 percent of its total consolidated revenues, assets or cash flow, or if the ratio of holding company debt to total consolidated debt rises above 20 percent, CECONY is required to notify the NYSPSC and submit a ring-fencing plan or a demonstration why additional ring-fencing measures (see Note U) are not necessary. (b) 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. (c) 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). (d) 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 will be effective as of January 1, 2023. CECONY will begin billing customers at the new levelized rate once the Joint Proposal is approved by the NYSPSC. Any shortfall in revenues due to the timing of billing to customers will be collected throu gh a surcharge billed through 2024, includin g 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. (e) 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: reflected in the January 2020 - December 2022 rate plan Yr 1 - 10.0 basis points; Yr 2 - 7.5 basis points; and Yr 3 - 5.0 basis points; reflected in the January 2023 - December 2025 Yr 1 - 10.0 basis points; Yr 2 - 5.0 basis points; and Yr 3 - 5.0 basis points, (f) 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. (g) In addition, the NYSPSC staff continues its focused operations audit to investigate CECONY's income tax accounting. Any NYSPSC ordered adjustment to CECONY’s income tax accounting is expected to be refunded to or collected from customers, as determined by the NYSPSC. See "Other Regulatory Matters," below. (h) Reconciliation of net utility plant for AMI will be done on a combined basis for electric and gas. (i) Calculated in accordance with the earnings calculation method prescribed in the rate order. (j) 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. (k) 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 ($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). (l) The February 2023 Joint Proposal is subject to NYSPSC approval. CECONY forecasts the need to construct a new project in Jamaica, Queens consisting of two substations and associated feeders at an estimated cost of $1,100 million (the Eastern Queens Reliability Project). Pursuant to the Joint Proposal, CECONY may petition the NYSPSC for approval to build and receive cost recovery for the Eastern Queens Reliability Project no sooner than 30 days after the NYSPSC adopts the Joint Proposal. CECONY – Gas Effective period January 2020 – December 2022 (a) January 2023 – December 2025 (l) Base rate changes Yr. 1 – $84 million (b) Yr. 2 – $122 million (b) Yr. 3 – $167 million (b) Yr. 1 – $217 million (d) Yr. 2 – $173 million (d) Yr. 3 – $122 million (d) Amortizations to income of net Yr. 1 – $45 million (c) Yr. 2 – $43 million (c) Yr. 3 – $10 million (c) Yr. 1 – $31 million (k) Yr. 2 – $24 million (k) Yr. 3 – $(11) million (k) 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 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. 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 Regulatory reconciliations Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (g). 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 (j) and expenses for uncollectibles, pension and other postretirement benefits, variable-rate debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (g). 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 (h): 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 (h): Yr. 1 - $234 million CSS: Yr. 1 - $2 million 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 (i) (j) Yr. 1 – 8.4 percent Yr. 2 – 8.48 percent Yr. 3 – 8.93 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. 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) In January 2020, the NYSPSC approved the October 2019 Joint Proposal for CECONY's gas rate plan for January 2020 through December 2022. If at the end of any semi-annual period ending June 30 and December 31, Con Edison’s investments in its non-utility businesses exceed 15 percent of its total consolidated revenues, assets or cash flow, or if the ratio of holding company debt to total consolidated debt rises above 20 percent, CECONY is required to notify the NYSPSC and submit a ring-fencing plan or a demonstration why additional ring-fencing measures (see Note U) are not necessary. (b) 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. (c) 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) (d) 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 will be effective as of January 1, 2023. CECONY will begin billing customers at the new levelized rate once the Joint Proposal is approved by the NYSPSC. Any shortfall in revenues due to the timing of billing to customers will be collected th rough 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. (e)-(i) See footnotes (e) - (i) to the table under “CECONY Electric,” above. (j) 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. (k) Amounts reflect amortization of the 2018 tax savings under the federal Tax Cuts and Jobs Act of 2017 (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). (l) The February 2023 Joint Proposal is subject to NYSPSC approval. CECONY – Steam Effective period January 2014 – December 2016 (a) Base rate changes Yr. 1 – $(22.4) million (b) Yr. 2 – $19.8 million (b) Yr. 3 – $20.3 million (b) Yr. 4 – None Yr. 5 – None Yr. 6 – None Yr. 7 – None Yr. 8 – None Amortizations to income of net $37 million over three years Recoverable energy costs Current rate recovery of purchased power and fuel costs. Negative revenue adjustments Potential charges (up to $1 million annually) if certain steam performance targets are not met. In years 2014 through 2022, the company did not record any negative revenue adjustments. Cost reconciliations (c)(d) In 2014, 2015, 2016, 2017, 2018, 2019, 2020, 2021 and 2022, 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 and $11 million of net regulatory assets, respectively. 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 million 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. Average rate base Yr. 1 – $1,511 million Yr. 2 – $1,547 million Yr. 3 – $1,604 million Weighted average cost of capital (after-tax) Yr. 1 – 7.10 percent Yr. 2 – 7.13 percent Yr. 3 – 7.21 percent Authorized return on common equity 9.3 percent Actual return on common equity (e) 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 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 and 2022, 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. Cost of long-term debt Yr. 1 – 5.17 percent Yr. 2 – 5.23 percent Yr. 3 – 5.39 percent Common equity ratio 48 percent (a) Rates determined pursuant to this rate plan continue in effect until a new rate plan is approved by the NYSPSC. (b) The impact of these base rate changes was deferred which resulted in an $8 million regulatory liability at December 31, 2016. (c) 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. (d) In addition, the NYSPSC staff has commenced a focused operations audit to investigate CECONY’s income tax accounting. Any NYSPSC ordered adjustment to CECONY’s income tax accounting is expected to be refunded to or collected from customers, as determined by the NYSPSC. CECONY’s historical inadvertent understatement of its calculation of total federal income tax expense for ratemaking purposes has not been addressed in the current steam rate plan. See "Other Regulatory Matters," below. (e) Calculated in accordance with the earnings calculation method prescribed in the rate order. O&R New York – Electric Effective period (a) January 2019 – December 2021 January 2022 – December 2024 Base rate changes Yr. 1 – $13.4 million (b) Yr. 2 – $8.0 million (b) Yr. 3 – $5.8 million (b) Yr. 1 – $4.9 million (i) Yr. 2 – $16.2 million (i) Yr. 3 – $23.1 million (i) Amortizations to income of net Yr. 1 – $(1.5) million (c) Yr. 2 – $(1.5) million (c) Yr. 3 – $(1.5) million (c) Yr. 1 – $11.8 million (j) Yr. 2 – $13.5 million (j) Yr. 3 – $15.2 million (j) Other revenue sources Potential earnings adjustment mechanism incentives for peak reduction, energy efficiency, Distributed Energy Resources utilization and other potential incentives of up to: Yr. 1 - $3.6 million Yr. 2 - $4.0 million Yr. 3 - $4.2 million Potential incentive if performance target related to customer service is met: $0.5 million annually. In 2019, 2020 and 2021, the company recorded $2.6 million, $1.9 million and $1.8 million of earnings adjustment mechanism incentives for energy efficiency, respectively. In 2019 and 2020, the company recorded $0.2 million and $0.5 million of incentives for customer service, respectively. In 2021, the company did not record incentives for customer service. In 2021, the company reversed the $0.5 million of incentives recorded in 2020 pursuant to the October 2021 Joint Proposal. 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 2019 and 2020, the company deferred $0.1 million and $6 million regulatory assets, respectively. In 2021, $10 million was deferred as regulatory liabilities. Continuation of reconciliation of actual to authorized electric delivery revenues. In 2022, the company deferred $6.9 million regulatory liabilities. Recoverable energy costs Continuation of current rate recovery of purchased power 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 a

Leases

Leases	12 Months Ended
	Dec. 31, 2022
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, and in 2021 of the Clean Energy Businesses, are included in operating lease right-of-use asset and operating lease liabilities on the Companies’ consolidated balance sheets. Operating leases of the Clean Energy businesses are included in assets held for sale and liabilities held for sale on Con Edison's consolidated balance sheet as of December 31,2022. See "Assets and Liabilities Held for Sale" in Note A and Note X. 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 twelve months ended December 31, 2022 and 2021 were as follows: Con Edison CECONY (Millions of Dollars) 2022 2021 2022 2021 Operating lease cost $88 $86 $67 $66 Operating lease cash flows $83 $80 $64 $63 As of December 31, 2022 and 2021, assets recorded as finance leases for Con Edison and CECONY were $2 million and $1 million, respectively. The accumulated amortization associated with finance leases for Con Edison and CECONY were $5 million and $2 million, respectively, at December 31, 2022 and $4 million and $2 million, respectively, at December 31, 2021. For the twelve months ended December 31, 2022 and 2021, 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 CECONY were $79 million and $68 million, respectively, for the twelve months ended December 31, 2022, of which $10 million for Con Edison related to the Clean Energy Businesses which were classified as held for sale, see "Assets and Liabilities Held for Sale" in Note A and Note X, and were $58 million and $12 million, respectively, for the twelve months ended December 31, 2021. Other information related to leases for Con Edison and CECONY at December 31, 2022 and 2021 was as follows: Con Edison CECONY 2022 2021 2022 2021 Weighted Average Remaining Lease Term: Operating leases, (a) 12.3 years 18.5 years 12.4 years 12.1 years Finance leases 7.2 years 7.1 years 2.3 years 3.1 years Weighted Average Discount Rate: Operating leases, (a) 3.7% 4.3% 3.7% 3.5% Finance leases 1.9% 1.8% 1.0% 1.1% (a) Amounts for Con Edison in 2022 exclude operating leases of the Clean Energy Businesses, which were classified as held for sale as of December 31, 2022, see "Assets and Liabilities Held for Sale" in Note A and Note X. Including the operating leases of the Clean Energy Businesses would result in a weighted average remaining lease term of 18.3 years and a weighted average discount rate of 4.4% as of December 31, 2022. Future minimum lease payments under non-cancellable leases at December 31, 2022 were as follows: (Millions of Dollars) Con Edison CECONY Year Ending December 31, (b) Operating Leases Finance Leases Operating Leases Finance Leases 2023 $64 $— $64 $— 2024 65 1 64 1 2025 65 — 64 — 2026 64 — 64 — 2027 64 — 64 — All years thereafter 419 1 419 — Total future minimum lease payments $741 $2 $739 $1 Less: imputed interest (162) — (161) — Total $579 $2 $578 $1 Reported as of December 31, 2022 Operating lease liabilities (current) (a) $103 $— $103 $— Operating lease liabilities held for sale (current) 33 — — — Operating lease liabilities (noncurrent) (a) 476 — 475 — Operating lease liabilities held for sale (noncurrent) 249 — — — Other current liabilities — — — — Other noncurrent liabilities — 2 — 1 Total $861 $2 $578 $1 (a) Amounts exclude operating lease liabilities of the Clean Energy Businesses ($281 million), which are classified as current liabilities held for sale on Con Edison's consolidated balance sheet as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X. (b) Amounts exclude operating lease future minimum lease payments of the Clean Energy Businesses, of $19 million, $18 million, $19 million, $17 million, $17 million, and $492 million for the 12 months ended December 31, 2023, 2024, 2025, 2026, 2027, and all years thereafter, respectively, and imputed interest of $301 million. At December 31, 2022, the Companies had an additional operating lease agreement that had not yet commenced, for a solar electric facility under construction by the Clean Energy Businesses, the amount of which was not material. The Clean Energy Businesses were classified as held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X.
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, and in 2021 of the Clean Energy Businesses, are included in operating lease right-of-use asset and operating lease liabilities on the Companies’ consolidated balance sheets. Operating leases of the Clean Energy businesses are included in assets held for sale and liabilities held for sale on Con Edison's consolidated balance sheet as of December 31,2022. See "Assets and Liabilities Held for Sale" in Note A and Note X. 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 twelve months ended December 31, 2022 and 2021 were as follows: Con Edison CECONY (Millions of Dollars) 2022 2021 2022 2021 Operating lease cost $88 $86 $67 $66 Operating lease cash flows $83 $80 $64 $63 As of December 31, 2022 and 2021, assets recorded as finance leases for Con Edison and CECONY were $2 million and $1 million, respectively. The accumulated amortization associated with finance leases for Con Edison and CECONY were $5 million and $2 million, respectively, at December 31, 2022 and $4 million and $2 million, respectively, at December 31, 2021. For the twelve months ended December 31, 2022 and 2021, 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 CECONY were $79 million and $68 million, respectively, for the twelve months ended December 31, 2022, of which $10 million for Con Edison related to the Clean Energy Businesses which were classified as held for sale, see "Assets and Liabilities Held for Sale" in Note A and Note X, and were $58 million and $12 million, respectively, for the twelve months ended December 31, 2021. Other information related to leases for Con Edison and CECONY at December 31, 2022 and 2021 was as follows: Con Edison CECONY 2022 2021 2022 2021 Weighted Average Remaining Lease Term: Operating leases, (a) 12.3 years 18.5 years 12.4 years 12.1 years Finance leases 7.2 years 7.1 years 2.3 years 3.1 years Weighted Average Discount Rate: Operating leases, (a) 3.7% 4.3% 3.7% 3.5% Finance leases 1.9% 1.8% 1.0% 1.1% (a) Amounts for Con Edison in 2022 exclude operating leases of the Clean Energy Businesses, which were classified as held for sale as of December 31, 2022, see "Assets and Liabilities Held for Sale" in Note A and Note X. Including the operating leases of the Clean Energy Businesses would result in a weighted average remaining lease term of 18.3 years and a weighted average discount rate of 4.4% as of December 31, 2022. Future minimum lease payments under non-cancellable leases at December 31, 2022 were as follows: (Millions of Dollars) Con Edison CECONY Year Ending December 31, (b) Operating Leases Finance Leases Operating Leases Finance Leases 2023 $64 $— $64 $— 2024 65 1 64 1 2025 65 — 64 — 2026 64 — 64 — 2027 64 — 64 — All years thereafter 419 1 419 — Total future minimum lease payments $741 $2 $739 $1 Less: imputed interest (162) — (161) — Total $579 $2 $578 $1 Reported as of December 31, 2022 Operating lease liabilities (current) (a) $103 $— $103 $— Operating lease liabilities held for sale (current) 33 — — — Operating lease liabilities (noncurrent) (a) 476 — 475 — Operating lease liabilities held for sale (noncurrent) 249 — — — Other current liabilities — — — — Other noncurrent liabilities — 2 — 1 Total $861 $2 $578 $1 (a) Amounts exclude operating lease liabilities of the Clean Energy Businesses ($281 million), which are classified as current liabilities held for sale on Con Edison's consolidated balance sheet as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X. (b) Amounts exclude operating lease future minimum lease payments of the Clean Energy Businesses, of $19 million, $18 million, $19 million, $17 million, $17 million, and $492 million for the 12 months ended December 31, 2023, 2024, 2025, 2026, 2027, and all years thereafter, respectively, and imputed interest of $301 million. At December 31, 2022, the Companies had an additional operating lease agreement that had not yet commenced, for a solar electric facility under construction by the Clean Energy Businesses, the amount of which was not material. The Clean Energy Businesses were classified as held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X.

Goodwill

Goodwill	12 Months Ended
	Dec. 31, 2022
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. Con Edison has recorded goodwill related to the O&R merger, the acquisition of a portion of Honeoye, and the acquisitions of a residential solar company and a battery storage company by the Clean Energy Businesses. In 2022 and 2021, Con Edison completed impairment tests for its goodwill of $406 million related to the O&R merger and determined that it was not impaired. For the impairment test, $245 million and $161 million of goodwill were allocated to CECONY and O&R, respectively. In 2022 and 2021, the Companies performed the qualitative assessment for goodwill related to the O&R merger. In 2022 and 2021, Con Edison completed impairment tests for goodwill of $1 million and $8 million, respectively, related to Honeoye, $14 million related to the residential solar company acquired by the Clean Energy Businesses and $18 million related to the battery storage company acquired by the Clean Energy Businesses. The amounts related to the Clean Energy Businesses were classified as held for sale on Con Edison's consolidated balance sheet as of December 31, 2022. In 2021, Con Edison determined, based on a discounted cash flow analysis, that $7 million of goodwill was impaired related to Honeoye, $5 million of which was attributed to CET and $2 million of which was attributed to CECONY. Estimates of future cash flows, projected growth rates, and discount rates inherent in the cash flow estimates for Con Edison subsidiaries other than the Utilities may vary significantly from actual results, which could result in a future impairment of goodwill. The Companies identified no triggering events or changes in circumstances related to the COVID-19 pandemic that would indicate that the carrying value of goodwill may not be recoverable at December 31, 2022 and 2021.

Income Tax

Income Tax	12 Months Ended
	Dec. 31, 2022
Income Tax Disclosure [Abstract]
Income Tax	Income Tax The components of income tax are as follows: Con Edison CECONY (Millions of Dollars) 2022 2021 2020 2022 2021 2020 State Current $5 $14 $7 $0 $1 $6 Deferred 324 79 50 110 106 97 Federal Current 58 43 (2) 170 121 41 Deferred 117 61 42 (23) 21 73 Amortization of investment tax credits (6) (7) (7) (2) (3) (2) Total income tax expense $498 $190 $90 $255 $246 $215 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) 2022 2021 2020 2022 2021 2020 STATUTORY TAX RATE Federal 21 % 21 % 21 % 21 % 21 % 21 % Changes in computed taxes resulting from: State income taxes, net of federal income tax benefit 6 4 4 5 5 5 Taxes attributable to noncontrolling interests 1 3 (1) — — — Cost of removal 1 2 2 1 1 1 Other plant-related items — (1) (1) (1) (1) (1) Amortization of excess deferred federal income taxes (9) (12) (14) (10) (11) (12) Renewable energy credits (2) (2) (3) — — — Research and development credits — (1) — — — — Remeasurement of accumulated deferred state income taxes, net of federal income tax benefit 6 — — — — — Other — — (1) — — 1 Effective tax rate 24 % 14 % 7 % 16 % 15 % 15 % Con Edison’s effective tax rate increased 10% in 2022 primarily due to higher income before income tax expense and the remeasurement of deferred state income tax assets and liabilities as a result of the anticipated sale of the Clean Energy Businesses (see Note X). Con Edison estimated the impact of the anticipated sale on its state apportionment factors and recorded an increase to its net accumulated deferred state income tax liabilities of $111 million and an increase to its valuation allowance on state and local net operating loss (NOL) carryforwards of $10 million, and recorded a corresponding deferred income tax expense of $121 million (net of federal income taxes) in the fourth quarter of 2022. During 2022, Con Edison wrote off $11 million of deferred tax assets (net of federal income taxes) and related valuation allowance on other state NOLs, with no impact on deferred income tax expense, and recognized a deferred income tax benefit of $3 million (net of federal income taxes) from net operating losses that were utilized during the year. The tax effects of temporary differences, which gave rise to deferred tax assets and liabilities, are as follows: Con Edison CECONY (Millions of Dollars) 2022 2021 2022 2021 Deferred tax liabilities: Property basis differences $8,770 $8,298 $7,475 $7,213 Regulatory Assets: Deferred storm costs 27 33 — — Environmental remediation costs 278 264 254 241 Other regulatory assets 754 640 720 609 Unrecognized pension and other postretirement costs 22 36 22 31 Pensions and retiree benefits – asset 917 478 894 471 Operating lease right-of-use asset 230 204 163 155 Equity investments 26 — — — Other — 30 — — Total deferred tax liabilities $11,024 $9,983 $9,528 $8,720 Deferred tax assets: Regulatory liabilities: Unrecognized pension and other postretirement costs 447 — 431 — Future income tax 489 554 454 517 Other regulatory liabilities 860 727 739 620 Tax credits carryforward 767 946 — — Loss carryforwards 117 144 24 38 Valuation allowance (18) (22) — — Superfund and other environmental costs 280 264 254 238 Operating lease liabilities 233 195 162 155 Pensions and retiree benefits – liability 162 218 148 188 Asset retirement obligations 153 177 140 141 Equity investments — 34 — — Other 14 — 45 42 Total deferred tax assets 3,504 3,237 2,397 1,939 Net deferred tax liabilities $7,520 $6,746 $7,131 $6,781 Unamortized investment tax credits 121 127 13 15 Net deferred tax liabilities and unamortized investment tax credits $7,641 $6,873 $7,144 $6,796 At December 31, 2022, Con Edison has $767 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 2034. 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, 2022, Con Edison has a New York State NOL of $892 million, primarily as a result of accelerated tax depreciation. A deferred tax asset of $84 million has been recognized for these New York State NOL carryforwards that will begin to expire, if unused, in 2038, and no valuation allowance is needed as it is more likely than not that the deferred tax asset will be realized. In addition, Con Edison has a deferred tax asset on its New York City NOL carryforward of $17 million that will begin to expire, if unused, in 2035, and a related valuation allowance of $14 million as it is not more likely than not that the deferred tax assets will be realized. Con Edison also has a deferred tax asset of $46 million on other state net operating loss carryforwards that will begin to expire if unused in 2038, and have a related valuation allowance of $10 million, as it is not more likely than not that the deferred tax assets will be realized. In April 2021, NY State passed a law that temporarily increased the corporate franchise tax rate on business income from 6.50 percent to 7.25 percent for a 3 year period, retroactive to January 1, 2021, for taxpayers with taxable income greater than $5 million. The law also temporarily reinstated the business capital tax, not to exceed an annual maximum tax liability of $5 million per taxpayer, with the corporation paying the higher of its franchise or income tax liability during the same period. The provisions to increase the corporate franchise tax rate and reinstate a business capital tax are scheduled to expire after 2023 and are not expected to have a material impact on the Company’s financial position, results of operations or liquidity. On November 19, 2021, the Acting Commissioner determined that the Metropolitan Transportation Authority (MTA) surcharge rate will remain the same at 30% for tax years beginning on or after January 1, 2022, and before January 1, 2023. As a result of the Clean Energy Businesses anticipated sale, Con Edison expects to have NY State taxable income in excess of the $5 million after utilizing its entire NY State NOL, and the group will be subject to the higher 7.25 percent (9.4 percent with MTA surcharge rate) rate on its taxable income, which was included in Con Edison's remeasurement of its deferred state income tax assets and liabilities at the end of 2022. 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) 2022 2021 2020 2022 2021 2020 Balance at January 1, $17 $14 $13 $5 $3 $2 Additions based on tax positions related to the current year 3 3 — 2 2 — Additions based on tax positions of prior years 6 2 1 1 1 1 Reductions for tax positions of prior years (1) (2) — — (1) — Settlements (2) — — — — — Balance at December 31, $23 $17 $14 $8 $5 $3 At December 31, 2022, the estimated liability for uncertain tax positions for Con Edison was $23 million ($8 million for CECONY). Con Edison reasonably expects to resolve within the next twelve months approximately $20 million of various federal uncertainties due to the expected completion of ongoing tax examinations, of which the entire amount, if recognized, would reduce Con Edison's effective tax rate. The amount related to CECONY is $6 million, which, if recognized, would reduce CECONY’s effective tax rate. The total amount of unrecognized tax benefits, if recognized, that would reduce Con Edison’s effective tax rate is $23 million with $8 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 2022, 2021 and 2020, the Companies recognized an immaterial amount of interest expense and no penalties for uncertain tax positions in their consolidated income statements. At December 31, 2022 and 2021, the Companies recognized an immaterial amount of accrued interest on their consolidated balance sheets. During 2022, Con Edison settled its Massachusetts corporation excise tax audit for tax years 2013 through 2018, and made a payment of $2 million during the year and released $1 million of uncertain tax positions as a result of the settlement. Con Edison's federal tax returns for tax years 2021 and 2020 remain under examination. State and local income tax returns remain open for examination in NY for tax years 2010 through 2021, in NJ for tax years 2018 through 2021 and in New York City for tax years 2018 through 2021.

Revenue Recognition

Revenue Recognition	12 Months Ended
	Dec. 31, 2022
Revenue from Contract with Customer [Abstract]
Revenue Recognition	Revenue Recognition The following table presents, for the years ended December 31, 2022, 2021 and 2020, revenue from contracts with customers as defined in Accounting Standards Codification (ASC) Topic 606, "Revenue from Contracts with Customers," as well as additional revenue from sources other than contracts with customers, disaggregated by major source. 2022 2021 2020 (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 $9,917 $(166) $9,751 $8,736 $70 $8,806 $8,026 $77 $8,103 Gas 2,875 49 2,924 2,324 54 2,378 1,998 38 2,036 Steam 584 9 593 519 13 532 494 14 508 Total CECONY $13,376 $(108) $13,268 $11,579 $137 $11,716 $10,518 $129 $10,647 O&R Electric 771 2 773 691 (10) 681 619 10 629 Gas 306 6 312 265 (5) 260 224 9 233 Total O&R $1,077 $8 $1,085 $956 $(15) $941 $843 $19 $862 Clean Energy Businesses (c) Renewables 637 — 637 638 — 638 608 — 608 Energy services 317 — 317 234 — 234 52 — 52 Develop/Transfer Projects 44 — 44 45 — 45 1 — 1 Other — 321 321 — 105 105 — 75 75 Total Clean Energy Businesses $998 $321 $1,319 $917 $105 $1,022 $661 $75 $736 Con Edison Transmission 4 — 4 4 — 4 4 — 4 Other (b) — (6) (6) — (7) (7) — (3) (3) Total Con Edison $15,455 $215 $15,670 $13,456 $220 $13,676 $12,026 $220 $12,246 (a) For the Utilities, this includes primarily revenue or negative revenue adjustments from alternative revenue programs, such as the revenue decoupling mechanisms under their NY electric and gas rate plans (see "Rate Plans" in Note B) and for 2021 recognition of late payment charges and fees that were not billed (LPCs) for the years ended December 31, 2020 and 2021 and for which recovery was granted by the NYSPSC. See "COVID-19 Regulatory Matters" in Note B and "Utilities' Assessment of Late Payment Charges" below. The amount of revenue recognized under such alternative revenue programs for 2021 includes $48 million, $34 million and $74 million for CECONY's revenue decoupling mechanisms, net EAMs, and LPCs, respectively, and $(18) million, $2 million and $4 million for O&R's revenue decoupling mechanisms, net EAMs, and LPCs, respectively. For the Clean Energy Businesses, this includes revenue from wholesale services. (b) Parent company and consolidation adjustments. (c) The Clean Energy Businesses were classified as held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A 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 recognize revenue for the sale of energy from renewable electric projects as energy is generated and billed to counterparties; accrue revenues at the end of each month for energy generated but not yet billed to counterparties; and recognize revenue as energy is delivered and services are 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 recognize revenue for providing energy-efficiency services to government and commercial customers, and recognize revenue for engineering, procurement and construction services, under the percentage-of-completion method of revenue recognition. The Clean Energy Businesses were classified as held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X. Clean Energy Businesses' Use of the Percentage-of-Completion Method Sales and profits on each percentage-of-completion contract are 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 result from contract modifications, performance or other reasons, are recognized on a cumulative catch-up basis in the period in which the revisions are made. The Clean Energy Businesses were classified as held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X. 2022 2021 2020 (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, $35 $7 $11 $41 $29 $17 Additions (c) 324 — 242 — 88 31 Subtractions (c) 279 4 (d) 218 34 (d) 106 7 (d) Ending balance as of December 31, $80 $3 $35 $7 $11 $41 (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. (d) Of the subtractions from unearned revenue, $4 million, $34 million and $7 million were included in the balances as of January 1, 2022, 2021, and 2020, respectively. As of December 31, 2022, the aggregate amount of the remaining fixed performance obligations of the Clean Energy Businesses under contracts with customers for energy services is $89 million, of which $51 million will be recognized within the next two years, and the remaining $38 million will be recognized pursuant to long-term service and maintenance agreements. The Clean Energy Businesses were classified as held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X. Utilities' Assessment of Late Payment Charges In March 2020, the Utilities began suspending new late payment charges and certain other fees for all customers. The Utilities also began providing payment extensions for all customers that were scheduled to be disconnected prior to the start of the COVID-19 pandemic. In November 2021, the NYSPSC issued an order establishing a surcharge recovery mechanism for CECONY to collect, commencing December 1, 2021 through December 31, 2022, $43 million and $7 million for electric and gas, respectively, of late payment charges and fees that were not billed for the year ended December 31, 2020. In April 2022, the NYSPSC approved the October 2021 O&R NY joint proposal for new electric and gas rate plans for the three-year period from January 2022 through December 2024 that includes certain COVID-19 provisions, such as: recovery of 2020 late payment charges over three years;

Current Expected Credit Losses

Current Expected Credit Losses	12 Months Ended
	Dec. 31, 2022
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. “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. The Clean Energy Businesses’ customer accounts receivable balance generally reflects 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 calculate 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 and December 31, 2021. The Clean Energy Businesses were classified as held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X. 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’ customer accounts receivable allowance for uncollectible accounts, 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 aged customer accounts receivable balances, among other factors; and forecasts about the future include assumptions related to the level of write-offs and recoveries. Generally, the Utilities write off customer accounts receivable as uncollectible 90 days after the account is turned off for non-payment, or the account is closed during the collection process. See "COVID-19 Regulatory Matters" in Note B. 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. Starting in 2020, the potential economic impact of the COVID-19 pandemic was also considered in forward-looking projections related to write-off and recovery rates and resulted in increases to the allowance for uncollectible accounts. The increases to the allowance for customer uncollectible accounts for Con Edison and CECONY were $5 million and $10 million, respectively, for the year ended December 31, 2022. The increases to the allowance for uncollectible accounts for Con Edison and CECONY were $169 million and $166 million for the year ended December 31, 2021. 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, 2022 and 2021: For the Year Ended December 31, Con Edison CECONY Accounts receivable - customers Other receivables Accounts receivable - customers Other receivables (Millions of Dollars) 2022 2021 2022 2021 2022 2021 2022 2021 Allowance for credit losses Beginning Balance at January 1, $317 $148 $22 $7 $304 $138 $19 $4 Recoveries 17 14 — 1 16 12 — 1 Write-offs (103) (91) (6) (2) (94) (86) (4) (1) Reserve adjustments 91 246 (6) 16 88 240 (8) 15 Ending Balance December 31, $322 $317 $10 $22 $314 $304 $7 $19

Stock-Based Compensation

Stock-Based Compensation	12 Months Ended
	Dec. 31, 2022
Share-Based Payment Arrangement [Abstract]
Stock-Based Compensation	Stock-Based Compensation The Companies may compensate employees and directors with, among other things, stock options, stock units, restricted stock units and contributions to the stock purchase plan. The Long Term Incentive Plan, which was approved by Con Edison’s shareholders in 2003 (2003 LTIP), and the Long Term Incentive Plan, which was approved by Con Edison’s shareholders in 2013 (2013 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 continue in effect, however no new awards may be issued under the 2003 LTIP. The 2013 LTIP provides for awards for up to five million shares of common stock. During the years ended December 31, 2022, 2021, and 2020, equity awards were granted under the 2013 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, 2022 were new shares. The Companies intend to use new shares to fulfill their stock-based compensation obligations for 2023. 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, 2022, 2021 and 2020: Con Edison CECONY (Millions of Dollars) 2022 2021 2020 2022 2021 2020 Performance-based restricted stock $52 $23 $7 $43 $19 $6 Time-based restricted stock 2 2 1 2 2 1 Non-employee director deferred stock compensation 3 3 2 3 3 2 Stock purchase plan 7 7 7 6 7 7 Total $64 $35 $17 $54 $31 $16 Income tax benefit $18 $10 $5 $15 $9 $4 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: 2022 2021 2020 Risk-free interest rate (a) 4.41% - 4.73% 0.39% - 0.73% 0.10% -0.13% Expected term (b) 3 years 3 years 3 years Expected share price volatility (c) 19.65% - 21.77% 17.25% - 31.42% 30.16% - 40.95% (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, 2022 is as follows: Con Edison CECONY Weighted Average Grant Date Fair Value (a) Weighted Average Grant Date Fair Value (a) Units TSR Portion (b) Non-TSR Portion (c) Units TSR Portion (b) Non-TSR Portion (c) Non-vested at December 31, 2021 984,728 $72.67 $79.14 744,278 $72.71 $79.20 Granted 231,600 89.90 83.76 172,003 90.25 84.32 Vested (320,821) 64.59 80.17 (240,022) 65.04 80.45 Forfeited (30,416) 80.08 77.73 (28,433) 80.04 77.68 Non-vested at December 31, 2022 865,091 $80.02 $80.04 647,826 $79.89 $80.16 (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. The total expense to be recognized by Con Edison in future periods for unvested Performance RSUs outstanding at December 31, 2022 is $37 million, including $30 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 $10 million and $9 million in 2022, $8 million and $7 million in 2021, and $21 million and $18 million in 2020, respectively, to settle vested Performance RSUs. In accordance with the accounting rules for stock compensation, for time-based awards, the Companies are accruing a liability and recognizing 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 officer or 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. A summary of changes in the status of time-based awards during the year ended December 31, 2022 is as follows: Con Edison CECONY Units Weighted Average Grant Date Fair Value Units Weighted Average Grant Date Fair Value Non-vested at December 31, 2021 61,620 $79.68 57,870 $79.70 Granted 149,650 86.59 118,458 87.46 Vested (22,450) 84.81 (21,200) 84.81 Forfeited (8,232) 81.51 (7,713) 81.54 Non-vested at December 31, 2022 180,588 $84.69 147,415 $85.10 The total expense to be recognized by Con Edison in future periods for unvested time-based awards outstanding at December 31, 2022 is $9 million, including $8 million for CECONY, and is expected to be recognized over a weighted average period of one year. Con Edison and CECONY paid cash of $2 million in 2022, and $1 million in 2021 and 2020, 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, 2022, approximately 31,000 units were issued at a weighted average grant date price of $93.60. Stock Purchase Plan The Stock Purchase Plan, which was approved by shareholders in 2004 and 2014, provides 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. Prior to September 1, 2020, the fair value of the shares of Con Edison common stock purchased under the plan was calculated using the average of the high and low composite sale prices at which shares were traded at the New York Stock Exchange on the trading day immediately preceding such purchase dates. During 2020, the plan was amended and as a result of the amendment, the fair value of the shares of Con Edison common stock purchased after September 1, 2020 under the plan was calculated using the closing price at which shares were traded on the New York Stock Exchange on the last business day of the month for all shares purchased during the month. During 2022, 2021 and 2020, 744,932, 957,866 and 836,984 shares were purchased under the Stock Purchase Plan at a weighted average price of $91.59, $73.38 and $79.82 per share, respectively.

Financial Information by Busine

Financial Information by Business Segment	12 Months Ended
	Dec. 31, 2022
Segment Reporting [Abstract]
Financial Information by Business Segment	Financial Information by Business Segment 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 principal business segments are CECONY’s regulated utility activities, O&R’s regulated utility activities, the Clean Energy Businesses 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, 2022 (Millions of Dollars) Operating revenues Inter- segment revenues Depreciation and amortization Operating income Other Income (deductions) Interest charges Income taxes on operating income (a) Total assets Capital expenditures CECONY Electric $9,751 $19 $1,315 $1,496 $259 $582 $138 $39,153 $2,522 Gas 2,924 8 367 660 52 198 141 15,361 1,128 Steam 593 76 96 (21) 21 42 (18) 2,931 108 Consolidation adjustments — (103) — — — — — — — Total CECONY $13,268 $— $1,778 $2,135 $332 $822 $261 $57,445 $3,758 O&R Electric $773 $— $71 $94 $17 $29 $17 $2,247 $167 Gas 312 — 27 42 6 17 8 1,264 76 Other — — — — — — — — — Total O&R $1,085 $— $98 $136 $23 $46 $25 $3,511 $243 Clean Energy Businesses $1,319 $— $178 $368 $3 $(35) $84 $7,224 (b) $399 Con Edison Transmission 4 — 1 (10) 19 5 1 314 65 Other (c) (6) — 1 (5) (51) 14 51 571 — Total Con Edison $15,670 $— $2,056 $2,624 $326 $852 $422 $69,065 $4,465 As of and for the Year Ended December 31, 2021 (Millions of Dollars) Operating revenues Inter- segment revenues Depreciation and amortization Operating income Other Income (deductions) Interest charges Income taxes on operating income (a) Total assets Capital expenditures CECONY Electric $8,806 $18 $1,286 $1,802 $(84) $542 $151 $36,260 $2,189 Gas 2,378 8 326 646 (16) 179 110 13,748 1,126 Steam 532 74 93 12 (8) 41 (9) 2,647 103 Consolidation adjustments — (100) — — — — — — — Total CECONY $11,716 $— $1,705 $2,460 $(108) $762 $252 $52,655 $3,418 O&R Electric $681 $— $69 $100 $(8) $27 $13 $2,123 $147 Gas 260 — 26 50 (4) 15 8 1,169 70 Other — — — — — — — — — Total O&R $941 $— $95 $150 $(12) $42 $21 $3,292 $217 Clean Energy Businesses $1,022 $— $231 $236 $(10) $68 $44 $6,554 (b) $298 Con Edison Transmission 4 — 1 (16) (407) 9 3 249 31 Other (c) (7) — — (4) (1) 24 20 366 — Total Con Edison $13,676 $— $2,032 $2,826 $(538) $905 $340 $63,116 $3,964 As of and for the Year Ended December 31, 2020 (Millions of Dollars) Operating Inter- Depreciation Operating Other Income (deductions) Interest Income Total Capital CECONY Electric $8,103 $18 $1,214 $1,731 $(134) $535 $130 $35,673 $2,080 Gas 2,036 7 294 574 (25) 164 102 12,678 1,044 Steam 508 74 90 5 (12) 40 (14) 2,616 122 Consolidation adjustments — (99) — — — — — — — Total CECONY $10,647 $— $1,598 $2,310 $(171) $739 $218 $50,967 $3,246 O&R Electric $629 $— $65 $99 $(10) $26 $13 $2,097 $159 Gas 233 — 25 48 (4) 15 8 1,150 61 Other — — — — — — — — — Total O&R $862 $— $90 $147 $(14) $41 $21 $3,247 $220 Clean Energy Businesses $736 $— $231 $215 $4 $196 $(43) $6,848 (b) $616 Con Edison Transmission 4 — 1 (8) $ (215) 18 — 1,348 3 Other (c) (3) — — (10) (5) 25 (3) 485 — Total Con Edison $12,246 $— $1,920 $2,654 $(401) $1,019 $193 $62,895 $4,085 (a) For Con Edison, the income tax expense/(benefit) on non-operating income was $76 million, $(150) million and $(103) million in 2022, 2021 and 2020, respectively. For CECONY, the income tax expense/(benefit) on non-operating income was $(6) million, $(6) million and $(3) million in 2022, 2021 and 2020, respectively. (b) The Clean Energy Businesses were classified as held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X. (c) Parent company and consolidation adjustments. Other does not represent a business segment.

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities	12 Months Ended
	Dec. 31, 2022
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, ba sis swaps, options, transmission congestion contracts and financial transmission rights contracts. These are economic hedges, for which the Utilities and the Clean Energy Business 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 is dependent 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. See "Recoverable Energy Costs" in Note A. The Clean Energy Businesses use interest rate swaps to manage the risks associated with interest rates related to outstanding and expected future debt issuan ces and borrowings. 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. The Clean Energy Businesses were classified as held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A 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, 2022 and 2021 were: (Millions of Dollars) 2022 2021 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 $378 $(332) $46 (b) $285 $(158) $127 (b)(d) Noncurrent 193 (108) 85 90 (13) 77 Total fair value of derivative assets held and used $571 $(440) $131 $375 $(171) $204 Current - assets held for sale (e) 93 (8) 85 (c) — — — Noncurrent - assets held for sale (e) 83 11 94 (c) — — — Total fair value of derivative assets $747 $(437) $310 $375 $(171) $204 Fair value of derivative liabilities Current $(198) $166 $(32) (b) $(289) $137 $(152) Noncurrent (49) 36 (13) (94) 10 (84) (d) Total fair value of derivative liabilities held and used $(247) $202 $(45) $(383) $147 $(236) Current - liabilities held for sale (e) (31) 6 (25) — — — Noncurrent - liabilities held for sale (e) (3) (8) (11) — — — Total fair value of derivative liabilities $(281) $200 $(81) $(383) $147 $(236) Net fair value derivative assets/(liabilities) $466 $(237) $229 $(8) $(24) $(32) CECONY Fair value of derivative assets Current $350 $(312) $38 (b) $135 $(64) $71 (b) Noncurrent 176 (96) 80 71 (15) 56 Total fair value of derivative assets $526 $(408) $118 $206 $(79) $127 Fair value of derivative liabilities Current $(189) $160 $(29) $(131) $43 $(88) Noncurrent (43) 34 (9) (50) 10 (40) Total fair value of derivative liabilities $(232) $194 $(38) $(181) $53 $(128) Net fair value derivative assets/(liabilities) $294 ($214) $80 $25 $(26) $(1) (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, 2022, margin deposits for Con Edison and CECONY of $13 million were classified as derivative assets, and ($(10) million and $(6) million, respectively) were classified as derivative liabilities on the consolidated balance sheet, but not included in the table. At December 31, 2021, margin deposits for Con Edison and CECONY ($1 million and an immaterial amount, respectively) were classified as derivative assets on the consolidated balance sheet, 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. (c) Includes amounts for interest rate swaps of $31 million in current assets and $75 million in noncurrent assets. At December 31, 2022, the Clean Energy Businesses had interest rate swaps with notional amounts of $982 million. The expiration dates of the swaps range from 2025-2041. (d) Includes amounts for interest rate swaps of $4 million in noncurrent assets, $(20) million in current liabilities and $(38) million in noncurrent liabilities. At December 31, 2021, the Clean Energy Businesses had interest rate swaps with notional amounts of $1,031 million. The expiration dates of the swaps ranged from 2025-2041. (e) Amounts represent derivative assets and liabilities included in current assets and current liabilities held for sale, respectively, on Con Edison's consolidated balance sheet as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X. 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. See "Recoverable Energy Costs" in Note A. 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 record 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 occur. The Clean Energy Businesses record 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. The Clean Energy Businesses were classified as held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A 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, 2022 and 2021: Con Edison CECONY (Millions of Dollars) Balance Sheet Location 2022 2021 2022 2021 Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations: Current Deferred derivative gains $168 $134 $155 $124 Noncurrent Deferred derivative gains 83 57 75 51 Total deferred gains/(losses) $251 $191 $230 $175 Current Deferred derivative losses $(43) $49 $(44) $43 Current Recoverable energy costs 408 3 372 — Noncurrent Deferred derivative losses 19 70 19 66 Total deferred gains/(losses) $384 $122 $347 $109 Net deferred gains/(losses) $635 $313 $577 $284 Income Statement Location Pre-tax gain/(loss) recognized in income Gas purchased for resale $5 $18 $— $— Non-utility revenue — 3 — — Other operations and maintenance expense 4 5 4 5 Other interest expense 159 (a) 52 — — Total pre-tax gain/(loss) recognized in income $168 $78 $4 $5 (a) Comprised of amounts related to interest rate swaps of the Clean Energy Businesses. The Clean Energy Businesses were held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X. The following table presents the hedged volume of Con Edison’s and CECONY’s commodity derivative transactions at December 31, 2022: Electric Energy Capacity (MW) (a) Natural Gas (Dt) (a)(b) Refined Fuels (gallons) Con Edison 33,546,670 46,116 290,398,144 168,000 CECONY 31,567,400 30,675 272,790,000 168,000 (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. (c) Included are electric energy, capacity, and natural gas ((240) MWh, 8,616 MW, and 3,518,144 Dt, respectively) volumes of the Clean Energy Businesses. The Companies are exposed to credit risk related to transactions entered into primarily for the various energy supply and hedging activities by the Utilities and the Clean Energy Businesses. 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, 2022, Con Edison and CECONY had $703 million and $357 million of credit exposure in connection with open energy supply net receivables and hedging activities, net of collateral, respectively. Con Edison’s net credit exposure consisted of $174 million with independent system operators and $41 million with non-investment grade/non-rated counterparties (which amounts related entirely to the Clean Energy Businesses), and $353 million with investment-grade counterparties and $133 million with commodity exchange brokers of which $50 million and $50 million, respectively, related to the Clean Energy Businesses. The Clean Energy Businesses were classified as held for sale as of December 31, 2022; see "Assets and Liabilities Held for Sale" in Note A and Note X. CECONY’s net credit exposure consisted of $83 million with commodity exchange brokers and $274 million with investment-grade counterparties. The collateral requirements associated with, and settlement of, derivative transactions are included in net cash flows from operating activities in the Companies’ consolidated statement 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, 2022: (Millions of Dollars) Con Edison (a) CECONY (a) Aggregate fair value – net liabilities $157 $86 Collateral posted 70 70 Additional collateral (b) (downgrade one level from current ratings) 65 15 Additional collateral (b)(c) (downgrade to below investment grade from current ratings) 138 67 (a) Non-derivative transactions for the purchase and sale of electricity and gas and qualifying derivative instruments, which 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 and the Clean Energy Businesses were no longer extended unsecured credit for such purchases, the Companies would be required to post additional collateral of $9 million at December 31, 2022. 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, 2022, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $115 million.

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2022
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, which 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, which 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, which 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, 2022 and 2021 are summarized below. 2022 2021 (Millions of Dollars) Level 1 Level 2 Level 3 Netting Adjustment (e) Total Level 1 Level 2 Level 3 Netting Adjustment (e) Total Con Edison Derivative assets: Commodity (a)(b)(c) $84 $476 $2 $(420) $142 $95 $260 $17 $(171) $201 Commodity held for sale (g) 6 34 31 2 73 — — — — — Interest rate swaps (a)(b)(c)(f) (g) — 106 — — 106 — 4 — — 4 Other (a)(b)(d) 437 116 — — 553 492 135 — — 627 Total assets $527 $732 $33 $(418) $874 $587 $399 $17 $(171) $832 Derivative liabilities: Commodity (a)(b)(c) $18 $204 $16 $(184) $54 $33 $266 $28 $(148) $179 Commodity held for sale (g) 8 24 2 2 36 Interest rate swaps (a)(b)(c)(f) (g) — — — — — — 57 — — 57 Total liabilities $26 $228 $18 $(182) $90 $33 $323 $28 $(148) $236 CECONY Derivative assets: Commodity (a)(b)(c) $83 $434 $2 $(388) $131 $67 $138 $1 $(79) $127 Other (a)(b)(d) 422 110 — — 532 474 127 — — 601 Total assets $505 $544 $2 $(388) $663 $541 $265 $1 $(79) $728 Derivative liabilities: Commodity (a)(b)(c) $18 $198 $8 $(180) $44 $1 $172 $8 $(53) $128 (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. Con Edison and CECONY had an immaterial amount of derivative liabilities and $10 million and $9 million of commodity derivative assets, respectively, transferred from level 3 to level 2 during the year ended December 31, 2022 because of availability of observable market data due to the decrease in the terms of certain contracts from beyond three years as of September 30, 2022 to less than three years as of December 31, 2022. Con Edison and CECONY had $1 million of commodity derivative assets and $4 million and $3 million of commodity derivative liabilities, respectively, transferred from level 3 to level 2 during the year ended December 31, 2021 because of availability of observable market data due to the decrease in the terms of certain contracts from beyond three years as of September 30, 2021 to less than three years as of December 31, 2021. (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, 2022 and 2021, the Companies determined that nonperformance risk would have no material impact on their financial position or results of operations. (d) Other assets are comprised of assets such as life insurance contracts within the deferred compensation plan and non-qualified retirement plans. (e) 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. (f) See Note Q. (g) Amounts for 2022 represent the Clean Energy Businesses' derivative assets and liabilities included in current assets and current liabilities held for sale, respectively on Con Edison's consolidated balance sheet as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X. 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 and interest rate swaps. Under the Companies’ policies and procedures, multiple independent sources of information are obtained for forward price curves used to value commodity derivatives and interest rate swaps. Fair value and changes in fair value of commodity derivatives and interest rate swaps are reported monthly to the Companies’ risk committees, comprised of officers and employees of the Companies that oversee energy hedging at the Utilities and the Clean Energy Businesses. The risk management group reports to the Companies’ Vice President and Treasurer. Fair Value of Level 3 at December 31, 2022 (Millions of Dollars) Valuation Techniques Unobservable Inputs Range Con Edison — Commodity Electricity - Held and Used $(15) Discounted Cash Flow Forward capacity prices (a) $1.42-$16.08 per kW-month Transmission Congestion Contracts/Financial Transmission Rights - Held and Used 1 Discounted Cash Flow Inter-zonal forward price curves adjusted for historical zonal losses (b) $0.91-$3.03 per MWh Total Con Edison - Commodity - Held and Used $(14) Electricity - Held for Sale $14 Discounted Cash Flow Forward energy prices (a) $22.00-$187.50 per MWh 10 Discounted Cash Flow Forward capacity prices (a) $0.96-$5.75 per kW-month Transmission Congestion Contracts/Financial Transmission Rights - Held for Sale 4 Discounted Cash Flow Inter-zonal forward price curves adjusted for historical zonal losses (b) $(12.44)-$195.57 per MWh Natural Gas - Held for Sale 1 Discounted Cash Flow Forward natural gas prices (a) $3.75-$14.51 per Dt Total Con Edison - Commodity - Held for Sale (c) $29 Total Con Edison — Commodity $15 CECONY — Commodity Electricity $(7) Discounted Cash Flow Forward capacity prices (a) $1.42-$16.08 per kW-month Transmission Congestion Contracts 1 Discounted Cash Flow Inter-zonal forward price curves adjusted for historical zonal losses (b) $0.91-$3.03 per MWh 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. (c) Amount represents the Fair Value of Level 3 assets of the Clean Energy Businesses, which were held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X. 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, 2022 and 2021 and classified as Level 3 in the fair value hierarchy: Con Edison CECONY (Millions of Dollars) 2022 2021 2022 2021 Beginning balance as of January 1, $(11) $(19) $(7) $(10) Included in earnings (11) (9) (5) (3) Included in regulatory assets and liabilities 11 3 10 1 Purchases — 6 — — Settlements 11 5 5 3 Changes in level 3 assets and liabilities held for sale (a) 25 — — — Transfer out of level 3 (10) 3 (9) 2 Ending balance as of December 31, $15 $(11) $(6) $(7) (a) Am ounts for 2022 represent the net change in the value of level 3 assets and liabilities of the Clean Energy Businesses. The Clean Energy Businesses were classified as held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A 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 are reported in non-utility revenues The Clean Energy Businesses were classified as held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X.

Variable Interest Entities

Variable Interest Entities	12 Months Ended
	Dec. 31, 2022
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 Partners, LP, a potential VIE. In 2022, 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 these electricity purchase agreements; the payments for this contract constitute CECONY's maximum exposure to loss with respect to the potential VIE. Clean Energy Businesses The Clean Energy Businesses were classified as held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X. In June 2021, a subsidiary of the Clean Energy Businesses sold substantially all of its membership interest in a renewable electric project, and retained an equity interest of $11 million in the project, which is accounted for as an equity method investment. See Note W. The earnings of the project are determined using the hypothetical liquidation at book value (HLBV) method of accounting which resulted in a loss of $11 million pre-tax ($8 million after-tax) for the year ended December 31, 2021. Con Edison is not the primary beneficiary since the power to direct the activities that most significantly impact the economics of the renewable electric project is not held by the Clean Energy Businesses. HLBV Accounting Con Edison has determined that the use of HLBV accounting is reasonable and appropriate to attribute income and loss to the tax equity investors. See "Use of Hypothetical Liquidation at Book Value" in Note A. CED Nevada Virginia In February 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 will be allocated. CED Nevada Virginia is a consolidated entity in which Con Edison has less than a 100 percent membership interest. Con Edison is the primary beneficiary since the power to direct the activities that most significantly impact the economics of CED Nevada Virginia is held by the Clean Energy Businesses. The HLBV method of accounting resulted in income/(loss) for the years ended December 31, 2022 and 2021, as follows: (Millions of Dollars) 2022 2021 Tax equity investor $(49) $(158) After tax (37) (119) Con Edison 41 155 After tax 31 117 Tax Equity 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. The Tax Equity Projects are consolidated entities in which Con Edison has less than a 100 percent membership interest. Con Edison is the primary beneficiary since the power to direct the activities that most significantly impact the economics of the Tax Equity Projects is held by the Clean Energy Businesses. Electricity generated by the Tax Equity Projects is sold to utilities and municipalities pursuant to long-term power purchase agreements. The HLBV method of accounting resulted in income/(loss) for the years ended December 31, 2022 and 2021, as follows: (Millions of Dollars) 2022 2021 Tax equity investor $(11) $6 After tax (8) 4 Con Edison 51 30 After tax 38 24 At December 31, 2022 and 2021, Con Edison’s consolidated balance sheet included the following amounts associated with its VIEs: Tax Equity Projects Great Valley Solar Copper Mountain - Mesquite Solar CED Nevada Virginia (c)(h) CED Nevada Virginia (c)(h) (Millions of Dollars) 2022 2021 2022 2021 2022 2021 Assets held for sale (a) $305 $— $580 $— $686 $— Non-utility property, less accumulated depreciation (f)(g) — 275 — 431 — 643 Other assets — 37 — 167 — 55 Total assets (a) $305 $312 $580 $598 $686 $698 Liabilities held for sale (b) 20 — 81 — 331 — Other liabilities — 14 — 74 — 315 Total liabilities (b) $20 $14 $81 $74 $331 $315 (a) The assets of the Tax Equity Projects and CED Nevada Virginia represent assets of a consolidated VIE that can be used only to settle obligations of the consolidated VIE. Amounts shown for 2022 are included in current assets held for sale on Con Edison's consolidated balance sheet as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X. (b) The liabilities of the Tax Equity Projects and CED Nevada Virginia represent liabilities of a consolidated VIE for which creditors do not have recourse to the general credit of the primary beneficiary. Amounts shown for 2022 are included in current liabilities held for sale on Con Edison's consolidated balance sheet as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X. (c) Con Edison did not provide any financial or other support during the year that was not previously contractually required. (d) Great Valley Solar consists of the Great Valley Solar 1, Great Valley Solar 2, Great Valley Solar 3 and Great Valley Solar 4 projects, for which the noncontrolling interest of the tax equity investor was $67 million and $84 million at December 31, 2022 and 2021, respectively. (e) Copper Mountain - Mesquite Solar consists of the Copper Mountain Solar 4, Mesquite Solar 2 and Mesquite Solar 3 projects for which the noncontrolling interest of the tax equity investor was $94 million and $118 million at December 31, 2022 and 2021, respectively. (f) Non-utility property is reduced by accumulated depreciation of $35 million for Great Valley Solar, $59 million for Copper Mountain - Mesquite Solar and $29 million for CED Nevada Virginia at December 31, 2022. (g) Non-utility property is reduced by accumulated depreciation of $26 million for Great Valley Solar, $44 million for Copper Mountain - Mesquite Solar and $10 million for CED Nevada Virginia at December 31, 2021. (h) CED Nevada Virginia consists of the Copper Mountain Solar 5, Battle Mountain Solar and Water Strider Solar projects for which the noncontrolling interest of the tax equity investor was $39 million and $95 million at December 31, 2022 and 2021, respectively. The following table summarizes the VIEs into which the Clean Energy Businesses have entered as of December 31, 2022. The Clean Energy Businesses were classified as held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X. Project Name Generating Capacity (a) (MW AC) Power Purchase Agreement Term in Years Year of Investment Location Maximum Millions of Dollars ) (b) Great Valley Solar (c) 200 15-20 2018 CA $218 Copper Mountain - Mesquite Solar (c) 344 20-25 2018 NV and AZ 404 CED Nevada Virginia (c) 431 20-25 2021 NV and VA 316 (a) Represents ownership interest in the project. (b) Maximum exposure is equal to the net assets of the project on the consolidated balance sheet less any applicable noncontrolling interest. Con Edison did not provide any financial or other support during the year that was not previously contractually required. (c) For the projects comprising Great Valley Solar, Copper Mountain Mesquite Solar and CED Nevada Virginia, refer to (d), (e) and (h) in the table above.

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2022
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 are located on property that is 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. The Clean Energy Businesses were classified as held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A 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, 2022 and 2021, and changes to the obligation for the years then ended: Con Edison CECONY (Millions of Dollars) 2022 2021 2022 2021 Beginning Balance as of January 1, $577 $577 $504 $508 ARO held for sale (a) (77) — — — Changes in estimated cash flows 44 58 43 55 Accretion expense 18 18 14 15 Liabilities settled (62) (75) (62) (74) Ending Balance as of December 31, (b) $500 $577 $499 $504 (a) The asset retirement obligations of the Clean Energy Businesses are reflected in current liabilities held for sale on Con Edison's consolidated balance sheet as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X. (b) At December 31, 2022, Con Edison and CECONY recorded reductions of $78 million and $77 million, respectively, to the regulatory liability associated with cost of removal to reflect depreciation and interest expense. At December 31, 2021, Con Edison and CECONY recorded reductions of $87 million and $85 million, respectively, to the regulatory liability associated with cost of removal to reflect depreciation and interest expense.

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2022
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 ($16,878 million and $931 million, respectively), at December 31, 2022, 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, 2022, 2021 and 2020 were as follows: CECONY (Millions of Dollars) 2022 2021 2020 Cost of services provided $135 $137 $128 Cost of services received 75 68 66 In addition, CECONY and O&R have joint gas supply arrangements in connection with which CECONY sold to O&R $144 million, $90 million and $59 million of natural gas for the years ended December 31, 2022, 2021 and 2020, respectively. These amounts are net of the effect of related hedging transactions. At December 31, 2022 and 2021, CECONY's net payable to Con Edison for income taxes was $89 million and $10 million, respectively. The Utilities perform work and incur expenses on behalf of NY Transco, a company in which CET has a 45.7 percent equity interest. The Utilities bill NY Transco for such work and expenses in accordance with established policies. For the years ended December 31, 2022 and 2021, the amounts billed by the Utilities to NY Transco were $8.0 million and $5.9 million, respectively. In May 2016, CECONY transferred certain electric transmission projects to NY Transco. CECONY has storage and wheeling service contracts with Stagecoach Gas Services LLC (Stagecoach), a joint venture formerly owned by a subsidiary of CET and a subsidiary of Crestwood Equity Partners LP (Crestwood). In addition, CECONY is the replacement shipper on one of Crestwood’s firm transportation agreements with Tennessee Gas Pipeline Company LLC. CECONY incurred costs for storage and wheeling services from Stagecoach of $31 million and $34 million for the years ended December 31, 2021 and 2020, respectively. During 2021, a subsidiary of CET completed the sale of its 50 percent interest in Stagecoach. See Note W. CECONY has a 20-year transportation contract with Mountain Valley Pipeline, LLC (MVP) for 250,000 dekatherms per day of capacity. CET owns a 9.6 percent equity interest in MVP (that is expected to be reduced to 8.0 percent). See "Investments - 2020 and 2021 Partial Impairments of 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 MVP contract 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 opened a proceeding to consider this request. For the years ended December 31, 2022 and 2021, CECONY incurred no costs under the contract. 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, 2022 and 2021 there were no outstanding loans to O&R. The Clean Energy Businesses had financial electric capacity contracts with CECONY and O&R during 2022 and 2021. For the years ended December 31, 2022 and 2021, the Clean Energy Businesses realized a $5 million gain and $4 million loss, respectively, under these contracts. The Clean Energy Businesses were classified as held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X.

New Financial Accounting Standa

New Financial Accounting Standards	12 Months Ended
	Dec. 31, 2022
Accounting Changes and Error Corrections [Abstract]
New Financial Accounting Standards	New Financial Accounting Standards In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting (ASU 2020-04). In 2017, the United Kingdom’s Financial Conduct Authority announced that it intends to stop persuading or compelling banks to submit the London Interbank Offered Rate (LIBOR), a benchmark interest rate referenced in a variety of agreements, after 2021. The United Kingdom's Financial Conduct Authority ceased publication of U.S. Dollar LIBOR after December 31, 2021 for one-week and two-month U.S. Dollar LIBOR tenors, and expects to cease publishing after June 30, 2023 for all other U.S. Dollar LIBOR tenors. ASU 2020-04 provides entities with optional expedients and exceptions for applying generally accepted accounting principles to contract modifications and hedging relationships, subject to meeting certain criteria, that reference LIBOR or another reference rate expected to be discontinued. In January 2021, the FASB issued amendments to the guidance through ASU 2021-01 to include all contract modifications and hedging relationships affected by reference rate reform, including those that do not directly reference LIBOR or another reference rate expected to be discontinued, and clarify which optional expedients may be applied to them. As the Companies continue to modify contracts that contain references to LIBOR that allow for the use of an alternative rate, they have applied the practical expedient to not assess each change for a contract modification. The guidance can be applied prospectively. The optional relief is temporary and generally cannot be applied to contract modifications and hedging relationships entered into or evaluated after December 31, 2024, which date reflects the updates in ASU 2022-06, Reference Rate Reform (Topic 848): Deferral of the Sunset Date of Topic 848. The Companies do not expect the guidance to have a material impact on their financial position, results of operations or liquidity. In December 2021, the FASB issued amendments to the guidance on accounting for government assistance through ASU 2021-10, Government Assistance (Topic 832): Disclosures by Business Entities about Government Assistance. The amendments require that business entities that apply a grant or contribution model by analogy to other accounting guidance disclose 1) the types of assistance, 2) an entity’s accounting for the assistance, and 3) the effect of the assistance on an entity’s financial statements. For public entities, the amendments are effective for reporting periods beginning after December 15, 2021. Early adoption is permitted. The Companies have concluded the new guidance does not have a material impact on the Companies’ financial position, results of operations and liquidity.

Dispositions

Dispositions	12 Months Ended
	Dec. 31, 2022
Discontinued Operations and Disposal Groups [Abstract]
Dispositions	Dispositions Crane and Coram In April 2021, a subsidiary of the Clean Energy Businesses entered into an agreement to sell substantially all of its membership interests in a renewable electric project that it developed and also all of its membership interests in a renewable electric project that it acquired in 2016. The sales were completed in June 2021. The combined carrying value of both projects was approximately $192 million in June 2021. The net pre-tax gain on the sales was $3 million ($2 million after-tax) and was included within "Other operations and maintenance" on Con Edison's consolidated income statement for the year ended December 31, 2021. The retained portion of the membership interest in the renewable electric project, of $11 million, was calculated based on a discounted cash flow of future projected earnings, and the retained portion is accounted for as an equity method investment. The portion of the gain attributable to the retained portion of the membership interest was not material for the year ended December 31, 2021. See Note S. The Clean Energy Businesses were held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X. Stagecoach Gas Services In 2021, a subsidiary of Con Edison Gas Pipeline and Storage, LLC (CET) and its joint venture partner agreed to sell their combined interests in Stagecoach Gas Services LLC (Stagecoach) for a total of $1,225 million, of which $629 million, including closing adjustments, was attributed to CET for its 50 percent interest. The purchase and sale agreement provided for a two-stage closing, the first of which was completed in July 2021 and the second of which was completed in November 2021. See "Investments - Partial Impairment of Investment in Stagecoach Gas Services LLC (Stagecoach)" in Note A. 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 the Clean Energy Businesses to RWE Renewables Americas, LLC, a subsidiary of RWE Aktiengesellschaft (RWE) for a total of $6,800 million, subject to closing adjustments. The purchase price will be 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) upward or downward to the extent that the net working capital varies from a set target, (v) upward or downward to the extent that capital expenditures incurred prior to the closing of the transaction vary from a set budget, and (vi) downward by the value allocated to certain assets and projects that are not able to be conveyed to RWE upon closing of the transaction. The purchase and sale agreement includes certain customary representations, warranties and covenants. The transaction is subject to customary closing conditions, including, among other things: expiration of the waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended, which occurred on November 28,2022; approval from the FERC under Section 203 of the Federal Power Act, which was obtained on January 20, 2023, and approval by the Committee on Foreign Investment in the United States, which was obtained on February 6, 2023. The transaction is expected to close on or about the end of the first quarter of 2023. Con Edison will retain the Clean Energy Businesses' tax equity interest in the Crane Solar project and its anticipated tax equity interest in two solar projects located in VA. These tax equity partnerships produce renewable energy tax credits that can be used to reduce Con Edison’s federal income tax in the year in which the projects are placed in service. These tax credits would be subject to recapture, in whole or in part, if the assets were 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. Con Edison will retain 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 deferred investment tax credits and accumulated amortized investment tax credits of the Clean Energy Businesses will be recognized in full upon the completion of the sale of the Clean Energy Businesses. In addition, certain projects where required transaction consents have not been obtained as of the closing of the transaction (see above) will be transferred to a Con Edison subsidiary and will be sold to RWE if and when consents to the sale have been obtained. Concurrent with entering into the purchase and sale agreement, Con Edison incurred costs in the normal course of the sale process. A majority of the expected transaction costs of approximately $70 million ($49 million after-tax) were recorded in 2022. Also, as described in Note A, depreciation and amortization expense of approximately $61 million ($42 million after-tax) were not recorded on the assets of the Clean Energy Businesses in the fourth quarter of 2022 and will continue to not be recorded through the closing of the transaction. Further, since the Clean Energy Businesses were classified as held for sale as of December 31, 2022 and the transaction is expected to close on or about the end of the first quarter of 2023 , Con Edison analyzed the potential impact of the anticipated sale on its state apportionment factors. Based on current estimates, Con Edison recorded an increase to its net deferred income tax liabilities and valuation allowance of $111 million and $10 million, respectively, and corresponding deferred income tax expense of approximately $121 million (net of federal income taxes) in the fourth quarter of 2022. The following table shows the pre-tax operating income for the Clean Energy Businesses for the years ended December 31, 2022, 2021 and 2020. Clean Energy Businesses (Millions of Dollars) 2022 2021 2020 Pre-tax operating income $466 $310 $68 Pre-tax operating income, excluding non-controlling interest 406 158 23 The Clean Energy Business represent a reportable segment. See Note P. At December 31, 2022, the carrying amounts of the major classes of assets and liabilities of the Clean Energy Businesses that are expected to be sold are presented on a held-for-sale basis, and accordingly exclude certain intercompany and net deferred tax liability balances, as follows : (Millions of Dollars) December 31, ASSETS CURRENT ASSETS Cash and temporary cash investments $25 Accounts receivable and other receivables - net allowance for uncollectible accounts 319 Accrued unbilled revenue 51 Fuel oil, gas in storage, materials and supplies, at average cost 56 Restricted cash 223 Fair value of derivatives assets 84 Prepayments 35 Other current assets 24 TOTAL CURRENT ASSETS 817 NON-UTILITY PLANT Non-utility property, net accumulated depreciation 4,197 Construction work in progress 522 NET PLANT 4,719 OTHER NONCURRENT ASSETS Goodwill 31 Intangible assets, less accumulated amortization 1,222 Operating lease right-of-use asset 266 Fair value of derivatives assets 93 Other deferred charges and noncurrent assets 14 TOTAL OTHER NONCURRENT ASSETS 1,626 TOTAL ASSETS $7,162 (a) Not included in the fair value of derivative assets above is $2 million related to an intercompany amount with CECONY, which amount is eliminated in consolidation. See Note U as that amount is governed by derivative agreements, it will remain an asset of the Clean Energy Businesses following the expected close of the sale transaction. (Millions of Dollars) December 31, LIABILITIES CURRENT LIABILITIES Long-term debt due within one year $353 Term loan 150 Accounts payable 326 Operating lease liabilities 33 Accrued Interest 40 Other current liabilities 71 TOTAL CURRENT LIABILITIES 973 NONCURRENT LIABILITIES Asset retirement obligations 77 Operating lease liabilities 248 Other deferred credits and noncurrent liabilities 20 TOTAL NONCURRENT LIABILITIES 345 LONG-TERM DEBT 2,292 TOTAL LIABILITIES $3,610

Held-for-Sale Treatment of the

Held-for-Sale Treatment of the Clean Energy Businesses	12 Months Ended
	Dec. 31, 2022
Discontinued Operations and Disposal Groups [Abstract]
Held-for-Sale Treatment of the Clean Energy Businesses	Dispositions Crane and Coram In April 2021, a subsidiary of the Clean Energy Businesses entered into an agreement to sell substantially all of its membership interests in a renewable electric project that it developed and also all of its membership interests in a renewable electric project that it acquired in 2016. The sales were completed in June 2021. The combined carrying value of both projects was approximately $192 million in June 2021. The net pre-tax gain on the sales was $3 million ($2 million after-tax) and was included within "Other operations and maintenance" on Con Edison's consolidated income statement for the year ended December 31, 2021. The retained portion of the membership interest in the renewable electric project, of $11 million, was calculated based on a discounted cash flow of future projected earnings, and the retained portion is accounted for as an equity method investment. The portion of the gain attributable to the retained portion of the membership interest was not material for the year ended December 31, 2021. See Note S. The Clean Energy Businesses were held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X. Stagecoach Gas Services In 2021, a subsidiary of Con Edison Gas Pipeline and Storage, LLC (CET) and its joint venture partner agreed to sell their combined interests in Stagecoach Gas Services LLC (Stagecoach) for a total of $1,225 million, of which $629 million, including closing adjustments, was attributed to CET for its 50 percent interest. The purchase and sale agreement provided for a two-stage closing, the first of which was completed in July 2021 and the second of which was completed in November 2021. See "Investments - Partial Impairment of Investment in Stagecoach Gas Services LLC (Stagecoach)" in Note A. 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 the Clean Energy Businesses to RWE Renewables Americas, LLC, a subsidiary of RWE Aktiengesellschaft (RWE) for a total of $6,800 million, subject to closing adjustments. The purchase price will be 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) upward or downward to the extent that the net working capital varies from a set target, (v) upward or downward to the extent that capital expenditures incurred prior to the closing of the transaction vary from a set budget, and (vi) downward by the value allocated to certain assets and projects that are not able to be conveyed to RWE upon closing of the transaction. The purchase and sale agreement includes certain customary representations, warranties and covenants. The transaction is subject to customary closing conditions, including, among other things: expiration of the waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended, which occurred on November 28,2022; approval from the FERC under Section 203 of the Federal Power Act, which was obtained on January 20, 2023, and approval by the Committee on Foreign Investment in the United States, which was obtained on February 6, 2023. The transaction is expected to close on or about the end of the first quarter of 2023. Con Edison will retain the Clean Energy Businesses' tax equity interest in the Crane Solar project and its anticipated tax equity interest in two solar projects located in VA. These tax equity partnerships produce renewable energy tax credits that can be used to reduce Con Edison’s federal income tax in the year in which the projects are placed in service. These tax credits would be subject to recapture, in whole or in part, if the assets were 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. Con Edison will retain 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 deferred investment tax credits and accumulated amortized investment tax credits of the Clean Energy Businesses will be recognized in full upon the completion of the sale of the Clean Energy Businesses. In addition, certain projects where required transaction consents have not been obtained as of the closing of the transaction (see above) will be transferred to a Con Edison subsidiary and will be sold to RWE if and when consents to the sale have been obtained. Concurrent with entering into the purchase and sale agreement, Con Edison incurred costs in the normal course of the sale process. A majority of the expected transaction costs of approximately $70 million ($49 million after-tax) were recorded in 2022. Also, as described in Note A, depreciation and amortization expense of approximately $61 million ($42 million after-tax) were not recorded on the assets of the Clean Energy Businesses in the fourth quarter of 2022 and will continue to not be recorded through the closing of the transaction. Further, since the Clean Energy Businesses were classified as held for sale as of December 31, 2022 and the transaction is expected to close on or about the end of the first quarter of 2023 , Con Edison analyzed the potential impact of the anticipated sale on its state apportionment factors. Based on current estimates, Con Edison recorded an increase to its net deferred income tax liabilities and valuation allowance of $111 million and $10 million, respectively, and corresponding deferred income tax expense of approximately $121 million (net of federal income taxes) in the fourth quarter of 2022. The following table shows the pre-tax operating income for the Clean Energy Businesses for the years ended December 31, 2022, 2021 and 2020. Clean Energy Businesses (Millions of Dollars) 2022 2021 2020 Pre-tax operating income $466 $310 $68 Pre-tax operating income, excluding non-controlling interest 406 158 23 The Clean Energy Business represent a reportable segment. See Note P. At December 31, 2022, the carrying amounts of the major classes of assets and liabilities of the Clean Energy Businesses that are expected to be sold are presented on a held-for-sale basis, and accordingly exclude certain intercompany and net deferred tax liability balances, as follows : (Millions of Dollars) December 31, ASSETS CURRENT ASSETS Cash and temporary cash investments $25 Accounts receivable and other receivables - net allowance for uncollectible accounts 319 Accrued unbilled revenue 51 Fuel oil, gas in storage, materials and supplies, at average cost 56 Restricted cash 223 Fair value of derivatives assets 84 Prepayments 35 Other current assets 24 TOTAL CURRENT ASSETS 817 NON-UTILITY PLANT Non-utility property, net accumulated depreciation 4,197 Construction work in progress 522 NET PLANT 4,719 OTHER NONCURRENT ASSETS Goodwill 31 Intangible assets, less accumulated amortization 1,222 Operating lease right-of-use asset 266 Fair value of derivatives assets 93 Other deferred charges and noncurrent assets 14 TOTAL OTHER NONCURRENT ASSETS 1,626 TOTAL ASSETS $7,162 (a) Not included in the fair value of derivative assets above is $2 million related to an intercompany amount with CECONY, which amount is eliminated in consolidation. See Note U as that amount is governed by derivative agreements, it will remain an asset of the Clean Energy Businesses following the expected close of the sale transaction. (Millions of Dollars) December 31, LIABILITIES CURRENT LIABILITIES Long-term debt due within one year $353 Term loan 150 Accounts payable 326 Operating lease liabilities 33 Accrued Interest 40 Other current liabilities 71 TOTAL CURRENT LIABILITIES 973 NONCURRENT LIABILITIES Asset retirement obligations 77 Operating lease liabilities 248 Other deferred credits and noncurrent liabilities 20 TOTAL NONCURRENT LIABILITIES 345 LONG-TERM DEBT 2,292 TOTAL LIABILITIES $3,610

Schedule I - Condensed Financia

Schedule I - Condensed Financial Information	12 Months Ended
	Dec. 31, 2022
Condensed Financial Information Disclosure [Abstract]
Schedule I - Condensed Financial Information	Schedule I Condensed Financial Information of Consolidated Edison, Inc. (a) (b) Condensed Statement of Income and Comprehensive Income (Parent Company Only) For the Years Ended December 31, (Millions of Dollars, except per share amounts) 2022 2021 2020 Equity in earnings of subsidiaries $1,860 $1,369 $1,105 Other operating and maintenance expenses (1) (1) (1) Taxes other than income taxes (7) (6) (12) Other income (deductions) (31) 14 33 Interest expense (32) (37) (60) Income tax expense (benefit) (129) 7 36 Net Income $1,660 $1,346 $1,101 Comprehensive Income $1,677 $1,376 $1,095 Net Income Per Share – Basic $4.68 $3.86 $3.29 Net Income Per Share – Diluted $4.66 $3.85 $3.28 Dividends Declared Per Share $3.16 $3.10 $3.06 Average Number Of Shares Outstanding—Basic (In Millions) 354.5 348.4 334.8 Average Number Of Shares Outstanding—Diluted (In Millions) 355.8 349.4 335.7 (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. (b) Certain prior period amounts have been reclassified to conform with current period presentation. Condensed Financial Information of Consolidated Edison, Inc. (a) (c) Condensed Statement of Cash Flows (Parent Company Only) For the Years Ended December 31, (Millions of Dollars) 2022 2021 2020 Net Income $1,660 $1,346 $1,101 Equity in earnings of subsidiaries (1,860) (1,369) (1,105) Deferred income taxes 163 119 32 Dividends received from: CECONY 978 988 982 O&R 57 52 49 Clean Energy Businesses 98 64 21 Con Edison Transmission 1 152 11 Change in Assets and Liabilities: Accounts receivable from affiliated companies (138) 57 (386) Accrued taxes to affiliated companies (1) (1) (78) Accounts payable to affiliated companies 1 1 — Other – net (b) 56 50 (89) Net Cash Flows from Operating Activities (b) 1,015 1,459 538 Investing Activities Contributions to subsidiaries (150) (1,135) (626) Debt receivable from affiliated companies — 875 400 Net Cash Flows Used in Investing Activities (150) (260) (226) Financing Activities Net proceeds of short-term debt 632 50 (537) Issuance of long-term debt — — 650 Retirement of long-term debt (b) (293) (1,178) (3) Debt issuance costs — (1) (3) Issuance of common shares for stock plans, net of repurchases 57 60 58 Issuance of common shares - public offering — 775 640 Common stock dividends (1,089) (1,030) (975) Net Cash Flows Used in Financing Activities (b) (693) (1,324) (170) Net Change for the Period 172 (125) 142 Balance at Beginning of Period 19 144 2 Balance at End of Period $191 $19 $144 (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. (b) During 2021, Con Edison identified that the reclassification of debt from long-term to current for the year ended December 31, 2020 had been erroneously presented within the operating cash flow section as a cash inflow and in the financing section as a cash outflow in the Condensed Statement of Cash Flows (Parent Company Only). The amounts for the year ended December 31, 2020 have been revised to correct the error in the classification of $1,175 million from Other - net within Net Cash Flows from Operating Activities to Retirement of long-term debt within Net Cash Flows Used in Financing Activities. Con Edison has evaluated the effect of these misstatements, both qualitatively and quantitatively, and concluded that they are not material to the financial statements issued for the year ended December 31, 2020. These amounts were correctly presented on the Consolidated Statement of Cash Flows for the year ended December 31, 2020. (c) Certain prior period amounts have been reclassified to conform with current period presentation. Condensed Financial Information of Consolidated Edison, Inc. (a) (b) Condensed Balance Sheet (Parent Company Only) December 31, (Millions of Dollars) 2022 2021 Assets Current Assets Cash and temporary cash investments $191 $19 Other receivables, net allowance for uncollectible accounts 4 — Tax receivable 5 3 Accounts receivable from affiliated companies 1,337 1,199 Prepayments 9 28 Other current assets 32 14 Total Current Assets 1,578 1,263 Investments in subsidiaries and others 20,839 19,951 Goodwill 406 406 Pension and retiree benefits - asset 5 — Other deferred charges and noncurrent assets 2 8 Total Assets $22,830 $21,628 Liabilities and Shareholders’ Equity Current Liabilities Long-term debt due within one year $649 $293 Term loan 400 — Notes payable 282 50 Accounts payable 39 1 Accounts payable to affiliated companies 11 10 Accrued taxes 7 2 Accrued taxes to affiliated companies 506 507 Accrued interest 7 2 Other current liabilities 7 7 Total Current Liabilities 1,908 872 Deferred income taxes and unamortized investment tax credits 235 72 Long-term debt — 647 Total Liabilities 2,143 1,591 Shareholders’ Equity Common stock, including additional paid-in capital 9,840 9,748 Retained earnings 10,847 10,289 Total Shareholders’ Equity 20,687 20,037 Total Liabilities and Shareholders’ Equity $22,830 $21,628 (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. (b) Certain prior period amounts have been reclassified to conform with current period presentation.

Schedule II - Valuation and Qua

Schedule II - Valuation and Qualifying Accounts	12 Months Ended
	Dec. 31, 2022
SEC Schedule, 12-09, Valuation and Qualifying Accounts [Abstract]
Schedule II - Valuation and Qualifying Accounts	Schedule II Valuation and Qualifying Accounts For the Years Ended December 31, 2022, 2021 and 2020 COLUMN C Additions Company (Millions of Dollars) COLUMN A Description COLUMN B Balance at Beginning of Period (1) Charged To Costs And Expenses (2) Charged To Other Accounts COLUMN D Deductions (b) COLUMN E Balance At End of Period Con Edison Allowance for uncollectible accounts (a): 2022 $339 $78 $80 $(165) $332 2021 $154 $83 $— $102 $339 2020 $74 $72 $— $8 $154 CECONY Allowance for uncollectible accounts (a): 2022 $323 $74 $80 $(156) $321 2021 $143 $78 $— $102 $323 2020 $68 $65 $— $10 $143 (a) This is a valuation account deducted in the balance sheet from the assets (Accounts receivable - customers and Other receivables) to which they apply. (b) Accounts written off less cash collections, miscellaneous adjustments and amounts reinstated as receivables previously written off.

Summary of Significant Accoun_2

Summary of Significant Accounting Policies and Other Matters (Policies)	12 Months Ended
	Dec. 31, 2022
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, 2022 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 NY 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 5.2 percent, 4.5 percent and 5.2 percent for 2022, 2021 and 2020, respectively. The AFUDC rates for O&R were 5.0 percent, 4.8 percent and 5.3 percent for 2022, 2021 and 2020, 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 3.5 percent for 2022 and 3.5 percent for 2021 and 3.5 percent for 2020. The average depreciation rates for O&R were 3.0 percent for 2022, 3.1 percent for 2021 and 3.2 percent for 2020. The estimated lives for utility plant for CECONY range from 5 to 80 years for electric, 5 to 90 years for gas, 5 to 80 years for steam and 5 to 55 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. For Con Edison, non-utility plant consists 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, respectively. The Clean Energy Businesses were classified as held for sale as of December 31, 2022, and depreciation on their assets was not recorded for the three months ended December 31, 2022. See "Assets and Liabilities Held for Sale" below, and Note X. 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 market 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. 2021 Partial Impairment of Investment in Stagecoach Gas Services LLC (Stagecoach) In May 2021, a subsidiary of Con Edison Gas Pipeline and Storage, LLC (CET) entered into a purchase and sale agreement pursuant to which the subsidiary and its joint venture partner agreed to sell their combined interests in Stagecoach Gas Services LLC (Stagecoach) for a total of $1,225 million, of which $629 million was attributed to CET for its 50 percent interest. The purchase and sale agreement contemplated a two-stage closing, the first of which was completed in July 2021 and the second of which was completed in November 2021. As a result of information made available to Stagecoach as part of the sale process, Stagecoach performed impairment tests that resulted in Stagecoach recording impairment charges of $414 million for the year ended December 31, 2021. Accordingly, Con Edison recorded pre-tax impairment losses on its 50 percent interest in Stagecoach of $212 million ($147 million after-tax), including working capital and transaction cost adjustments, within "Investment income/(loss)" on Con Edison's consolidated income statement for the year ended December 31, 2021. Stagecoach’s impairment charges and information obtained from the sales process constituted triggering events for Con Edison's investment in Stagecoach as of March 31, 2021 and June 30, 2021. Con Edison evaluated the carrying value of its investment in Stagecoach for other-than-temporary declines in value using income and market-based approaches. Con Edison determined that the carrying value of its investment in Stagecoach of $667 million and $630 million as of March 31, 2021 and June 30, 2021, respectively, was not impaired. The carrying value of $630 million at June 30, 2021 reflected the final sales price received in July and the remaining amount received in November 2021, including closing adjustments. CET had no remaining investment in Stagecoach as of December 31, 2021 and 2022. 2020 and 2021 Partial Impairments of Investment in Mountain Valley Pipeline, LLC (MVP) In January 2016, Con Edison Gas Pipeline and Storage, LLC (CET), an indirect subsidiary of Con Edison, acquired a 12.5 percent equity interest in MVP, a company developing a proposed 300-mile gas transmission project (the Project) in WV and VA. During 2019, Con Edison exercised its right to limit, and did limit, its cash contributions to the joint venture to approximately $530 million, which reduced CET's interest in MVP to 11.3 percent and 10.2 percent as of December 31, 2020 and 2021, respectively. As of December 31, 2022 CET's interest in MVP is 9.6 percent and is expected to be reduced to 8.0 percent based on the Project's current cost estimate and CET's previous capping of its cash contributions. As of December 31, 2021 and 2022, the Project was approximately 94 percent complete. During 2020, progress was made on the construction of the Project, and the U.S. Supreme Court issued favorable decisions in cases unrelated to MVP regarding the permitting process for pipeline construction and water crossings. In November 2020, the U.S. Court of Appeals for the Fourth Circuit issued a stay on the Nationwide Permit 12, effectively blocking the Project’s ability to pursue water crossings under that permit. As a result, in November 2020 the Project applied to the FERC for a certificate amendment to bore under water bodies in a portion of the Project in WV, allowing this portion of the pipe to be completed and placed in-service while a plan for the remaining water crossings was pursued. If approved, this certificate amendment would have led to additional Project costs and would have extended the anticipated in-service date. In January 2021, the FERC did not approve the requested certificate amendment. Later in January 2021, the Project indicated its plans to apply for U.S. Army Corps of Engineers individual permits for certain water crossings and a new certificate amendment application to the FERC to bore under other water crossings that, in total, would cover the entire Project length. The uncertainty related to obtaining necessary water crossing permits, the resulting Project costs and the likelihood of the Project not reaching eventual completion increased as a result of actions taken by the U.S. Court of Appeals for the Fourth Circuit. This action and associated delays constituted a triggering event (the "2020 triggering event") that required Con Edison to test its investment in MVP for an other-than-temporary impairment as of December 31, 2020. In December 2021, the VA Department of Environmental Quality and the WV Department of Environmental Protection both issued water quality certification permits which are required in order for the U.S. Army Corps of Engineers to proceed with the permitting process for construction of certain Project water crossings. In January 2022, the U.S. Court of Appeals for the Fourth Circuit rejected permits for crossings through the Jefferson National Forest issued by the U.S. Forest Service and Bureau of Land Management. In February 2022, the U.S. Court of Appeals for the Fourth Circuit vacated a biological opinion from the U.S. Fish and Wildlife Service, applicable to all remaining construction. The biological opinion had been issued and was the subject of litigation prior to December 31, 2021. Con Edison believed that the February 2022 action by the U.S. Court of Appeals for the Fourth Circuit, along with the potential outcome of other matters pending before that Court, may lead to further delays and increased Project costs, which constituted a triggering event (the “2021 triggering event”) that required Con Edison to test its investment in MVP for an other-than-temporary impairment as of December 31, 2021. In response to the 2020 triggering event and 2021 triggering event, Con Edison assessed the value of its equity investment in the Project to determine whether the fair value of its investment in MVP had declined below its carrying value on an other-than-temporary basis as of December 31, 2020 and 2021, respectively. The estimated fair value of the investment was determined using a discounted cash flow analysis, which is a level 3 fair value measurement. The analysis discounted probability-weighted future cash flows, including revenues based on long-term firm transportation contracts, that are secured for the first 20 years following completion of the Project. See Note U. Con Edison has also assumed cash flows extending beyond this period. All cash flows were discounted at a pre-tax discount rate of 8.3 percent and then weighted based on Con Edison’s estimate of the likelihood that the Project will be completed. For the 2020 triggering event, Con Edison estimated that the likelihood of Project completion was in the upper end of a reasonably possible range. For the 2021 triggering event, Con Edison anticipated that the Project faces legal and regulatory challenges that make construction completion increasingly remote. The Project faces additional delays and increased costs that could further reduce CET's interest in MVP to below 8 percent based on CET's previous capping of its cash contributions. The likelihood that the Project will be completed and, for 2020, the discount rate, are the most significant and sensitive assumptions; changes in these assumptions may materially change the results of the impairment calculation. Based on the discounted cash flow analyses, Con Edison concluded as of December 31, 2020 and 2021 that the fair value of its investment in MVP declined below its carrying value and the declines were other-than-temporary. Accordingly, Con Edison recorded a pre-tax impairment loss of $320 million ($223 million, after tax) for the year ended December 31, 2020 that reduced the carrying value of its investment in MVP from $662 million to $342 million, with an associated deferred tax asset of $53 million. Additionally, Con Edison recorded a pre-tax impairment loss of $231 million ($162 million, after tax) for the year ended December 31, 2021 that reduced the carrying value of its investment in MVP from $342 million to $111 million, with an additional $77 million associated deferred tax asset, totaling a deferred tax asset of $130 million at December 31, 2021 and 2022. The impairments were recorded within “Investment income (loss)” on Con Edison’s Consolidated Income Statement. In addition, Con Edison did not record non-cash equity in earnings from allowance for funds used during construction from MVP beginning in January 2021 and will continue to refrain from recording such amounts until such time as substantial construction activities resume, which would be indicative of probable Project completion. There were no impairments or substantial changes in the carrying value of Con Edison's investment in MVP for the year ended December 31, 2022. There is risk that the fair value of Con Edison’s investment in MVP may be further or fully impaired in the future. There are ongoing legal and regulatory matters that must be resolved favorably before the Project can be completed. Assumptions and estimates used to test Con Edison’s investment in MVP for impairment may change if adverse or delayed resolutions to the Project’s pending legal and regulatory challenges were to occur, which could have a material adverse effect on the fair value of Con Edison’s investment in 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.
Research and Development Costs	Research and Development CostsResearch and development costs are charged to operating expenses as incurred.
Reclassification	Reclassification Certain prior period amounts have been reclassified within the Companies' Consolidated Statements of Cash Flows and Consolidated Balance Sheets to conform with current period presentation.
Earnings Per Common Share	Earnings Per Common 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 March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting (ASU 2020-04). In 2017, the United Kingdom’s Financial Conduct Authority announced that it intends to stop persuading or compelling banks to submit the London Interbank Offered Rate (LIBOR), a benchmark interest rate referenced in a variety of agreements, after 2021. The United Kingdom's Financial Conduct Authority ceased publication of U.S. Dollar LIBOR after December 31, 2021 for one-week and two-month U.S. Dollar LIBOR tenors, and expects to cease publishing after June 30, 2023 for all other U.S. Dollar LIBOR tenors. ASU 2020-04 provides entities with optional expedients and exceptions for applying generally accepted accounting principles to contract modifications and hedging relationships, subject to meeting certain criteria, that reference LIBOR or another reference rate expected to be discontinued. In January 2021, the FASB issued amendments to the guidance through ASU 2021-01 to include all contract modifications and hedging relationships affected by reference rate reform, including those that do not directly reference LIBOR or another reference rate expected to be discontinued, and clarify which optional expedients may be applied to them. As the Companies continue to modify contracts that contain references to LIBOR that allow for the use of an alternative rate, they have applied the practical expedient to not assess each change for a contract modification. The guidance can be applied prospectively. The optional relief is temporary and generally cannot be applied to contract modifications and hedging relationships entered into or evaluated after December 31, 2024, which date reflects the updates in ASU 2022-06, Reference Rate Reform (Topic 848): Deferral of the Sunset Date of Topic 848. The Companies do not expect the guidance to have a material impact on their financial position, results of operations or liquidity. In December 2021, the FASB issued amendments to the guidance on accounting for government assistance through ASU 2021-10, Government Assistance (Topic 832): Disclosures by Business Entities about Government Assistance. The amendments require that business entities that apply a grant or contribution model by analogy to other accounting guidance disclose 1) the types of assistance, 2) an entity’s accounting for the assistance, and 3) the effect of the assistance on an entity’s financial statements. For public entities, the amendments are effective for reporting periods beginning after December 15, 2021. Early adoption is permitted. The Companies have concluded the new guidance does not have a material impact on the Companies’ 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, 2022
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) 2022 2021 2020 Con Edison $400 $358 $323 CECONY 387 346 312
Capitalized Cost of Utility Plant	At December 31, 2022 and 2021, the capitalized cost of the Companies’ utility plant, net of accumulated depreciation, was as follows: Con Edison CECONY (Millions of Dollars) 2022 2021 2022 2021 Electric Generation $534 $559 $534 $559 Transmission 4,223 3,955 3,916 3,658 Distribution 23,345 22,418 22,130 21,240 General 113 87 113 87 Gas (a) 11,326 10,473 10,567 9,748 Steam 1,962 1,924 1,962 1,924 General 2,648 2,566 2,410 2,338 Held for future use 117 80 109 72 Construction work in progress 2,484 2,152 2,268 1,985 Net Utility Plant $46,752 $44,214 $44,009 $41,611 (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) 2022 2021 2022 2021 Prepayments (a)(b) $24 $16 $23 $15 Other Deferred Charges and Noncurrent Assets (a)(b) 105 81 103 78 (a) Depreciation on these assets is computed using the straight-line method for financial statement purposes over their estimated useful lives. (b) Depreciation expense related to these assets incurred during the year ended December 31, 2022 for Con Edison and CECONY was $15 million and $14 million, respectively, and for the year ended December 31, 2021 for Con Edison and CECONY was $12 million and $11 million , respectively. Accumulated depreciation related to these assets for Con Edison and CECONY was $37 million and $33 million, respectively at December 31, 2022 and was $22 million and $19 million, respectively at December 31, 2021.
Schedule of Investment Assets	The following investment assets are included in the Companies' consolidated balance sheets at December 31, 2022 and 2021: Con Edison CECONY (Millions of Dollars) 2022 2021 2022 2021 CET investment in Mountain Valley Pipeline, LLC (a) $111 $111 $— $— Supplemental retirement income plan assets (b) 459 525 439 499 Deferred income plan assets 93 102 93 102 CET investment in New York Transco, LLC (c) 176 112 — — Other 2 3 7 7 Total investments $841 $853 $539 $608 (a) At December 31, 2022 and 2021, CET's cash investment in MVP was $530 million. In May 2021, the operator of the Mountain Valley Pipeline indicated that, subject to receipt of certain authorizations and resolution of certain challenges, it is targeting an in-service date for the project of the second half of 2023 at an overall project cost of approximately $6,600 million excluding allowance for funds used during construction. See "2020 and 2021 Partial Impairments of Investment in Mountain Valley Pipeline, LLC (MVP)" above. (b) See Note E.
Research and Development Costs	Research and development costs were as follows: For the Years Ended December 31, (Millions of Dollars) 2022 2021 2020 Con Edison $27 $25 $24 CECONY 25 24 23
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) 2022 2021 2020 Net income for common stock $1,660 $1,346 $1,101 Weighted average common shares outstanding – basic 354.5 348.4 334.8 Add: Incremental shares attributable to effect of potentially dilutive securities 1.3 1.0 0.9 Adjusted weighted average common shares outstanding – diluted 355.8 349.4 335.7 Net Income per common share – basic $4.68 $3.86 $3.29 Net Income per common share – diluted $4.66 $3.85 $3.28
Changes in Accumulated Other Comprehensive Income/(Loss)	Changes to accumulated other comprehensive income/(loss) (OCI) for Con Edison and CECONY are as follows: (Millions of Dollars) Con Edison CECONY Accumulated OCI, net of taxes, at December 31, 2019 (a) $(19) $(6) OCI before reclassifications, net of tax of $4 and $1 for Con Edison and CECONY, respectively (11) (3) Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(2) for Con Edison (a)(b) 5 2 Total OCI, net of taxes, at December 31, 2020 (6) (1) Accumulated OCI, net of taxes, at December 31, 2020 (a) $(25) $(7) OCI before reclassifications, net of tax of $(8) and $(2) for Con Edison and CECONY, respectively 22 5 Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(3) and $(1) for Con Edison and CECONY, respectively (a)(b) 8 2 Total OCI, net of taxes, at December 31, 2021 30 7 Accumulated OCI, net of taxes, at December 31, 2021 (a) $5 $— OCI before reclassifications, net of tax of $(5) and $(1) for Con Edison and CECONY, respectively 13 3 Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(1) and for Con Edison (a)(b) 4 1 Total OCI, net of taxes, at December 31, 2022 17 4 Accumulated OCI, net of taxes, at December 31, 2022 (a) $22 $4 (a) Tax reclassified from accumulated OCI is reported in the income tax expense line item of the consolidated income statement. (b) For the portion of unrecognized pension and other postretirement benefit costs relating to the Utilities, costs are recorded into, and amortized out of, regulatory assets and liabilities instead of OCI. The net actuarial losses and prior service costs recognized during the period are included in the computation of total periodic pension and other postretirement benefit cost. See Notes E and F.
Restrictions on Cash and Cash Equivalents	At December 31, 2022 and 2021, cash, temporary cash investments and restricted cash for Con Edison and CECONY were as follows: At December 31, Con Edison CECONY (Millions of Dollars) 2022 2021 2022 2021 Cash and temporary cash investments $1,282 $992 $1,056 $920 Restricted cash (a) 223 154 — — Total cash, temporary cash investments and restricted cash $1,505 $1,146 $1,056 $920 (a) Restricted cash included cash of the Clean Energy Businesses' renewable electric project subsidiaries ($223 million and $154 million at December 31, 2022 and 2021, respectively) that, under the related project debt agreements, is restricted to being used for normal operating expenditures, debt service, and required reserves until the various maturity dates of the project debt. The Clean Energy Businesses were classified as held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale," below, and Note X. Accordingly, the restricted cash of the Clean Energy Businesses is shown in "Assets Held for Sale" on Con Edison's consolidated balance sheet for 2022.
Schedule of Cash and Cash Equivalents	At December 31, 2022 and 2021, cash, temporary cash investments and restricted cash for Con Edison and CECONY were as follows: At December 31, Con Edison CECONY (Millions of Dollars) 2022 2021 2022 2021 Cash and temporary cash investments $1,282 $992 $1,056 $920 Restricted cash (a) 223 154 — — Total cash, temporary cash investments and restricted cash $1,505 $1,146 $1,056 $920 (a) Restricted cash included cash of the Clean Energy Businesses' renewable electric project subsidiaries ($223 million and $154 million at December 31, 2022 and 2021, respectively) that, under the related project debt agreements, is restricted to being used for normal operating expenditures, debt service, and required reserves until the various maturity dates of the project debt. The Clean Energy Businesses were classified as held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale," below, and Note X. Accordingly, the restricted cash of the Clean Energy Businesses is shown in "Assets Held for Sale" on Con Edison's consolidated balance sheet for 2022.

Regulatory Matters (Tables)

Regulatory Matters (Tables)	12 Months Ended
	Dec. 31, 2022
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 (a) January 2023 – December 2025 (l) Base rate changes Yr. 1 – $113 million (b) Yr. 2 – $370 million (b) Yr. 3 – $326 million (b) Yr. 1 – $442 million (d) Yr. 2 – $518 million (d) Yr. 3 – $382 million (d) Amortizations to income of net regulatory (assets) and liabilities Yr. 1 – $267 million (c) Yr. 2 – $269 million (c) Yr. 3 – $272 million (c) Yr. 1 – $104 million (k) Yr. 2 – $49 million (k) Yr. 3 – $-205 million (k) 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 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. 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 Regulatory reconciliations Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (g). 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 (j) and expenses for uncollectibles, pension and other postretirement benefits, variable-rate debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (g). 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 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 (i) (j) Yr. 1 – 8.5 percent Yr. 2 – 8.03 percent Yr. 3 – 8.41 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. 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) In January 2020, the NYSPSC approved the October 2019 Joint Proposal for CECONY's electric rate plan for January 2020 through December 2022. If at the end of any semi-annual period ending June 30 and December 31, Con Edison’s investments in its non-utility businesses exceed 15 percent of its total consolidated revenues, assets or cash flow, or if the ratio of holding company debt to total consolidated debt rises above 20 percent, CECONY is required to notify the NYSPSC and submit a ring-fencing plan or a demonstration why additional ring-fencing measures (see Note U) are not necessary. (b) 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. (c) 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). (d) 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 will be effective as of January 1, 2023. CECONY will begin billing customers at the new levelized rate once the Joint Proposal is approved by the NYSPSC. Any shortfall in revenues due to the timing of billing to customers will be collected throu gh a surcharge billed through 2024, includin g 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. (e) 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: reflected in the January 2020 - December 2022 rate plan Yr 1 - 10.0 basis points; Yr 2 - 7.5 basis points; and Yr 3 - 5.0 basis points; reflected in the January 2023 - December 2025 Yr 1 - 10.0 basis points; Yr 2 - 5.0 basis points; and Yr 3 - 5.0 basis points, (f) 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. (g) In addition, the NYSPSC staff continues its focused operations audit to investigate CECONY's income tax accounting. Any NYSPSC ordered adjustment to CECONY’s income tax accounting is expected to be refunded to or collected from customers, as determined by the NYSPSC. See "Other Regulatory Matters," below. (h) Reconciliation of net utility plant for AMI will be done on a combined basis for electric and gas. (i) Calculated in accordance with the earnings calculation method prescribed in the rate order. (j) 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. (k) 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 ($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). (l) The February 2023 Joint Proposal is subject to NYSPSC approval. CECONY – Gas Effective period January 2020 – December 2022 (a) January 2023 – December 2025 (l) Base rate changes Yr. 1 – $84 million (b) Yr. 2 – $122 million (b) Yr. 3 – $167 million (b) Yr. 1 – $217 million (d) Yr. 2 – $173 million (d) Yr. 3 – $122 million (d) Amortizations to income of net Yr. 1 – $45 million (c) Yr. 2 – $43 million (c) Yr. 3 – $10 million (c) Yr. 1 – $31 million (k) Yr. 2 – $24 million (k) Yr. 3 – $(11) million (k) 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 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. 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 Regulatory reconciliations Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (g). 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 (j) and expenses for uncollectibles, pension and other postretirement benefits, variable-rate debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (g). 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 (h): 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 (h): Yr. 1 - $234 million CSS: Yr. 1 - $2 million 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 (i) (j) Yr. 1 – 8.4 percent Yr. 2 – 8.48 percent Yr. 3 – 8.93 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. 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) In January 2020, the NYSPSC approved the October 2019 Joint Proposal for CECONY's gas rate plan for January 2020 through December 2022. If at the end of any semi-annual period ending June 30 and December 31, Con Edison’s investments in its non-utility businesses exceed 15 percent of its total consolidated revenues, assets or cash flow, or if the ratio of holding company debt to total consolidated debt rises above 20 percent, CECONY is required to notify the NYSPSC and submit a ring-fencing plan or a demonstration why additional ring-fencing measures (see Note U) are not necessary. (b) 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. (c) 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) (d) 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 will be effective as of January 1, 2023. CECONY will begin billing customers at the new levelized rate once the Joint Proposal is approved by the NYSPSC. Any shortfall in revenues due to the timing of billing to customers will be collected th rough 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. (e)-(i) See footnotes (e) - (i) to the table under “CECONY Electric,” above. (j) 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. (k) Amounts reflect amortization of the 2018 tax savings under the federal Tax Cuts and Jobs Act of 2017 (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). (l) The February 2023 Joint Proposal is subject to NYSPSC approval. CECONY – Steam Effective period January 2014 – December 2016 (a) Base rate changes Yr. 1 – $(22.4) million (b) Yr. 2 – $19.8 million (b) Yr. 3 – $20.3 million (b) Yr. 4 – None Yr. 5 – None Yr. 6 – None Yr. 7 – None Yr. 8 – None Amortizations to income of net $37 million over three years Recoverable energy costs Current rate recovery of purchased power and fuel costs. Negative revenue adjustments Potential charges (up to $1 million annually) if certain steam performance targets are not met. In years 2014 through 2022, the company did not record any negative revenue adjustments. Cost reconciliations (c)(d) In 2014, 2015, 2016, 2017, 2018, 2019, 2020, 2021 and 2022, 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 and $11 million of net regulatory assets, respectively. 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 million 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. Average rate base Yr. 1 – $1,511 million Yr. 2 – $1,547 million Yr. 3 – $1,604 million Weighted average cost of capital (after-tax) Yr. 1 – 7.10 percent Yr. 2 – 7.13 percent Yr. 3 – 7.21 percent Authorized return on common equity 9.3 percent Actual return on common equity (e) 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 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 and 2022, 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. Cost of long-term debt Yr. 1 – 5.17 percent Yr. 2 – 5.23 percent Yr. 3 – 5.39 percent Common equity ratio 48 percent (a) Rates determined pursuant to this rate plan continue in effect until a new rate plan is approved by the NYSPSC. (b) The impact of these base rate changes was deferred which resulted in an $8 million regulatory liability at December 31, 2016. (c) 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. (d) In addition, the NYSPSC staff has commenced a focused operations audit to investigate CECONY’s income tax accounting. Any NYSPSC ordered adjustment to CECONY’s income tax accounting is expected to be refunded to or collected from customers, as determined by the NYSPSC. CECONY’s historical inadvertent understatement of its calculation of total federal income tax expense for ratemaking purposes has not been addressed in the current steam rate plan. See "Other Regulatory Matters," below. (e) Calculated in accordance with the earnings calculation method prescribed in the rate order. O&R New York – Electric Effective period (a) January 2019 – December 2021 January 2022 – December 2024 Base rate changes Yr. 1 – $13.4 million (b) Yr. 2 – $8.0 million (b) Yr. 3 – $5.8 million (b) Yr. 1 – $4.9 million (i) Yr. 2 – $16.2 million (i) Yr. 3 – $23.1 million (i) Amortizations to income of net Yr. 1 – $(1.5) million (c) Yr. 2 – $(1.5) million (c) Yr. 3 – $(1.5) million (c) Yr. 1 – $11.8 million (j) Yr. 2 – $13.5 million (j) Yr. 3 – $15.2 million (j) Other revenue sources Potential earnings adjustment mechanism incentives for peak reduction, energy efficiency, Distributed Energy Resources utilization and other potential incentives of up to: Yr. 1 - $3.6 million Yr. 2 - $4.0 million Yr. 3 - $4.2 million Potential incentive if performance target related to customer service is met: $0.5 million annually. In 2019, 2020 and 2021, the company recorded $2.6 million, $1.9 million and $1.8 million of earnings adjustment mechanism incentives for energy efficiency, respectively. In 2019 and 2020, the company recorded $0.2 million and $0.5 million of incentives for customer service, respectively. In 2021, the company did not record incentives for customer service. In 2021, the company reversed the $0.5 million of incentives recorded in 2020 pursuant to the October 2021 Joint Proposal. 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 2019 and 2020, the company deferred $0.1 million and $6 million regulatory assets, respectively. In 2021, $10 million was deferred as regulatory liabilities. Continuation of reconciliation of actual to authorized electric delivery revenues. In 2022, the company deferred $6.9 million regulatory liabilities. Recoverable energy costs Continuation of current rate recovery of purchased power 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 - $4.4 million Yr. 2 - $4.4 million Yr. 3 - $4.5 million In 2019,2020 and 2021, 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 – $4.3 million Yr. 2 – $4.4 million Yr. 3 – $5.1 million In 2022, the company did not record any negative revenue adjustments. Regulatory reconciliations Reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (d), energy efficiency program (e), major storms, the impact of new laws and certain other costs to amounts reflected in rates (f). In 2019, 2020 and 2021, the company deferred $4.3 million, $30.3 million and $24 million as net regulatory assets, respectively. Reconciliation of late payment charges (l) and reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (d), energy efficiency program (k), major storms, uncollectible expenses and certain other costs to amounts reflected in rates. In 2022, the company deferred $9.4 million as net regulatory liabilities. Net utility plant reconciliations Target levels reflected in rates were: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 - $1,008 million Yr. 2 - $1,032 million Yr. 3 - $1,083 million AMI (g): Yr. 1 - $48 million Yr. 2 - $58 million Yr. 3 - $61 million The company increased regulatory asset by an immaterial amount in 2019, $0.4 million as a regulatory liability in 2020 and an immaterial amount as a regulatory liability in 2021. 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 increased regulatory asset by an immaterial amount in 2022. Average rate base Yr. 1 – $878 million Yr. 2 – $906 million Yr. 3 – $948 million Yr. 1 – $1,021 million Yr. 2 – $1,044 million Yr. 3 – $1,144 million Weighted average cost of capital (after-tax) Yr. 1 – 6.97 percent Yr. 2 – 6.96 percent Yr. 3 – 6.96 percent Yr. 1 – 6.77 percent Yr. 2 – 6.73 percent Yr. 3 – 6.72 percent Authorized return on common equity 9.0 percent 9.2 percent Actual return on common equity (h) Yr. 1 – 9.6 percent Yr. 2 – 8.76 percent Yr. 3 – 9.16 percent Yr. 1 – 8.96 percent Earnings sharing Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2019, 2020 and 2021, earnings did not exceed the earnings threshold. 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, earnings did not exceed the earnings threshold. Cost of long-term debt Yr. 1 – 5.17 percent Yr. 2 – 5.14 percent Yr. 3 – 5.14 percent Yr. 1 – 4.58 percent Yr. 2 – 4.51 percent Yr. 3 – 4.49 percent Common equity ratio 48 percent 48 percent (a) If at the end of any year, Con Edison’s investments in its non-utility businesses exceed 15 percent of Con Edison’s total consolidated revenues, assets or cash flow, or if the ratio of holding company debt to total consolidated debt rises above 20 percent, O&R is required to notify the NYSPSC and submit a ring-fencing plan or a demonstration why additional ring-fencing measures (see Note U ) are not necessary. (b) The electric base rate increases were implemented with increases of: Yr. 1 - $8.6 million; Yr. 2 - $12.1 million; and Yr. 3 - $12.2 million. (c) Reflects amortization of, among other things, the company’s net benefits under the TCJA prior to January 1, 2019, amortization of net regulatory liability for future income taxes and reduction of previously incurred regulatory assets for environmental remediation costs. Also, for electric, reflects amortization over a six year period of previously incurred incremental major storm costs. See "Other Regulatory Matters," below. (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. (e) Energy efficiency costs are expensed as incurred. Such costs are subject to a downward-only reconciliation over the terms of the electric and gas rate plans. The company will defer for the benefit of customers any cumulative shortfall over the terms of the electric and gas rate plans between actual expenditures and the levels provided in rates. (f) In addition, the NYSPSC staff has commenced a focused operations audit to investigate O&R’s income tax accounting. Any NYSPSC ordered adjustment to O&R’s income tax accounting is expected to be refunded to or collected from customers, as determined by the NYSPSC. See "Other Regulatory Matters," below. (g) Net plant reconciliation for AMI expenditures will be implemented for a single category of AMI capital expenditures that includes amounts allocated to both electric and gas customers. (h) Calculated in accordance with the earnings calculation method prescribed in the rate order. (i) The Joint Proposal recommends that these base rate changes may be implemented with increases of: Yr. 1 - $11.7 million; Yr. 2 - $11.7 million; and Yr. 3 - $11.7 million. (j) Reflects amortization of, among other things, previously incurred incremental deferred storm costs over a five-year period. See "Other Regulatory Matters," below (k) Energy efficiency costs are expensed as incurred. Such costs are subject to a cumulative reconciliation that is evenly distributed over the term of the rate plan subject to the caps set forth in the January 2020 NYSPSC New Efficiency New York (“NENY”) order. If the NYSPSC modifies O&R's NENY budgets during the rate term, such modifications will be reflected at the time of the cumulative reconciliations. (l) The rate plan includes certain COVID-19 provisions, such as: recovery of 2020 late payment charges over three years ($2.2 million); reconciliation of late payment charges to amounts reflected in rates for years 2021 through 2024, with full recovery/refund via surcharge/sur-credit once the annual variance equals or exceeds 5 basis points of return on equity; and reconciliation of write-offs of customer accounts receivable balances to amounts reflected in rates from January 1, 2020 through December 31, 2024, with full recovery/refund via surcharge/sur-credit once the annual variance equals or exceeds 5 basis points of return on equity. O&R New York – Gas Effective period (a) January 2019 – December 2021 January 2022 – December 2024 Base rate changes Yr. 1 – $(7.5) million (b) Yr. 2 – $3.6 million (b) Yr. 3 – $0.7 million (b) Yr. 1 – $0.7 million (i) Yr. 2 – $7.4 million (i) Yr. 3 – $9.9 million (i) Amortization to income of net regulatory (assets) and liabilities Yr. 1 – $1.8 million (c) Yr. 2 – $1.8 million (c) Yr.
Schedule of Regulatory Assets	Regulatory assets and liabilities at December 31, 2022 and 2021 were comprised of the following items: Con Edison CECONY (Millions of Dollars) 2022 2021 2022 2021 Regulatory assets Environmental remediation costs $991 $938 $906 $860 System peak reduction and energy efficiency programs (h) 783 285 780 284 Revenue taxes 436 395 417 378 Pension and other postretirement benefits deferrals 279 496 240 435 COVID - 19 pandemic deferrals (f) 292 282 288 277 Deferred storm costs (c) 270 276 173 158 Property tax reconciliation (g) 121 202 121 202 COVID - 19 arrears relief deferrals programs 104 — 101 — Gas service line deferred costs 99 100 99 100 MTA power reliability deferral (b) 92 140 92 140 Unrecognized pension and other postretirement costs (a) 78 128 78 110 Brooklyn Queens demand management program 33 36 33 36 Deferred derivative losses - long term 31 51 26 45 Electric vehicle make ready (j) 33 8 30 7 Municipal infrastructure support costs 29 44 29 44 Meadowlands heater odorization project 27 29 27 29 Non-wire alternative projects 22 23 22 23 Legacy meters 20 2 — — Preferred stock redemption 19 20 19 20 Unamortized loss on reacquired debt 11 16 10 14 Recoverable Demonstration project costs 17 16 16 15 Gate station upgrade project 14 14 14 14 Other 173 138 148 125 Regulatory assets – noncurrent 3,974 3,639 3,669 3,316 Deferred derivative losses 184 141 178 133 Recoverable energy costs 121 65 108 55 Regulatory assets – current 305 206 286 188 Total Regulatory Assets $4,279 $3,845 $3,955 $3,504 Regulatory liabilities Future income tax* $1,753 $1,984 $1,616 $1,840 Unrecognized pension and other postretirement costs 1,638 32 1,536 — Allowance for cost of removal less salvage (i) 1,315 1,199 1,137 1,033 Net unbilled revenue deferrals 204 209 204 209 Deferred derivative gains - long term 145 61 130 55 Pension and other postretirement benefit deferrals 144 102 98 55 2022 late payment charge deferral 127 — 123 — System benefit charge carrying charge 73 70 69 63 Net proceeds from sale of property 69 103 69 103 Sales and use tax refunds 37 17 36 16 Property tax refunds 35 35 35 35 BQDM and Demonstration project reconciliations 23 25 21 22 Earnings sharing - electric, gas and steam 13 13 10 10 COVID - 19 pandemic uncollectible reconciliation deferral 12 — 12 — Workers’ compensation 11 8 11 8 Settlement of prudence proceeding (d) 10 6 10 6 Energy efficiency portfolio standard unencumbered funds 5 15 7 19 Settlement of gas proceedings (e) — 12 — 12 Other 413 490 357 435 Regulatory liabilities – noncurrent 6,027 4,381 5,481 3,921 Deferred derivative gains - short term 311 142 287 132 Refundable energy costs 34 32 — 2 Revenue decoupling mechanism 29 11 21 — Regulatory liabilities—current 374 185 308 134 Total Regulatory Liabilities $6,401 $4,566 $5,789 $4,055 * See "Federal Income Tax" in Note A, "Other Regulatory Matters," above, and Note L.
Schedule of Regulatory Liabilities	Regulatory assets and liabilities at December 31, 2022 and 2021 were comprised of the following items: Con Edison CECONY (Millions of Dollars) 2022 2021 2022 2021 Regulatory assets Environmental remediation costs $991 $938 $906 $860 System peak reduction and energy efficiency programs (h) 783 285 780 284 Revenue taxes 436 395 417 378 Pension and other postretirement benefits deferrals 279 496 240 435 COVID - 19 pandemic deferrals (f) 292 282 288 277 Deferred storm costs (c) 270 276 173 158 Property tax reconciliation (g) 121 202 121 202 COVID - 19 arrears relief deferrals programs 104 — 101 — Gas service line deferred costs 99 100 99 100 MTA power reliability deferral (b) 92 140 92 140 Unrecognized pension and other postretirement costs (a) 78 128 78 110 Brooklyn Queens demand management program 33 36 33 36 Deferred derivative losses - long term 31 51 26 45 Electric vehicle make ready (j) 33 8 30 7 Municipal infrastructure support costs 29 44 29 44 Meadowlands heater odorization project 27 29 27 29 Non-wire alternative projects 22 23 22 23 Legacy meters 20 2 — — Preferred stock redemption 19 20 19 20 Unamortized loss on reacquired debt 11 16 10 14 Recoverable Demonstration project costs 17 16 16 15 Gate station upgrade project 14 14 14 14 Other 173 138 148 125 Regulatory assets – noncurrent 3,974 3,639 3,669 3,316 Deferred derivative losses 184 141 178 133 Recoverable energy costs 121 65 108 55 Regulatory assets – current 305 206 286 188 Total Regulatory Assets $4,279 $3,845 $3,955 $3,504 Regulatory liabilities Future income tax* $1,753 $1,984 $1,616 $1,840 Unrecognized pension and other postretirement costs 1,638 32 1,536 — Allowance for cost of removal less salvage (i) 1,315 1,199 1,137 1,033 Net unbilled revenue deferrals 204 209 204 209 Deferred derivative gains - long term 145 61 130 55 Pension and other postretirement benefit deferrals 144 102 98 55 2022 late payment charge deferral 127 — 123 — System benefit charge carrying charge 73 70 69 63 Net proceeds from sale of property 69 103 69 103 Sales and use tax refunds 37 17 36 16 Property tax refunds 35 35 35 35 BQDM and Demonstration project reconciliations 23 25 21 22 Earnings sharing - electric, gas and steam 13 13 10 10 COVID - 19 pandemic uncollectible reconciliation deferral 12 — 12 — Workers’ compensation 11 8 11 8 Settlement of prudence proceeding (d) 10 6 10 6 Energy efficiency portfolio standard unencumbered funds 5 15 7 19 Settlement of gas proceedings (e) — 12 — 12 Other 413 490 357 435 Regulatory liabilities – noncurrent 6,027 4,381 5,481 3,921 Deferred derivative gains - short term 311 142 287 132 Refundable energy costs 34 32 — 2 Revenue decoupling mechanism 29 11 21 — Regulatory liabilities—current 374 185 308 134 Total Regulatory Liabilities $6,401 $4,566 $5,789 $4,055 * See "Federal Income Tax" in Note A, "Other Regulatory Matters," above, and Note L.
Schedule of Regulatory Assets Not Earning Return	At December 31, 2022 and 2021, 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) 2022 2021 2022 2021 Unrecognized pension and other postretirement costs $78 $128 $78 $110 Environmental remediation costs 987 928 903 850 Revenue taxes 414 375 397 359 Deferred derivative losses - long term 31 51 26 45 COVID-19 deferral for uncollectible accounts receivable 253 236 249 231 Other 28 24 27 24 Deferred derivative losses - current 184 141 178 134 Total $1,975 $1,883 $1,858 $1,753

Capitalization (Tables)

Capitalization (Tables)	12 Months Ended
	Dec. 31, 2022
Debt Disclosure [Abstract]
Schedule of Long-Term Debt Maturities	Long-term debt maturing in the period 2023-2027 is as follows: (Millions of Dollars) Con Edison (a) CECONY 2023 $650 $— 2024 250 250 2025 — — 2026 250 250 2027 430 350 (a) Amounts shown exclude the debt of the Clean Energy Businesses, which were classified as held for sale as of December 31, 2022 and are shown under "Project Debt Held for Sale" on Con Edison's Consolidated Statement of Capitalization. See "Assets and Liabilities Held for Sale" in Note A and Note X for additional information.
Carrying Amounts and Fair Values of Long-Term Debt	The carrying amounts and fair values of long-term debt at December 31, 2022 and 2021 are: (Millions of Dollars) 2022 2021 Long-Term Debt (including current portion) (a) Carrying Fair Carrying Amount Fair Value Con Edison $20,796 (b) $18,234 (b) $23,044 $26,287 CECONY 19,080 16,699 18,382 21,382 (a) Amounts shown are net of unamortized debt expense and unamortized debt discount of $202 million and $195 million for Con Edison and CECONY, respectively, as of December 31, 2022 and $226 million and $193 million for Con Edison and CECONY, respectively, as of December 31, 2021. (b) Amounts shown exclude the debt of the Clean Energy Businesses, which were classified as held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A, and Note X for additional information. The carrying value and fair value of the Clean Energy Businesses’ long-term debt, including the current portion, as of December 31, 2022 was $2,645 million and $2,489 million, respectively.

Pension Benefits (Tables)

Pension Benefits (Tables)	12 Months Ended
	Dec. 31, 2022
Retirement Benefits [Abstract]
Total Periodic Benefit Costs	The components of the Companies’ total periodic benefit costs for 2022, 2021 and 2020 were as follows: Con Edison CECONY (Millions of Dollars) 2022 2021 2020 2022 2021 2020 Service cost – including administrative expenses $287 $343 $293 $270 $321 $274 Interest cost on projected benefit obligation 505 471 549 475 443 515 Expected return on plan assets (1,168) (1,096) (1,034) (1,109) (1,040) (980) Recognition of net actuarial loss 377 787 699 358 746 661 Recognition of prior service credit (16) (17) (16) (21) (19) (19) TOTAL PERIODIC BENEFIT COST $(15) $488 $491 $(27) $451 $451 Cost capitalized (137) (154) (130) (129) (146) (123) Reconciliation to rate level 259 (226) (250) 245 (216) (239) Total expense recognized $107 $108 $111 $89 $89 $89 Con Edison CECONY (Millions of Dollars) 2022 2021 2020 2022 2021 2020 Service cost $18 $22 $21 $15 $16 $16 Interest cost on accumulated other postretirement benefit obligation 35 33 37 30 28 31 Expected return on plan assets (72) (68) (66) (58) (56) (54) Recognition of net actuarial loss/(gain) (14) 31 37 (9) 27 36 Recognition of prior service credit (1) (3) (3) — (1) (2) TOTAL PERIODIC POSTRETIREMENT BENEFIT COST/(CREDIT) $(34) $15 $26 $(22) $14 $27 Cost capitalized (8) (9) (9) (7) (7) (7) Reconciliation to rate level 29 (7) (17) 24 (12) (25) Total credit recognized $(13) ($1) $— $(5) $(5) $(5)
Schedule of Funded Status	The funded status at December 31, 2022, 2021 and 2020 was as follows: Con Edison CECONY (Millions of Dollars) 2022 2021 2020 2022 2021 2020 CHANGE IN PROJECTED BENEFIT OBLIGATION Projected benefit obligation at beginning of year $17,357 $18,965 $16,792 $16,341 $17,821 $15,750 Service cost – excluding administrative expenses 283 337 288 266 317 269 Interest cost on projected benefit obligation 505 471 549 475 443 515 Net actuarial loss/(gain) (5,102) (1,547) 2,281 (4,845) (1,441) 2,154 Benefits paid (930) (869) (945) (842) (799) (867) PROJECTED BENEFIT OBLIGATION AT END OF YEAR $12,113 $17,357 $18,965 $11,395 $16,341 $17,821 CHANGE IN PLAN ASSETS Fair value of plan assets at beginning of year $18,504 $17,022 $15,608 $17,566 $16,147 $14,790 Actual return on plan assets (2,583) 1,935 1,927 (2,453) 1,838 1,830 Employer contributions 30 469 475 17 432 435 Benefits paid (930) (869) (945) (842) (799) (867) Administrative expenses (42) (53) (43) (40) (52) (41) FAIR VALUE OF PLAN ASSETS AT END OF YEAR $14,979 $18,504 $17,022 $14,248 $17,566 $16,147 FUNDED STATUS $2,866 $1,147 $(1,943) $2,853 $1,225 $(1,674) Unrecognized net loss/(gain) $(1,485) $205 $3,330 $(1,397) $207 $3,145 Unrecognized prior service costs/(credits) (124) (140) (156) (143) (163) (183) Accumulated benefit obligation $11,167 $15,469 $16,768 $10,478 $14,504 $15,676 The funded status of the programs at December 31, 2022, 2021 and 2020 were as follows: Con Edison CECONY (Millions of Dollars) 2022 2021 2020 2022 2021 2020 CHANGE IN BENEFIT OBLIGATION Benefit obligation at beginning of year $1,398 $1,425 $1,357 $1,189 $1,209 $1,154 Service cost 18 22 21 15 16 16 Interest cost on accumulated postretirement benefit obligation 35 33 37 30 28 31 Net actuarial loss/(gain) (311) (13) 74 (239) (3) 63 Benefits paid and administrative expenses, net of subsidies (130) (117) (117) (121) (107) (107) Participant contributions 48 48 53 47 46 52 BENEFIT OBLIGATION AT END OF YEAR $1,058 $1,398 $1,425 $921 $1,189 $1,209 CHANGE IN PLAN ASSETS Fair value of plan assets at beginning of year $1,150 $1,115 $1,026 $955 $940 $872 Actual return on plan assets (225) 92 142 (187) 67 117 Employer contributions 13 6 7 10 3 4 Employer group waiver plan subsidies 55 21 20 50 19 19 Participant contributions 48 48 53 47 46 51 Benefits paid (181) (132) (133) (167) (120) (123) FAIR VALUE OF PLAN ASSETS AT END OF YEAR $860 $1,150 $1,115 $708 $955 $940 FUNDED STATUS $(198) $(248) $(310) $(213) $(234) $(269) Unrecognized net loss/(gain) $37 $41 $115 $78 $67 $114 Unrecognized prior service costs (12) (13) (16) — — (1)
Schedule of Assumptions	The actuarial assumptions were as follows: 2022 2021 2020 Weighted-average assumptions used to determine benefit obligations at December 31: Discount rate 5.45 % 3.00 % 2.55 % Interest crediting rate for cash balance plan 4.00 % 3.50 % 3.00 % 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 3.00 % 2.55 % 3.35 % Interest crediting rate for cash balance plan 3.50 % 3.00 % 3.30 % Expected return on plan assets 7.00 % 7.00 % 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: 2022 2021 2020 Weighted-average assumptions used to determine benefit obligations at December 31: Discount Rate CECONY 5.35 % 2.75 % 2.25 % O&R 5.45 % 3.00 % 2.55 % Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31: Discount Rate CECONY 2.75 % 2.25 % 3.10 % O&R 3.00 % 2.55 % 3.35 % Expected Return on Plan Assets 6.80 % 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) 2023 2024 2025 2026 2027 2028-2032 Con Edison $748 $759 $809 $780 $792 $4,095 CECONY 692 703 754 725 738 3,824 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) 2023 2024 2025 2026 2027 2028-2032 Con Edison $79 $80 $85 $86 $87 $430 CECONY 71 71 76 77 78 384
Schedule of Plan Assets Allocations	The asset allocations for the pension plan at the end of 2022, 2021 and 2020, and the target allocation for 2023 are as follows: Target Allocation Range Plan Assets at December 31, Asset Category 2023 2022 2021 2020 Equity Securities 28% - 38% 33 % 50 % 51 % Debt Securities 42% - 60% 50 % 38 % 38 % Real Estate and Other Alternatives 12% - 22% 17 % 12 % 11 % Total 100 % 100 % 100 % The asset allocations for CECONY’s other postretirement benefit plans at the end of 2022, 2021 and 2020, and the target allocation for 2023 are as follows: Target Allocation Range Plan Assets at December 31, Asset Category 2023 2022 2021 2020 Equity Securities 42%-80% 49 % 55 % 54 % Debt Securities 20%-58% 51 % 45 % 46 % Total 100% 100 % 100 % 100 %
Schedule of Fair Value of Plan Assets	The fair values of the pension plan assets at December 31, 2022 by asset category are as follows: (Millions of Dollars) Level 1 Level 2 Total Investments within the fair value hierarchy U.S. Equity (a) $2,150 $3 $2,153 International Equity (b) 1,534 — 1,534 U.S. Government Issued Debt (c) — 823 823 Corporate Bonds Debt (d) — 4,961 4,961 Structured Assets Debt (e) — 183 183 Other Fixed Income Debt (f) — 1,088 1,088 Cash and Cash Equivalents (g) 71 274 345 Futures (h) (1) — (1) Total investments within the fair value hierarchy $3,754 $7,332 $11,086 Investments measured at NAV per share (n) Private Equity (i) 1,018 Real Estate (j) 2,366 Hedge Funds (k) 657 Total investments valued using NAV per share $4,041 Funds for retiree health benefits (l) (48) (91) (139) Funds for retiree health benefits measured at NAV per share (l)(n) (51) Total funds for retiree health benefits $(190) Investments (excluding funds for retiree health benefits) $3,706 $7,241 $14,937 Pending activities (m) 42 Total fair value of plan net assets $14,979 (a) U.S. Equity includes both actively- and passively-managed assets with investments in domestic equity index funds and actively-managed small-capitalization equities. (b) International Equity includes international equity index funds and actively-managed international equities. (c) U.S. Government Issued Debt includes agency and treasury securities. (d) Corporate Bonds Debt consists of debt issued by various corporations. (e) Structured Assets Debt includes commercial-mortgage-backed securities and collateralized mortgage obligations. (f) Other Fixed Income Debt includes municipal bonds, sovereign debt and regional governments. (g) Cash and Cash Equivalents include short term investments, money markets, foreign currency and cash collateral. (h) Futures consist of exchange-traded financial contracts encompassing U.S. Equity, International Equity and U.S. Government indices. (i) Private Equity consists 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 $260 million at December 31, 2022. However, the managers also expect to make significant cash flow distributions in 2023 and 2024. 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 (j) Real Estate investments include 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. (k) Hedge Funds are structured as a custom fund of one and that strategy can invest in external hedge fund managers that can pursue a wide array of strategies including event driven, fundamental long/short, relative value, directional trading, and direct sourcing. This asset class seeks to generate positive absolute returns with lower volatility than other asset classes. It invests in various hedge fund managers who can invest in all financial instruments. If desired, substantially all of the investment could be liquidated within 18 months. (l) 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. (m) 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. (n) 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, 2021 by asset category are as follows: (Millions of Dollars) Level 1 Level 2 Total Investments within the fair value hierarchy U.S. Equity (a) $4,381 $— $4,381 International Equity (b) 3,536 — 3,536 U.S. Government Issued Debt (c) — 1,500 1,500 Corporate Bonds Debt (d) — 3,936 3,936 Structured Assets Debt (e) — 262 262 Other Fixed Income Debt (f) — 1,186 1,186 Cash and Cash Equivalents (g) 80 425 505 Futures (h) 2 — 2 Total investments within the fair value hierarchy $7,999 $7,309 $15,308 Investments measured at NAV per share (n) Private Equity (i) 913 Real Estate (j) 2,306 Hedge Funds (k) 315 Total investments valued using NAV per share $3,534 Funds for retiree health benefits (l) (110) (100) (210) Funds for retiree health benefits measured at NAV per share (l)(n) (48) Total funds for retiree health benefits $(258) Investments (excluding funds for retiree health benefits) $7,889 $7,209 $18,584 Pending activities (m) (80) Total fair value of plan net assets $18,504 (a) - (n) Reference is made to footnotes (a) through (n) in the above table of pension plan assets at December 31, 2022 by asset category. The fair values of the plans' assets at December 31, 2022 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) $— $339 $339 Other Fixed Income Debt (b) 10 275 285 Cash and Cash Equivalents (c) — 25 25 Total investments $10 $639 $649 Funds for retiree health benefits (d) 48 91 139 Investments (including funds for retiree health benefits) $58 $730 $788 Funds for retiree health benefits measured at net asset value (d)(e) 51 Pending activities (f) 21 Total fair value of plan net assets $860 (a) Equity includes a passively managed commingled index fund benchmarked to the MSCI All Country World Index. (b) Other Fixed Income Debt includes a passively managed commingled index fund benchmarked to the Bloomberg Barclays U.S. Long Credit Index and an active separately managed fund indexed to the Bloomberg Barclays U.S. Long Credit Index. (c) Cash and Cash Equivalents include short-term investments and money markets. (d) 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. (e) 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. (f) 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, 2021 by asset category (see Note R) are as follows: (Millions of Dollars) Level 1 Level 2 Total Equity (a) $— $474 $474 Other Fixed Income Debt (b) — 379 379 Cash and Cash Equivalents (c) — 22 22 Total investments $— $875 $875 Funds for retiree health benefits (d) 110 100 210 Investments (including funds for retiree health benefits) $110 $975 $1,085 Funds for retiree health benefits measured at net asset value (d)(e) 48 Pending activities (f) 17 Total fair value of plan net assets $1,150
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) 2022 2021 2020 Con Edison $57 $55 $52 CECONY 48 46 43

Other Postretirement Benefits (

Other Postretirement Benefits (Tables)	12 Months Ended
	Dec. 31, 2022
Retirement Benefits [Abstract]
Net Periodic Benefit Costs	The components of the Companies’ total periodic benefit costs for 2022, 2021 and 2020 were as follows: Con Edison CECONY (Millions of Dollars) 2022 2021 2020 2022 2021 2020 Service cost – including administrative expenses $287 $343 $293 $270 $321 $274 Interest cost on projected benefit obligation 505 471 549 475 443 515 Expected return on plan assets (1,168) (1,096) (1,034) (1,109) (1,040) (980) Recognition of net actuarial loss 377 787 699 358 746 661 Recognition of prior service credit (16) (17) (16) (21) (19) (19) TOTAL PERIODIC BENEFIT COST $(15) $488 $491 $(27) $451 $451 Cost capitalized (137) (154) (130) (129) (146) (123) Reconciliation to rate level 259 (226) (250) 245 (216) (239) Total expense recognized $107 $108 $111 $89 $89 $89 Con Edison CECONY (Millions of Dollars) 2022 2021 2020 2022 2021 2020 Service cost $18 $22 $21 $15 $16 $16 Interest cost on accumulated other postretirement benefit obligation 35 33 37 30 28 31 Expected return on plan assets (72) (68) (66) (58) (56) (54) Recognition of net actuarial loss/(gain) (14) 31 37 (9) 27 36 Recognition of prior service credit (1) (3) (3) — (1) (2) TOTAL PERIODIC POSTRETIREMENT BENEFIT COST/(CREDIT) $(34) $15 $26 $(22) $14 $27 Cost capitalized (8) (9) (9) (7) (7) (7) Reconciliation to rate level 29 (7) (17) 24 (12) (25) Total credit recognized $(13) ($1) $— $(5) $(5) $(5)
Schedule of Funded Status	The funded status at December 31, 2022, 2021 and 2020 was as follows: Con Edison CECONY (Millions of Dollars) 2022 2021 2020 2022 2021 2020 CHANGE IN PROJECTED BENEFIT OBLIGATION Projected benefit obligation at beginning of year $17,357 $18,965 $16,792 $16,341 $17,821 $15,750 Service cost – excluding administrative expenses 283 337 288 266 317 269 Interest cost on projected benefit obligation 505 471 549 475 443 515 Net actuarial loss/(gain) (5,102) (1,547) 2,281 (4,845) (1,441) 2,154 Benefits paid (930) (869) (945) (842) (799) (867) PROJECTED BENEFIT OBLIGATION AT END OF YEAR $12,113 $17,357 $18,965 $11,395 $16,341 $17,821 CHANGE IN PLAN ASSETS Fair value of plan assets at beginning of year $18,504 $17,022 $15,608 $17,566 $16,147 $14,790 Actual return on plan assets (2,583) 1,935 1,927 (2,453) 1,838 1,830 Employer contributions 30 469 475 17 432 435 Benefits paid (930) (869) (945) (842) (799) (867) Administrative expenses (42) (53) (43) (40) (52) (41) FAIR VALUE OF PLAN ASSETS AT END OF YEAR $14,979 $18,504 $17,022 $14,248 $17,566 $16,147 FUNDED STATUS $2,866 $1,147 $(1,943) $2,853 $1,225 $(1,674) Unrecognized net loss/(gain) $(1,485) $205 $3,330 $(1,397) $207 $3,145 Unrecognized prior service costs/(credits) (124) (140) (156) (143) (163) (183) Accumulated benefit obligation $11,167 $15,469 $16,768 $10,478 $14,504 $15,676 The funded status of the programs at December 31, 2022, 2021 and 2020 were as follows: Con Edison CECONY (Millions of Dollars) 2022 2021 2020 2022 2021 2020 CHANGE IN BENEFIT OBLIGATION Benefit obligation at beginning of year $1,398 $1,425 $1,357 $1,189 $1,209 $1,154 Service cost 18 22 21 15 16 16 Interest cost on accumulated postretirement benefit obligation 35 33 37 30 28 31 Net actuarial loss/(gain) (311) (13) 74 (239) (3) 63 Benefits paid and administrative expenses, net of subsidies (130) (117) (117) (121) (107) (107) Participant contributions 48 48 53 47 46 52 BENEFIT OBLIGATION AT END OF YEAR $1,058 $1,398 $1,425 $921 $1,189 $1,209 CHANGE IN PLAN ASSETS Fair value of plan assets at beginning of year $1,150 $1,115 $1,026 $955 $940 $872 Actual return on plan assets (225) 92 142 (187) 67 117 Employer contributions 13 6 7 10 3 4 Employer group waiver plan subsidies 55 21 20 50 19 19 Participant contributions 48 48 53 47 46 51 Benefits paid (181) (132) (133) (167) (120) (123) FAIR VALUE OF PLAN ASSETS AT END OF YEAR $860 $1,150 $1,115 $708 $955 $940 FUNDED STATUS $(198) $(248) $(310) $(213) $(234) $(269) Unrecognized net loss/(gain) $37 $41 $115 $78 $67 $114 Unrecognized prior service costs (12) (13) (16) — — (1)
Schedule of Actuarial Assumptions	The actuarial assumptions were as follows: 2022 2021 2020 Weighted-average assumptions used to determine benefit obligations at December 31: Discount rate 5.45 % 3.00 % 2.55 % Interest crediting rate for cash balance plan 4.00 % 3.50 % 3.00 % 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 3.00 % 2.55 % 3.35 % Interest crediting rate for cash balance plan 3.50 % 3.00 % 3.30 % Expected return on plan assets 7.00 % 7.00 % 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: 2022 2021 2020 Weighted-average assumptions used to determine benefit obligations at December 31: Discount Rate CECONY 5.35 % 2.75 % 2.25 % O&R 5.45 % 3.00 % 2.55 % Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31: Discount Rate CECONY 2.75 % 2.25 % 3.10 % O&R 3.00 % 2.55 % 3.35 % Expected Return on Plan Assets 6.80 % 6.80 % 6.80 %
Schedule of Health Care Cost Trend Rates	The health care cost trend rates for covered medical and prescription medication expenses used to determine the accumulated other postretirement benefit obligations (APBO) at December 31, 2022 were assumed to increase each year, with the initial rate gradually decreasing to the ultimate rate as follows: Initial Cost Trend Rate Ultimate Cost Trend Rate Year That Ultimate Rate is Reached Pre-65 Medical 7.00% 4.50% 2036 Post-65 Medical 4.50% 4.50% — Prescription Medications 7.50% 4.50% 2035
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) 2023 2024 2025 2026 2027 2028-2032 Con Edison $748 $759 $809 $780 $792 $4,095 CECONY 692 703 754 725 738 3,824 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) 2023 2024 2025 2026 2027 2028-2032 Con Edison $79 $80 $85 $86 $87 $430 CECONY 71 71 76 77 78 384
Schedule of Plan Assets Allocations	The asset allocations for the pension plan at the end of 2022, 2021 and 2020, and the target allocation for 2023 are as follows: Target Allocation Range Plan Assets at December 31, Asset Category 2023 2022 2021 2020 Equity Securities 28% - 38% 33 % 50 % 51 % Debt Securities 42% - 60% 50 % 38 % 38 % Real Estate and Other Alternatives 12% - 22% 17 % 12 % 11 % Total 100 % 100 % 100 % The asset allocations for CECONY’s other postretirement benefit plans at the end of 2022, 2021 and 2020, and the target allocation for 2023 are as follows: Target Allocation Range Plan Assets at December 31, Asset Category 2023 2022 2021 2020 Equity Securities 42%-80% 49 % 55 % 54 % Debt Securities 20%-58% 51 % 45 % 46 % Total 100% 100 % 100 % 100 %
Schedule of Fair Value of Plan Assets	The fair values of the pension plan assets at December 31, 2022 by asset category are as follows: (Millions of Dollars) Level 1 Level 2 Total Investments within the fair value hierarchy U.S. Equity (a) $2,150 $3 $2,153 International Equity (b) 1,534 — 1,534 U.S. Government Issued Debt (c) — 823 823 Corporate Bonds Debt (d) — 4,961 4,961 Structured Assets Debt (e) — 183 183 Other Fixed Income Debt (f) — 1,088 1,088 Cash and Cash Equivalents (g) 71 274 345 Futures (h) (1) — (1) Total investments within the fair value hierarchy $3,754 $7,332 $11,086 Investments measured at NAV per share (n) Private Equity (i) 1,018 Real Estate (j) 2,366 Hedge Funds (k) 657 Total investments valued using NAV per share $4,041 Funds for retiree health benefits (l) (48) (91) (139) Funds for retiree health benefits measured at NAV per share (l)(n) (51) Total funds for retiree health benefits $(190) Investments (excluding funds for retiree health benefits) $3,706 $7,241 $14,937 Pending activities (m) 42 Total fair value of plan net assets $14,979 (a) U.S. Equity includes both actively- and passively-managed assets with investments in domestic equity index funds and actively-managed small-capitalization equities. (b) International Equity includes international equity index funds and actively-managed international equities. (c) U.S. Government Issued Debt includes agency and treasury securities. (d) Corporate Bonds Debt consists of debt issued by various corporations. (e) Structured Assets Debt includes commercial-mortgage-backed securities and collateralized mortgage obligations. (f) Other Fixed Income Debt includes municipal bonds, sovereign debt and regional governments. (g) Cash and Cash Equivalents include short term investments, money markets, foreign currency and cash collateral. (h) Futures consist of exchange-traded financial contracts encompassing U.S. Equity, International Equity and U.S. Government indices. (i) Private Equity consists 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 $260 million at December 31, 2022. However, the managers also expect to make significant cash flow distributions in 2023 and 2024. 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 (j) Real Estate investments include 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. (k) Hedge Funds are structured as a custom fund of one and that strategy can invest in external hedge fund managers that can pursue a wide array of strategies including event driven, fundamental long/short, relative value, directional trading, and direct sourcing. This asset class seeks to generate positive absolute returns with lower volatility than other asset classes. It invests in various hedge fund managers who can invest in all financial instruments. If desired, substantially all of the investment could be liquidated within 18 months. (l) 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. (m) 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. (n) 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, 2021 by asset category are as follows: (Millions of Dollars) Level 1 Level 2 Total Investments within the fair value hierarchy U.S. Equity (a) $4,381 $— $4,381 International Equity (b) 3,536 — 3,536 U.S. Government Issued Debt (c) — 1,500 1,500 Corporate Bonds Debt (d) — 3,936 3,936 Structured Assets Debt (e) — 262 262 Other Fixed Income Debt (f) — 1,186 1,186 Cash and Cash Equivalents (g) 80 425 505 Futures (h) 2 — 2 Total investments within the fair value hierarchy $7,999 $7,309 $15,308 Investments measured at NAV per share (n) Private Equity (i) 913 Real Estate (j) 2,306 Hedge Funds (k) 315 Total investments valued using NAV per share $3,534 Funds for retiree health benefits (l) (110) (100) (210) Funds for retiree health benefits measured at NAV per share (l)(n) (48) Total funds for retiree health benefits $(258) Investments (excluding funds for retiree health benefits) $7,889 $7,209 $18,584 Pending activities (m) (80) Total fair value of plan net assets $18,504 (a) - (n) Reference is made to footnotes (a) through (n) in the above table of pension plan assets at December 31, 2022 by asset category. The fair values of the plans' assets at December 31, 2022 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) $— $339 $339 Other Fixed Income Debt (b) 10 275 285 Cash and Cash Equivalents (c) — 25 25 Total investments $10 $639 $649 Funds for retiree health benefits (d) 48 91 139 Investments (including funds for retiree health benefits) $58 $730 $788 Funds for retiree health benefits measured at net asset value (d)(e) 51 Pending activities (f) 21 Total fair value of plan net assets $860 (a) Equity includes a passively managed commingled index fund benchmarked to the MSCI All Country World Index. (b) Other Fixed Income Debt includes a passively managed commingled index fund benchmarked to the Bloomberg Barclays U.S. Long Credit Index and an active separately managed fund indexed to the Bloomberg Barclays U.S. Long Credit Index. (c) Cash and Cash Equivalents include short-term investments and money markets. (d) 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. (e) 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. (f) 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, 2021 by asset category (see Note R) are as follows: (Millions of Dollars) Level 1 Level 2 Total Equity (a) $— $474 $474 Other Fixed Income Debt (b) — 379 379 Cash and Cash Equivalents (c) — 22 22 Total investments $— $875 $875 Funds for retiree health benefits (d) 110 100 210 Investments (including funds for retiree health benefits) $110 $975 $1,085 Funds for retiree health benefits measured at net asset value (d)(e) 48 Pending activities (f) 17 Total fair value of plan net assets $1,150

Environmental Matters (Tables)

Environmental Matters (Tables)	12 Months Ended
	Dec. 31, 2022
Environmental Remediation Obligations [Abstract]
Accrued Liabilities and Regulatory Assets	The accrued liabilities and regulatory assets related to Superfund Sites at December 31, 2022 and 2021 were as follows: Con Edison CECONY (Millions of Dollars) 2022 2021 2022 2021 Accrued Liabilities: Manufactured gas plant sites $876 $845 $782 $755 Other Superfund Sites 121 95 121 95 Total $997 $940 $903 $850 Regulatory assets $991 $938 $906 $860
Environmental Remediation Costs	Environmental remediation costs incurred related to Superfund Sites at December 31, 2022 and 2021 were as follows: Con Edison CECONY (Millions of Dollars) 2022 2021 2022 2021 Remediation costs incurred $21 $25 $20 $24
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, 2022 and 2021 were as follows: Con Edison CECONY (Millions of Dollars) 2022 2021 2022 2021 Accrued liability – asbestos suits $8 $8 $7 $7 Regulatory assets – asbestos suits 8 8 7 7 Accrued liability – workers’ compensation 61 65 59 62 Regulatory liabilities – workers’ compensation 11 8 11 8

Material Contingencies (Tables)

Material Contingencies (Tables)	12 Months Ended
	Dec. 31, 2022
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, 2022 is as follows: Guarantee Type 0 – 3 years 4 – 10 years > 10 years Total (Millions of Dollars) Con Edison Transmission $407 $— $— $407 Energy transactions (a) 489 22 294 805 Renewable electric projects (a) 354 69 555 978 Other (a) 222 — — 222 Total $1,472 $91 $849 $2,412

Electricity and Gas Purchase _2

Electricity and Gas Purchase Agreements (Tables)	12 Months Ended
	Dec. 31, 2022
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) 2023 2024 2025 2026 2027 All Years Thereafter Con Edison Electricity power purchase agreements $121 $90 $64 $58 $44 $390 Natural gas 679 9 — — — — Gas transportation and storage 471 558 484 454 369 3,164 CECONY Electricity power purchase agreements 121 90 64 58 44 390 Natural gas 603 8 — — — — Gas transportation and storage 412 488 424 397 323 2,762
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 2022, 2021 and 2020 were as follows: For the Years Ended December 31, (Millions of Dollars) 2022 2021 2020 Con Edison Astoria Generating Company (a) $45 $20 $26 Brooklyn Navy Yard (b) 165 139 113 Gas Transportation and Storage (c) 386 393 347 Total $596 552 $486 CECONY Astoria Generating Company (a) $45 $20 $26 Brooklyn Navy Yard (b) 165 139 113 Gas Transportation and Storage (c) 340 347 307 Total $550 $506 $446 (a) Capacity purchase agreements with terms ending in 2022 through 2025. (b) Contract for plant output, which started in 1996 and ends in 2036. (c) Contracts for various counterparties and terms extending through 2043.

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2022
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 twelve months ended December 31, 2022 and 2021 were as follows: Con Edison CECONY (Millions of Dollars) 2022 2021 2022 2021 Operating lease cost $88 $86 $67 $66 Operating lease cash flows $83 $80 $64 $63 Other information related to leases for Con Edison and CECONY at December 31, 2022 and 2021 was as follows: Con Edison CECONY 2022 2021 2022 2021 Weighted Average Remaining Lease Term: Operating leases, (a) 12.3 years 18.5 years 12.4 years 12.1 years Finance leases 7.2 years 7.1 years 2.3 years 3.1 years Weighted Average Discount Rate: Operating leases, (a) 3.7% 4.3% 3.7% 3.5% Finance leases 1.9% 1.8% 1.0% 1.1% (a) Amounts for Con Edison in 2022 exclude operating leases of the Clean Energy Businesses, which were classified as held for sale as of December 31, 2022, see "Assets and Liabilities Held for Sale" in Note A and Note X. Including the operating leases of the Clean Energy Businesses would result in a weighted average remaining lease term of 18.3 years and a weighted average discount rate of 4.4% as of December 31, 2022.
Operating Leases, Future Minimum Lease Payments	Future minimum lease payments under non-cancellable leases at December 31, 2022 were as follows: (Millions of Dollars) Con Edison CECONY Year Ending December 31, (b) Operating Leases Finance Leases Operating Leases Finance Leases 2023 $64 $— $64 $— 2024 65 1 64 1 2025 65 — 64 — 2026 64 — 64 — 2027 64 — 64 — All years thereafter 419 1 419 — Total future minimum lease payments $741 $2 $739 $1 Less: imputed interest (162) — (161) — Total $579 $2 $578 $1 Reported as of December 31, 2022 Operating lease liabilities (current) (a) $103 $— $103 $— Operating lease liabilities held for sale (current) 33 — — — Operating lease liabilities (noncurrent) (a) 476 — 475 — Operating lease liabilities held for sale (noncurrent) 249 — — — Other current liabilities — — — — Other noncurrent liabilities — 2 — 1 Total $861 $2 $578 $1 (a) Amounts exclude operating lease liabilities of the Clean Energy Businesses ($281 million), which are classified as current liabilities held for sale on Con Edison's consolidated balance sheet as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X.
Finance Leases, Future Minimum Lease Payments	Future minimum lease payments under non-cancellable leases at December 31, 2022 were as follows: (Millions of Dollars) Con Edison CECONY Year Ending December 31, (b) Operating Leases Finance Leases Operating Leases Finance Leases 2023 $64 $— $64 $— 2024 65 1 64 1 2025 65 — 64 — 2026 64 — 64 — 2027 64 — 64 — All years thereafter 419 1 419 — Total future minimum lease payments $741 $2 $739 $1 Less: imputed interest (162) — (161) — Total $579 $2 $578 $1 Reported as of December 31, 2022 Operating lease liabilities (current) (a) $103 $— $103 $— Operating lease liabilities held for sale (current) 33 — — — Operating lease liabilities (noncurrent) (a) 476 — 475 — Operating lease liabilities held for sale (noncurrent) 249 — — — Other current liabilities — — — — Other noncurrent liabilities — 2 — 1 Total $861 $2 $578 $1 (a) Amounts exclude operating lease liabilities of the Clean Energy Businesses ($281 million), which are classified as current liabilities held for sale on Con Edison's consolidated balance sheet as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X.

Income Tax (Tables)

Income Tax (Tables)	12 Months Ended
	Dec. 31, 2022
Income Tax Disclosure [Abstract]
Schedule of Components of Income Tax	The components of income tax are as follows: Con Edison CECONY (Millions of Dollars) 2022 2021 2020 2022 2021 2020 State Current $5 $14 $7 $0 $1 $6 Deferred 324 79 50 110 106 97 Federal Current 58 43 (2) 170 121 41 Deferred 117 61 42 (23) 21 73 Amortization of investment tax credits (6) (7) (7) (2) (3) (2) Total income tax expense $498 $190 $90 $255 $246 $215
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) 2022 2021 2020 2022 2021 2020 STATUTORY TAX RATE Federal 21 % 21 % 21 % 21 % 21 % 21 % Changes in computed taxes resulting from: State income taxes, net of federal income tax benefit 6 4 4 5 5 5 Taxes attributable to noncontrolling interests 1 3 (1) — — — Cost of removal 1 2 2 1 1 1 Other plant-related items — (1) (1) (1) (1) (1) Amortization of excess deferred federal income taxes (9) (12) (14) (10) (11) (12) Renewable energy credits (2) (2) (3) — — — Research and development credits — (1) — — — — Remeasurement of accumulated deferred state income taxes, net of federal income tax benefit 6 — — — — — Other — — (1) — — 1 Effective tax rate 24 % 14 % 7 % 16 % 15 % 15 %
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) 2022 2021 2022 2021 Deferred tax liabilities: Property basis differences $8,770 $8,298 $7,475 $7,213 Regulatory Assets: Deferred storm costs 27 33 — — Environmental remediation costs 278 264 254 241 Other regulatory assets 754 640 720 609 Unrecognized pension and other postretirement costs 22 36 22 31 Pensions and retiree benefits – asset 917 478 894 471 Operating lease right-of-use asset 230 204 163 155 Equity investments 26 — — — Other — 30 — — Total deferred tax liabilities $11,024 $9,983 $9,528 $8,720 Deferred tax assets: Regulatory liabilities: Unrecognized pension and other postretirement costs 447 — 431 — Future income tax 489 554 454 517 Other regulatory liabilities 860 727 739 620 Tax credits carryforward 767 946 — — Loss carryforwards 117 144 24 38 Valuation allowance (18) (22) — — Superfund and other environmental costs 280 264 254 238 Operating lease liabilities 233 195 162 155 Pensions and retiree benefits – liability 162 218 148 188 Asset retirement obligations 153 177 140 141 Equity investments — 34 — — Other 14 — 45 42 Total deferred tax assets 3,504 3,237 2,397 1,939 Net deferred tax liabilities $7,520 $6,746 $7,131 $6,781 Unamortized investment tax credits 121 127 13 15 Net deferred tax liabilities and unamortized investment tax credits $7,641 $6,873 $7,144 $6,796
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) 2022 2021 2020 2022 2021 2020 Balance at January 1, $17 $14 $13 $5 $3 $2 Additions based on tax positions related to the current year 3 3 — 2 2 — Additions based on tax positions of prior years 6 2 1 1 1 1 Reductions for tax positions of prior years (1) (2) — — (1) — Settlements (2) — — — — — Balance at December 31, $23 $17 $14 $8 $5 $3

Revenue Recognition (Tables)

Revenue Recognition (Tables)	12 Months Ended
	Dec. 31, 2022
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	The following table presents, for the years ended December 31, 2022, 2021 and 2020, revenue from contracts with customers as defined in Accounting Standards Codification (ASC) Topic 606, "Revenue from Contracts with Customers," as well as additional revenue from sources other than contracts with customers, disaggregated by major source. 2022 2021 2020 (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 $9,917 $(166) $9,751 $8,736 $70 $8,806 $8,026 $77 $8,103 Gas 2,875 49 2,924 2,324 54 2,378 1,998 38 2,036 Steam 584 9 593 519 13 532 494 14 508 Total CECONY $13,376 $(108) $13,268 $11,579 $137 $11,716 $10,518 $129 $10,647 O&R Electric 771 2 773 691 (10) 681 619 10 629 Gas 306 6 312 265 (5) 260 224 9 233 Total O&R $1,077 $8 $1,085 $956 $(15) $941 $843 $19 $862 Clean Energy Businesses (c) Renewables 637 — 637 638 — 638 608 — 608 Energy services 317 — 317 234 — 234 52 — 52 Develop/Transfer Projects 44 — 44 45 — 45 1 — 1 Other — 321 321 — 105 105 — 75 75 Total Clean Energy Businesses $998 $321 $1,319 $917 $105 $1,022 $661 $75 $736 Con Edison Transmission 4 — 4 4 — 4 4 — 4 Other (b) — (6) (6) — (7) (7) — (3) (3) Total Con Edison $15,455 $215 $15,670 $13,456 $220 $13,676 $12,026 $220 $12,246 (a) For the Utilities, this includes primarily revenue or negative revenue adjustments from alternative revenue programs, such as the revenue decoupling mechanisms under their NY electric and gas rate plans (see "Rate Plans" in Note B) and for 2021 recognition of late payment charges and fees that were not billed (LPCs) for the years ended December 31, 2020 and 2021 and for which recovery was granted by the NYSPSC. See "COVID-19 Regulatory Matters" in Note B and "Utilities' Assessment of Late Payment Charges" below. The amount of revenue recognized under such alternative revenue programs for 2021 includes $48 million, $34 million and $74 million for CECONY's revenue decoupling mechanisms, net EAMs, and LPCs, respectively, and $(18) million, $2 million and $4 million for O&R's revenue decoupling mechanisms, net EAMs, and LPCs, respectively. For the Clean Energy Businesses, this includes revenue from wholesale services. (b) Parent company and consolidation adjustments.
Change in Unbilled Contract and Unearned Revenues	2022 2021 2020 (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, $35 $7 $11 $41 $29 $17 Additions (c) 324 — 242 — 88 31 Subtractions (c) 279 4 (d) 218 34 (d) 106 7 (d) Ending balance as of December 31, $80 $3 $35 $7 $11 $41 (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. (d) Of the subtractions from unearned revenue, $4 million, $34 million and $7 million were included in the balances as of January 1, 2022, 2021, and 2020, respectively.

Current Expected Credit Losses

Current Expected Credit Losses (Tables)	12 Months Ended
	Dec. 31, 2022
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, 2022 and 2021: For the Year Ended December 31, Con Edison CECONY Accounts receivable - customers Other receivables Accounts receivable - customers Other receivables (Millions of Dollars) 2022 2021 2022 2021 2022 2021 2022 2021 Allowance for credit losses Beginning Balance at January 1, $317 $148 $22 $7 $304 $138 $19 $4 Recoveries 17 14 — 1 16 12 — 1 Write-offs (103) (91) (6) (2) (94) (86) (4) (1) Reserve adjustments 91 246 (6) 16 88 240 (8) 15 Ending Balance December 31, $322 $317 $10 $22 $314 $304 $7 $19

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2022
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, 2022, 2021 and 2020: Con Edison CECONY (Millions of Dollars) 2022 2021 2020 2022 2021 2020 Performance-based restricted stock $52 $23 $7 $43 $19 $6 Time-based restricted stock 2 2 1 2 2 1 Non-employee director deferred stock compensation 3 3 2 3 3 2 Stock purchase plan 7 7 7 6 7 7 Total $64 $35 $17 $54 $31 $16 Income tax benefit $18 $10 $5 $15 $9 $4
Assumptions Used to Calculate Fair Value of Awards	The assumptions used to calculate the fair value of the awards were as follows: 2022 2021 2020 Risk-free interest rate (a) 4.41% - 4.73% 0.39% - 0.73% 0.10% -0.13% Expected term (b) 3 years 3 years 3 years Expected share price volatility (c) 19.65% - 21.77% 17.25% - 31.42% 30.16% - 40.95% (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, 2022 is as follows: Con Edison CECONY Weighted Average Grant Date Fair Value (a) Weighted Average Grant Date Fair Value (a) Units TSR Portion (b) Non-TSR Portion (c) Units TSR Portion (b) Non-TSR Portion (c) Non-vested at December 31, 2021 984,728 $72.67 $79.14 744,278 $72.71 $79.20 Granted 231,600 89.90 83.76 172,003 90.25 84.32 Vested (320,821) 64.59 80.17 (240,022) 65.04 80.45 Forfeited (30,416) 80.08 77.73 (28,433) 80.04 77.68 Non-vested at December 31, 2022 865,091 $80.02 $80.04 647,826 $79.89 $80.16 (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.
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, 2022 is as follows: Con Edison CECONY Units Weighted Average Grant Date Fair Value Units Weighted Average Grant Date Fair Value Non-vested at December 31, 2021 61,620 $79.68 57,870 $79.70 Granted 149,650 86.59 118,458 87.46 Vested (22,450) 84.81 (21,200) 84.81 Forfeited (8,232) 81.51 (7,713) 81.54 Non-vested at December 31, 2022 180,588 $84.69 147,415 $85.10

Financial Information by Busi_2

Financial Information by Business Segment (Tables)	12 Months Ended
	Dec. 31, 2022
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, 2022 (Millions of Dollars) Operating revenues Inter- segment revenues Depreciation and amortization Operating income Other Income (deductions) Interest charges Income taxes on operating income (a) Total assets Capital expenditures CECONY Electric $9,751 $19 $1,315 $1,496 $259 $582 $138 $39,153 $2,522 Gas 2,924 8 367 660 52 198 141 15,361 1,128 Steam 593 76 96 (21) 21 42 (18) 2,931 108 Consolidation adjustments — (103) — — — — — — — Total CECONY $13,268 $— $1,778 $2,135 $332 $822 $261 $57,445 $3,758 O&R Electric $773 $— $71 $94 $17 $29 $17 $2,247 $167 Gas 312 — 27 42 6 17 8 1,264 76 Other — — — — — — — — — Total O&R $1,085 $— $98 $136 $23 $46 $25 $3,511 $243 Clean Energy Businesses $1,319 $— $178 $368 $3 $(35) $84 $7,224 (b) $399 Con Edison Transmission 4 — 1 (10) 19 5 1 314 65 Other (c) (6) — 1 (5) (51) 14 51 571 — Total Con Edison $15,670 $— $2,056 $2,624 $326 $852 $422 $69,065 $4,465 As of and for the Year Ended December 31, 2021 (Millions of Dollars) Operating revenues Inter- segment revenues Depreciation and amortization Operating income Other Income (deductions) Interest charges Income taxes on operating income (a) Total assets Capital expenditures CECONY Electric $8,806 $18 $1,286 $1,802 $(84) $542 $151 $36,260 $2,189 Gas 2,378 8 326 646 (16) 179 110 13,748 1,126 Steam 532 74 93 12 (8) 41 (9) 2,647 103 Consolidation adjustments — (100) — — — — — — — Total CECONY $11,716 $— $1,705 $2,460 $(108) $762 $252 $52,655 $3,418 O&R Electric $681 $— $69 $100 $(8) $27 $13 $2,123 $147 Gas 260 — 26 50 (4) 15 8 1,169 70 Other — — — — — — — — — Total O&R $941 $— $95 $150 $(12) $42 $21 $3,292 $217 Clean Energy Businesses $1,022 $— $231 $236 $(10) $68 $44 $6,554 (b) $298 Con Edison Transmission 4 — 1 (16) (407) 9 3 249 31 Other (c) (7) — — (4) (1) 24 20 366 — Total Con Edison $13,676 $— $2,032 $2,826 $(538) $905 $340 $63,116 $3,964 As of and for the Year Ended December 31, 2020 (Millions of Dollars) Operating Inter- Depreciation Operating Other Income (deductions) Interest Income Total Capital CECONY Electric $8,103 $18 $1,214 $1,731 $(134) $535 $130 $35,673 $2,080 Gas 2,036 7 294 574 (25) 164 102 12,678 1,044 Steam 508 74 90 5 (12) 40 (14) 2,616 122 Consolidation adjustments — (99) — — — — — — — Total CECONY $10,647 $— $1,598 $2,310 $(171) $739 $218 $50,967 $3,246 O&R Electric $629 $— $65 $99 $(10) $26 $13 $2,097 $159 Gas 233 — 25 48 (4) 15 8 1,150 61 Other — — — — — — — — — Total O&R $862 $— $90 $147 $(14) $41 $21 $3,247 $220 Clean Energy Businesses $736 $— $231 $215 $4 $196 $(43) $6,848 (b) $616 Con Edison Transmission 4 — 1 (8) $ (215) 18 — 1,348 3 Other (c) (3) — — (10) (5) 25 (3) 485 — Total Con Edison $12,246 $— $1,920 $2,654 $(401) $1,019 $193 $62,895 $4,085 (a) For Con Edison, the income tax expense/(benefit) on non-operating income was $76 million, $(150) million and $(103) million in 2022, 2021 and 2020, respectively. For CECONY, the income tax expense/(benefit) on non-operating income was $(6) million, $(6) million and $(3) million in 2022, 2021 and 2020, respectively. (b) The Clean Energy Businesses were classified as held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X. (c) Parent company and consolidation adjustments. Other does not represent a business segment.

Derivative Instruments and He_2

Derivative Instruments and Hedging Activities (Tables)	12 Months Ended
	Dec. 31, 2022
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, 2022 and 2021 were: (Millions of Dollars) 2022 2021 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 $378 $(332) $46 (b) $285 $(158) $127 (b)(d) Noncurrent 193 (108) 85 90 (13) 77 Total fair value of derivative assets held and used $571 $(440) $131 $375 $(171) $204 Current - assets held for sale (e) 93 (8) 85 (c) — — — Noncurrent - assets held for sale (e) 83 11 94 (c) — — — Total fair value of derivative assets $747 $(437) $310 $375 $(171) $204 Fair value of derivative liabilities Current $(198) $166 $(32) (b) $(289) $137 $(152) Noncurrent (49) 36 (13) (94) 10 (84) (d) Total fair value of derivative liabilities held and used $(247) $202 $(45) $(383) $147 $(236) Current - liabilities held for sale (e) (31) 6 (25) — — — Noncurrent - liabilities held for sale (e) (3) (8) (11) — — — Total fair value of derivative liabilities $(281) $200 $(81) $(383) $147 $(236) Net fair value derivative assets/(liabilities) $466 $(237) $229 $(8) $(24) $(32) CECONY Fair value of derivative assets Current $350 $(312) $38 (b) $135 $(64) $71 (b) Noncurrent 176 (96) 80 71 (15) 56 Total fair value of derivative assets $526 $(408) $118 $206 $(79) $127 Fair value of derivative liabilities Current $(189) $160 $(29) $(131) $43 $(88) Noncurrent (43) 34 (9) (50) 10 (40) Total fair value of derivative liabilities $(232) $194 $(38) $(181) $53 $(128) Net fair value derivative assets/(liabilities) $294 ($214) $80 $25 $(26) $(1) (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, 2022, margin deposits for Con Edison and CECONY of $13 million were classified as derivative assets, and ($(10) million and $(6) million, respectively) were classified as derivative liabilities on the consolidated balance sheet, but not included in the table. At December 31, 2021, margin deposits for Con Edison and CECONY ($1 million and an immaterial amount, respectively) were classified as derivative assets on the consolidated balance sheet, 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. (c) Includes amounts for interest rate swaps of $31 million in current assets and $75 million in noncurrent assets. At December 31, 2022, the Clean Energy Businesses had interest rate swaps with notional amounts of $982 million. The expiration dates of the swaps range from 2025-2041. (d) Includes amounts for interest rate swaps of $4 million in noncurrent assets, $(20) million in current liabilities and $(38) million in noncurrent liabilities. At December 31, 2021, the Clean Energy Businesses had interest rate swaps with notional amounts of $1,031 million. The expiration dates of the swaps ranged from 2025-2041. (e) Amounts represent derivative assets and liabilities included in current assets and current liabilities held for sale, respectively, on Con Edison's consolidated balance sheet as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X.
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, 2022 and 2021 were: (Millions of Dollars) 2022 2021 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 $378 $(332) $46 (b) $285 $(158) $127 (b)(d) Noncurrent 193 (108) 85 90 (13) 77 Total fair value of derivative assets held and used $571 $(440) $131 $375 $(171) $204 Current - assets held for sale (e) 93 (8) 85 (c) — — — Noncurrent - assets held for sale (e) 83 11 94 (c) — — — Total fair value of derivative assets $747 $(437) $310 $375 $(171) $204 Fair value of derivative liabilities Current $(198) $166 $(32) (b) $(289) $137 $(152) Noncurrent (49) 36 (13) (94) 10 (84) (d) Total fair value of derivative liabilities held and used $(247) $202 $(45) $(383) $147 $(236) Current - liabilities held for sale (e) (31) 6 (25) — — — Noncurrent - liabilities held for sale (e) (3) (8) (11) — — — Total fair value of derivative liabilities $(281) $200 $(81) $(383) $147 $(236) Net fair value derivative assets/(liabilities) $466 $(237) $229 $(8) $(24) $(32) CECONY Fair value of derivative assets Current $350 $(312) $38 (b) $135 $(64) $71 (b) Noncurrent 176 (96) 80 71 (15) 56 Total fair value of derivative assets $526 $(408) $118 $206 $(79) $127 Fair value of derivative liabilities Current $(189) $160 $(29) $(131) $43 $(88) Noncurrent (43) 34 (9) (50) 10 (40) Total fair value of derivative liabilities $(232) $194 $(38) $(181) $53 $(128) Net fair value derivative assets/(liabilities) $294 ($214) $80 $25 $(26) $(1) (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, 2022, margin deposits for Con Edison and CECONY of $13 million were classified as derivative assets, and ($(10) million and $(6) million, respectively) were classified as derivative liabilities on the consolidated balance sheet, but not included in the table. At December 31, 2021, margin deposits for Con Edison and CECONY ($1 million and an immaterial amount, respectively) were classified as derivative assets on the consolidated balance sheet, 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. (c) Includes amounts for interest rate swaps of $31 million in current assets and $75 million in noncurrent assets. At December 31, 2022, the Clean Energy Businesses had interest rate swaps with notional amounts of $982 million. The expiration dates of the swaps range from 2025-2041. (d) Includes amounts for interest rate swaps of $4 million in noncurrent assets, $(20) million in current liabilities and $(38) million in noncurrent liabilities. At December 31, 2021, the Clean Energy Businesses had interest rate swaps with notional amounts of $1,031 million. The expiration dates of the swaps ranged from 2025-2041. (e) Amounts represent derivative assets and liabilities included in current assets and current liabilities held for sale, respectively, on Con Edison's consolidated balance sheet as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X.
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, 2022 and 2021: Con Edison CECONY (Millions of Dollars) Balance Sheet Location 2022 2021 2022 2021 Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations: Current Deferred derivative gains $168 $134 $155 $124 Noncurrent Deferred derivative gains 83 57 75 51 Total deferred gains/(losses) $251 $191 $230 $175 Current Deferred derivative losses $(43) $49 $(44) $43 Current Recoverable energy costs 408 3 372 — Noncurrent Deferred derivative losses 19 70 19 66 Total deferred gains/(losses) $384 $122 $347 $109 Net deferred gains/(losses) $635 $313 $577 $284 Income Statement Location Pre-tax gain/(loss) recognized in income Gas purchased for resale $5 $18 $— $— Non-utility revenue — 3 — — Other operations and maintenance expense 4 5 4 5 Other interest expense 159 (a) 52 — — Total pre-tax gain/(loss) recognized in income $168 $78 $4 $5 (a) Comprised of amounts related to interest rate swaps of the Clean Energy Businesses. The Clean Energy Businesses were held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X.
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, 2022: Electric Energy Capacity (MW) (a) Natural Gas (Dt) (a)(b) Refined Fuels (gallons) Con Edison 33,546,670 46,116 290,398,144 168,000 CECONY 31,567,400 30,675 272,790,000 168,000 (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. (c) Included are electric energy, capacity, and natural gas ((240) MWh, 8,616 MW, and 3,518,144 Dt, respectively) volumes of the Clean Energy Businesses.
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, 2022: (Millions of Dollars) Con Edison (a) CECONY (a) Aggregate fair value – net liabilities $157 $86 Collateral posted 70 70 Additional collateral (b) (downgrade one level from current ratings) 65 15 Additional collateral (b)(c) (downgrade to below investment grade from current ratings) 138 67 (a) Non-derivative transactions for the purchase and sale of electricity and gas and qualifying derivative instruments, which 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 and the Clean Energy Businesses were no longer extended unsecured credit for such purchases, the Companies would be required to post additional collateral of $9 million at December 31, 2022. 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, 2022, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $115 million.

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2022
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, which 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, 2022 and 2021 are summarized below. 2022 2021 (Millions of Dollars) Level 1 Level 2 Level 3 Netting Adjustment (e) Total Level 1 Level 2 Level 3 Netting Adjustment (e) Total Con Edison Derivative assets: Commodity (a)(b)(c) $84 $476 $2 $(420) $142 $95 $260 $17 $(171) $201 Commodity held for sale (g) 6 34 31 2 73 — — — — — Interest rate swaps (a)(b)(c)(f) (g) — 106 — — 106 — 4 — — 4 Other (a)(b)(d) 437 116 — — 553 492 135 — — 627 Total assets $527 $732 $33 $(418) $874 $587 $399 $17 $(171) $832 Derivative liabilities: Commodity (a)(b)(c) $18 $204 $16 $(184) $54 $33 $266 $28 $(148) $179 Commodity held for sale (g) 8 24 2 2 36 Interest rate swaps (a)(b)(c)(f) (g) — — — — — — 57 — — 57 Total liabilities $26 $228 $18 $(182) $90 $33 $323 $28 $(148) $236 CECONY Derivative assets: Commodity (a)(b)(c) $83 $434 $2 $(388) $131 $67 $138 $1 $(79) $127 Other (a)(b)(d) 422 110 — — 532 474 127 — — 601 Total assets $505 $544 $2 $(388) $663 $541 $265 $1 $(79) $728 Derivative liabilities: Commodity (a)(b)(c) $18 $198 $8 $(180) $44 $1 $172 $8 $(53) $128 (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. Con Edison and CECONY had an immaterial amount of derivative liabilities and $10 million and $9 million of commodity derivative assets, respectively, transferred from level 3 to level 2 during the year ended December 31, 2022 because of availability of observable market data due to the decrease in the terms of certain contracts from beyond three years as of September 30, 2022 to less than three years as of December 31, 2022. Con Edison and CECONY had $1 million of commodity derivative assets and $4 million and $3 million of commodity derivative liabilities, respectively, transferred from level 3 to level 2 during the year ended December 31, 2021 because of availability of observable market data due to the decrease in the terms of certain contracts from beyond three years as of September 30, 2021 to less than three years as of December 31, 2021. (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, 2022 and 2021, the Companies determined that nonperformance risk would have no material impact on their financial position or results of operations. (d) Other assets are comprised of assets such as life insurance contracts within the deferred compensation plan and non-qualified retirement plans. (e) 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. (f) See Note Q. (g) Amounts for 2022 represent the Clean Energy Businesses' derivative assets and liabilities included in current assets and current liabilities held for sale, respectively on Con Edison's consolidated balance sheet as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X.
Schedule of Commodity Derivatives	Fair Value of Level 3 at December 31, 2022 (Millions of Dollars) Valuation Techniques Unobservable Inputs Range Con Edison — Commodity Electricity - Held and Used $(15) Discounted Cash Flow Forward capacity prices (a) $1.42-$16.08 per kW-month Transmission Congestion Contracts/Financial Transmission Rights - Held and Used 1 Discounted Cash Flow Inter-zonal forward price curves adjusted for historical zonal losses (b) $0.91-$3.03 per MWh Total Con Edison - Commodity - Held and Used $(14) Electricity - Held for Sale $14 Discounted Cash Flow Forward energy prices (a) $22.00-$187.50 per MWh 10 Discounted Cash Flow Forward capacity prices (a) $0.96-$5.75 per kW-month Transmission Congestion Contracts/Financial Transmission Rights - Held for Sale 4 Discounted Cash Flow Inter-zonal forward price curves adjusted for historical zonal losses (b) $(12.44)-$195.57 per MWh Natural Gas - Held for Sale 1 Discounted Cash Flow Forward natural gas prices (a) $3.75-$14.51 per Dt Total Con Edison - Commodity - Held for Sale (c) $29 Total Con Edison — Commodity $15 CECONY — Commodity Electricity $(7) Discounted Cash Flow Forward capacity prices (a) $1.42-$16.08 per kW-month Transmission Congestion Contracts 1 Discounted Cash Flow Inter-zonal forward price curves adjusted for historical zonal losses (b) $0.91-$3.03 per MWh 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. (c) Amount represents the Fair Value of Level 3 assets of the Clean Energy Businesses, which were held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X.
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, 2022 and 2021 and classified as Level 3 in the fair value hierarchy: Con Edison CECONY (Millions of Dollars) 2022 2021 2022 2021 Beginning balance as of January 1, $(11) $(19) $(7) $(10) Included in earnings (11) (9) (5) (3) Included in regulatory assets and liabilities 11 3 10 1 Purchases — 6 — — Settlements 11 5 5 3 Changes in level 3 assets and liabilities held for sale (a) 25 — — — Transfer out of level 3 (10) 3 (9) 2 Ending balance as of December 31, $15 $(11) $(6) $(7) (a) Am ounts for 2022 represent the net change in the value of level 3 assets and liabilities of the Clean Energy Businesses. The Clean Energy Businesses were classified as held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X.

Variable Interest Entities (Tab

Variable Interest Entities (Tables)	12 Months Ended
	Dec. 31, 2022
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 years ended December 31, 2022 and 2021, as follows: (Millions of Dollars) 2022 2021 Tax equity investor $(49) $(158) After tax (37) (119) Con Edison 41 155 After tax 31 117 (Millions of Dollars) 2022 2021 Tax equity investor $(11) $6 After tax (8) 4 Con Edison 51 30 After tax 38 24
Schedule of Business Acquisitions, by Acquisition	At December 31, 2022 and 2021, Con Edison’s consolidated balance sheet included the following amounts associated with its VIEs: Tax Equity Projects Great Valley Solar Copper Mountain - Mesquite Solar CED Nevada Virginia (c)(h) CED Nevada Virginia (c)(h) (Millions of Dollars) 2022 2021 2022 2021 2022 2021 Assets held for sale (a) $305 $— $580 $— $686 $— Non-utility property, less accumulated depreciation (f)(g) — 275 — 431 — 643 Other assets — 37 — 167 — 55 Total assets (a) $305 $312 $580 $598 $686 $698 Liabilities held for sale (b) 20 — 81 — 331 — Other liabilities — 14 — 74 — 315 Total liabilities (b) $20 $14 $81 $74 $331 $315 (a) The assets of the Tax Equity Projects and CED Nevada Virginia represent assets of a consolidated VIE that can be used only to settle obligations of the consolidated VIE. Amounts shown for 2022 are included in current assets held for sale on Con Edison's consolidated balance sheet as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X. (b) The liabilities of the Tax Equity Projects and CED Nevada Virginia represent liabilities of a consolidated VIE for which creditors do not have recourse to the general credit of the primary beneficiary. Amounts shown for 2022 are included in current liabilities held for sale on Con Edison's consolidated balance sheet as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X. (c) Con Edison did not provide any financial or other support during the year that was not previously contractually required. (d) Great Valley Solar consists of the Great Valley Solar 1, Great Valley Solar 2, Great Valley Solar 3 and Great Valley Solar 4 projects, for which the noncontrolling interest of the tax equity investor was $67 million and $84 million at December 31, 2022 and 2021, respectively. (e) Copper Mountain - Mesquite Solar consists of the Copper Mountain Solar 4, Mesquite Solar 2 and Mesquite Solar 3 projects for which the noncontrolling interest of the tax equity investor was $94 million and $118 million at December 31, 2022 and 2021, respectively. (f) Non-utility property is reduced by accumulated depreciation of $35 million for Great Valley Solar, $59 million for Copper Mountain - Mesquite Solar and $29 million for CED Nevada Virginia at December 31, 2022. (g) Non-utility property is reduced by accumulated depreciation of $26 million for Great Valley Solar, $44 million for Copper Mountain - Mesquite Solar and $10 million for CED Nevada Virginia at December 31, 2021. (h) CED Nevada Virginia consists of the Copper Mountain Solar 5, Battle Mountain Solar and Water Strider Solar projects for which the noncontrolling interest of the tax equity investor was $39 million and $95 million at December 31, 2022 and 2021, respectively.
Summary of VIEs	The following table summarizes the VIEs into which the Clean Energy Businesses have entered as of December 31, 2022. The Clean Energy Businesses were classified as held for sale as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X. Project Name Generating Capacity (a) (MW AC) Power Purchase Agreement Term in Years Year of Investment Location Maximum Millions of Dollars ) (b) Great Valley Solar (c) 200 15-20 2018 CA $218 Copper Mountain - Mesquite Solar (c) 344 20-25 2018 NV and AZ 404 CED Nevada Virginia (c) 431 20-25 2021 NV and VA 316 (a) Represents ownership interest in the project. (b) Maximum exposure is equal to the net assets of the project on the consolidated balance sheet less any applicable noncontrolling interest. Con Edison did not provide any financial or other support during the year that was not previously contractually required. (c) For the projects comprising Great Valley Solar, Copper Mountain Mesquite Solar and CED Nevada Virginia, refer to (d), (e) and (h) in the table above.

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2022
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, 2022 and 2021, and changes to the obligation for the years then ended: Con Edison CECONY (Millions of Dollars) 2022 2021 2022 2021 Beginning Balance as of January 1, $577 $577 $504 $508 ARO held for sale (a) (77) — — — Changes in estimated cash flows 44 58 43 55 Accretion expense 18 18 14 15 Liabilities settled (62) (75) (62) (74) Ending Balance as of December 31, (b) $500 $577 $499 $504 (a) The asset retirement obligations of the Clean Energy Businesses are reflected in current liabilities held for sale on Con Edison's consolidated balance sheet as of December 31, 2022. See "Assets and Liabilities Held for Sale" in Note A and Note X. (b) At December 31, 2022, Con Edison and CECONY recorded reductions of $78 million and $77 million, respectively, to the regulatory liability associated with cost of removal to reflect depreciation and interest expense. At December 31, 2021, Con Edison and CECONY recorded reductions of $87 million and $85 million, respectively, 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
	Dec. 31, 2022
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, 2022, 2021 and 2020 were as follows: CECONY (Millions of Dollars) 2022 2021 2020 Cost of services provided $135 $137 $128 Cost of services received 75 68 66

Held-for-Sale Treatment of th_2

Held-for-Sale Treatment of the Clean Energy Businesses (Tables)	12 Months Ended
	Dec. 31, 2022
Discontinued Operations and Disposal Groups [Abstract]
Disposal Groups, Including Discontinued Operations	Clean Energy Businesses (Millions of Dollars) 2022 2021 2020 Pre-tax operating income $466 $310 $68 Pre-tax operating income, excluding non-controlling interest 406 158 23 The Clean Energy Business represent a reportable segment. See Note P. At December 31, 2022, the carrying amounts of the major classes of assets and liabilities of the Clean Energy Businesses that are expected to be sold are presented on a held-for-sale basis, and accordingly exclude certain intercompany and net deferred tax liability balances, as follows : (Millions of Dollars) December 31, ASSETS CURRENT ASSETS Cash and temporary cash investments $25 Accounts receivable and other receivables - net allowance for uncollectible accounts 319 Accrued unbilled revenue 51 Fuel oil, gas in storage, materials and supplies, at average cost 56 Restricted cash 223 Fair value of derivatives assets 84 Prepayments 35 Other current assets 24 TOTAL CURRENT ASSETS 817 NON-UTILITY PLANT Non-utility property, net accumulated depreciation 4,197 Construction work in progress 522 NET PLANT 4,719 OTHER NONCURRENT ASSETS Goodwill 31 Intangible assets, less accumulated amortization 1,222 Operating lease right-of-use asset 266 Fair value of derivatives assets 93 Other deferred charges and noncurrent assets 14 TOTAL OTHER NONCURRENT ASSETS 1,626 TOTAL ASSETS $7,162 (a) Not included in the fair value of derivative assets above is $2 million related to an intercompany amount with CECONY, which amount is eliminated in consolidation. See Note U as that amount is governed by derivative agreements, it will remain an asset of the Clean Energy Businesses following the expected close of the sale transaction. (Millions of Dollars) December 31, LIABILITIES CURRENT LIABILITIES Long-term debt due within one year $353 Term loan 150 Accounts payable 326 Operating lease liabilities 33 Accrued Interest 40 Other current liabilities 71 TOTAL CURRENT LIABILITIES 973 NONCURRENT LIABILITIES Asset retirement obligations 77 Operating lease liabilities 248 Other deferred credits and noncurrent liabilities 20 TOTAL NONCURRENT LIABILITIES 345 LONG-TERM DEBT 2,292 TOTAL LIABILITIES $3,610

General (Details)

General (Details)	12 Months Ended
	Dec. 31, 2022 subsidiary registrant
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, 2022	Dec. 31, 2021	Dec. 31, 2020
Revenue from External Customer [Line Items]
Excise taxes	$ 400	$ 358	$ 323
CECONY
Revenue from External Customer [Line Items]
Excise taxes	$ 387	$ 346	$ 312

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, 2022	Dec. 31, 2021	Dec. 31, 2020
Public Utility, Property, Plant and Equipment [Line Items]
Accumulated amortization		$ 297
Annual aggregate depreciation allowance	$ 1,907
Software Licenses
Public Utility, Property, Plant and Equipment [Line Items]
Gross asset	72	79
Estimated aggregate annual amortization expense	7
Accumulated amortization	$ 31	$ 24
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
Non-Utility Plant | Maximum | Solar Powered Generating Assets
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	35 years
CECONY
Public Utility, Property, Plant and Equipment [Line Items]
AFUDC rates (percent)	5.20%	4.50%	5.20%
Average depreciation rates (percent)	3.50%	3.50%	3.50%
Annual aggregate depreciation allowance	$ 1,808
CECONY | Software Licenses
Public Utility, Property, Plant and Equipment [Line Items]
Gross asset	69	$ 74
Estimated aggregate annual amortization expense	7
Accumulated amortization	$ 29	$ 24
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)	90 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)	80 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)	55 years
O&R
Public Utility, Property, Plant and Equipment [Line Items]
AFUDC rates (percent)	5%	4.80%	5.30%
Average depreciation rates (percent)	3%	3.10%	3.20%
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, 2022	Dec. 31, 2021
Public Utility, Property, Plant and Equipment [Line Items]
General	$ 4,205	$ 4,170
Held for future use	117	80
Construction work in progress	2,484	2,152
NET UTILITY PLANT	46,752	44,214
Electric Generation
Public Utility, Property, Plant and Equipment [Line Items]
Generation	534	559
Electric Transmission
Public Utility, Property, Plant and Equipment [Line Items]
Transmission	4,223	3,955
Electric Distribution
Public Utility, Property, Plant and Equipment [Line Items]
Distribution	23,345	22,418
General
Public Utility, Property, Plant and Equipment [Line Items]
General	113	87
Gas
Public Utility, Property, Plant and Equipment [Line Items]
Gas	11,326	10,473
Steam
Public Utility, Property, Plant and Equipment [Line Items]
Steam	1,962	1,924
General
Public Utility, Property, Plant and Equipment [Line Items]
General	2,648	2,566
CECONY
Public Utility, Property, Plant and Equipment [Line Items]
General	3,879	3,854
Held for future use	109	72
Construction work in progress	2,268	1,985
NET UTILITY PLANT	44,009	41,611
CECONY | Electric Generation
Public Utility, Property, Plant and Equipment [Line Items]
Generation	534	559
CECONY | Electric Transmission
Public Utility, Property, Plant and Equipment [Line Items]
Transmission	3,916	3,658
CECONY | Electric Distribution
Public Utility, Property, Plant and Equipment [Line Items]
Distribution	22,130	21,240
CECONY | General
Public Utility, Property, Plant and Equipment [Line Items]
General	113	87
CECONY | Gas
Public Utility, Property, Plant and Equipment [Line Items]
Gas	10,567	9,748
CECONY | Steam
Public Utility, Property, Plant and Equipment [Line Items]
Steam	1,962	1,924
CECONY | General
Public Utility, Property, Plant and Equipment [Line Items]
General	$ 2,410	$ 2,338

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, 2022	Dec. 31, 2021
Public Utility, Property, Plant and Equipment [Line Items]
Prepayments	$ 24	$ 16
Other deferred charges and noncurrent assets	105	81
Depreciation expense, other deferred charges and noncurrent assets and prepayments	15	12
Accumulated depreciation, other deferred charges and noncurrent assets and prepayments	37	22
CECONY
Public Utility, Property, Plant and Equipment [Line Items]
Prepayments	23	15
Other deferred charges and noncurrent assets	103	78
Depreciation expense, other deferred charges and noncurrent assets and prepayments	14	11
Accumulated depreciation, other deferred charges and noncurrent assets and prepayments	$ 33	$ 19

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, 2022	Dec. 31, 2021	Dec. 31, 2020
Finite-Lived Intangible Assets [Line Items]
Intangible assets, net	$ 1,219,000,000	$ 1,290,000,000
Accumulated amortization		297,000,000
Amortization of intangible assets	71,000,000	95,000,000	$ 102,000,000
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
Power Purchase Agreements
Finite-Lived Intangible Assets [Line Items]
Accumulated amortization	359,000,000	288,000,000
Other Intangible Assets
Finite-Lived Intangible Assets [Line Items]
Intangible assets, net	2,000,000	2,000,000
Accumulated amortization	$ 9,000,000	$ 9,000,000

Summary of Significant Accoun_9

Summary of Significant Accounting Policies and Other Matters - Recoverable Energy Costs (Details)	12 Months Ended
	Dec. 31, 2022
Minimum
Public Utilities, General Disclosures [Line Items]
Recovery or refund of energy costs, deferral period	1 month
Maximum
Public Utilities, General Disclosures [Line Items]
Recovery or refund of energy costs, deferral period	2 months

Summary of Significant Accou_10

Summary of Significant Accounting Policies and Other Matters - Investments (Details)	1 Months Ended	12 Months Ended
	May 31, 2021 USD ($)	Dec. 31, 2022 USD ($) mi	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)	Dec. 30, 2021 USD ($)	Jun. 30, 2021 USD ($)	Mar. 31, 2021 USD ($)	Dec. 30, 2020 USD ($)	Dec. 31, 2019 USD ($)	Jan. 31, 2016
Stagecoach
Schedule of Equity Method Investments [Line Items]
Loss on sale of investment (pre-tax)			$ 212,000,000
Loss on sale of investment			147,000,000
Equity method investments						$ 630,000,000	$ 667,000,000
Mountain Valley Pipeline
Schedule of Equity Method Investments [Line Items]
Equity method investments		$ 530,000,000	530,000,000
CET | Mountain Valley Pipeline
Schedule of Equity Method Investments [Line Items]
Equity method investments		111,000,000	$ 111,000,000
CET | Stagecoach | Subsidiaries
Schedule of Equity Method Investments [Line Items]
Proceeds from sale	$ 1,225,000,000
Equity method investment, ownership percent (in percent)	50%		50%
Impairment loss		$ 414,000,000
CET Gas | Stagecoach | Subsidiaries
Schedule of Equity Method Investments [Line Items]
Proceeds from sale	$ 629,000,000
CET Gas | Mountain Valley Pipeline
Schedule of Equity Method Investments [Line Items]
Equity method investment, ownership percent (in percent)		9.60%	10.20%	11.30%
Impairment loss		$ 0	$ 231,000,000	$ 320,000,000
Equity method investments									$ 530,000,000
Number of miles in pipeline construction | mi		300
Expected reduction in equity interest		8%
Project, percent completion		94%	94%
Long -term firm transportation contract period		20 years
Cash flows discount rate		8.30%
Impairment loss, after tax			$ 162,000,000	223,000,000
Carrying value of investment			111,000,000	342,000,000	$ 342,000,000			$ 662,000,000
Deferred tax assets		$ 130,000,000	130,000,000	$ 53,000,000
Increase in deferred tax assets			$ 77,000,000
CET Gas | Mountain Valley Pipeline | 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	Dec. 31, 2022	Dec. 31, 2021	May 31, 2021	Dec. 31, 2019
Schedule of Equity Method Investments [Line Items]
Supplemental retirement income plan assets	$ 459	$ 525
Deferred income plan assets	93	102
Other	2	3
INVESTMENTS	$ 841	853
NY Transco | Payment Guarantee by CET Electric of Contributions to New York Transco LLC
Schedule of Equity Method Investments [Line Items]
Ownership interest, percentage	45.70%
CECONY
Schedule of Equity Method Investments [Line Items]
Supplemental retirement income plan assets	$ 439	499
Deferred income plan assets	93	102
Other	7	7
INVESTMENTS	539	608
Mountain Valley Pipeline
Schedule of Equity Method Investments [Line Items]
Equity method investment	530	530
Mountain Valley Pipeline | CET Gas
Schedule of Equity Method Investments [Line Items]
Equity method investment				$ 530
Aggregate project cost			$ 6,600
Mountain Valley Pipeline | Con Edison Transmission
Schedule of Equity Method Investments [Line Items]
Equity method investment	111	111
Mountain Valley Pipeline | Con Edison Transmission | CECONY
Schedule of Equity Method Investments [Line Items]
Equity method investment	0	0
New York Transco, LLC | Con Edison Transmission
Schedule of Equity Method Investments [Line Items]
Equity method investment	176	112
New York Transco, LLC | Con Edison Transmission | 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, 2022
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 - Research and Development Costs (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Research and Development Expenses [Line Items]
Research and development costs	$ 27	$ 25	$ 24
CECONY
Research and Development Expenses [Line Items]
Research and development costs	$ 25	$ 24	$ 23

Summary of Significant Accou_14

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, 2022	Dec. 31, 2021	Dec. 31, 2020
Accounting Policies [Abstract]
Net income	$ 1,660	$ 1,346	$ 1,101
Weighted average common shares outstanding – basic (in shares)	354.5	348.4	334.8
Add: Incremental shares attributable to effect of potentially dilutive securities (in shares)	1.3	1	0.9
Adjusted weighted average common shares outstanding – diluted (in shares)	355.8	349.4	335.7
Net income per common share — basic (in dollars per share)	$ 4.68	$ 3.86	$ 3.29
Net income per common share — diluted (in dollars per share)	$ 4.66	$ 3.85	$ 3.28

Summary of Significant Accou_15

Summary of Significant Accounting Policies and Other Matters - Changes in Accumulated Other Comprehensive Income/(Loss) by Component (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
AOCI Attributable to Parent, Net of Tax [Roll Forward]
BALANCE AS OF BEGINNING OF PERIOD	$ 20,336	$ 19,065	$ 18,213
BALANCE AS OF BEGINNING OF PERIOD	20,037
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	17	30	(6)
BALANCE AS OF END OF PERIOD	20,889	20,336	19,065
BALANCE AS OF END OF PERIOD	20,687	20,037
Accumulated OCI
AOCI Attributable to Parent, Net of Tax [Roll Forward]
BALANCE AS OF BEGINNING OF PERIOD	5	(25)	(19)
BALANCE AS OF END OF PERIOD	22	5	(25)
Pension Plan Liabilities
AOCI Attributable to Parent, Net of Tax [Roll Forward]
OCI before reclassifications, net of tax	13	22	(11)
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax	4	8	5
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	17	30	(6)
OCI before reclassifications, tax	(5)	(8)	4
Amounts reclassified from accumulated OCI related to pension plan liabilities, tax	(1)	(3)	(2)
Accumulated OCI
AOCI Attributable to Parent, Net of Tax [Roll Forward]
BALANCE AS OF BEGINNING OF PERIOD	5	(25)	(19)
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	17	30	(6)
BALANCE AS OF END OF PERIOD	22	5	(25)
Pension Plan Liabilities
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from accumulated OCI related to pension plan liabilities, tax
CECONY
AOCI Attributable to Parent, Net of Tax [Roll Forward]
BALANCE AS OF BEGINNING OF PERIOD	16,312	14,849	14,147
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	4	7	(1)
BALANCE AS OF END OF PERIOD	16,878	16,312	14,849
CECONY | Pension Plan Liabilities
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from accumulated OCI related to pension plan liabilities, tax		(1)
CECONY | Accumulated OCI
AOCI Attributable to Parent, Net of Tax [Roll Forward]
BALANCE AS OF BEGINNING OF PERIOD	0	(7)	(6)
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	4	7	(1)
BALANCE AS OF END OF PERIOD	4	0	(7)
CECONY | Pension Plan Liabilities
AOCI Attributable to Parent, Net of Tax [Roll Forward]
OCI before reclassifications, net of tax	3	5	(3)
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax	1	2	2
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	4	7	(1)
OCI before reclassifications, tax	$ (1)	$ (2)	$ 1

Summary of Significant Accou_16

Summary of Significant Accounting Policies and Other Matters - Reconciliation of Cash, Temporary Investments and Restricted Cash (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Cash and Cash Equivalents [Line Items]
Cash and temporary cash investments	$ 1,282	$ 992
Restricted cash	223	154
Total cash, temporary cash investments and restricted cash	1,505	1,146
Cash Collateral Held For Project Finance Agreements | Clean Energy Businesses
Cash and Cash Equivalents [Line Items]
Restricted cash	223	154
CECONY
Cash and Cash Equivalents [Line Items]
Cash and temporary cash investments	1,056	920
Restricted cash	0	0
Total cash, temporary cash investments and restricted cash	$ 1,056	$ 920

Regulatory Matters - Utility Ra

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

1 Months Ended

12 Months Ended

23 Months Ended

35 Months Ended

36 Months Ended

Feb. 15, 2023

Jan. 01, 2022 USD ($)

Dec. 31, 2021 USD ($)

Feb. 28, 2023 USD ($)

Dec. 31, 2022 USD ($)

Nov. 30, 2022 USD ($)

Apr. 30, 2022

Jan. 31, 2022 USD ($)

Jul. 31, 2021

Dec. 31, 2023 USD ($) substation

Dec. 31, 2022

Dec. 31, 2021

Jan. 31, 2020

Dec. 31, 2025

Dec. 31, 2024 USD ($)

Dec. 31, 2021 USD ($)

Scenario, Forecast | Eastern Queens Reliability Project | Substation

Public Utilities, General Disclosures [Line Items]

Estimated cost of substations

$ 1,100,000

CECONY | Scenario, Forecast | Eastern Queens Reliability Project

Public Utilities, General Disclosures [Line Items]

Number of substations | substation

2

Minimum number of days after adoption of the join proposal to petition

30 days

RECO

Public Utilities, General Disclosures [Line Items]

Common equity ratio (percent)

48.51%

48.32%

49.70%

RECO | New Jersey Board of Public Utilities

Public Utilities, General Disclosures [Line Items]

Investment plan

$ 47,800

Investment plan, term (in years)

5 years

Electric | CECONY

Public Utilities, General Disclosures [Line Items]

Common equity ratio (percent)

48%

Electric | CECONY | Scenario, Forecast

Public Utilities, General Disclosures [Line Items]

Common equity ratio (percent)

48%

Electric | RECO

Public Utilities, General Disclosures [Line Items]

Requested rate increase (decrease), amount

$ 16,900

$ 20,400

Return on common equity (percent)

11.04%

0.50%

Electric | RECO | New Jersey Board of Public Utilities

Public Utilities, General Disclosures [Line Items]

Requested rate increase (decrease), amount

$ 9,650

Electric | O&R

Public Utilities, General Disclosures [Line Items]

Common equity ratio (percent)

48%

Electric | O&R | Scenario, Forecast

Public Utilities, General Disclosures [Line Items]

Common equity ratio (percent)

48%

Steam | CECONY

Public Utilities, General Disclosures [Line Items]

Return on common equity (percent)

10%

Common equity ratio (percent)

50%

Deviation of inflation rate and revenue requirement (in basis points)

50

Steam | CECONY | NYSPSC

Public Utilities, General Disclosures [Line Items]

Requested rate increase (decrease), amount

$ 137,000

Return on common equity (percent)

10%

Common equity ratio (percent)

50%

Electric and Gas Transmission Projects | O&R | Subsidiaries

Public Utilities, General Disclosures [Line Items]

Public utility, rate plan term (in years)

3 years

Electric and Gas Transmission Projects | O&R | Subsidiaries | Subsequent Event

Public Utilities, General Disclosures [Line Items]

Public utility, rate plan term (in years)

3 years

Rate Plan for Year 1 | Electric | O&R

Public Utilities, General Disclosures [Line Items]

Requested rate increase (decrease), amount

$ 8,600

Rate Plan for Year 1 | Electric | O&R | Scenario, Forecast

Public Utilities, General Disclosures [Line Items]

Requested rate increase (decrease), amount

$ 11,700

Rate Plan for Year 1 | Steam | CECONY | Subsequent Event | Scenario, Forecast

Public Utilities, General Disclosures [Line Items]

Requested rate increase (decrease), amount

$ 4,000

Total requested amount

141,000

Rate Plan for Year 2 | Electric | O&R

Public Utilities, General Disclosures [Line Items]

Requested rate increase (decrease), amount

12,100

Rate Plan for Year 2 | Electric | O&R | Scenario, Forecast

Public Utilities, General Disclosures [Line Items]

Requested rate increase (decrease), amount

11,700

Rate Plan for Year 2 | Steam | CECONY

Public Utilities, General Disclosures [Line Items]

Requested rate increase (decrease), amount

$ 54,000

Rate Plan for Year 2 | Steam | CECONY | Subsequent Event | Scenario, Forecast

Public Utilities, General Disclosures [Line Items]

Requested rate increase (decrease), amount

1,000

Total requested amount

55,000

Rate Plan for Year 3 | Electric | O&R

Public Utilities, General Disclosures [Line Items]

Requested rate increase (decrease), amount

$ 12,200

Rate Plan for Year 3 | Electric | O&R | Scenario, Forecast

Public Utilities, General Disclosures [Line Items]

Requested rate increase (decrease), amount

$ 11,700

Rate Plan for Year 3 | Steam | CECONY

Public Utilities, General Disclosures [Line Items]

Requested rate increase (decrease), amount

$ 49,000

Rate Plan for Year 3 | Steam | CECONY | Subsequent Event | Scenario, Forecast

Public Utilities, General Disclosures [Line Items]

Requested rate increase (decrease), amount

4,000

Total requested amount

$ 53,000

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, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2025	Dec. 31, 2022	Dec. 31, 2019
Public Utilities, General Disclosures [Line Items]
Deferred regulatory liabilities		$ 3,000,000	$ 7,000,000	$ 41,000,000		$ 3,000,000	$ 17,000,000
Revenues		$ 15,670,000,000	13,676,000,000	12,246,000,000
NYSPSC
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues		15%				15%
NYSPSC | Maximum
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues		15%				15%
Percentage of debt to total consolidated debt						20%
CECONY
Public Utilities, General Disclosures [Line Items]
Revenues		$ 13,268,000,000	11,716,000,000	10,647,000,000
CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Retention of annual transmission congestion revenues						$ 75,000,000
Actual earnings adjustment mechanism incentives		33,000,000	64,000,000	34,000,000
Deferred regulatory liabilities		90,000,000	226,000,000	242,000,000		90,000,000
Negative revenue adjustments		3,000,000	0	5,000,000
Cost reconciliation, deferred net regulatory liabilities		138,000,000	191,000,000	288,000,000		138,000,000
Deferred regulatory asset (liability)		$ 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%				9.30%
Earnings sharing, threshold limit		$ 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%				15%
CECONY | Electric | Gas Leak Backlog, Leak Prone Pipe and Service Terminations
Public Utilities, General Disclosures [Line Items]
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)					9.25%
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			$ 43,000,000
CECONY | Electric | Rate Plan for Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes		$ 113,000,000				$ 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
Average rate base						$ 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%				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
Average rate base					$ 26,095,000,000
Weighted average cost of capital (after-tax) (percent)					6.75%
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				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
Average rate base						$ 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%				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
Average rate base					$ 27,925,000,000
Weighted average cost of capital (after-tax) (percent)					6.79%
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				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
Average rate base						$ 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%				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
Average rate base					$ 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 | Rate Plan for Year 1 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Amount of cost recovery					244,000,000
Requested rate increase (decrease), amount					457,000,000
Over Seven To Fifteen Years | CECONY | Electric | Rate Plan for Year 2 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Amount of cost recovery					237,000,000
Requested rate increase (decrease), amount					457,000,000
Over Seven To Fifteen Years | CECONY | Electric | Rate Plan for Year 3 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Amount of cost recovery					281,000,000
Requested rate increase (decrease), amount					457,000,000
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 - 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, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2025	Dec. 31, 2022	Dec. 31, 2019
Public Utilities, General Disclosures [Line Items]
Revenues		$ 15,670,000,000	$ 13,676,000,000	$ 12,246,000,000
Deferred regulatory liabilities		3,000,000	7,000,000	41,000,000		$ 3,000,000	$ 17,000,000
CECONY
Public Utilities, General Disclosures [Line Items]
Revenues		13,268,000,000	11,716,000,000	10,647,000,000
CECONY | Gas
Public Utilities, General Disclosures [Line Items]
Percentage of revenue reserve						15%
Other earnings incentives		8,000,000	26,000,000	3,000,000
Deferred regulatory liabilities		141,000,000	100,000,000	27,000,000		$ 141,000,000
Negative revenue adjustments		8,000,000	0	0
Cost reconciliation, deferred net regulatory liabilities		70,000,000	14,000,000	91,000,000		70,000,000
Deferred regulatory asset (liability)		10,800,000	(26,000,000)	$ (24,700,000)		$ 10,800,000
Authorized return on common equity (percent)						8.80%
Earnings sharing (percent)				9.30%
Earnings sharing, threshold limit		0	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]
Revenues		$ 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
Average rate base						$ 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%
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
Average rate base					$ 9,647,000,000
Weighted average cost of capital (after-tax) (percent)					6.75%
Authorized return on common equity (percent)					9.25%
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]
Net utility plant reconciliations						$ 8,108,000,000
CECONY | Gas | Rate Plan for Year 1 | Gas average excluding AMI | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations					$ 10,466,000,000
CECONY | Gas | Rate Plan for Year 1 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						142,000,000
CECONY | Gas | Rate Plan for Year 1 | AMI | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations					234,000,000
CECONY | Gas | Rate Plan for Year 1 | Customer Service Systems (CSS) | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations					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
Average rate base						$ 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%
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
Average rate base					$ 10,428,000,000
Weighted average cost of capital (after-tax) (percent)					6.79%
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]
Net utility plant reconciliations						$ 8,808,000,000
CECONY | Gas | Rate Plan for Year 2 | Gas average excluding AMI | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations					$ 11,442,000,000
CECONY | Gas | Rate Plan for Year 2 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						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
Average rate base						$ 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%
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
Average rate base					$ 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]
Net utility plant reconciliations						$ 9,510,000,000
CECONY | Gas | Rate Plan for Year 3 | Gas average excluding AMI | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations					$ 12,142,000,000
CECONY | Gas | Rate Plan for Year 3 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						$ 211,000,000
NYSPSC
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues		15%				15%
NYSPSC | Maximum
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues		15%				15%
Percentage of debt to total consolidated debt						20%
NYSPSC | CECONY | Gas
Public Utilities, General Disclosures [Line Items]
Actual return on common equity (percent)				8.56%
Amount of cost recovery	$ 7,000,000			$ 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 | 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) - CECONY - Steam - USD ($)	12 Months Ended									36 Months Ended	108 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2016	Dec. 31, 2022
Public Utilities, General Disclosures [Line Items]
Amortizations to income of net regulatory (assets) and liabilities										$ 37,000,000
Regulatory liabilities, amortization period										3 years
Negative revenue adjustments											$ 0
Cost reconciliation, deferred net regulatory liabilities				$ 8,000,000		$ 14,000,000	$ 8,000,000		$ 42,000,000	$ 8,000,000
Cost reconciliation, deferred net regulatory assets	$ 11,000,000	$ 32,000,000	$ 35,000,000		$ 1,000,000			$ 17,000,000			$ 11,000,000
Increase (decrease) in regulatory liabilities	(100,000)	(1,000,000)	(2,000,000)						0
Authorized return on common equity (percent)										9.30%
Earnings sharing (percent)					9.90%
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, positive adjustment					$ 2,300,000	$ 1,100,000	4,000,000
Earnings sharing, additional adjustment		$ 200,000					400,000
Common equity ratio (percent)										48%
Other regulatory liabilities							$ 8,000,000			$ 8,000,000
Difference in property taxes (percent)										90%
Deferral, annual maximum (not more than) (percent)										10%
Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)										$ 1,000,000
Rate Plan for Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes										(22,400,000)
Average rate base										$ 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%			5.17%
Rate Plan for Year 1 | Production
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations										$ 1,752,000,000
Rate Plan for Year 1 | Distribution
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations										6,000,000
Rate Plan for Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes										19,800,000
Average rate base										$ 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%			5.23%
Rate Plan for Year 2 | Production
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations										$ 1,732,000,000
Rate Plan for Year 2 | Distribution
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations										11,000,000
Rate Plan for Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes										20,300,000
Average rate base										$ 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%			5.39%
Rate Plan for Year 3 | Production
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations										$ 1,720,000,000
Rate Plan for Year 3 | Distribution
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations										25,000,000
Year 4
Public Utilities, General Disclosures [Line Items]
Base rate changes										$ 0
Actual return on common equity (percent)										9.51%
Year 5
Public Utilities, General Disclosures [Line Items]
Base rate changes										$ 0
Actual return on common equity (percent)										11.73%
Year 6
Public Utilities, General Disclosures [Line Items]
Base rate changes										$ 0
Actual return on common equity (percent)										10.45%
Year 7
Public Utilities, General Disclosures [Line Items]
Base rate changes										$ 0
Actual return on common equity (percent)										7.91%
Year 8
Public Utilities, General Disclosures [Line Items]
Base rate changes										$ 0
Actual return on common equity (percent)										5.99%
Year 9
Public Utilities, General Disclosures [Line Items]
Actual return on common equity (percent)										5.72%

Regulatory Matters - Summary _4

Regulatory Matters - Summary of Utilities Rate Plans (O&R New York-Electric) (Details) - USD ($)	12 Months Ended				36 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2024	Dec. 31, 2021
Public Utilities, General Disclosures [Line Items]
Deferred regulatory assets	$ 702,000,000	$ 662,000,000				$ 662,000,000
Deferred regulatory liabilities	$ 3,000,000	7,000,000	$ 41,000,000	$ 17,000,000		7,000,000
NYSPSC
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues	15%
Percentage of debt to total consolidated debt	20%
Maximum | NYSPSC
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues	15%
O&R | Electric
Public Utilities, General Disclosures [Line Items]
Deferred regulatory assets			6,000,000	100,000
Deferred regulatory liabilities	$ 6,900,000	10,000,000				10,000,000
Negative revenue adjustments		0	0	0
Deferral of net increase (decrease) to regulatory assets	$ 9,400,000	24,000,000	30,300,000	$ 4,300,000
Deferred regulatory asset (liability)		(400,000)				$ (400,000)
Earnings sharing (percent)				9.60%
Common equity ratio (percent)						48%
Recovery of late payment charges, period (in years)	3 years
Recovery of late payment charges, amount	$ 2,200,000
Recovery of late payment charges, return on equity threshold rate	500%
Deferrals for property taxes limitation from rates (percent)						90%
O&R | Electric | Rate Plan for Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes						$ 13,400,000
Amortization to income of net regulatory assets						1,500,000
Potential earnings adjustment mechanism incentives						3,600,000
Potential incentive if target is met, related to service terminations						500,000
Average rate base						$ 878,000,000
Weighted average cost of capital (after-tax) (percent)						6.97%
Authorized return on common equity (percent)						9%
Actual return on common equity (percent)						9.60%
Cost of long-term debt (percent)						5.17%
Regulatory assets, amortization period (in years)						6 years
Requested rate increase (decrease), amount						$ 8,600,000
Deferral, annual maximum (not more than) (percent)						0.10%
O&R | Electric | Rate Plan for Year 1 | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						$ 1,008,000,000
O&R | Electric | Rate Plan for Year 1 | Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						48,000,000
O&R | Electric | Rate Plan for Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)						4,400,000
O&R | Electric | Rate Plan for Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes						8,000,000
Amortization to income of net regulatory assets						1,500,000
Potential earnings adjustment mechanism incentives						4,000,000
Potential incentive if target is met, related to service terminations						500,000
Average rate base						$ 906,000,000
Weighted average cost of capital (after-tax) (percent)						6.96%
Actual return on common equity (percent)						8.76%
Cost of long-term debt (percent)						5.14%
Requested rate increase (decrease), amount						$ 12,100,000
Deferral, annual maximum (not more than) (percent)						0.075%
O&R | Electric | Rate Plan for Year 2 | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						$ 1,032,000,000
O&R | Electric | Rate Plan for Year 2 | Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						58,000,000
O&R | Electric | Rate Plan for Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)						4,400,000
O&R | Electric | Rate Plan for Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes						5,800,000
Amortization to income of net regulatory assets						1,500,000
Potential earnings adjustment mechanism incentives						4,200,000
Potential incentive if target is met, related to service terminations	$ 2,700,000					500,000
Average rate base						$ 948,000,000
Weighted average cost of capital (after-tax) (percent)						6.96%
Actual return on common equity (percent)						9.16%
Cost of long-term debt (percent)						5.14%
Requested rate increase (decrease), amount						$ 12,200,000
Deferral, annual maximum (not more than) (percent)						0.05%
O&R | Electric | Rate Plan for Year 3 | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						$ 1,083,000,000
O&R | Electric | Rate Plan for Year 3 | Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						61,000,000
O&R | Electric | Rate Plan for Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)						$ 4,500,000
O&R | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Actual return on common equity (percent)					0.0009%
Earnings sharing (percent)					9.70%
Common equity ratio (percent)					48%
O&R | Electric | Scenario, Forecast | Rate Plan for Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes					$ 4,900,000
Amortization to income of net regulatory assets					11,800,000
Potential earnings adjustment mechanism incentives					3,300,000
Average rate base					$ 1,021,000,000
Weighted average cost of capital (after-tax) (percent)					6.77%
Authorized return on common equity (percent)					9.20%
Cost of long-term debt (percent)					4.58%
Regulatory assets, amortization period (in years)					5 years
Requested rate increase (decrease), amount					$ 11,700,000
O&R | Electric | Scenario, Forecast | Rate Plan for Year 1 | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations					1,175,000,000
O&R | Electric | Scenario, Forecast | Rate Plan for Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)					4,300,000
O&R | Electric | Scenario, Forecast | Rate Plan for Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes					16,200,000
Amortization to income of net regulatory assets					13,500,000
Potential earnings adjustment mechanism incentives					2,300,000
Average rate base					$ 1,044,000,000
Weighted average cost of capital (after-tax) (percent)					6.73%
Cost of long-term debt (percent)					4.51%
Requested rate increase (decrease), amount					$ 11,700,000
O&R | Electric | Scenario, Forecast | Rate Plan for Year 2 | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations					1,198,000,000
O&R | Electric | Scenario, Forecast | Rate Plan for Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)					4,400,000
O&R | Electric | Scenario, Forecast | Rate Plan for Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes					23,100,000
Amortization to income of net regulatory assets					15,200,000
Potential earnings adjustment mechanism incentives					4,000,000
Average rate base					$ 1,144,000,000
Weighted average cost of capital (after-tax) (percent)					6.72%
Cost of long-term debt (percent)					4.49%
Requested rate increase (decrease), amount					$ 11,700,000
O&R | Electric | Scenario, Forecast | Rate Plan for Year 3 | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations					1,304,000,000
O&R | Electric | Scenario, Forecast | Rate Plan for Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)					$ 5,100,000
Energy Efficiency | O&R | Electric
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		1,800,000	1,900,000	$ 2,600,000
Service Termination | O&R | Electric
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		0	$ 500,000	$ 200,000
Incentives reversed		$ 500,000

Regulatory Matters - Summary _5

Regulatory Matters - Summary of Utilities Rate Plans (O&R New York-Gas) (Details) - USD ($)	12 Months Ended				36 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2024	Dec. 31, 2021
Public Utilities, General Disclosures [Line Items]
Deferred regulatory assets	$ 702,000,000	$ 662,000,000				$ 662,000,000
NYSPSC
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues	15%
Percentage of debt to total consolidated debt	20%
Maximum | NYSPSC
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues	15%
O&R
Public Utilities, General Disclosures [Line Items]
Earnings above threshold	$ 1,100,000	1,700,000
O&R | Gas
Public Utilities, General Disclosures [Line Items]
Amount of revenues retained		4,000,000				$ 4,000,000
Share in variances in annual revenue retained (percent)						20%
Potential earnings adjustment mechanism incentives						$ 300,000
Deferred regulatory assets	2,000,000	4,000,000	$ 500,000	$ 800,000		4,000,000
Negative revenue adjustments		0	0	200,000
Cost reconciliation, deferred net regulatory liabilities	$ 3,400,000			6,000,000
Cost reconciliation, deferred net regulatory assets		$ 8,000,000	1,800,000			$ 8,000,000
Earnings sharing (percent)		9.60%				9.60%
Common equity ratio (percent)						48%
Recovery of late payment charges, period (in years)	3 years
Recovery of late payment charges, amount	$ 600,000
Recovery of late payment charges, return on equity threshold rate	0.05%
O&R | Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Negative revenue adjustments					$ 100,000
Earnings sharing (percent)					9.70%
Common equity ratio (percent)					48%
Deferrals for property taxes limitation from rates (percent)					90%
O&R | Gas | Customers
Public Utilities, General Disclosures [Line Items]
Share in variances in annual revenue retained (percent)						80%
O&R | Gas | Rate Plan for Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes						$ (7,500,000)
Amortization to income of net regulatory assets						1,800,000
Potential earnings adjustment mechanism incentives						1,200,000
Net utility plant reconciliations						593,000,000
Average rate base						$ 454,000,000
Weighted average cost of capital (after-tax) (percent)						6.97%
Authorized return on common equity (percent)						9%
Actual return on common equity (percent)						8.90%
Cost of long-term debt (percent)						5.17%
Requested rate increase (decrease), amount						$ (5,900,000)
O&R | Gas | Rate Plan for Year 1 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes					$ 700,000
Amortization to income of net regulatory assets					800,000
Potential earnings adjustment mechanism incentives					200,000
Potential positive rate adjustment for gas safety and performance					1,200,000
Net utility plant reconciliations					720,000,000
Average rate base					$ 566,000,000
Weighted average cost of capital (after-tax) (percent)					6.77%
Authorized return on common equity (percent)					9.20%
Actual return on common equity (percent)					10.01%
Cost of long-term debt (percent)					4.58%
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 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						20,000,000
O&R | Gas | Rate Plan for Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)						5,500,000
O&R | Gas | Rate Plan for Year 1 | Maximum | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)					$ 6,300,000
O&R | Gas | Rate Plan for Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes						3,600,000
Amortization to income of net regulatory assets						1,800,000
Potential earnings adjustment mechanism incentives						1,300,000
Net utility plant reconciliations						611,000,000
Average rate base						$ 476,000,000
Weighted average cost of capital (after-tax) (percent)						6.96%
Actual return on common equity (percent)						9.58%
Cost of long-term debt (percent)						5.14%
Requested rate increase (decrease), amount						$ 1,000,000
O&R | Gas | Rate Plan for Year 2 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes					7,400,000
Amortization to income of net regulatory assets					700,000
Potential earnings adjustment mechanism incentives					200,000
Potential positive rate adjustment for gas safety and performance					1,300,000
Net utility plant reconciliations					761,000,000
Average rate base					$ 607,000,000
Weighted average cost of capital (after-tax) (percent)					6.73%
Cost of long-term debt (percent)					4.51%
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 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						24,000,000
O&R | Gas | Rate Plan for Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)						5,700,000
O&R | Gas | Rate Plan for Year 2 | Maximum | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)					$ 6,700,000
O&R | Gas | Rate Plan for Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes						700,000
Amortization to income of net regulatory assets						1,800,000
Potential earnings adjustment mechanism incentives						1,300,000
Net utility plant reconciliations						632,000,000
Average rate base						$ 498,000,000
Weighted average cost of capital (after-tax) (percent)						6.96%
Actual return on common equity (percent)						10.11%
Cost of long-term debt (percent)						5.14%
Requested rate increase (decrease), amount						$ 1,000,000
O&R | Gas | Rate Plan for Year 3 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes					9,900,000
Amortization to income of net regulatory assets					300,000
Potential earnings adjustment mechanism incentives					400,000
Potential positive rate adjustment for gas safety and performance					1,400,000
Net utility plant reconciliations					803,000,000
Average rate base					$ 694,000,000
Weighted average cost of capital (after-tax) (percent)					6.72%
Cost of long-term debt (percent)					4.49%
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 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						25,000,000
O&R | Gas | Rate Plan for Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)						$ 6,000,000
O&R | Gas | Rate Plan for Year 3 | Maximum | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)					$ 7,300,000
Energy Efficiency | O&R | Gas
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives	$ 200,000	$ 500,000	500,000	500,000
Service Termination | O&R | Gas
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives	$ 200,000	200,000	$ 300,000	$ 700,000
Incentives reversed		$ 300,000

Regulatory Matters - Summary _6

Regulatory Matters - Summary of Utilities Rate Plans (RECO) (Details) - RECO - USD ($) $ in Thousands		1 Months Ended	12 Months Ended	23 Months Ended	35 Months Ended
	Jan. 01, 2022	Jan. 31, 2022	Dec. 31, 2016	Dec. 31, 2021	Jan. 31, 2020	Jan. 31, 2016
Public Utilities, General Disclosures [Line Items]
Amortizations to income of net regulatory (assets) and liabilities					$ 200
Regulatory liabilities, amortization period	3 years				3 years
Amortization to income of net regulatory assets	$ 9,200			$ 4,800	$ 25,600
Regulatory assets, amortization period (in years)	3 years			4 years	4 years
Average rate base	$ 262,800			$ 229,900	$ 178,700
Weighted average cost of capital (after-tax) (percent)		7.08%		7.11%	7.47%
Authorized return on common equity (percent)		9.60%		9.50%	9.60%
Cost of long-term debt (percent)		4.74%		4.88%	5.37%
Common equity ratio (percent)		48.51%		48.32%	49.70%
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
Electric
Public Utilities, General Disclosures [Line Items]
Plan electric system storm hardening amount						$ 15,700
Plan period (years)			3 years
Rate Plan for Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes		$ 9,650		$ 12,000	$ 1,700
Actual return on common equity (percent)	9.60%			5.40%	7.50%
Rate Plan for Year 2
Public Utilities, General Disclosures [Line Items]
Actual return on common equity (percent)				2.30%	5.70%
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) - RECO - USD ($) $ in Thousands			1 Months Ended
	Jan. 01, 2022	Dec. 31, 2021	Dec. 31, 2022	Jan. 31, 2022	Jul. 31, 2021
New Jersey Board of Public Utilities
Public Utilities, General Disclosures [Line Items]
Investment plan			$ 47,800
Investment plan, term (in years)			5 years
Electric
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount		$ 16,900		$ 20,400
Return on common equity (percent)				11.04%	0.50%
Common equity ratio				47%
Electric | New Jersey Board of Public Utilities
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount	$ 9,650

Regulatory Matters - COVID-19 R

Regulatory Matters - COVID-19 Regulatory Matters (Details) - USD ($) $ in Millions	1 Months Ended			12 Months Ended				25 Months Ended	34 Months Ended
	Jan. 31, 2023	Jun. 30, 2022	Jan. 31, 2021	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Mar. 31, 2022	Dec. 31, 2022	Nov. 30, 2021	Jan. 01, 2021
Public Utilities, General Disclosures [Line Items]
Reserve adjustments					$ 5	$ 169	$ 78
Accounts receivable - customers, allowance for uncollectible accounts					$ 322	317			$ 322
Government Assistance Statement Of Income Or Comprehensive Income Extensible Enumeration Not Disclosed Flag					Government
CECONY
Public Utilities, General Disclosures [Line Items]
Reserve adjustments					$ 10	166	74
Accounts receivable - customers, allowance for uncollectible accounts					314	304			314
CECONY | Subsidiaries | COVID-19 Arrears Assistance Program
Public Utilities, General Disclosures [Line Items]
Government assistance		$ 164.5			359.9
Government assistance, transaction duration (in years)		4 years
CECONY | Subsidiaries | COVID-19 Arrears Assistance Program | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Government assistance	$ 388.7
Government assistance, transaction duration (in years)	10 years
O&R | Subsidiaries | COVID-19 Arrears Assistance Program
Public Utilities, General Disclosures [Line Items]
Government assistance		$ 1.6			6.1
Government assistance, transaction duration (in years)		1 year
O&R | Subsidiaries | COVID-19 Arrears Assistance Program | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Government assistance	$ 2.9
Government assistance, transaction duration (in years)	1 year
COVID-19
Public Utilities, General Disclosures [Line Items]
Deferred costs					0.5				0.5
COVID-19 | Electric | Subsidiaries | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Late payment charges and fees				$ 19
COVID-19 | Gas | Subsidiaries | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Late payment charges and fees				$ 4
COVID-19 | CECONY
Public Utilities, General Disclosures [Line Items]
Reserve adjustments					249
Allowance for credit loss, write-off									3
COVID-19 | CECONY | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Reserve for customer arrearages										$ 7
COVID-19 | CECONY | Electric | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Late payment charges and fees					43
COVID-19 | CECONY | Gas | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Late payment charges and fees					7
COVID-19 | CECONY | Electric and Gas Transmission Projects | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Accounts receivable, before allowance for credit loss, current					164.5				164.5
Accounts receivable - customers, allowance for uncollectible accounts					108.4				108.4
Income tax rate reconciliation, tax credit					80
COVID-19 | O&R
Public Utilities, General Disclosures [Line Items]
Reserve adjustments					3
Allowance for credit loss, write-off									0
COVID-19 | O&R | Electric | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Late payment charges and fees							$ 1.7
COVID-19 | O&R | Gas | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Late payment charges and fees						2.4
COVID-19 | O&R | Electric and Gas Transmission Projects | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Accounts receivable, before allowance for credit loss, current					1.6				1.6
Accounts receivable - customers, allowance for uncollectible accounts					3.2				3.2
Income tax rate reconciliation, tax credit					$ 1.3
COVID-19 | Consolidated Edison Company of New York, Inc. And Orange And Rockland Utilities, Inc. | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Reserve for customer arrearages						$ 7
COVID-19 | Consolidated Edison Company of New York, Inc. And Orange And Rockland Utilities, Inc. | Electric and Gas Transmission Projects | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Allowance for credit loss, write-off								$ 11	$ 46
Suspension period of residential terminations (in years)					30 days
Summer Cooling Credit Program | Residential Customers | COVID-19 | CECONY | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Expected deferred revenue											$ 63.4
Cost of the program, recovery period			5 years

Regulatory Matters - Other Regu

Regulatory Matters - Other Regulatory Matters (Details) customer in Thousands, $ in Millions		1 Months Ended			12 Months Ended			36 Months Ended
	Jan. 01, 2022 USD ($)	Jul. 31, 2021 USD ($)	Aug. 31, 2020 customer	Jul. 31, 2019 customer	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)	Dec. 31, 2019 USD ($)	Dec. 31, 2022 USD ($)
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities					$ 6,027	$ 4,381		$ 6,027
Other customer-provided capital rate					1.75%	1.80%
Return on regulatory assets					$ 2,304	$ 1,962
Deferred derivative losses, current, recovery period (in years)					1 year
Deferred derivative losses, noncurrent, recovery period (in years)					3 years
Net unbilled revenue deferrals
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities					$ 204	209		204
CECONY
Public Utilities, General Disclosures [Line Items]
Net regulatory assets					1,150	1,176		1,150
Regulatory liabilities					5,481	3,921		5,481
Return on regulatory assets					$ 2,097	1,751
CECONY | Commodity
Public Utilities, General Disclosures [Line Items]
Regulatory assets, recovery period					4 years
CECONY | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities					$ 5,481	3,921		5,481
CECONY | Net unbilled revenue deferrals | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities					$ 204	209		204
CECONY | Electric | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA								$ 377
TCJA, net benefit amortization, allocation period								3 years
CECONY | Electric | Tropical Storm | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Number of customers affected with interrupted service | customer			330
Litigation settlement, amount awarded to other party		$ 75.1
Litigation settlement, period (in years)					35 years
CECONY | Electric | Protected Portion
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA								$ 1,663
CECONY | Electric | Protected Portion | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA								1,663
CECONY | Electric | Unprotected Portion
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA								$ 784
CECONY | Electric | Unprotected Portion | Subsidiaries
Public Utilities, General Disclosures [Line Items]
TCJA, net benefit amortization, allocation period								5 years
Increase in regulatory liability resulting from TCJA								$ 784
CECONY | Gas | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA								$ 63
TCJA, net benefit amortization, allocation period								2 years
CECONY | Gas | Protected Portion
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA								$ 725
CECONY | Gas | Protected Portion | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA								$ 725
CECONY | Gas | Unprotected Portion | Subsidiaries
Public Utilities, General Disclosures [Line Items]
TCJA, net benefit amortization, allocation period								5 years
Increase in regulatory liability resulting from TCJA								$ 107
CECONY | NYSPSC | Steam | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA							$ 185
O&R
Public Utilities, General Disclosures [Line Items]
Net regulatory assets					$ 22	26		22
O&R | Electric | Tropical Storm | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Number of customers affected with interrupted service | customer			200
Litigation settlement, amount awarded to other party		7
O&R | Electric and Gas | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA								$ 22
TCJA, net benefit amortization, allocation period								3 years
O&R | Electric and Gas | Protected Portion | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA								$ 123
O&R | Electric and Gas | Unprotected Portion | Subsidiaries
Public Utilities, General Disclosures [Line Items]
TCJA, net benefit amortization, allocation period	6 years
Increase in regulatory liability resulting from TCJA	$ 34
RECO
Public Utilities, General Disclosures [Line Items]
Return on regulatory assets					$ 21	$ 25
Manhattan | CECONY | Electric | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Number of customers affected with interrupted service | customer			190	72
Brooklyn | CECONY | Electric | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Number of customers affected with interrupted service | customer				30
Foregone Customer Recovery | CECONY | Electric | Tropical Storm | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Litigation settlement, amount awarded to other party		25
Foregone Customer Recovery | O&R | Electric | Tropical Storm | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Litigation settlement, amount awarded to other party		2.5
Ongoing Operations And Maintenance Costs | CECONY | Electric | Tropical Storm | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Litigation settlement, amount awarded to other party		15.8
Ongoing Operations And Maintenance Costs | O&R | Electric | Tropical Storm | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Litigation settlement, amount awarded to other party		2.9
Previously Incurred Or Accrued Costs | CECONY | Electric | Tropical Storm | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Litigation settlement, amount awarded to other party		34.3
Previously Incurred Or Accrued Costs | O&R | Electric | Tropical Storm | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Litigation settlement, amount awarded to other party		1.6
Negative Revenue Adjustment | CECONY | Electric | Rainey Outages | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Litigation settlement, amount awarded to other party		5
Negative Revenue Adjustment | CECONY | Electric | 2019 Manhattan and Brooklyn Outages | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Litigation settlement, amount awarded to other party		15
Costs To Reimburse Customers For Food And Medicine Spoilage | CECONY | Electric | Tropical Storm | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Litigation settlement, amount awarded to other party		$ 14.3

Regulatory Matters - Regulatory

Regulatory Matters - Regulatory Assets (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	$ 3,974	$ 3,639
Regulatory assets – current	305	206
Total Regulatory Assets	4,279	3,845
Environmental remediation costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	991	938
System peak reduction and energy efficiency programs (h)
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	783	285
Revenue taxes
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	436	395
Pension and other postretirement benefits deferrals
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	279	496
COVID - 19 pandemic deferrals (f)
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	292	282
Deferred storm costs (c)
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	270	276
Property tax reconciliation (g)
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	121	202
Gas service line deferred costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	99	100
COVID - 19 arrears relief deferrals programs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	104	0
MTA power reliability deferral (b)
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	92	140
Unrecognized pension and other postretirement costs (a)
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	78	128
Brooklyn Queens demand management program
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	33	36
Deferred derivative losses - long term
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	31	51
Electric vehicle make ready (j)
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	33	8
Municipal infrastructure support costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	29	44
Meadowlands heater odorization project
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	27	29
Non-wire alternative projects
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	22	23
Legacy meters
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	20	2
Preferred stock redemption
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	19	20
Unamortized loss on reacquired debt
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	11	16
Recoverable Demonstration project costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	17	16
Gate station upgrade project
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	14	14
Other
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	173	138
Deferred derivative losses
Regulatory Assets [Line Items]
Regulatory assets – current	184	141
Recoverable energy costs
Regulatory Assets [Line Items]
Regulatory assets – current	121	65
CECONY
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	3,669	3,316
Regulatory assets – current	286	188
CECONY | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	3,669	3,316
Regulatory assets – current	286	188
Total Regulatory Assets	3,955	3,504
CECONY | Environmental remediation costs | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	906	860
CECONY | System peak reduction and energy efficiency programs (h) | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	780	284
CECONY | Revenue taxes | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	417	378
CECONY | Pension and other postretirement benefits deferrals | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	240	435
CECONY | COVID - 19 pandemic deferrals (f) | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	288	277
CECONY | Deferred storm costs (c) | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	173	158
CECONY | Property tax reconciliation (g) | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	121	202
CECONY | Gas service line deferred costs | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	99	100
CECONY | COVID - 19 arrears relief deferrals programs | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	101	0
CECONY | MTA power reliability deferral (b) | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	92	140
CECONY | Unrecognized pension and other postretirement costs (a) | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	78	110
CECONY | Brooklyn Queens demand management program | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	33	36
CECONY | Deferred derivative losses - long term | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	26	45
CECONY | Electric vehicle make ready (j) | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	30	7
CECONY | Municipal infrastructure support costs | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	29	44
CECONY | Meadowlands heater odorization project | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	27	29
CECONY | Non-wire alternative projects | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	22	23
CECONY | Legacy meters | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	0	0
CECONY | Preferred stock redemption | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	19	20
CECONY | Unamortized loss on reacquired debt | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	10	14
CECONY | Recoverable Demonstration project costs | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	16	15
CECONY | Gate station upgrade project | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	14	14
CECONY | Other | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	148	125
CECONY | Deferred derivative losses | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – current	178	133
CECONY | Recoverable energy costs | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – current	$ 108	$ 55

Regulatory Matters - Regulato_2

Regulatory Matters - Regulatory Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	$ 6,027	$ 4,381
Regulatory liabilities—current	374	185
Total Regulatory Liabilities	6,401	4,566
Future income tax
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	1,753	1,984
Unrecognized pension and other postretirement costs
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	1,638	32
Allowance for cost of removal less salvage (i)
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	1,315	1,199
2022 late payment charge deferral
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	127	0
Net unbilled revenue deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	204	209
Deferred derivative gains - long term
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	145	61
Pension and other postretirement benefit deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	144	102
System benefit charge carrying charge
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	73	70
Net proceeds from sale of property
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	69	103
Sales and use tax refunds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	37	17
Property tax refunds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	35	35
BQDM and Demonstration project reconciliations
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	23	25
Earnings sharing - electric, gas and steam
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	13	13
Energy efficiency portfolio standard unencumbered funds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	5	15
COVID - 19 pandemic uncollectible reconciliation deferral
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	12	0
Workers’ compensation
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	11	8
Settlement of prudence proceeding (d)
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	10	6
Settlement of gas proceedings (e)
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	0	12
Other
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	413	490
Deferred derivative gains - short term
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	311	142
Refundable energy costs
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	34	32
Revenue decoupling mechanism
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	29	11
CECONY
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	5,481	3,921
Regulatory liabilities—current	308	134
CECONY | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	5,481	3,921
Regulatory liabilities—current	308	134
Total Regulatory Liabilities	5,789	4,055
CECONY | Future income tax | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	1,616	1,840
CECONY | Unrecognized pension and other postretirement costs | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	1,536	0
CECONY | Allowance for cost of removal less salvage (i) | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	1,137	1,033
CECONY | 2022 late payment charge deferral | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	123	0
CECONY | Net unbilled revenue deferrals | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	204	209
CECONY | Deferred derivative gains - long term | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	130	55
CECONY | Pension and other postretirement benefit deferrals | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	98	55
CECONY | System benefit charge carrying charge | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	69	63
CECONY | Net proceeds from sale of property | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	69	103
CECONY | Sales and use tax refunds | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	36	16
CECONY | Property tax refunds | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	35	35
CECONY | BQDM and Demonstration project reconciliations | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	21	22
CECONY | Earnings sharing - electric, gas and steam | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	10	10
CECONY | Energy efficiency portfolio standard unencumbered funds | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	7	19
CECONY | COVID - 19 pandemic uncollectible reconciliation deferral | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	12	0
CECONY | Workers’ compensation | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	11	8
CECONY | Settlement of prudence proceeding (d) | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	10	6
CECONY | Settlement of gas proceedings (e) | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	0	12
CECONY | Other | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	357	435
CECONY | Deferred derivative gains - short term | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	287	132
CECONY | Refundable energy costs | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	0	2
CECONY | Revenue decoupling mechanism | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	$ 21	$ 0

Regulatory Matters - Schedule o

Regulatory Matters - Schedule of Regulatory Assets Not Earning a Return (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Regulatory Assets [Line Items]
Regulatory assets not earning return	$ 1,975	$ 1,883
CECONY
Regulatory Assets [Line Items]
Regulatory assets not earning return	1,858	1,753
Unrecognized pension and other postretirement costs (a)
Regulatory Assets [Line Items]
Regulatory assets not earning return	78	128
Unrecognized pension and other postretirement costs (a) | CECONY
Regulatory Assets [Line Items]
Regulatory assets not earning return	78	110
Environmental remediation costs
Regulatory Assets [Line Items]
Regulatory assets not earning return	987	928
Environmental remediation costs | CECONY
Regulatory Assets [Line Items]
Regulatory assets not earning return	903	850
Revenue taxes
Regulatory Assets [Line Items]
Regulatory assets not earning return	414	375
Revenue taxes | CECONY
Regulatory Assets [Line Items]
Regulatory assets not earning return	397	359
Deferred derivative losses - long term
Regulatory Assets [Line Items]
Regulatory assets not earning return	31	51
Deferred derivative losses - long term | CECONY
Regulatory Assets [Line Items]
Regulatory assets not earning return	26	45
COVID-19 deferral for uncollectible accounts receivable
Regulatory Assets [Line Items]
Regulatory assets not earning return	253	236
COVID-19 deferral for uncollectible accounts receivable | CECONY
Regulatory Assets [Line Items]
Regulatory assets not earning return	249	231
Other
Regulatory Assets [Line Items]
Regulatory assets not earning return	28	24
Other | CECONY
Regulatory Assets [Line Items]
Regulatory assets not earning return	27	24
Deferred derivative losses
Regulatory Assets [Line Items]
Regulatory assets not earning return	184	141
Deferred derivative losses | CECONY
Regulatory Assets [Line Items]
Regulatory assets not earning return	$ 178	$ 134

Capitalization - Common Stock (

Capitalization - Common Stock (Details) - shares	Dec. 31, 2022	Dec. 31, 2021
Schedule of Capitalization [Line Items]
Common stock, shares authorized (in shares)	500,000,000
Common stock, shares outstanding (in shares)	354,962,058	353,983,712
Treasury shares (in shares)	23,210,700	23,210,700
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
	Dec. 31, 2022
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, 2022 USD ($)
Debt Instrument [Line Items]
2023	$ 650
2024	250
2025	0
2026	250
2027	430
CECONY
Debt Instrument [Line Items]
2023	0
2024	250
2026	250
2027	$ 350

Capitalization - Long-term Debt

Capitalization - Long-term Debt, Additional Information (Details) - USD ($)	Dec. 31, 2022	Jun. 30, 2022
Debt Instrument [Line Items]
Debt instrument, face amount		$ 400,000,000
CECONY | Tax-Exempt Debt
Debt Instrument [Line Items]
Debt instrument, face amount	$ 450,000,000

Capitalization - Carrying Amoun

Capitalization - Carrying Amounts and Fair Values of Long-Term Debt (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Debt Instrument [Line Items]
Unamortized debt expense	$ 202	$ 226
Carrying Amount
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	20,796	23,044
Fair Value
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	18,234	26,287
CECONY
Debt Instrument [Line Items]
Unamortized debt discount	195	193
CECONY | Carrying Amount
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	19,080	18,382
CECONY | Fair Value
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	16,699	$ 21,382
Clean Energy Businesses | Carrying Amount
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	2,645
Clean Energy Businesses | Fair Value
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	$ 2,489

Capitalization - Significant De

Capitalization - Significant Debt Covenants (Details) $ in Millions	12 Months Ended
	Dec. 31, 2022 USD ($)
Debt Instrument [Line Items]
Maximum ratio of consolidated debt to consolidated total capital	0.54
CECONY
Debt Instrument [Line Items]
Maximum ratio of consolidated debt to consolidated total capital	0.56
Tax-Exempt Debt | CECONY
Debt Instrument [Line Items]
Maximum ratio of consolidated debt to consolidated total capital	0.65
Term Loan | CECONY
Debt Instrument [Line Items]
Covenant principal balance amount limit	$ 150
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
	Jan. 31, 2023 USD ($)	Aug. 31, 2022 USD ($)	Jun. 30, 2022 USD ($)	Mar. 31, 2022 USD ($)	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)
Short-term Debt [Line Items]
Commercial paper, outstanding					$ 2,640,000,000	$ 1,488,000,000
Weighted average interest rate (percent)					4.80%	0.30%
Loans outstanding under credit agreement					$ 0	$ 0
Maximum ratio of consolidated debt to consolidated total capital					0.54
Minimum percentage of liens on assets			0.05		0.05
Failure to pay, maximum aggregate limit			$ 150,000,000		$ 150,000,000
Short-term borrowings			400,000,000
Debt instrument, face amount			$ 400,000,000
Debt term (in years)			364 days
Interest Rate					4.94%
Ratio of consolidated debt to consolidated total capital			0.65
Subsequent Event
Short-term Debt [Line Items]
Short-term borrowings	$ 200,000,000
Debt instrument, face amount	$ 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					$ 1,500,000,000
Current amount available					1,000,000,000
Letters of Credit
Short-term Debt [Line Items]
Maximum borrowing capacity					1,200,000,000
CECONY
Short-term Debt [Line Items]
Commercial paper, outstanding					$ 2,300,000,000	$ 1,361,000,000
Weighted average interest rate (percent)					4.80%	0.30%
Maximum ratio of consolidated debt to consolidated total capital					0.56
Clean Energy Businesses
Short-term Debt [Line Items]
Short-term borrowings		$ 150,000,000
Debt term (in years)		364 days
Interest Rate					5.06%
Credit Availability Through December 2022 | CECONY | Revolving Credit
Short-term Debt [Line Items]
Maximum borrowing capacity					$ 2,250,000,000
Credit Availability Through December 2023 | CECONY | Revolving Credit
Short-term Debt [Line Items]
Maximum borrowing capacity					$ 2,200,000,000
March 2022 Credit Agreement Variable Rate 364 Day Revolving Credit Agreement | Revolving Credit | Subsidiaries
Short-term Debt [Line Items]
Maximum borrowing capacity				$ 750,000,000
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, 2022	Dec. 31, 2021	Dec. 31, 2020
Defined Benefit Plan Disclosure [Line Items]
Service cost – including administrative expenses	$ 287	$ 343	$ 293
Interest cost on projected benefit obligation	505	471	549
Expected return on plan assets	(1,168)	(1,096)	(1,034)
Recognition of net actuarial loss	377	787	699
Recognition of prior service credit	(16)	(17)	(16)
TOTAL PERIODIC BENEFIT COST	(15)	488	491
Cost capitalized	(137)	(154)	(130)
Reconciliation to rate level	259	(226)	(250)
Total credit recognized	107	108	111
CECONY
Defined Benefit Plan Disclosure [Line Items]
Service cost – including administrative expenses	270	321	274
Interest cost on projected benefit obligation	475	443	515
Expected return on plan assets	(1,109)	(1,040)	(980)
Recognition of net actuarial loss	358	746	661
Recognition of prior service credit	(21)	(19)	(19)
TOTAL PERIODIC BENEFIT COST	(27)	451	451
Cost capitalized	(129)	(146)	(123)
Reconciliation to rate level	245	(216)	(239)
Total credit recognized	$ 89	$ 89	$ 89

Pension Benefits - Schedule of

Pension Benefits - Schedule of Funded Status (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	$ 525
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	459	$ 525
Pension Benefits
CHANGE IN PROJECTED BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	17,357	18,965	$ 16,792
Service cost – excluding administrative expenses	283	337	288
Interest cost on projected benefit obligation	505	471	549
Net actuarial loss/(gain)	(5,102)	(1,547)	2,281
Benefits paid	(930)	(869)	(945)
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	12,113	17,357	18,965
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	18,504	17,022	15,608
Actual return on plan assets	(2,583)	1,935	1,927
Employer contributions	30	469	475
Benefits paid	(930)	(869)	(945)
Administrative expenses	(42)	(53)	(43)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	14,979	18,504	17,022
FUNDED STATUS	2,866	1,147	(1,943)
Unrecognized net loss/(gain)	(1,485)	205	3,330
Unrecognized prior service costs/(credits)	(124)	(140)	(156)
Accumulated benefit obligation	11,167	15,469	16,768
CECONY
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	499
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	439	499
CECONY | Pension Benefits
CHANGE IN PROJECTED BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	16,341	17,821	15,750
Service cost – excluding administrative expenses	266	317	269
Interest cost on projected benefit obligation	475	443	515
Net actuarial loss/(gain)	(4,845)	(1,441)	2,154
Benefits paid	(842)	(799)	(867)
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	11,395	16,341	17,821
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	17,566	16,147	14,790
Actual return on plan assets	(2,453)	1,838	1,830
Employer contributions	17	432	435
Benefits paid	(842)	(799)	(867)
Administrative expenses	(40)	(52)	(41)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	14,248	17,566	16,147
FUNDED STATUS	2,853	1,225	(1,674)
Unrecognized net loss/(gain)	(1,397)	207	3,145
Unrecognized prior service costs/(credits)	(143)	(163)	(183)
Accumulated benefit obligation	$ 10,478	$ 14,504	$ 15,676

Pension Benefits - Additional I

Pension Benefits - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Defined Benefit Plan Disclosure [Line Items]
Pension liability	$ 1,719	$ 3,090
Investments value	459	525
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Regulatory assets and liabilities for future income taxes, net	1,655
Charge to OCI	15
Noncurrent liabilities	311	459
Investments value	14,979	18,504	$ 17,022	$ 15,608
Accumulated benefit obligation	11,167	15,469	16,768
Estimated future employer contributions	10
Other Nonqualified Supplemental Defined Benefit Pension
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	306	386
CECONY
Defined Benefit Plan Disclosure [Line Items]
Pension liability	1,628	2,899
Investments value	439	499
CECONY | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Regulatory assets and liabilities for future income taxes, net	1,579
Charge to OCI	3
Noncurrent liabilities	287	381
Investments value	14,248	17,566	16,147	$ 14,790
Accumulated benefit obligation	10,478	14,504	$ 15,676
Estimated future employer contributions	8
CECONY | Other Nonqualified Supplemental Defined Benefit Pension
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	$ 280	$ 352

Pension Benefits - Schedule o_2

Pension Benefits - Schedule of Assumptions (Details)	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
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)	5.45%	3%	2.55%
Interest crediting rate for cash balance plan (percent)	4%	3.50%	3%
Discount rate, net periodic benefit cost (percent)	3%	2.55%	3.35%
Interest crediting rate for cash balance plan (percent)	3.50%	3%	3.30%
Expected return on plan assets (percent)	7%	7%	7%

Pension Benefits - Schedule o_3

Pension Benefits - Schedule of Expected Benefit Payments (Details) - Pension Benefits $ in Millions	Dec. 31, 2022 USD ($)
Defined Benefit Plan Disclosure [Line Items]
2023	$ 748
2023	759
2025	809
2026	780
2027	792
2028-2032	4,095
CECONY
Defined Benefit Plan Disclosure [Line Items]
2023	692
2023	703
2025	754
2026	725
2027	738
2028-2032	$ 3,824

Pension Benefits - Schedule o_4

Pension Benefits - Schedule of Plan Assets Allocations (Details) - Pension Benefits	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
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)	33%	50%	51%
Equity Securities | Minimum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range (percent)	28%
Equity Securities | Maximum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range (percent)	38%
Debt Securities
Defined Benefit Plan Disclosure [Line Items]
Plan Assets Percentage (percent)	50%	38%	38%
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)	17%	12%	11%
Real Estate and Other Alternatives | Minimum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range (percent)	12%
Real Estate and Other Alternatives | Maximum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range (percent)	22%

Pension Benefits - Schedule o_5

Pension Benefits - Schedule of Fair Value of Plan Assets (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	$ 459	$ 525
Defined benefit plan, funded (unfunded) status of plan related to private equity	$ 260
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	$ 14,979	$ 18,504	$ 17,022	$ 15,608
Pension Benefits | U.S. Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	2,153	4,381
Pension Benefits | International Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,534	3,536
Pension Benefits | U.S. Government Issued Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	823	1,500
Pension Benefits | Corporate Bonds Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	4,961	3,936
Pension Benefits | Structured Assets Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	183	262
Pension Benefits | Other Fixed Income Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,088	1,186
Pension Benefits | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	345	505
Pension Benefits | Futures
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	(1)	2
Pension Benefits | Private Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,018	913
Pension Benefits | Real Estate and Other Alternatives
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	2,366	2,306
Pension Benefits | Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	657	315
Pension Benefits | Total Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	(190)	(258)
Pension Benefits | Pending Activities
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	42	(80)
Pension Benefits | Fair Value, Inputs, Level 1 and 2 | Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	11,086	15,308
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	(139)	(210)
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	14,937	18,584
Pension Benefits | Level 1 | Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	3,754	7,999
Pension Benefits | Level 1 | U.S. Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	2,150	4,381
Pension Benefits | Level 1 | International Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,534	3,536
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 | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	71	80
Pension Benefits | Level 1 | Futures
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	(1)	2
Pension Benefits | Level 1 | Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	(48)	(110)
Pension Benefits | Level 1 | Investments Excluding Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	3,706	7,889
Pension Benefits | Level 2 | Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	7,332	7,309
Pension Benefits | Level 2 | U.S. Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	3	0
Pension Benefits | Level 2 | U.S. Government Issued Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	823	1,500
Pension Benefits | Level 2 | Corporate Bonds Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	4,961	3,936
Pension Benefits | Level 2 | Structured Assets Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	183	262
Pension Benefits | Level 2 | Other Fixed Income Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,088	1,186
Pension Benefits | Level 2 | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	274	425
Pension Benefits | Level 2 | Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	(91)	(100)
Pension Benefits | Level 2 | Investments Excluding Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	7,241	7,209
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	4,041	3,534
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	$ (51)	$ (48)

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, 2022	Dec. 31, 2021	Dec. 31, 2020
Defined Benefit Plan Disclosure [Line Items]
Employer contribution to the defined savings plan	$ 57	$ 55	$ 52
CECONY
Defined Benefit Plan Disclosure [Line Items]
Employer contribution to the defined savings plan	$ 48	$ 46	$ 43

Other Postretirement Benefits -

Other Postretirement Benefits - Net Periodic Postretirement Benefit Costs (Details) - Other Postretirement Benefits - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 18	$ 22	$ 21
Interest cost on accumulated other postretirement benefit obligation	35	33	37
Expected return on plan assets	(72)	(68)	(66)
Recognition of net actuarial loss/(gain)	(14)	31	37
Recognition of prior service credit	(1)	(3)	(3)
TOTAL PERIODIC POSTRETIREMENT BENEFIT COST/(CREDIT)	(34)	15	26
Cost capitalized	(8)	(9)	(9)
Reconciliation to rate level	29	(7)	(17)
Total credit recognized	(13)	(1)	0
CECONY
Defined Benefit Plan Disclosure [Line Items]
Service cost	15	16	16
Interest cost on accumulated other postretirement benefit obligation	30	28	31
Expected return on plan assets	(58)	(56)	(54)
Recognition of net actuarial loss/(gain)	(9)	27	36
Recognition of prior service credit	0	(1)	(2)
TOTAL PERIODIC POSTRETIREMENT BENEFIT COST/(CREDIT)	(22)	14	27
Cost capitalized	(7)	(7)	(7)
Reconciliation to rate level	24	(12)	(25)
Total credit recognized	$ (5)	$ (5)	$ (5)

Other Postretirement Benefits_2

Other Postretirement Benefits - Schedule of Funded Status (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	$ 525
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	459	$ 525
CECONY
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	499
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	439	499
Other Postretirement Benefits
CHANGE IN BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	1,398	1,425	$ 1,357
Service cost	18	22	21
Interest cost on accumulated other postretirement benefit obligation	35	33	37
Net actuarial loss/(gain)	(311)	(13)	74
Benefits paid and administrative expenses, net of subsidies	(130)	(117)	(117)
Participant contributions	48	48	53
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	1,058	1,398	1,425
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	1,150	1,115	1,026
Actual return on plan assets	(225)	92	142
Employer contributions	13	6	7
Employer group waiver plan subsidies	55	21	20
Participant contributions	48	48	53
Benefits paid	(181)	(132)	(133)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	860	1,150	1,115
FUNDED STATUS	(198)	(248)	(310)
Unrecognized net loss/(gain)	37	41	115
Unrecognized prior service costs	(12)	(13)	(16)
Other Postretirement Benefits | CECONY
CHANGE IN BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	1,189	1,209	1,154
Service cost	15	16	16
Interest cost on accumulated other postretirement benefit obligation	30	28	31
Net actuarial loss/(gain)	(239)	(3)	63
Benefits paid and administrative expenses, net of subsidies	(121)	(107)	(107)
Participant contributions	47	46	52
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	921	1,189	1,209
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	955	940	872
Actual return on plan assets	(187)	67	117
Employer contributions	10	3	4
Employer group waiver plan subsidies	50	19	19
Participant contributions	47	46	51
Benefits paid	(167)	(120)	(123)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	708	955	940
FUNDED STATUS	(213)	(234)	(269)
Unrecognized net loss/(gain)	78	67	114
Unrecognized prior service costs	$ 0	$ 0	$ (1)

Other Postretirement Benefits_3

Other Postretirement Benefits - Additional Information (Details) - Other Postretirement Benefits - USD ($)	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Defined Benefit Plan Disclosure [Line Items]
Increase (decrease) in liability for other postretirement benefits	$ (50,000,000)	$ 62,000,000
Noncurrent liabilities	72,000,000	79,000,000
Increase (decrease) in regulatory liabilities	2,000,000
Other comprehensive income (loss), unrecognized net losses	2,000,000
Other comprehensive (income) loss, prior service cost	0
Expected contributions	1,000,000
CECONY
Defined Benefit Plan Disclosure [Line Items]
Increase (decrease) in liability for other postretirement benefits	(21,000,000)	35,000,000
Noncurrent liabilities	27,000,000	$ 55,000,000
Increase (decrease) in regulatory liabilities	11,000,000
Other comprehensive income (loss), unrecognized net losses	1,000,000
Other comprehensive (income) loss, prior service cost	$ 0

Other Postretirement Benefits_4

Other Postretirement Benefits - Schedule of Actuarial Assumptions (Details) - Other Postretirement Benefits	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets (percent)	6.80%	6.80%	6.80%
CECONY
Defined Benefit Plan Disclosure [Line Items]
Discount rate, benefit obligations (percent)	5.35%	2.75%	2.25%
Discount rate, net periodic benefit cost (percent)	2.75%	2.25%	3.10%
O&R
Defined Benefit Plan Disclosure [Line Items]
Discount rate, benefit obligations (percent)	5.45%	3%	2.55%
Discount rate, net periodic benefit cost (percent)	3%	2.55%	3.35%

Other Postretirement Benefits_5

Other Postretirement Benefits - Schedule of Change of Assumed Health Care Cost Trend Rate (Details) - Other Postretirement Benefits	Dec. 31, 2022
Pre-65 Medical
Defined Benefit Plan Disclosure [Line Items]
Initial Cost Trend Rate	7%
Ultimate Cost Trend Rate	4.50%
Post-65 Medical
Defined Benefit Plan Disclosure [Line Items]
Initial Cost Trend Rate	4.50%
Ultimate Cost Trend Rate	4.50%
Prescription Medications
Defined Benefit Plan Disclosure [Line Items]
Initial Cost Trend Rate	7.50%
Ultimate Cost Trend Rate	4.50%

Other Postretirement Benefits_6

Other Postretirement Benefits - Schedule of Expected Benefit Payments (Details) - Other Postretirement Benefits $ in Millions	Dec. 31, 2022 USD ($)
Defined Benefit Plan Disclosure [Line Items]
2023	$ 79
2023	80
2025	85
2026	86
2027	87
2028-2032	430
CECONY
Defined Benefit Plan Disclosure [Line Items]
2023	71
2023	71
2025	76
2026	77
2027	78
2028-2032	$ 384

Other Postretirement Benefits_7

Other Postretirement Benefits - Schedule of Plan Assets Allocations (Details) - Other Postretirement Benefits - CECONY	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range (percent)	100%
Plan Assets Percentage (percent)	100%	100%	100%
Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Plan Assets Percentage (percent)	49%	55%	54%
Equity Securities | Minimum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range (percent)	42%
Equity Securities | Maximum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range (percent)	80%
Debt Securities
Defined Benefit Plan Disclosure [Line Items]
Plan Assets Percentage (percent)	51%	45%	46%
Debt Securities | Minimum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range (percent)	20%
Debt Securities | Maximum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range (percent)	58%

Other Postretirement Benefits_8

Other Postretirement Benefits - Schedule of Fair Values of Plan Assets (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	$ 459	$ 525
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	860	1,150	$ 1,115	$ 1,026
Other Postretirement Benefits | Fair Value, Inputs, Level 1 and 2 | Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	649	875
Other Postretirement Benefits | Fair Value, Inputs, Level 1 and 2 | Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	339	474
Other Postretirement Benefits | Fair Value, Inputs, Level 1 and 2 | Other Fixed Income Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	285	379
Other Postretirement Benefits | Fair Value, Inputs, Level 1 and 2 | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	25	22
Other Postretirement 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	139	210
Other Postretirement Benefits | Fair Value, Inputs, Level 1 and 2 | Investments, Including Funds For Retiree Health Benefit
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	788	1,085
Other Postretirement Benefits | Fair Value, Inputs, Level 1 and 2 | Funds For Retiree Health Benefits Measured At Net Asset Value
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	51	48
Other Postretirement Benefits | Fair Value, Inputs, Level 1 and 2 | Pending Activities
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	21	17
Other Postretirement Benefits | Level 1 | Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	10	0
Other Postretirement Benefits | Level 1 | Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	0
Other Postretirement Benefits | Level 1 | Other Fixed Income Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	10	0
Other Postretirement Benefits | Level 1 | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	0
Other Postretirement Benefits | Level 1 | Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	48	110
Other Postretirement Benefits | Level 1 | Investments, Including Funds For Retiree Health Benefit
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	58	110
Other Postretirement Benefits | Level 2 | Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	639	875
Other Postretirement Benefits | Level 2 | Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	339	474
Other Postretirement Benefits | Level 2 | Other Fixed Income Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	275	379
Other Postretirement Benefits | Level 2 | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	25	22
Other Postretirement Benefits | Level 2 | Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	91	100
Other Postretirement Benefits | Level 2 | Investments, Including Funds For Retiree Health Benefit
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	$ 730	$ 975

Environmental Matters - Accrued

Environmental Matters - Accrued Liabilities and Regulatory Assets (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Site Contingency [Line Items]
Accrued Liabilities	$ 997	$ 940
Regulatory assets	4,279	3,845
Manufactured gas plant sites
Site Contingency [Line Items]
Accrued Liabilities	876	845
Other Superfund Sites
Site Contingency [Line Items]
Accrued Liabilities	121	95
Superfund Sites
Site Contingency [Line Items]
Accrued Liabilities	997	940
Regulatory assets	991	938
CECONY
Site Contingency [Line Items]
Accrued Liabilities	903	850
CECONY | Manufactured gas plant sites
Site Contingency [Line Items]
Accrued Liabilities	782	755
CECONY | Other Superfund Sites
Site Contingency [Line Items]
Accrued Liabilities	121	95
CECONY | Superfund Sites
Site Contingency [Line Items]
Accrued Liabilities	903	850
Regulatory assets	$ 906	$ 860

Environmental Matters - Environ

Environmental Matters - Environmental Remediation Costs (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Environmental Exit Cost [Line Items]
Remediation costs incurred	$ 21	$ 25
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	$ 20	$ 24
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) $ in Millions	12 Months Ended
	Dec. 31, 2022 USD ($)
Asbestos Proceedings
Site Contingency [Line Items]
Estimated undiscounted asbestos liability (years)	15 years
CECONY | Asbestos Proceedings
Site Contingency [Line Items]
Estimated undiscounted asbestos liability (years)	15 years
Superfund Sites
Site Contingency [Line Items]
Remediation cost estimate	$ 63
Superfund Sites | Manufactured Gas Plant Sites | Maximum
Site Contingency [Line Items]
Estimated aggregate undiscounted potential liability related environmental contaminants (up to)	3,140
Superfund Sites | CECONY
Site Contingency [Line Items]
Remediation cost estimate	61
Superfund Sites | CECONY | Manufactured Gas Plant Sites | Maximum
Site Contingency [Line Items]
Estimated aggregate undiscounted potential liability related environmental contaminants (up to)	$ 2,990

Environmental Matters - Accru_2

Environmental Matters - Accrued Liability for Asbestos Suits and Workers' Compensation Proceedings (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Site Contingency [Line Items]
Regulatory assets	$ 4,279	$ 3,845
Regulatory liabilities	6,401	4,566
Asbestos Suits
Site Contingency [Line Items]
Accrued liability	8	8
Regulatory assets	8	8
Workers' Compensation
Site Contingency [Line Items]
Accrued liability	61	65
Regulatory liabilities	$ 11	$ 8
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	59	62
Regulatory liabilities	$ 11	$ 8
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 ($)	Dec. 31, 2022 USD ($) lawsuit	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)
Loss Contingencies [Line Items]
Accrued regulatory liability			$ 6,027	$ 4,381
Settlement of gas proceedings (e)
Loss Contingencies [Line Items]
Accrued regulatory liability			$ 0	$ 12
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
Number of pending lawsuits | lawsuit			80
Loss contingency accrual			$ 40		$ 40
Insurance receivable			$ 40		$ 40
Manhattan Explosion and Fire | Settlement of gas proceedings (e)
Loss Contingencies [Line Items]
Accrued regulatory liability		$ 27

Material Contingencies - Guaran

Material Contingencies - Guarantees (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Commitments and Contingencies Disclosure [Abstract]
Guarantee obligations maximum exposure	$ 2,412	$ 2,157

Material Contingencies - Total

Material Contingencies - Total Guarantees (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Guarantor Obligations [Line Items]
Total guarantees, by type and term	$ 2,412	$ 2,157
Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	407
Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	805
Renewable electric projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	978
Other
Guarantor Obligations [Line Items]
Total guarantees, by type and term	222
0 – 3 years
Guarantor Obligations [Line Items]
Total guarantees, by type and term	1,472
0 – 3 years | Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	407
0 – 3 years | Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	489
0 – 3 years | Renewable electric projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	354
0 – 3 years | Other
Guarantor Obligations [Line Items]
Total guarantees, by type and term	222
4 – 10 years
Guarantor Obligations [Line Items]
Total guarantees, by type and term	91
4 – 10 years | Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	22
4 – 10 years | Renewable electric projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	69
4 – 10 years | Other
Guarantor Obligations [Line Items]
Total guarantees, by type and term	0
> 10 years
Guarantor Obligations [Line Items]
Total guarantees, by type and term	849
> 10 years | Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	0
> 10 years | Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	294
> 10 years | Renewable electric projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	555
> 10 years | Other
Guarantor Obligations [Line Items]
Total guarantees, by type and term	$ 0

Material Contingencies - Con Ed

Material Contingencies - Con Edison Transmission (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 2,412	$ 2,157
Payment Guarantee by CET Electric of Contributions to New York Transco LLC
Guarantor Obligations [Line Items]
Estimated project cost percentage	175%
Con Edison Transmission
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 407
NY Transco | Payment Guarantee by CET Electric of Contributions to New York Transco LLC
Guarantor Obligations [Line Items]
Ownership interest, percentage	45.70%

Material Contingencies - Other

Material Contingencies - Other (Details) - USD ($) $ in Millions	1 Months Ended
	Aug. 31, 2022	Jun. 30, 2022	Dec. 31, 2022	Dec. 31, 2021
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure			$ 2,412	$ 2,157
Debt term (in years)		364 days
Clean Energy Businesses
Guarantor Obligations [Line Items]
Debt term (in years)	364 days
Financial Guarantee for Indemnity Agreements for Surety Bonds in Connection with Operation of Solar Energy Facilities and Energy Service Projects
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure			70
Financial Guarantee For Obligations Under Senior Unsecured Term Loan Credit Agreement
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure			$ 150

Electricity and Gas Purchase _3

Electricity and Gas Purchase Agreements - Summary of Estimated Capacity and Other Fixed Payments (Details) $ in Millions	Dec. 31, 2022 USD ($)
Long-term Contract for Purchase of Electric Power [Line Items]
2023
2024
2025
2026
2027
All Years Thereafter
Electricity power purchase agreements
Long-term Contract for Purchase of Electric Power [Line Items]
2023	121
2024	90
2025	64
2026	58
2027	44
All Years Thereafter	390
Natural gas
Long-term Contract for Purchase of Electric Power [Line Items]
2023	679
2024	9
2025	0
2026	0
2027	0
All Years Thereafter	0
Gas transportation and storage
Long-term Contract for Purchase of Electric Power [Line Items]
2023	471
2024	558
2025	484
2026	454
2027	369
All Years Thereafter	3,164
CECONY
Long-term Contract for Purchase of Electric Power [Line Items]
2023
2024
2025
2026
2027
All Years Thereafter
CECONY | Electricity power purchase agreements
Long-term Contract for Purchase of Electric Power [Line Items]
2023	121
2024	90
2025	64
2026	58
2027	44
All Years Thereafter	390
CECONY | Natural gas
Long-term Contract for Purchase of Electric Power [Line Items]
2023	603
2024	8
2025	0
2026	0
2027	0
All Years Thereafter	0
CECONY | Gas transportation and storage
Long-term Contract for Purchase of Electric Power [Line Items]
2023	412
2024	488
2025	424
2026	397
2027	323
All Years Thereafter	$ 2,762

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, 2022	Dec. 31, 2021	Dec. 31, 2020
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	$ 596	$ 552	$ 486
Astoria Generating Company
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	45	20	26
Brooklyn Navy Yard
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	165	139	113
Gas transportation and storage
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	386	393	347
CECONY
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	550	506	446
CECONY | Astoria Generating Company
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	45	20	26
CECONY | Brooklyn Navy Yard
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	165	139	113
CECONY | Gas transportation and storage
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	$ 340	$ 347	$ 307

Leases - Additional Information

Leases - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Lessee, Lease, Description [Line Items]
Lease, renewal term (in years)	5 years
Assets under finance leases	$ 2
Finance leases, accumulated amortization	5	$ 4
Right-of-use asset obtained in exchange for operating lease liability	79	58
Clean Energy Businesses
Lessee, Lease, Description [Line Items]
Right-of-use asset, held for sale	10
CECONY
Lessee, Lease, Description [Line Items]
Assets under finance leases	1
Finance leases, accumulated amortization	2	2
Right-of-use asset obtained in exchange for operating lease liability	$ 68	$ 12
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, 2022	Dec. 31, 2021
Lessee, Lease, Description [Line Items]
Operating lease cost	$ 88	$ 86
Operating lease cash flows	83	80
CECONY
Lessee, Lease, Description [Line Items]
Operating lease cost	67	66
Operating lease cash flows	$ 64	$ 63

Leases - Other Related Informat

Leases - Other Related Information (Details)	Dec. 31, 2022	Dec. 31, 2021
Lessee, Lease, Description [Line Items]
Weighted Average Remaining Lease Term, Operating leases (in years)	12 years 3 months 18 days	18 years 6 months
Weighted Average Remaining Lease Term, Finance leases (in years)	7 years 2 months 12 days	7 years 1 month 6 days
Weighted Average Discount Rate, Operating leases (percent)	3.70%	4.30%
Weighted Average Discount Rate, Finance leases (percent)	1.90%	1.80%
Clean Energy Businesses
Lessee, Lease, Description [Line Items]
Weighted Average Remaining Lease Term, Operating leases (in years)	18 years 3 months 18 days
Weighted Average Discount Rate, Operating leases (percent)	4.40%
CECONY
Lessee, Lease, Description [Line Items]
Weighted Average Remaining Lease Term, Operating leases (in years)	12 years 4 months 24 days	12 years 1 month 6 days
Weighted Average Remaining Lease Term, Finance leases (in years)	2 years 3 months 18 days	3 years 1 month 6 days
Weighted Average Discount Rate, Operating leases (percent)	3.70%	3.50%
Weighted Average Discount Rate, Finance leases (percent)	1%	1.10%

Leases - Future Minimum Lease P

Leases - Future Minimum Lease Payments (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Operating Leases
2023	$ 64
2024	65
2025	65
2026	64
2027	64
All years thereafter	419
Total future minimum lease payments	741
Less: imputed interest	(162)
Total	579
Operating lease liabilities (current)	103	$ 113
Operating lease liabilities held for sale (current)	33
Operating lease liabilities (noncurrent)	476	$ 717
Operating lease liabilities held for sale (noncurrent)	249
Total	861
Finance Leases
2023	0
2024	1
2025	0
2026	0
2027	0
All years thereafter	1
Total future minimum lease payments	2
Less: imputed interest	0
Total	2
Other current liabilities	0
Other noncurrent liabilities	2
Total	$ 2
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Liabilities, Current	Liabilities, Current
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
Clean Energy Businesses
Operating Leases
2023	$ 19
2024	18
2025	19
2026	17
2027	17
All years thereafter	492
Less: imputed interest	(301)
Operating lease liabilities (current)	281
CECONY
Operating Leases
2023	64
2024	64
2025	64
2026	64
2027	64
All years thereafter	419
Total future minimum lease payments	739
Less: imputed interest	(161)
Total	578
Operating lease liabilities (current)	103	$ 90
Operating lease liabilities held for sale (current)		0
Operating lease liabilities (noncurrent)	475	462
Operating lease liabilities held for sale (noncurrent)		$ 0
Total	578
Finance Leases
2023	0
2024	1
2025	0
2026	0
2027	0
All years thereafter	0
Total future minimum lease payments	1
Less: imputed interest	0
Total	1
Other current liabilities	0
Other noncurrent liabilities	1
Total	$ 1

Goodwill (Details)

Goodwill (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2022
Goodwill [Line Items]
Goodwill	$ 439	$ 408
Goodwill impaired	7
CECONY
Goodwill [Line Items]
Goodwill	245	245
Goodwill impaired	2
O&R
Goodwill [Line Items]
Goodwill	161	161
CET Gas
Goodwill [Line Items]
Goodwill impaired	5
O&R Merger
Goodwill [Line Items]
Goodwill	406	406
Gas Storage Company | CET Gas
Goodwill [Line Items]
Goodwill	8	1
Residential Solar Company | Clean Energy Businesses
Goodwill [Line Items]
Goodwill	14	14
Battery Storage Company | Clean Energy Businesses
Goodwill [Line Items]
Goodwill	$ 18	$ 18

Income Tax - Schedule of Compon

Income Tax - Schedule of Components of Income Tax (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
State
Current	$ 5	$ 14	$ 7
Deferred	324	79	50
Federal
Current	58	43	(2)
Deferred	117	61	42
Amortization of investment tax credits	(6)	(7)	(7)
Total income tax expense	498	190	90
CECONY
State
Current	0	1	6
Deferred	110	106	97
Federal
Current	170	121	41
Deferred	(23)	21	73
Amortization of investment tax credits	(2)	(3)	(2)
Total income tax expense	$ 255	$ 246	$ 215

Income Tax - Schedule of Income

Income Tax - Schedule of Income Tax Reconciliation (Details)	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
STATUTORY TAX RATE
Federal	21%	21%	21%
Changes in computed taxes resulting from:
State income taxes, net of federal income tax benefit	6%	4%	4%
Taxes attributable to noncontrolling interests	1%	3%	(1.00%)
Cost of removal	1%	2%	2%
Other plant-related items	0%	(1.00%)	(1.00%)
Amortization of excess deferred federal income taxes	(9.00%)	(12.00%)	(14.00%)
Renewable energy credits	(2.00%)	(2.00%)	(3.00%)
Research and development credits	0%	(1.00%)	0%
Remeasurement of accumulated deferred state income taxes, net of federal income tax benefit	0.06	0	0
Other	0%	0%	(1.00%)
Effective tax rate	24%	14%	7%
CECONY
STATUTORY TAX RATE
Federal	21%	21%	21%
Changes in computed taxes resulting from:
State income taxes, net of federal income tax benefit	5%	5%	5%
Taxes attributable to noncontrolling interests	0%	0%	0%
Cost of removal	1%	1%	1%
Other plant-related items	(1.00%)	(1.00%)	(1.00%)
Amortization of excess deferred federal income taxes	(10.00%)	(11.00%)	(12.00%)
Renewable energy credits	0%	0%	0%
Research and development credits	0%	0%	0%
Remeasurement of accumulated deferred state income taxes, net of federal income tax benefit	0	0	0
Other	0%	0%	1%
Effective tax rate	16%	15%	15%

Income Tax - Additional Informa

Income Tax - Additional Information (Details) - USD ($)	3 Months Ended	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Operating Loss Carryforwards [Line Items]
Increase in effective tax rate (in percent)		10%
Increase to net deferred income tax liabilities	$ 111,000,000
Increase in valuation allowance	10,000,000
Deferred income taxes	121,000,000	$ 435,000,000	$ 133,000,000	$ 85,000,000
Write-off of deferred tax assets of other state net operating losses		11,000,000
Deferred income tax benefit from net operating losses		$ 3,000,000
State income tax rate (in percent)		6%	4%	4%
Unrecognized tax benefits	23,000,000	$ 23,000,000	$ 17,000,000	$ 14,000,000	$ 13,000,000
Effective income tax rate reconciliation, uncertainty of taxes		20,000,000
Unrecognized tax benefits that would have an impact on effective tax rate	23,000,000	23,000,000
Penalties for uncertain tax positions		0	0	0
Excise taxes paid		2,000,000
Uncertain tax positions, released		1,000,000
General Business Tax Credit
Operating Loss Carryforwards [Line Items]
Tax credit carryovers	767,000,000	767,000,000
State | New York State
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards	892,000,000	892,000,000
Deferred tax assets	84,000,000	84,000,000
Expected taxable income minimum		$ 5,000,000
State income tax rate (in percent)		7.25%
State | New York City
Operating Loss Carryforwards [Line Items]
Deferred tax assets	17,000,000	$ 17,000,000
Valuation allowance reversed	14,000,000	$ 14,000,000
State | Metropolitan Transportation Authority Subcharge
Operating Loss Carryforwards [Line Items]
State income tax rate (in percent)		9.40%
State | Other States
Operating Loss Carryforwards [Line Items]
Deferred tax assets	46,000,000	$ 46,000,000
Valuation allowance reversed	10,000,000	10,000,000
CECONY
Operating Loss Carryforwards [Line Items]
Deferred income taxes		$ 85,000,000	$ 124,000,000	$ 168,000,000
State income tax rate (in percent)		5%	5%	5%
Unrecognized tax benefits	8,000,000	$ 8,000,000	$ 5,000,000	$ 3,000,000	$ 2,000,000
Effective income tax rate reconciliation, uncertainty of taxes		6,000,000
Unrecognized tax benefits that would have an impact on effective tax rate	$ 8,000,000	$ 8,000,000

Income Tax - Schedule of Differ

Income Tax - Schedule of Differences on Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Deferred tax liabilities:
Property basis differences	$ 8,770	$ 8,298
Regulatory Assets:
Deferred storm costs	27	33
Environmental remediation costs	278	264
Other regulatory assets	754	640
Unrecognized pension and other postretirement costs	22	36
Pensions and retiree benefits – asset	917	478
Operating lease right-of-use asset	230	204
Equity investments	26	0
Other	0	30
Total deferred tax liabilities	11,024	9,983
Deferred tax assets:
Unrecognized pension and other postretirement costs	447	0
Future income tax	489	554
Other regulatory liabilities	860	727
Tax credits carryforward	767	946
Loss carryforwards	117	144
Valuation allowance	(18)	(22)
Superfund and other environmental costs	280	264
Operating lease liabilities	233	195
Pensions and retiree benefits – liability	162	218
Asset retirement obligations	153	177
Equity investments	0	34
Other	14	0
Total deferred tax assets	3,504	3,237
Net deferred tax liabilities	7,520	6,746
Unamortized investment tax credits	121	127
Net deferred tax liabilities and unamortized investment tax credits	7,641	6,873
CECONY
Deferred tax liabilities:
Property basis differences	7,475	7,213
Regulatory Assets:
Deferred storm costs	0	0
Environmental remediation costs	254	241
Other regulatory assets	720	609
Unrecognized pension and other postretirement costs	22	31
Pensions and retiree benefits – asset	894	471
Operating lease right-of-use asset	163	155
Equity investments	0	0
Other	0	0
Total deferred tax liabilities	9,528	8,720
Deferred tax assets:
Unrecognized pension and other postretirement costs	431	0
Future income tax	454	517
Other regulatory liabilities	739	620
Tax credits carryforward	0	0
Loss carryforwards	24	38
Valuation allowance	0	0
Superfund and other environmental costs	254	238
Operating lease liabilities	162	155
Pensions and retiree benefits – liability	148	188
Asset retirement obligations	140	141
Equity investments	0	0
Other	45	42
Total deferred tax assets	2,397	1,939
Net deferred tax liabilities	7,131	6,781
Unamortized investment tax credits	13	15
Net deferred tax liabilities and unamortized investment tax credits	$ 7,144	$ 6,796

Income Tax - Summary of Unrecog

Income Tax - Summary of Unrecognized Tax Benefits (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at beginning of period	$ 17	$ 14	$ 13
Additions based on tax positions related to the current year	3	3	0
Additions based on tax positions of prior years	6	2	1
Reductions for tax positions of prior years	(1)	(2)	0
Settlements	(2)	0	0
Balance at end of period	23	17	14
CECONY
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at beginning of period	5	3	2
Additions based on tax positions related to the current year	2	2	0
Additions based on tax positions of prior years	1	1	1
Reductions for tax positions of prior years	0	(1)	0
Settlements	0	0	0
Balance at end of period	$ 8	$ 5	$ 3

Revenue Recognition - Disaggreg

Revenue Recognition - Disaggregation of Revenue (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 15,455	$ 13,456	$ 12,026
Revenues	15,670	13,676	12,246
Other
Disaggregation of Revenue [Line Items]
Revenues	215	220	220
CECONY
Disaggregation of Revenue [Line Items]
Revenues	13,268	11,716	10,647
CECONY | Decoupling Mechanisms
Disaggregation of Revenue [Line Items]
Revenues		48
CECONY | EAMs
Disaggregation of Revenue [Line Items]
Revenues		34
CECONY | LPCs
Disaggregation of Revenue [Line Items]
Revenues		74
O&R | Decoupling Mechanisms
Disaggregation of Revenue [Line Items]
Revenues		(18)
O&R | EAMs
Disaggregation of Revenue [Line Items]
Revenues		2
O&R | LPCs
Disaggregation of Revenue [Line Items]
Revenues		4
Operating Segments | Clean Energy Businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	998	917	661
Revenues	1,319	1,022	736
Operating Segments | Clean Energy Businesses | Other
Disaggregation of Revenue [Line Items]
Revenues	321	105	75
Operating Segments | Clean Energy Businesses | Renewables
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	637	638	608
Revenues	637	638	608
Operating Segments | Clean Energy Businesses | Renewables | Other
Disaggregation of Revenue [Line Items]
Revenues	0	0	0
Operating Segments | Clean Energy Businesses | Energy services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	317	234	52
Revenues	317	234	52
Operating Segments | Clean Energy Businesses | Energy services | Other
Disaggregation of Revenue [Line Items]
Revenues	0	0	0
Operating Segments | Clean Energy Businesses | Develop/Transfer Projects
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	44	45	1
Revenues	44	45	1
Operating Segments | Clean Energy Businesses | Develop/Transfer Projects | Other
Disaggregation of Revenue [Line Items]
Revenues	0	0	0
Operating Segments | Clean Energy Businesses | Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0
Revenues	321	105	75
Operating Segments | Clean Energy Businesses | Other | Other
Disaggregation of Revenue [Line Items]
Revenues	321	105	75
Operating Segments | Con Edison Transmission
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	4	4	4
Revenues	4	4	4
Operating Segments | Con Edison Transmission | Other
Disaggregation of Revenue [Line Items]
Revenues	0	0	0
Operating Segments | CECONY
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	13,376	11,579	10,518
Revenues	13,268	11,716	10,647
Operating Segments | CECONY | Other
Disaggregation of Revenue [Line Items]
Revenues	(108)	137	129
Operating Segments | CECONY | Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	9,917	8,736	8,026
Revenues	9,751	8,806	8,103
Operating Segments | CECONY | Electric | Other
Disaggregation of Revenue [Line Items]
Revenues	(166)	70	77
Operating Segments | CECONY | Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2,875	2,324	1,998
Revenues	2,924	2,378	2,036
Operating Segments | CECONY | Gas | Other
Disaggregation of Revenue [Line Items]
Revenues	49	54	38
Operating Segments | CECONY | Steam
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	584	519	494
Revenues	593	532	508
Operating Segments | CECONY | Steam | Other
Disaggregation of Revenue [Line Items]
Revenues	9	13	14
Operating Segments | O&R
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,077	956	843
Revenues	1,085	941	862
Operating Segments | O&R | Other
Disaggregation of Revenue [Line Items]
Revenues	8	(15)	19
Operating Segments | O&R | Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	771	691	619
Revenues	773	681	629
Operating Segments | O&R | Electric | Other
Disaggregation of Revenue [Line Items]
Revenues	2	(10)	10
Operating Segments | O&R | Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	306	265	224
Revenues	312	260	233
Operating Segments | O&R | Gas | Other
Disaggregation of Revenue [Line Items]
Revenues	6	(5)	9
Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0
Revenues	(6)	(7)	(3)
Other | Other
Disaggregation of Revenue [Line Items]
Revenues	(6)	(7)	(3)
Other | O&R
Disaggregation of Revenue [Line Items]
Revenues	$ 0	$ 0	$ 0

Revenue Recognition - Change in

Revenue Recognition - Change in Unbilled Contract and Unearned Revenues (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Unbilled contract revenue
Beginning balance	$ 35	$ 11	$ 29
Additions	324	242	88
Subtractions	279	218	106
Ending balance	80	35	11
Unearned revenue
Beginning balance	7	41	17
Additions	0	0	31
Subtractions	4	34	7
Ending balance	3	7	41
Contracts with customer, revenue recognized, amount outstanding end of last period	$ 4	$ 34	$ 7

Revenue Recognition - Revenue R

Revenue Recognition - Revenue Recognition, Remaining Performance Obligation (Details) $ in Millions	Dec. 31, 2022 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 89
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 51
Expected timing of satisfaction	2 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 38
Expected timing of satisfaction

Revenue Recognition - Additiona

Revenue Recognition - Additional information (Details) - USD ($) $ in Millions	1 Months Ended		12 Months Ended
	Apr. 30, 2022	Nov. 30, 2021	Dec. 31, 2020	Dec. 31, 2022
Disaggregation of Revenue [Line Items]
Remaining performance obligation				$ 89
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Disaggregation of Revenue [Line Items]
Remaining performance obligation				51
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Disaggregation of Revenue [Line Items]
Remaining performance obligation				$ 38
CECONY | Electric | NYSPSC
Disaggregation of Revenue [Line Items]
Amount of cost recovery		$ 43	$ 43
CECONY | Gas | NYSPSC
Disaggregation of Revenue [Line Items]
Amount of cost recovery		$ 7	$ 7
O&R | Electric and Gas Transmission Projects | Subsidiaries
Disaggregation of Revenue [Line Items]
Public utility, rate plan term (in years)	3 years

Current Expected Credit Losse_2

Current Expected Credit Losses - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Accounts, Notes, Loans and Financing Receivable [Line Items]
Increase in allowance for uncollectible accounts resulting from COVID-19 pandemic	$ 5	$ 169
CECONY
Accounts, Notes, Loans and Financing Receivable [Line Items]
Increase in allowance for uncollectible accounts resulting from COVID-19 pandemic	$ 10	$ 166

Current Expected Credit Losse_3

Current Expected Credit Losses - Schedule of Major Portfolio Segment Type (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Reserve adjustments	$ 5	$ 169	$ 78
Accounts receivable - customers
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance at January 1,	317	148
Recoveries	17	14
Write-offs	(103)	(91)
Reserve adjustments	91	246
Ending Balance December 31,	322	317	148
Other receivables
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance at January 1,	22	7
Recoveries	0	1
Write-offs	(6)	(2)
Reserve adjustments	(6)	16
Ending Balance December 31,	10	22	7
CECONY
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Reserve adjustments	10	166	74
CECONY | Accounts receivable - customers | Subsidiaries
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance at January 1,	304	138
Recoveries	16	12
Write-offs	(94)	(86)
Reserve adjustments	88	240
Ending Balance December 31,	314	304	138
CECONY | Other receivables | Subsidiaries
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance at January 1,	19	4
Recoveries	0	1
Write-offs	(4)	(1)
Reserve adjustments	(8)	15
Ending Balance December 31,	$ 7	$ 19	$ 4

Stock-Based Compensation - Addi

Stock-Based Compensation - Additional Information (Details) - USD ($)	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
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	$ 37,000,000
Nonvested awards, compensation cost not yet recognized, period for recognition (years)	1 year
Payment for settlement of vested units	$ 10,000,000	$ 8,000,000	$ 21,000,000
Performance RSUs | CECONY
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense to be recognized	$ 30,000,000
Nonvested awards, compensation cost not yet recognized, period for recognition (years)	1 year
Payment for settlement of vested units	$ 9,000,000	7,000,000	18,000,000
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	$ 9,000,000
Nonvested awards, compensation cost not yet recognized, period for recognition (years)	1 year
Payment for settlement of vested units	$ 2,000,000	1,000,000	1,000,000
Weighted average grant date price per share (in dollars per share)	$ 86.59
Time-based Awards | CECONY
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense to be recognized	$ 8,000,000
Nonvested awards, compensation cost not yet recognized, period for recognition (years)	1 year
Payment for settlement of vested units	$ 2,000,000	$ 1,000,000	$ 1,000,000
Weighted average grant date price per share (in dollars per share)	$ 87.46
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	5,000,000
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)	$ 89.90
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)	$ 90.25
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)	$ 83.76
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)	$ 84.32
LTIP
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of units issued (in shares)	31,000
Weighted average grant date price per share (in dollars per share)	$ 93.60
Stock Purchase Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares purchased on the open market	744,932	957,866	836,984
Weighted average share price per share, on shares purchased on open market (in dollars per share)	$ 91.59	$ 73.38	$ 79.82

Stock-Based Compensation - Stoc

Stock-Based Compensation - Stock-Based Compensation Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	$ 64	$ 35	$ 17
Income tax benefit	18	10	5
Performance-based restricted stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	52	23	7
Time-based restricted stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	2	2	1
Non-employee director deferred stock compensation
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	3	3	2
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	54	31	16
Income tax benefit	15	9	4
CECONY | Performance-based restricted stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	43	19	6
CECONY | Time-based restricted stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	2	2	1
CECONY | Non-employee director deferred stock compensation
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	3	3	2
CECONY | Stock purchase plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	$ 6	$ 7	$ 7

Stock-Based Compensation - Assu

Stock-Based Compensation - Assumptions Used to Calculate Fair Value (Details) - Performance RSUs	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Risk-free interest rate, minimum (percent)	4.41%	0.39%	0.10%
Risk-free interest rate, maximum (percent)	4.73%	0.73%	0.13%
Expected term (years)	3 years	3 years	3 years
Expected share price volatility, minimum (percent)	19.65%	17.25%	30.16%
Expected share price volatility, maximum (percent)	21.77%	31.42%	40.95%

Stock-Based Compensation - Summ

Stock-Based Compensation - Summary of Changes in Status of Performance RSUs' (Details) - Performance RSUs	12 Months Ended
	Dec. 31, 2022 $ / shares shares
Units
Non-vested at beginning of period (in shares) | shares	984,728
Granted (in shares) | shares	231,600
Vested (in shares) | shares	(320,821)
Forfeited (in shares) | shares	(30,416)
Non-vested at end of period (in shares) | shares	865,091
CECONY
Units
Non-vested at beginning of period (in shares) | shares	744,278
Granted (in shares) | shares	172,003
Vested (in shares) | shares	(240,022)
Forfeited (in shares) | shares	(28,433)
Non-vested at end of period (in shares) | shares	647,826
TSR Portion
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share)	$ 72.67
Granted (in dollars per share)	89.90
Vested (in dollars per share)	64.59
Forfeited (in dollars per share)	80.08
Non-vested at end of period (in dollars per share)	$ 80.02
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)	$ 72.71
Granted (in dollars per share)	90.25
Vested (in dollars per share)	65.04
Forfeited (in dollars per share)	80.04
Non-vested at end of period (in dollars per share)	79.89
Non-TSR Portion
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share)	79.14
Granted (in dollars per share)	83.76
Vested (in dollars per share)	80.17
Forfeited (in dollars per share)	77.73
Non-vested at end of period (in dollars per share)	$ 80.04
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)	$ 79.20
Granted (in dollars per share)	84.32
Vested (in dollars per share)	80.45
Forfeited (in dollars per share)	77.68
Non-vested at end of period (in dollars per share)	$ 80.16

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, 2022 $ / shares shares
Units
Non-vested at beginning of period (in shares) | shares	61,620
Granted (in shares) | shares	149,650
Vested (in shares) | shares	(22,450)
Forfeited (in shares) | shares	(8,232)
Non-vested at end of period (in shares) | shares	180,588
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share) | $ / shares	$ 79.68
Granted (in dollars per share) | $ / shares	86.59
Vested (in dollars per share) | $ / shares	84.81
Forfeited (in dollars per share) | $ / shares	81.51
Non-vested at end of period (in dollars per share) | $ / shares	$ 84.69
CECONY
Units
Non-vested at beginning of period (in shares) | shares	57,870
Granted (in shares) | shares	118,458
Vested (in shares) | shares	(21,200)
Forfeited (in shares) | shares	(7,713)
Non-vested at end of period (in shares) | shares	147,415
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share) | $ / shares	$ 79.70
Granted (in dollars per share) | $ / shares	87.46
Vested (in dollars per share) | $ / shares	84.81
Forfeited (in dollars per share) | $ / shares	81.54
Non-vested at end of period (in dollars per share) | $ / shares	$ 85.10

Financial Information by Busi_3

Financial Information by Business Segment (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Segment Reporting Information [Line Items]
Revenues	$ 15,670	$ 13,676	$ 12,246
Depreciation and amortization	2,056	2,032	1,920
Operating income	2,624	2,826	2,654
Other Income (deductions)	326	(538)	(401)
Interest charges	852	905	1,019
Income taxes on operating income	422	340	193
Total assets	69,065	63,116	62,895
Capital expenditures	4,465	3,964	4,085
Income tax expense (benefit) on non-operating income	76	(150)	(103)
CECONY
Segment Reporting Information [Line Items]
Revenues	13,268	11,716	10,647
Depreciation and amortization	1,778	1,705	1,598
Operating income	2,135	2,460	2,310
Other Income (deductions)	332	(108)	(171)
Total assets	57,445	52,655
Income tax expense (benefit) on non-operating income	(6)	(6)	(3)
Operating segment | Clean Energy Businesses
Segment Reporting Information [Line Items]
Revenues	1,319	1,022	736
Depreciation and amortization	178	231	231
Operating income	368	236	215
Other Income (deductions)	3	(10)	4
Interest charges	(35)	68	196
Income taxes on operating income	84	44	(43)
Total assets	7,224	6,554	6,848
Capital expenditures	399	298	616
Operating segment | Con Edison Transmission
Segment Reporting Information [Line Items]
Revenues	4	4	4
Depreciation and amortization	1	1	1
Operating income	(10)	(16)	(8)
Other Income (deductions)	19	(407)	(215)
Interest charges	5	9	18
Income taxes on operating income	1	3	0
Total assets	314	249	1,348
Capital expenditures	65	31	3
Operating segment | CECONY
Segment Reporting Information [Line Items]
Revenues	13,268	11,716	10,647
Depreciation and amortization	1,778	1,705	1,598
Operating income	2,135	2,460	2,310
Other Income (deductions)	332	(108)	(171)
Interest charges	822	762	739
Income taxes on operating income	261	252	218
Total assets	57,445	52,655	50,967
Capital expenditures	3,758	3,418	3,246
Operating segment | CECONY | Electric
Segment Reporting Information [Line Items]
Revenues	9,751	8,806	8,103
Depreciation and amortization	1,315	1,286	1,214
Operating income	1,496	1,802	1,731
Other Income (deductions)	259	(84)	(134)
Interest charges	582	542	535
Income taxes on operating income	138	151	130
Total assets	39,153	36,260	35,673
Capital expenditures	2,522	2,189	2,080
Operating segment | CECONY | Gas
Segment Reporting Information [Line Items]
Revenues	2,924	2,378	2,036
Depreciation and amortization	367	326	294
Operating income	660	646	574
Other Income (deductions)	52	(16)	(25)
Interest charges	198	179	164
Income taxes on operating income	141	110	102
Total assets	15,361	13,748	12,678
Capital expenditures	1,128	1,126	1,044
Operating segment | CECONY | Steam
Segment Reporting Information [Line Items]
Revenues	593	532	508
Depreciation and amortization	96	93	90
Operating income	(21)	12	5
Other Income (deductions)	21	(8)	(12)
Interest charges	42	41	40
Income taxes on operating income	(18)	(9)	(14)
Total assets	2,931	2,647	2,616
Capital expenditures	108	103	122
Operating segment | O&R
Segment Reporting Information [Line Items]
Revenues	1,085	941	862
Depreciation and amortization	98	95	90
Operating income	136	150	147
Other Income (deductions)	23	(12)	(14)
Interest charges	46	42	41
Income taxes on operating income	25	21	21
Total assets	3,511	3,292	3,247
Capital expenditures	243	217	220
Operating segment | O&R | Electric
Segment Reporting Information [Line Items]
Revenues	773	681	629
Depreciation and amortization	71	69	65
Operating income	94	100	99
Other Income (deductions)	17	(8)	(10)
Interest charges	29	27	26
Income taxes on operating income	17	13	13
Total assets	2,247	2,123	2,097
Capital expenditures	167	147	159
Operating segment | O&R | Gas
Segment Reporting Information [Line Items]
Revenues	312	260	233
Depreciation and amortization	27	26	25
Operating income	42	50	48
Other Income (deductions)	6	(4)	(4)
Interest charges	17	15	15
Income taxes on operating income	8	8	8
Total assets	1,264	1,169	1,150
Capital expenditures	76	70	61
Other
Segment Reporting Information [Line Items]
Revenues	(6)	(7)	(3)
Depreciation and amortization	1	0	0
Operating income	(5)	(4)	(10)
Other Income (deductions)	(51)	(1)	(5)
Interest charges	14	24	25
Income taxes on operating income	51	20	(3)
Total assets	571	366	485
Capital expenditures	0	0	0
Other | O&R
Segment Reporting Information [Line Items]
Revenues	0	0	0
Depreciation and amortization	0	0	0
Operating income	0	0	0
Other Income (deductions)	0	0	0
Interest charges	0	0	0
Income taxes on operating income	0	0	0
Total assets	0	0	0
Capital expenditures	0	0	0
Inter- segment revenues
Segment Reporting Information [Line Items]
Revenues	0	0	0
Inter- segment revenues | Clean Energy Businesses
Segment Reporting Information [Line Items]
Revenues	0	0	0
Inter- segment revenues | CECONY
Segment Reporting Information [Line Items]
Revenues	(103)	(100)	(99)
Inter- segment revenues | CECONY | Electric
Segment Reporting Information [Line Items]
Revenues	19	18	18
Inter- segment revenues | CECONY | Gas
Segment Reporting Information [Line Items]
Revenues	8	8	7
Inter- segment revenues | CECONY | Steam
Segment Reporting Information [Line Items]
Revenues	$ 76	$ 74	$ 74

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities - Fair Values of Commodity Derivatives Including Offsetting of Assets and Liabilities (Details) - USD ($)	Dec. 31, 2022	Dec. 31, 2021
Net fair value derivative assets/(liabilities)
Gross Amounts of Recognized Assets/ (Liabilities)	$ 466,000,000	$ (8,000,000)
Gross Amounts Offset	(237,000,000)	(24,000,000)
Net Amounts of Assets/ (Liabilities)	229,000,000	(32,000,000)
Fair value of derivative assets	85,000,000	77,000,000
CECONY
Net fair value derivative assets/(liabilities)
Gross Amounts of Recognized Assets/ (Liabilities)	294,000,000	25,000,000
Gross Amounts Offset	(214,000,000)	(26,000,000)
Net Amounts of Assets/ (Liabilities)	80,000,000	(1,000,000)
Fair value of derivative assets	80,000,000	56,000,000
Clean Energy Businesses | Interest Rate Swap
Net fair value derivative assets/(liabilities)
Notional amount	982,000,000	1,031,000,000
Fair Value of Derivative Liabilities, Current
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(198,000,000)	(289,000,000)
Gross Amounts Offset	166,000,000	137,000,000
Net Amounts of Assets/ (Liabilities)	(32,000,000)	(152,000,000)
Fair Value of Derivative Liabilities, Current | Interest Rate Swap
Fair value of derivative liabilities
Net Amounts of Assets/ (Liabilities)		(20,000,000)
Fair Value of Derivative Liabilities, Current | CECONY
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(189,000,000)	(131,000,000)
Gross Amounts Offset	160,000,000	43,000,000
Net Amounts of Assets/ (Liabilities)	(29,000,000)	(88,000,000)
Fair Value of Derivative Liabilities, Non-current
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(49,000,000)	(94,000,000)
Gross Amounts Offset	36,000,000	10,000,000
Net Amounts of Assets/ (Liabilities)	(13,000,000)	(84,000,000)
Fair Value of Derivative Liabilities, Non-current | Interest Rate Swap
Fair value of derivative liabilities
Net Amounts of Assets/ (Liabilities)		(38,000,000)
Fair Value of Derivative Liabilities, Non-current | CECONY
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(43,000,000)	(50,000,000)
Gross Amounts Offset	34,000,000	10,000,000
Net Amounts of Assets/ (Liabilities)	(9,000,000)	(40,000,000)
Fair Value of Derivative Liabilities, Held and Used Liabilities
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(247,000,000)	(383,000,000)
Gross Amounts Offset	202,000,000	147,000,000
Net Amounts of Assets/ (Liabilities)	(45,000,000)	(236,000,000)
Fair Value of Derivative Liabilities, Held for Sale Liabilities, Current
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(31,000,000)	0
Gross Amounts Offset	6,000,000	0
Net Amounts of Assets/ (Liabilities)	(25,000,000)	0
Fair Value of Derivative Liabilities, Held for Sale Liabilities, Non-Current
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(3,000,000)	0
Gross Amounts Offset	(8,000,000)	0
Net Amounts of Assets/ (Liabilities)	(11,000,000)	0
Fair Value of Derivative Liabilities
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(281,000,000)	(383,000,000)
Gross Amounts Offset	200,000,000	147,000,000
Net Amounts of Assets/ (Liabilities)	(81,000,000)	(236,000,000)
Net fair value derivative assets/(liabilities)
Margin deposit liability	(10,000,000)
Fair Value of Derivative Liabilities | CECONY
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(232,000,000)	(181,000,000)
Gross Amounts Offset	194,000,000	53,000,000
Net Amounts of Assets/ (Liabilities)	(38,000,000)	(128,000,000)
Net fair value derivative assets/(liabilities)
Margin deposit liability	(6,000,000)
Fair Value of Derivative Assets, Current
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	378,000,000	285,000,000
Gross Amounts Offset	(332,000,000)	(158,000,000)
Net Amounts of Assets/ (Liabilities)	46,000,000	127,000,000
Fair Value of Derivative Assets, Current | CECONY
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	350,000,000	135,000,000
Gross Amounts Offset	(312,000,000)	(64,000,000)
Net Amounts of Assets/ (Liabilities)	38,000,000	71,000,000
Fair Value of Derivative Assets, Non-current
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	193,000,000	90,000,000
Gross Amounts Offset	(108,000,000)	(13,000,000)
Net Amounts of Assets/ (Liabilities)	85,000,000	77,000,000
Fair Value of Derivative Assets, Non-current | Interest Rate Swap
Fair value of derivative assets
Net Amounts of Assets/ (Liabilities)		4,000,000
Net fair value derivative assets/(liabilities)
Fair value of derivative assets	75,000,000
Fair Value of Derivative Assets, Non-current | CECONY
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	176,000,000	71,000,000
Gross Amounts Offset	(96,000,000)	(15,000,000)
Net Amounts of Assets/ (Liabilities)	80,000,000	56,000,000
Fair Value of Derivative Assets, Held and Used Assets
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	571,000,000	375,000,000
Gross Amounts Offset	(440,000,000)	(171,000,000)
Net Amounts of Assets/ (Liabilities)	131,000,000	204,000,000
Fair Value of Derivative Assets, Held-For-Sale Assets, Current
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	93,000,000	0
Gross Amounts Offset	(8,000,000)	0
Net Amounts of Assets/ (Liabilities)	85,000,000	0
Fair Value of Derivative Assets, Held-For Sale Assets, Non-Current
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	83,000,000	0
Gross Amounts Offset	11,000,000	0
Net Amounts of Assets/ (Liabilities)	94,000,000	0
Fair Value of Derivative Assets
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	747,000,000	375,000,000
Gross Amounts Offset	(437,000,000)	(171,000,000)
Net Amounts of Assets/ (Liabilities)	310,000,000	204,000,000
Net fair value derivative assets/(liabilities)
Margin deposits	13,000,000	1,000,000
Fair Value of Derivative Assets | Interest Rate Swap
Net fair value derivative assets/(liabilities)
Fair value of derivative assets	31,000,000
Fair Value of Derivative Assets | CECONY
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	526,000,000	206,000,000
Gross Amounts Offset	(408,000,000)	(79,000,000)
Net Amounts of Assets/ (Liabilities)	118,000,000	127,000,000
Net fair value derivative assets/(liabilities)
Margin deposits	$ 13,000,000	$ 0

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, 2022	Dec. 31, 2021
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	$ 251	$ 191
Total deferred gains/(losses)	384	122
Net deferred gains/(losses)	635	313
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	$ 168	$ 78
Gas purchased for resale
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 gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	$ 5	$ 18
Other operations and maintenance expense
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 gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	$ 4	$ 5
Interest Expense (Income), Other, Net
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	Other interest
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	$ 159	$ 52
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 gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	$ 0	$ 3
Deferred Derivative Gains,Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	168	134
Deferred Derivative Gains, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	83	57
Deferred Derivative Losses, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(43)	49
Recoverable Energy Costs, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	408	3
Deferred Derivative Losses, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	19	70
CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	230	175
Total deferred gains/(losses)	347	109
Net deferred gains/(losses)	577	284
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	$ 4	$ 5
CECONY | Gas purchased for resale
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 gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	$ 0	$ 0
CECONY | Other operations and maintenance expense
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 gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	$ 4	$ 5
CECONY | Interest Expense (Income), Other, Net
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	Other interest
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	$ 0	$ 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 gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	$ 0	$ 0
CECONY | Deferred Derivative Gains,Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	155	124
CECONY | Deferred Derivative Gains, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	75	51
CECONY | Deferred Derivative Losses, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(44)	43
CECONY | Recoverable Energy Costs, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	372	0
CECONY | Deferred Derivative Losses, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	$ 19	$ 66

Derivative Instruments and He_5

Derivative Instruments and Hedging Activities - Hedged Volume of Derivative Transactions (Details)	Dec. 31, 2022 gal MMBTU MWh MW
Electric Energy
Derivatives, Fair Value [Line Items]
Notional amount | MWh	33,546,670
Capacity
Derivatives, Fair Value [Line Items]
Notional amount | MW	46,116
Natural Gas
Derivatives, Fair Value [Line Items]
Notional amount | MMBTU	290,398,144
Refined Fuels
Derivatives, Fair Value [Line Items]
Notional amount | gal	168,000
CECONY | Electric Energy
Derivatives, Fair Value [Line Items]
Notional amount | MWh	31,567,400
CECONY | Capacity
Derivatives, Fair Value [Line Items]
Notional amount | MW	30,675
CECONY | Natural Gas
Derivatives, Fair Value [Line Items]
Notional amount | MMBTU	272,790,000
CECONY | Refined Fuels
Derivatives, Fair Value [Line Items]
Notional amount | gal	168,000
Clean Energy Businesses | Electric Energy
Derivatives, Fair Value [Line Items]
Notional amount | MWh	240
Clean Energy Businesses | Capacity
Derivatives, Fair Value [Line Items]
Notional amount | MW	8,616
Clean Energy Businesses | Natural Gas
Derivatives, Fair Value [Line Items]
Notional amount | MMBTU	3,518,144

Derivative Instruments and He_6

Derivative Instruments and Hedging Activities - Additional Information (Details) $ in Millions	12 Months Ended
	Dec. 31, 2022 USD ($)
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	$ 703
Makeup of net credit exposure independent system operators	174
Makeup of net credit exposure with investment-grade counterparties	353
Makeup of net credit exposure non-investment grade/non-rated counterparties	41
Makeup of net credit exposure with commodity exchange brokers	133
CECONY
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	357
Makeup of net credit exposure with investment-grade counterparties	274
Makeup of net credit exposure with commodity exchange brokers	83
Clean Energy Businesses
Investment Holdings [Line Items]
Makeup of net credit exposure with investment-grade counterparties	50
Makeup of net credit exposure with commodity exchange brokers	$ 50

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, 2022 USD ($)
Derivatives, Fair Value [Line Items]
Aggregate fair value – net liabilities	$ 157
Collateral posted	70
Downgrade One Level from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	65
Downgrade to Below Investment Grade from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	138
Derivatives in net asset position additional collateral	9
Additional Collateral Required Due To Loss Of Unsecured Credit
Derivatives, Fair Value [Line Items]
Collateral posted	115
CECONY
Derivatives, Fair Value [Line Items]
Aggregate fair value – net liabilities	86
Collateral posted	70
CECONY | Downgrade One Level from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	15
CECONY | Downgrade to Below Investment Grade from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	$ 67

Fair Value Measurements - Asset

Fair Value Measurements - Assets and Liabilities Measured at Fair Value on Recurring Basis (Details) - USD ($)	9 Months Ended	12 Months Ended
	Sep. 30, 2021	Dec. 31, 2022	Dec. 31, 2021
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
Derivative Liability, Statement of Financial Position [Extensible Enumeration]		Liabilities, Current	Liabilities, Current
Derivative liabilities transferred from Level 3 to Level 2		$ 0
Minimum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Term of contract (in years)	3 years	3 years
Maximum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Term of contract (in years)		3 years	3 years
CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities transferred from Level 3 to Level 2		$ 0
Level 3 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		(6,000,000)
Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities transferred from Level 3 to Level 2			$ 4,000,000
Derivative assets transferred out of level 3		10,000,000
Commodity | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities transferred from Level 3 to Level 2			3,000,000
Derivative assets transferred out of level 3		9,000,000	1,000,000
Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		874,000,000	832,000,000
Derivative liabilities		90,000,000	236,000,000
Recurring | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		663,000,000	728,000,000
Recurring | Netting Adjustment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		(418,000,000)	(171,000,000)
Derivative liabilities		(182,000,000)	(148,000,000)
Recurring | Netting Adjustment | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		(388,000,000)	(79,000,000)
Recurring | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		527,000,000	587,000,000
Derivative liabilities		26,000,000	33,000,000
Recurring | Level 1 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		505,000,000	541,000,000
Recurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		732,000,000	399,000,000
Derivative liabilities		228,000,000	323,000,000
Recurring | Level 2 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		544,000,000	265,000,000
Recurring | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		33,000,000	17,000,000
Derivative liabilities		18,000,000	28,000,000
Recurring | Level 3 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		2,000,000	1,000,000
Recurring | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		142,000,000	201,000,000
Derivative liabilities		54,000,000	179,000,000
Recurring | Commodity | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		131,000,000	127,000,000
Derivative liabilities		44,000,000	128,000,000
Recurring | Commodity | Netting Adjustment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		(420,000,000)	(171,000,000)
Derivative liabilities		(184,000,000)	(148,000,000)
Recurring | Commodity | Netting Adjustment | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		(388,000,000)	(79,000,000)
Derivative liabilities		(180,000,000)	(53,000,000)
Recurring | Commodity | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		84,000,000	95,000,000
Derivative liabilities		18,000,000	33,000,000
Recurring | Commodity | Level 1 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		83,000,000	67,000,000
Derivative liabilities		18,000,000	1,000,000
Recurring | Commodity | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		476,000,000	260,000,000
Derivative liabilities		204,000,000	266,000,000
Recurring | Commodity | Level 2 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		434,000,000	138,000,000
Derivative liabilities		198,000,000	172,000,000
Recurring | Commodity | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		2,000,000	17,000,000
Derivative liabilities		16,000,000	28,000,000
Recurring | Commodity | Level 3 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		2,000,000	1,000,000
Derivative liabilities		8,000,000	8,000,000
Recurring | Commodity held for sale
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		73,000,000
Derivative liabilities		36,000,000
Recurring | Commodity held for sale | Netting Adjustment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		2,000,000
Derivative liabilities		2,000,000
Recurring | Commodity held for sale | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		6,000,000
Derivative liabilities		8,000,000
Recurring | Commodity held for sale | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		34,000,000
Derivative liabilities		24,000,000
Recurring | Commodity held for sale | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		31,000,000
Derivative liabilities		2,000,000
Recurring | Interest Rate Swaps
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		106,000,000	4,000,000
Derivative liabilities			57,000,000
Recurring | Interest Rate Swaps | Netting Adjustment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities		0	0
Recurring | Interest Rate Swaps | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities		0	0
Recurring | Interest Rate Swaps | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		106,000,000	4,000,000
Derivative liabilities			57,000,000
Recurring | Interest Rate Swaps | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities		0	0
Recurring | Other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		553,000,000	627,000,000
Recurring | Other | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		532,000,000	601,000,000
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 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		437,000,000	492,000,000
Recurring | Other | Level 1 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		422,000,000	474,000,000
Recurring | Other | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		116,000,000	135,000,000
Recurring | Other | Level 2 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		110,000,000	127,000,000
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, 2022 USD ($) $ / MWh $ / kW-month
CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ (6)
Electricity - Held and Used | Forward Capacity Prices
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	(15)
Electricity - Held and Used | Forward Capacity Prices | CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ (7)
Electricity - Held and Used | Forward Capacity Prices | Minimum | CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / kW-month	1.42
Electricity - Held and Used | Forward Capacity Prices | Maximum | CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / kW-month	16.08
Transmission Congestion Contracts/Financial Transmission Rights - Held and Used | Inter-Zonal Forward Price Curves
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ 1
Transmission Congestion Contracts/Financial Transmission Rights - Held and Used | Inter-Zonal Forward Price Curves | Minimum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / MWh	0.91
Transmission Congestion Contracts/Financial Transmission Rights - Held and Used | Inter-Zonal Forward Price Curves | Maximum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / MWh	3.03
Total Con Edison - Commodity - Held and Used
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ (14)
Electricity - Held for Sale | Forward Energy Prices
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	14
Electricity - Held for Sale | Forward Capacity Prices
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	10
Transmission Congestion Contracts/Financial Transmission Rights - Held for Sale | Inter-Zonal Forward Price Curves
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	4
Natural Gas - Held for Sale | Forward Natural Gas Price
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	1
Commodity Contract, Held For Sale
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	29
Commodity Contract
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	15
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 | CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / MWh	0.91
Transmission Congestion Contracts | Inter-Zonal Forward Price Curves | Maximum | CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / MWh	3.03

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, 2022	Dec. 31, 2021
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning Balance	$ (11)	$ (19)
Included in earnings	(11)	(9)
Included in regulatory assets and liabilities	11	3
Purchases	0	6
Settlements	11	5
Changes in level 3 assets and liabilities held for sale	25	0
Transfer out of level 3	(10)	3
Ending Balance	15	(11)
CECONY
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning Balance	(7)	(10)
Included in earnings	(5)	(3)
Included in regulatory assets and liabilities	10	1
Purchases	0	0
Settlements	5	3
Changes in level 3 assets and liabilities held for sale	0	0
Transfer out of level 3	(9)	2
Ending Balance	$ (6)	$ (7)

Fair Value Measurements - Addit

Fair Value Measurements - Additional Information (Details) - Clean Energy Businesses - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Gain (loss) on Level 3 energy derivative assets and liabilities	$ 26	$ (2)
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) - Clean Energy Businesses - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Jun. 30, 2021
Variable Interest Entity [Line Items]
Equity method investment			$ 11
Loss from the project, pre-tax		$ 11
Loss from the project, after-tax		$ 8
Tax Equity Projects | Con Edison | Variable Interest Entity, Primary Beneficiary
Variable Interest Entity [Line Items]
Percentage of variable interests (less than)	100%
CED Nevada Virginia | Con Edison | Variable Interest Entity, Primary Beneficiary
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 - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
CED Nevada Virginia | Tax equity investor
Schedule of Equity Method Investments [Line Items]
Income (loss)	$ (49)	$ (158)
Net income (loss)	(37)	(119)
CED Nevada Virginia | Con Edison
Schedule of Equity Method Investments [Line Items]
Income (loss)	41	155
Net income (loss)	31	117
Tax Equity Projects | Tax equity investor
Schedule of Equity Method Investments [Line Items]
Income (loss)	(11)	6
Net income (loss)	(8)	4
Tax Equity Projects | Con Edison
Schedule of Equity Method Investments [Line Items]
Income (loss)	51	30
Net income (loss)	$ 38	$ 24

Variable Interest Entities - Ne

Variable Interest Entities - Net Assets (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Business Acquisition [Line Items]
Noncontrolling interest	$ 202	$ 299
Great Valley Solar
Business Acquisition [Line Items]
Assets held for sale	305	0
Non-utility property, less accumulated depreciation	0	275
Other assets	0	37
Total assets	305	312
Liabilities held for sale	20	0
Other liabilities	0	14
Total liabilities	20	14
Accumulated depreciation	35	26
Copper Mountain Solar - Mesquite Solar
Business Acquisition [Line Items]
Assets held for sale	580	0
Non-utility property, less accumulated depreciation	0	431
Other assets	0	167
Total assets	580	598
Liabilities held for sale	81	0
Other liabilities	0	74
Total liabilities	81	74
Accumulated depreciation	59	44
CED Nevada Virginia
Business Acquisition [Line Items]
Assets held for sale	686	0
Non-utility property, less accumulated depreciation	0	643
Other assets	0	55
Total assets	686	698
Liabilities held for sale	331	0
Other liabilities	0	315
Total liabilities	331	315
Accumulated depreciation	29	10
Tax equity investor
Business Acquisition [Line Items]
Noncontrolling interest	39	95
Tax equity investor | Great Valley Solar
Business Acquisition [Line Items]
Noncontrolling interest	67	84
Tax equity investor | Copper Mountain Solar - Mesquite Solar
Business Acquisition [Line Items]
Noncontrolling interest	$ 94	$ 118

Variable Interest Entities - Su

Variable Interest Entities - Summary of VIEs (Details) - Variable Interest Entity, Not Primary Beneficiary $ in Millions	12 Months Ended
	Dec. 31, 2022 USD ($) MW
Great Valley Solar
Variable Interest Entity [Line Items]
Generating Capacity Owned (MW AC) | MW	200
Maximum Exposure to Loss | $	$ 218
Great Valley Solar | Minimum
Variable Interest Entity [Line Items]
Power Purchase Agreement Term in Years	15 years
Great Valley Solar | Maximum
Variable Interest Entity [Line Items]
Power Purchase Agreement Term in Years	20 years
Copper Mountain Solar - Mesquite Solar
Variable Interest Entity [Line Items]
Generating Capacity Owned (MW AC) | MW	344
Maximum Exposure to Loss | $	$ 404
Copper Mountain Solar - Mesquite Solar | Minimum
Variable Interest Entity [Line Items]
Power Purchase Agreement Term in Years	20 years
Copper Mountain Solar - Mesquite Solar | Maximum
Variable Interest Entity [Line Items]
Power Purchase Agreement Term in Years	25 years
CED Nevada Virginia
Variable Interest Entity [Line Items]
Generating Capacity Owned (MW AC) | MW	431
Maximum Exposure to Loss | $	$ 316
CED Nevada Virginia | Minimum
Variable Interest Entity [Line Items]
Power Purchase Agreement Term in Years	20 years
CED Nevada Virginia | Maximum
Variable Interest Entity [Line Items]
Power Purchase Agreement Term in Years	25 years

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance as of January 1,	$ 577	$ 577
Less ARO held for sale	(77)	0
Changes in estimated cash flows	44	58
Accretion expense	18	18
Liabilities settled	(62)	(75)
Ending Balance as of December 31,	500	577
Asset Retirement Obligation, Period Increase (Decrease)	78	87
CECONY
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance as of January 1,	504	508
Less ARO held for sale	0	0
Changes in estimated cash flows	43	55
Accretion expense	14	15
Liabilities settled	(62)	(74)
Ending Balance as of December 31,	499	504
Asset Retirement Obligation, Period Increase (Decrease)	$ 77	$ 85

Related Party Transactions - Ad

Related Party Transactions - Additional Information (Details) MMBTU in Thousands	12 Months Ended
	Dec. 31, 2022 USD ($) MMBTU	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)
Related Party Transaction [Line Items]
Net assets	$ 20,687,000,000	$ 20,037,000,000
CECONY
Related Party Transaction [Line Items]
Net assets	16,878,000,000	16,312,000,000	$ 14,849,000,000	$ 14,147,000,000
Sale of natural gas	144,000,000	90,000,000	59,000,000
Tax expense due to affiliates	89,000,000	10,000,000
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]
Amount of transaction	$ 0	0
Contract term (years)	20 years
Generating capacity per day (in dekatherms) | MMBTU	250
CECONY | Equity Method Investee | Stagecoach | Purchased Power Costs
Related Party Transaction [Line Items]
Amount of transaction		$ 31,000,000	$ 34,000,000
Percentage of equity interest owned		50%
CECONY | Affiliated Entity | Financial Electric Capacity Contract | Con Edison Energy
Related Party Transaction [Line Items]
Gain (loss) on financial electric capacity contracts	$ 5,000,000	$ (4,000,000)
O&R
Related Party Transaction [Line Items]
Net assets	931,000,000
Outstanding loans	$ 0	0
CET Electric | NY Transco
Related Party Transaction [Line Items]
Ownership interest, percentage	45.70%
Amounts billed	$ 8,000,000	$ 5,900,000
CET Gas | Mountain Valley Pipeline
Related Party Transaction [Line Items]
Percentage of equity interest owned	9.60%	10.20%	11.30%
Expected reduction in equity interest	8%

Related Party Transactions - Su

Related Party Transactions - Summary of Costs of Administrative and Other Services Provided and Received (Details) - CECONY - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Related Party Transaction [Line Items]
Cost of services provided	$ 135	$ 137	$ 128
Cost of services received	$ 75	$ 68	$ 66

Dispositions (Details)

Dispositions (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	May 31, 2021	Dec. 31, 2022	Jun. 30, 2022	Dec. 31, 2021	Jun. 30, 2021	Mar. 31, 2021
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Carrying value of projects sold		$ 46,752		$ 44,214
Stagecoach
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Equity method investment					$ 630	$ 667
Clean Energy Businesses | Subsidiaries
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Carrying value of projects sold			$ 192
Gain (loss) on sale of projects		3
Gain on sale, after tax		2
Equity method investment		11
Con Edison Transmission | Subsidiaries | Stagecoach
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale	$ 1,225
Percentage of equity interest acquired (in percent)	50%			50%
CECONY
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Carrying value of projects sold		$ 44,009		$ 41,611
CECONY | Stagecoach | Purchased Power Costs | Equity Method Investee
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Percentage of equity interest acquired (in percent)				50%

Held-for-Sale Treatment of th_3

Held-for-Sale Treatment of the Clean Energy Businesses - Additional Information (Details) $ in Millions	3 Months Ended	7 Months Ended	12 Months Ended
	Dec. 31, 2022 USD ($) solarProject	Dec. 31, 2021	Dec. 31, 2022 USD ($) solarProject	Oct. 01, 2022 USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Number of solar projects | solarProject	2		2
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				$ 6,800
Depreciation and amortization, before tax	$ 61		$ 70
Depreciation and amortization, after tax	42		49
Disposal group, deferred tax liabilities	111		111
Disposal group, valuation allowance	10		$ 10
Disposal group, deferred income taxes	$ 121
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

Held-for-Sale Treatment of th_4

Held-for-Sale Treatment of the Clean Energy Businesses - Schedule of Pre-Tax Profit (Details) - Clean Energy Businesses - Disposal Group, Held-for-sale, Not Discontinued Operations - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Pre-tax operating income	$ 466	$ 310	$ 68
Pre-tax operating income, excluding non-controlling interest	$ 406	$ 158	$ 23

Held-for-Sale Treatment of th_5

Held-for-Sale Treatment of the Clean Energy Businesses - Schedule of Carrying Amounts (Details) - USD ($) $ in Millions	Dec. 31, 2022	Sep. 30, 2022	Dec. 31, 2021
CURRENT ASSETS
TOTAL CURRENT ASSETS	$ 7,162		$ 0
CURRENT LIABILITIES
TOTAL CURRENT LIABILITIES	3,610		$ 0
Disposal Group, Held-for-sale, Not Discontinued Operations | Clean Energy Businesses
CURRENT ASSETS
Cash and temporary cash investments	25
Accounts receivable and other receivables - net allowance for uncollectible accounts	319
Accrued unbilled revenue	51
Fuel oil, gas in storage, materials and supplies, at average cost	56
Restricted cash	223
Fair value of derivatives assets	84
Prepayments	35
Other current assets	24
TOTAL CURRENT ASSETS	817
Non-utility property, net accumulated depreciation	4,197
Construction work in progress	522
NET PLANT	4,719
OTHER NONCURRENT ASSETS
Goodwill	31
Intangible assets, less accumulated amortization	1,222
Operating lease right-of-use asset	266
Fair value of derivatives assets	93
Other deferred charges and noncurrent assets	14
TOTAL OTHER NONCURRENT ASSETS	1,626
TOTAL ASSETS		$ 7,162
CURRENT LIABILITIES
Long-term debt due within one year	353
Term loan	150
Accounts payable	326
Operating lease liabilities	33
Accrued Interest	40
Other current liabilities	71
TOTAL CURRENT LIABILITIES	973
NONCURRENT LIABILITIES
Asset retirement obligations	77
Operating lease liabilities	248
Other deferred credits and noncurrent liabilities	20
TOTAL NONCURRENT LIABILITIES	345
LONG-TERM DEBT	2,292
TOTAL LIABILITIES	3,610
Disposal Group, Held-for-sale, Not Discontinued Operations | Clean Energy Businesses | Consolidation, Eliminations
OTHER NONCURRENT ASSETS
Fair value of derivatives assets	$ 2

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, 2022	Dec. 31, 2021	Dec. 31, 2020
Condensed Income Statements,Captions [Line Items]
Taxes, other than income taxes	$ (3,005)	$ (2,810)	$ (2,575)
Interest expense	(852)	(905)	(1,019)
Income tax expense (benefit)	(498)	(190)	(90)
NET INCOME	1,660	1,346	1,101
Comprehensive Income	$ 1,677	$ 1,376	$ 1,095
Net Income Per Share – Basic (in dollars per share)	$ 4.68	$ 3.86	$ 3.29
Net Income Per Share – Diluted (in dollars per share)	$ 4.66	$ 3.85	$ 3.28
Average Number Of Shares Outstanding—Basic (in shares)	354.5	348.4	334.8
Average Number Of Shares Outstanding—Diluted (in shares)	355.8	349.4	335.7
Parent Company
Condensed Income Statements,Captions [Line Items]
Equity in earnings of subsidiaries	$ 1,860	$ 1,369	$ 1,105
Other operating and maintenance expenses	(1)	(1)	(1)
Taxes, other than income taxes	(7)	(6)	(12)
Other income (deductions)	(31)	14	33
Interest expense	(32)	(37)	(60)
Income tax expense (benefit)	(129)	7	36
NET INCOME	1,660	1,346	1,101
Comprehensive Income	$ 1,677	$ 1,376	$ 1,095
Net Income Per Share – Basic (in dollars per share)	$ 4.68	$ 3.86	$ 3.29
Net Income Per Share – Diluted (in dollars per share)	4.66	3.85	3.28
Dividends Declared Per Share (in dollars per share)	$ 3.16	$ 3.10	$ 3.06
Average Number Of Shares Outstanding—Basic (in shares)	354.5	348.4	334.8
Average Number Of Shares Outstanding—Diluted (in shares)	355.8	349.4	335.7

Schedule I - Condensed Financ_3

Schedule I - Condensed Financial Information - Cash Flows (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Condensed Cash Flow Statements, Captions [Line Items]
Net Income		$ 1,660	$ 1,346	$ 1,101
Deferred income taxes	$ 121	435	133	85
Change in Assets and Liabilities:
Other – net (b)		31	(234)	(179)
NET CASH FLOWS FROM OPERATING ACTIVITIES		3,935	2,733	2,198
INVESTING ACTIVITIES
NET CASH FLOWS USED IN INVESTING ACTIVITIES		(4,565)	(3,484)	(4,224)
FINANCING ACTIVITIES
Net proceeds of short-term debt		1,702	(382)	178
Issuance of long-term debt		800	2,804	2,925
Retirement of long-term debt		(406)	(1,960)	(518)
Debt issuance costs		(13)	(40)	(47)
Issuance of common shares for stock plans		57	60	58
Issuance of common shares - public offering		0	775	640
Common stock dividends		(1,089)	(1,030)	(975)
NET CASH FLOWS FROM FINANCING ACTIVITIES		1,014	461	2,245
NET CHANGE FOR THE PERIOD		384	(290)	219
BALANCE AT BEGINNING OF PERIOD		1,146	1,436	1,217
BALANCE AT END OF PERIOD	1,530	1,530	1,146	1,436
CECONY
Condensed Cash Flow Statements, Captions [Line Items]
Net Income		1,390	1,344	1,185
Deferred income taxes		85	124	168
Change in Assets and Liabilities:
Accounts receivable from affiliated companies		8	(96)	61
Accrued taxes to affiliated companies		79	9	1
Accounts payable to affiliated companies		(1)	(4)	9
Other – net (b)		56	(354)	(98)
NET CASH FLOWS FROM OPERATING ACTIVITIES		3,263	2,186	1,693
INVESTING ACTIVITIES
NET CASH FLOWS USED IN INVESTING ACTIVITIES		(3,926)	(3,729)	(3,416)
FINANCING ACTIVITIES
Net proceeds of short-term debt		939	(299)	523
Issuance of long-term debt		700	2,250	2,200
Retirement of long-term debt		0	(640)	(350)
Debt issuance costs		(12)	(27)	(34)
NET CASH FLOWS FROM FINANCING ACTIVITIES		799	1,396	1,857
NET CHANGE FOR THE PERIOD		136	(147)	134
BALANCE AT BEGINNING OF PERIOD		920	1,067	933
BALANCE AT END OF PERIOD	1,056	1,056	920	1,067
Parent Company
Condensed Cash Flow Statements, Captions [Line Items]
Net Income		1,660	1,346	1,101
Equity in earnings of subsidiaries		(1,860)	(1,369)	(1,105)
Deferred income taxes		163	119	32
Change in Assets and Liabilities:
Accounts receivable from affiliated companies		(138)	57	(386)
Accrued taxes to affiliated companies		(1)	(1)	(78)
Accounts payable to affiliated companies		1	1	0
Other – net (b)		56	50	(89)
NET CASH FLOWS FROM OPERATING ACTIVITIES		1,015	1,459	538
INVESTING ACTIVITIES
Contributions to subsidiaries		(150)	(1,135)	(626)
Debt receivable from affiliated companies		0	875	400
NET CASH FLOWS USED IN INVESTING ACTIVITIES		(150)	(260)	(226)
FINANCING ACTIVITIES
Net proceeds of short-term debt		632	50	(537)
Issuance of long-term debt		0	0	650
Retirement of long-term debt		(293)	(1,178)	(3)
Debt issuance costs		0	(1)	(3)
Issuance of common shares for stock plans		57	60	58
Issuance of common shares - public offering		0	775	640
Common stock dividends		(1,089)	(1,030)	(975)
NET CASH FLOWS FROM FINANCING ACTIVITIES		(693)	(1,324)	(170)
NET CHANGE FOR THE PERIOD		172	(125)	142
BALANCE AT BEGINNING OF PERIOD		19	144	2
BALANCE AT END OF PERIOD	$ 191	191	19	144
Parent Company | Revision of Prior Period, Adjustment
FINANCING ACTIVITIES
Retirement of long-term debt			(1,175)
Parent Company | CECONY
Condensed Cash Flow Statements, Captions [Line Items]
Dividends received		978	988	982
Parent Company | O&R
Condensed Cash Flow Statements, Captions [Line Items]
Dividends received		57	52	49
Parent Company | Clean Energy Businesses
Condensed Cash Flow Statements, Captions [Line Items]
Dividends received		98	64	21
Parent Company | Con Edison Transmission
Condensed Cash Flow Statements, Captions [Line Items]
Dividends received		$ 1	$ 152	$ 11

Schedule I - Condensed Financ_4

Schedule I - Condensed Financial Information - Balance Sheet (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Current Assets
Cash and temporary cash investments	$ 1,282	$ 992
Taxes receivable	10	13
Prepayments	264	295
Other current assets	176	233
TOTAL CURRENT ASSETS	12,972	5,551
Investments in subsidiaries and others	841	853
Goodwill	408	439
Pension and retiree benefits - asset	3,269	1,654
Other deferred charges and noncurrent assets	8,486	8,116
TOTAL ASSETS	69,065	63,116	$ 62,895
Current Liabilities
Long-term debt due within one year	1,002	440
Term Loan	400	0
Notes payable	2,640	1,488
Accounts payable	1,955	1,497
Accrued taxes	102	104
Accrued interest	153	151
Other current liabilities	444	461
TOTAL CURRENT LIABILITIES	11,336	5,427
Long-term debt	22,439	22,604
Shareholders’ Equity
Equity	20,687	20,037
TOTAL LIABILITIES AND EQUITY	69,065	63,116
Parent Company
Current Assets
Cash and temporary cash investments	191	19
Other receivables, net allowance for uncollectible accounts	4	0
Taxes receivable	5	3
Accounts receivable from affiliated companies	1,337	1,199
Prepayments	9	28
Other current assets	32	14
TOTAL CURRENT ASSETS	1,578	1,263
Investments in subsidiaries and others	20,839	19,951
Goodwill	406	406
Pension and retiree benefits - asset	5	0
Other deferred charges and noncurrent assets	2	8
TOTAL ASSETS	22,830	21,628
Current Liabilities
Long-term debt due within one year	649	293
Term Loan	400	0
Notes payable	282	50
Accounts payable	39	1
Accounts payable to affiliated companies	11	10
Accrued taxes	7	2
Accrued taxes to affiliated companies	506	507
Accrued interest	7	2
Other current liabilities	7	7
TOTAL CURRENT LIABILITIES	1,908	872
Deferred income taxes and unamortized investment tax credits	235	72
Total Liabilities	2,143	1,591
Long-term debt	0	647
Shareholders’ Equity
Common stock, including additional paid-in capital	9,840	9,748
Retained earnings	10,847	10,289
Equity	20,687	20,037
TOTAL LIABILITIES AND EQUITY	$ 22,830	$ 21,628

Schedule II - Valuation and Q_2

Schedule II - Valuation and Qualifying Accounts (Details) - Allowance For Uncollectible Accounts - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Period	$ 339	$ 154	$ 74
Charged To Costs And Expenses	78	83	72
Charged To Other Accounts	80	0	0
Deductions	(165)	102	8
Balance At End of Period	332	339	154
CECONY
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Period	323	143	68
Charged To Costs And Expenses	74	78	65
Charged To Other Accounts	80	0	0
Deductions	(156)	102	10
Balance At End of Period	$ 321	$ 323	$ 143